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209-105
. • 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. Qq - log Well History File Identifier Organizing (done) El Two - sided 1 I III ❑ Rescan Needed 11111111 11111 RE AN DIGITAL DATA OVERSIZED (Scannable) C • for Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: 1 ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner or Quality Originals: , por OVERSIZED (Non - Scannable) Other: ❑ Logs of various kinds: NOTES: ❑ Other:: If P BY: Date: 1/31/1/ /s/ Project Proofing 1111111 MI ! g BY: Maria Date: V I r f tsl ne Scanning Preparation l x 3 = 0 + / d� = TOTAL PAGES ' c� (Count does not include cover sheet)' J3 BY: (Maria Date: f 31 11 /s/ r rr f) Production Scanning II I Stage 1 Page Count from Scanned File: 14z (Count does include cover eet) Matches Number in Scanning reparation: Count Matc g aration: YES NO p BY: igs, Date: i 3 f I I /s/ V14 p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11 1111111 III ReScanned I 4111111ln BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111111111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091050 Well Name /No. KUPARUK RIV UNIT 3H -33AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -61 -00 MD 9382 TVD 6188 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: none (data taken from Logs Portion of Master Well Data Maint • Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED C Lis 19147 "Induction /Resistivity 7529 9382 Open 1/13/2010 MPR plus logs in CGm, EMF and TIFF graphics og Induction /Resistivity 5 Col 7665 9382 Open 1/13/2010 MD MPR, GR og Induction /Resistivity 2 Col 7665 9382 Open 1/13/2010 MD MPR, GR • og Induction/Resistivity 7665 9382 Open 1/13/2010 TVD MPR, GR g y 5 Col 665 p , 'D ' C Asc Directional Survey 40 9382 Open 'pt Directional Survey 40 9382 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /) Daily History Received? `A Chips Received? Y-4-N— Formation Tops (/ N Analysis Y / N Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091050 Well Name /No. KUPARUK RIV UNIT 3H -33AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -61 -00 MD 9382 TVD 6188 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: Date: S J &A I • • . 0 ,-,,,,,.., ,., i.,, ,,,, , - ,;,. pp r- . T.7 . in F -F ..1,,,1„,r.„.1 '="."..,, , ,.., • ‘L . , . ' \\ ir7.7, 44, 4.' :',...,... )' V' w-,--- '0,4. `1, , pAP . , , \--' -' ,, :,- ti Itraill Company ConocoPhillips, Alaska, Inc." - BAKER Well Name 3H-3113k1Sk. Of4 El '305 Ciaix,. ( rnrninc.', r7, AMt 7,, kAi ,',', ',, (,'....1 C,orc)rril ,r,' r...";, r-...3Pi,,, '7,-,;.).f.: , ',.-/ -.HUGHES Arr:4-,01.Ac, Andfot icitc,W, 'Af.v.:1-ze3rtr,i''. Date 1/6/2010 INTEQ ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution d0'I' ca /9/ RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wri • ht, 907 263-4823 hardcop prints 4, ConocoPhillips Alaska, Inc. ,!....km Sharon Allsup-Drake ..::. Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print ' 1 '- NSK Wells Aide, NSK 69 ....„ . ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 . .., ConocoPhillips Alaska, Inc. - -, ... Ricky Elgarico 1 Graphic Image 1 Disk*/ , — - - •_ - _e , ■ II :t. File**/*** Electronic Z .., 1 700 G Street, CGM/TIFF LIS . ... . - - — Anchorage, AK 09501 . ,•.., ftp://b2bftp.conocophillips.com AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of s epi a ** Electronic 1 40 Anchorage, Alaska 99501 CGM / TIFF LIS jj BP 1 Hardcopy Print, , ,71- i, 1, 7, ' , , i1F,IFil Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ ,, ‘'4.x' David Douglas in lieu of sepia** Electronic 1 - ,-,f,f , , , ,f:it,::: , =,11 P.O. Box 196612 CGM/ LIS Anchorage, Alaska 99519-6612 . . CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS , .: '7= ' ; t 1 . 71 7 - ' ,7:1 T , T; ' ,331741Y7. ' tir Brandon Tucker, NRT . State of Alaska; DNR, Div. of Oil and Gas 1 Disk"/ 550 W. 7th Ave, Suite 800 Electronic 1 Anchorage, Alaska 99501-3510 LIS ..., ,...._...,...!..,.,..;,.............6. DS Engineer / Rig Foreman ._...,.,,.:....,......L;i2.k. TOTAL Hardcopy Prints 4 Page 1 of 4 . RECEIVED t • STATE OF ALASKA • NOV 2 0 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOR TAND (1106. C0 anssron la. Well Status: Oil Q Gas ❑ SPLUG ❑ Plugged ❑ Abandoned Suspended ❑ 1b. Well Class: Anthor 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 30, 2009 209 - 105 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 25, 2009 50 103 - 20578 - 61 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM October 27, 2009 3H - 33AL2 Top of Productive Horizon: 8. KB (ft above MSL): 77 ' RKB 15. Field /Pool(s): 623' FSL, 141' FEL, Sec. 1, T12N, R8E, UM GL (ft above MSL): 36' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 651' FSL, 157' FEL, Sec. 1, T12N, R8E, UM 9382' MD / 6188' TVD Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498655 y 6000588 Zone 4 9382' MD / 6188' TVD ADL 25531 TPI: x - 503512 y - 6002281 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 503496 y 6002308.5 Zone 4 2110' MD / 1998' TVD 2657 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) approx. 1738' MD / 1680' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD none 7805' MD / 6149' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 36' 149' 36' 149' 30" 97 sx AS 1 9.625" 40# L -80 36' 4315' 36' 3614' 12.25" 640 sx AS Lite, 178 sx LiteCRETE 7" 26# L -80 36' 8020' 36' 6396' 8.75" 309 sx Class G 2.375" 4.7# L -80 7984' 9382' 6153' 6188' 3" slotted liner 24. Open to production or injection? Yes Q No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7606' 7547' MD / 5969' TVD 7985-9373' MD 6152' -6186' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 7, 2009 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 11/11/2009 24 hours Test Period - -> 1179 1631 499 176 Bean 1383 Flow Tubing Casing Pressure Calculated OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - API (corr) Press. 145 psi 1319 24 - Hour Rate - 1179 1631 499 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. . 56Q F j $' I, 4 t NONE Form 10 -407 Revised 7/2009 f t k . w $ ' i n, ) a t a i CONTINUED ON REVERSE J Submit on ' al only ,1 J, / , 7 < / 0 � //,J�O G 28. GEOLOGIC MARKERS (List all formations and marker countered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1738' 1680' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk A3 8450' 6140' Top Kuparuk A3 8600' 6144' Top Kuparuk A2 9350' 6182' N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ( - Contact: J. Gary Eller @ 263 1 Printed N. , e Von Ca - Title: CT Drilling Manager / ��� Signature \,- �i . Phone 265 - 6306 Date lj / 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 7/2009 KUP le 3H -33AL2 Cat t y Well 5o / UWI KUd a RIVER UNIT Max Angle Well Status Inc' ( °) MD (ftKB69) TD A1iaSliiP hTr" Act Btm (ftKB) ux»ccoN eels. Cam 010 H2S (ppm) Date Anno ' PROD 96 90 7,990 58 9,382.0 pP - -- I l Cation End Date KB -Grd (ft) Rig Release Date Well Coniig. DEVIATED 3H- 33AL2, 1 ^/72005 3 03 PM ,,. - Rev n SIDETRACK 11/2/2009 Flapper Locked Out 0 11200 Last WO- 2/14/2009 _ . m Schematic A of Annotatio �n Depth (ftKB) End Date 'Annotation L t Mod ... End Date Tag:___ 1 DETRACK w/4 laterals total 1 Imosbor 19 , Last Casing Strings °' Casing Des option String 0... String ID .. Top (ftKB) It Depth (f ...r Depth (ND) .. String Wt... String ... String Top Thrd HANGER, 37 -. F LINER AL2 - __ 1 2 3/8 i 995 'Top 3 { 9,382.7 L._ .__ _, 4.60 I L-80 STL Liner Details Top Depth L i t . ; - (ND) Top Inc' Nomi... Top (ftKB) (B) (% Nam Daecriptlon Comment ID (in) - ' ' - 7,973.3 6,153.5 96.25 BILLET 2.625" openhole anchor - billet 7,984.5 6,152.3 96.67 DEPLOY 2.625" Baker deployment sleeve 1.995 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth - _.. (TVD) Top Inc! Top (KB) MOB) (•) Description Comment Run Date ID (in) 7,974 6,153.4 96.28 WHIPSTOCK WHIPSTOCK - ANCHOR BILLET 10/28/2009 1.000 CONDUCTOR, Perforations Sr Slots 40 - 149 Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Ben (ftKB) NEB) (ftKB) Zone Date (eh... Type Comment 7,985 9,373 6,152.2 6,186.4 10/27/2009 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid /slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered SAFETYVLV,_ 18 deg, 3' non slotted ends 2,110 Notes: General & Safety End Date Annotation 2/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT._ ., _ ww.�. 2 ,]35 - 11/2/2009 NOTE: WELL SIDETRACKED - A, AL7, AL2, AL2 -01 t . I ' i SURFACE, 42 -4,315 GAS LIFT, :46 4,444 GASLIFT, l 5,710 i. GAS LIFT, , IL 6,789 GAS LIFT, 7,453 NIPPLE, 7,504 PACKER, 7,547 - - NIPPLE, 7,591 - -' WLEG, 7,606 — WINDOWAli, 7,660 -7,665 WHIPSTOCK, 7,665 WHIPSTOCK, 4 . 974 NTERM 39 -9020 ,,, Iti Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (MB) () Meke Model (in) Son TYw T6089 (in) (Pal) Run Date Com... 1 2,735.0 2,471.9 44.14 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,327.0 11/6/2009 2 4,444.2 3,698.4 46.93 CAMCO MMG t 12 GAS LIFT GLV RK 0.188 1,303.0 11/6/2009 1 12 GAS LIFT GLV RK 0.788 1,282.0 11/4/2009 3 5,709.7 4,598.0 45.83 CAMCO MMG SLOTS, 4 6,789.1 5,362.3 44.45 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,263.0 11/4/2009 7.995 - 9373 s Irg .__.___ _._....,:.. ,_. . ..... . ............. ° - 5 7,453.3 5,887.6 30.64 CAMCO MMG 1 12 GAS LIFT OV RK 0.188 0.0 11/3/2009 TD(3H- 33AL2), 9,382 LINER AL2, 7,973 -9,383 3H -33 Actual CTD Sidetrack Schematic Updated: 11/2/2009 - 3-1/2" Cameo TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) ■ 3 -1/2 ", 9.3 #, L -80 EUE 8rd Tubing to surface 16 ", 624, H-40 conductor shoe 149' MD —.moll l;#,- 3 -112" Camco MMG gas lift mandrels at 2735', 4444', 5710', 6789', & 7453' illEll MIIII ' 9 -5/8 ", 404, L -80 casing shoe at 4315' MD ...lima Pet: _"` X- nipple at 7504' MD (2.813" min ID) Baker Premier packer at 7547' MD. No sealbore or seal assembly. 2 -3/8" liner top at 7583' MD " "' BELOW 2.318" LINER TOP at 7583' MD*** Camco D- nipple @ 7594 MD (2.75" min ID, No -Go) Nipple milled out to 2.80' ID _ 3 -1/2" tubing. tail at 7606' MD (7602' ELM) _ Top of cement at tubing tail at 1 7606' MD „,,y µ� N AL2 -01 Lateral (7974' - 9275') KOP #2 at 7665' MD r 2-3/8” liner 7583 - 9275' MD KOP #1 at 7685' MD M w Blank liner 7679' -7762' /i.-0 . -7.) l Baker monobore whipstock trays on \\ AL2 Lateral (7803' - 9382'1 openhole anchors at 7665' & 7685' M M- ' l'1 \ \ 2-3/8" slotted liner 7984 - 9382' MD 2.80" pilot hole in cement drilled to " �j _ 11111E - . —141 ) Anchor - Billet at 7974' • 7715' MD M ME \ \ J _ \ \ \ AL1 -PB1 (8810' - 960T) AL1 Lateral (7665' - 10.100') A -sand perfs (sgz'd) w • Anchor - Billet at 8810' 2 -3/8" liner 7803' - 10,100' 7740' - 7760' MD ""w _ - \ \ \ ® Blank liner 885V- 8977' 8, goy . •_. \ — — 9040' -9178 — ���' — — — — — _ — — _ Liner junction @ 8662' MD \� Aluminum billet at 7803' 7 ", 26 4, L -80 casing — - - - - - - - - - - - - \I — —) / shoe at 8020' MD " �',,,,,,,,,,,,� \ A Sidetrack (7685' - 10.307'1 2 -3/8" slotted liner 7673' -9944 Unlined hole 9944'- 10,307' 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:27 22:27 1.00 903 903 COMPZ CASING RGRP T While P/U Coiltrac the safety lock out pins on the top drive came out. System is disabled but not working correctly. Stop and repair. (By -pass hydraulic override manually) 22:27 23:27 1.00 903 903 COMPZ CASING PULD P Complete lowering in Coiltrack and inspect injector prepare to RIH. 23:27 00:00 0.55 903 903 COMPZ CASING RUNL P RIH with BHA # 20: 2nd segment of liner. 10/25/2009 RIH set upper liner & billet top © 7804.4', POOH. P/U BHA # 21 - 1.3 AKO with Bi- center - Rlh swap to 10 # drilling mud. Kick off Top of Billet from 7803 - 7808'. Continue drilling lateral in A -2 formation. 00:00 02:00 2.00 8,662 8,662 COMPZ CASING RUNL P RIH from 2000' EOP flag on depth © 6000', continue RIH with liner. Perform weight check prior to exiting window. 22k, RIH slowly 20 fpm through window, no problems, RIH tag liner top from 1st segment @ 8662.4 - sat down 5k at surface. Start pumping . 1 bpm, build pressure to 3000 psi & release from liner. 02:00 04:00 2.00 7,804 0 COMPZ CASING RUNL P Top of billet is 7803.7, POOH pumping down CT to keep hole full of KWF while POOH 04:00 05:30 1.50 0 0 COMPZ CASING PULD P At surface, Check the well for flow (15 min.) lay down BHA #20. 05:30 06:45 1.25 0 0 PROD3 DRILL PULD P Service injector head, check stripper rubber, PU BHA #21. 1.3deg AKO, 06:45 08:54 2.15 0 7,565 PROD3 DRILL TRIP P RIH with lateral BHA #21 with EDC open, pumping 0.4 BPM to sidetrack AL2 08:54 09:03 0.15 7,565 7,582 PROD3 DRILL DLOG P Tie in depth to gamma +3' correction 09:03 09:12 0.15 7,582 7,806 PROD3 DRILL TRIP P Close EDC RIH through window no pumps. Online with pumps RIH hrough build section. Offline with pumps tag billet 7806'. 09:12 10:12 1.00 7,806 7,350 PROD3 DRILL CIRC P PUH circulating 13.1 ppg KWM out of hole. 10:12 11:24 1.20 7,350 780 PROD3 DRILL TRIP P RIH to mill 11:24 14:24 3.00 7,803 7,805 PROD3 STK KOST P Start time milling .03 /6min. Aluminum over the shakers 14:24 15:00 0.60 7,805 7,806 PROD3 STK KOST P Increase ROP to .05' /6min 15:00 15:39 0.65 7,806 7,807 PROD3 STK KOST P Increase ROP to 2' /hour 15:39 16:09 0.50 7,807 7,808 PROD3 STK KOST P Increase ROP to 3' /hour 16:09 16:30 0.35 7,808 7,825 PROD3 DRILL DRLG P Confirmed Sidetrack with near bit /►�L 2- inclination. 7805'- 7808'. PUH through /'� sidetrack and 10' above, did not see anything. Offline with pumps, RIH through sidetrack dry, did not see anything. 16:30 18:30 2.00 7,825 7,955 PROD3 DRILL DRLG P Drill ahead 1K DHWOB, 30- 50FPH, 1.4BPM 3990psi CTP, 4100psi BHP, 13.1 ECD, 240psi WHP Page 22 of 27 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:12 0.70 7,955 7,955 PROD3 DRILL WPRT P Wiper to window, P/U weight 22k 19:12 20:42 1.50 7,955 8,105 PROD3 DRILL DRLG P BOBD - CT weight 2K, circ - 3900, 1.44 bpm, BHP 4144, ECD 13.14, WHP 150, ROP - 80 fph. Drilling in A -2 formation but crossed a fault © 8040', possible nosed up to A -3. 20:42 21:42 1.00 8,105 8,105 PROD3 DRILL WPRT P Wiper trip - P/U weight 22K 21:42 23:00 1.30 8,105 8,255 PROD3 DRILL DRLG P BOBD - CT weight 3300, circ 3900psi, 1.45 bpm, WOB 1.7, ROP 90, BHP 4145, ECD 13.2, WHP 150. 23:00 00:00 1.00 8,255 8,255 PROD3 DRILL WPRT P Wiper trip to window, perfrom tie in +1 ft correction 10/26/2009 Drilled ahead to 9245', perfromed mud swap @ 8709'. 00:00 01:36 1.60 8,255 8,405 PROD3 DRILL DRLG P BOBD - CT weight 3000, circ 3900, 1.44 bpm, BHP 4187, WHP 150, ECD 13.2, WOB 1.6, ROP 100fph. 01:36 03:06 1.50 8,405 8,405 PROD3 DRILL WPRT P Wiper trip - P/U 22k - Samples indicate A -2 03:06 04:06 1.00 8,405 8,463 PROD3 DRILL DRLG P BOBD - CT weight 2300, circ 3900, 1.40 bpm, BHP 4166, WHp 120, WOB 2.0, ECD 13.2, ROP 80 fph. Samples indicate A -2 sand 04:06 06:06 2.00 8,463 7,690 PROD3 DRILL WPRT P Wiper trip early (ROP slowed) going out the top of A2. Geo's calling town. 06:06 08:06 2.00 8,463 8,615 PROD3 DRILL DRLG P Drill Ahead 08:06 09:06 1.00 8,615 7,690 PROD3 DRILL WPRT P Wiper trip back to window 21K CTW 09:06 09:15 0.15 7,670 7,710 PROD3 DRILL DLOG P Tie in to RA marker, correction -no correction 09:15 09:45 0.50 7,710 8,621 PROD3 DRILL WPRT P RIH to drill 09:45 11:45 2.00 8,621 8,765 PROD3 DRILL DRLG P Drill Ahead, start pumping new mud down hole. New mud back to surface 11 am. 11:45 13:18 1.55 8,765 7,690 PROD3 DRILL WPRT P Wiper trip back to window 23K CTW 13:18 15:03 1.75 8,765 8,915 PROD3 DRILL DRLG P Drill ahead 15:03 16:42 1.65 8,915 7,690 PROD3 DRILL WPRT P Wiper trip back to window 16:42 18:06 1.40 8,915 9,065 PROD3 DRILL DRLG P Drill Ahead 18:06 20:06 2.00 9,065 9,065 PROD3 DRILL WPRT P Wiper trip to window with tie in ( zero correction). CT weight off bottom 23K. 20:06 21:36 1.50 9,065 9,215 PROD3 DRILL DRLG P BOBD - CT weight 3000, circ - 3800, 1.44 BPM, WOB 1.3K, ECD 13.2, BHP 4180, WHP 100, ROP 90 fph 21:36 22:06 0.50 9,215 9,248 PROD3 DRILL DRLG P Wiper trip - 200 ft - weight check 23K, RIH drill another 30 ft. 22:06 00:00 1.90 9,248 9,248 PROD3 DRILL WPRT P Wiper trip to window, Geo's feel we need to drill another 100'. P/U weight off bottom. 23K. Static test. 10/27/2009 Drilled AL2 lateral to depth 9382'. RIH and dropped off liner at TD up to 7984'. MU open hole anchor and aluminium billet BHA and RIH Page23of27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 9,248 7,650 PROD3 DRILL OWFF P 7650' - 30 minute static test - WHP 700 psi, ECD 12.92. BHP - 4023 psi. END - WHP 815, ECD 12.93, BHP - 3991. 00:30 02:00 1.50 7,650 9,248 PROD3 DRILL WPRT P RIH 02:00 03:18 1.30 9,248 9,380 PROD3 DRILL DRLG P BOBD - CT weight 2000, circ - 3900, BHP 4170, ECD 13.2, ROP - 80fph, Drilling for data, turning down 80 degrees. TD lateral @ 9380' - 6110' TVD. 03:18 04:48 1.50 9,380 7,690 PROD3 DRILL WPRT P Wiper trip to window, P/U weight 25K 04:48 05:03 0.25 7,670 7,680 PROD3 DRILL DLOG P Tie in depth to RA marker, +2 correction. 05:03 06:33 1.50 7,680 9,380 PROD3 DRILL WPRT P RIH to TD 06:33 09:33 3.00 9,383 0 PROD3 DRILL DISP P Tag TD 9382.69', POOH laying in 13.1 ppg liner pil to window. Swap to non - beaded 13.1 ppg at window. POOH killing well 09:33 11:03 1.50 0 0 PROD3 DRILL TRIP P POOH to surface 11:03 11:33 0.50 0 0 COMPZ CASING SFTY P Watch for flo at surface. Hold a BHA lay down iner running safety meeting. 11:33 15:33 4.00 0 1,442 COMPZ CASING PUTB P Make up liner & P/U Coiltrac assembly ( BHA # 22). total Ienght 1442.28 15:33 17:05 1.54 1,442 9,000 COMPZ CASING RUNL P RIH @ 45 fmp (20 fpm through window). Wt check @ 9000 ft 30K#. 17:05 19:05 2.00 9,000 9,382 COMPZ CASING RUNL P Tag btm @ 9382 with liner. Pump off liner @ 1.2 bpm 4100 psi. PU wt 22K #. Top of liner @ 7984 19:05 21:20 2.25 7,984 45 COMPZ CASING RUNL P POOH 80 fpm pumping 0.8 bpm. 21:20 22:20 1.00 45 74 COMPZ CASING PULD P Tag up, monitor well. PJSM. Rig down liner running BHA. 22:20 23:20 1.00 1,900 PROD4 STK PULD P RU AL billet on openhole anchor (BHA #23). test tool, open EDC. 23:20 23:59 0.66 74 1,900 PROD4 STK TRIP P RIH 45 fpm with open hole anchor and AL billet. Pumping 0.25 bpm 670 psi. 10/28/2009 Run and set aluminium KO billet for AL2 -01. Mill and KO from billet and start drilling AL2 -01 lateral. 00:00 02:00 2.00 1,900 7,690 PROD4 STK TRIP P Continue to RIH with open hole anchor and aluminium billet for AL2 -01 lateral. Pump through open EDC @ 0.20 bpm 650 psi. 02:00 02:20 0.34 7,690 7,983 PROD4 STK DLOG P Tie in to RA marker with 0' correction. Continue to RIH. 02:20 02:45 0.42 7,983 7,971 PROD4 STK WPST P Tag liner at 7983', sit 2K# down. Pick up wt and PUH 1'. Close EDC and press up to 4100 psi and broke back. Wt on bit 1.5K #. Pull out of billet. Bottom of anchor at 7982' top of aluminium billet at 7971'. 02:45 04:30 1.75 7,971 71 PROD4 STK TRIP P POOH at 45 fpm pumping 0.8 bpm 2250 psi. Page24of27 ConochiIIips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33AL2 501032057861 0 Cb Baker Hughes INTEQ Survey Report B AKER Y HUGHES 03 November, 2009 y • ConocoPhillips rill ConocoPhil ps Definitive Survey Report BAILER Alaska MOM; idCorilpanyh ConocoPhillips(Alaska) Inc. Local Co ordir('ate Reference 3H -33 i Pro( Kuparuk River Unit ,`I'VD Refer e I 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) I Site: Kuparuk 3H Pad Mb References s. " 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: 3H -33 North Reference: w, True ""Wellb ie : 3H -33 St Ivey Calc lation 'Method, Minimum Curvature benign '* 3H 33 Database EDM Alaska Prod v16 � , ,P� M ',' Map ' VeAlcal, 4 ' 1D; Inc -°41; �zi TV TVD +N/ 5, +EI W x , Northing Easti ti ro ,,, DLS Section Survey► Tool Named Annothtlor (ft) . (ft) (fty S su 40.75 0.00 0.00 40.75 -36.10 0.00 0.00 6,000,588.21 498,655.30 0.00 0.00 UNDEFINED 100.50 0.57 321.50 100.50 23.65 0.23 -0.19 6,000,588.44 498,655.11 0.95 -0.10 GYD -CT -CMS (1) 200.80 0.27 96.68 200.80 123.95 0.60 -0.26 6,000,588.81 498,655.04 0.78 -0.05 GYD -CT -CMS (1) 300.00 4.10 89.70 299.91 223.06 0.59 3.52 6,000,588.80 498,658.81 3.86 3.51 GYD -CT -CMS (1) 400.20 8.33 83.73 399.50 322.65 1.40 14.32 6,000,589.61 498,669.62 4.26 13.96 GYD -CT -CMS (1) 499.60 9.32 82.44 497.72 420.87 3.24 29.46 6,000,591.45 498,684.75 1.02 28.84 GYD -CT -CMS (1) 600.60 10.75 78.66 597.17 520.32 6.17 46.80 6,000,594.37 498,702.09 1.56 46.16 GYD -CT -CMS (1) 700.30 12.39 72.34 694.85 618.00 11.25 66.11 6,000,599.44 498,721.40 2.08 66.06 GYD -CT -CMS (1) 800.80 12.28 73.50 793.03 716.18 17.55 86.63 6,000,605.75 498,741.92 0.27 87.51 GYD -CT -CMS (1) 900.30 11.35 69.39 890.42 813.57 24.00 105.94 6,000,612.19 498,761.23 1.26 107.86 GYD -CT -CMS (1) 1,000.20 11.36 69.33 988.36 911.51 30.94 124.35 6,000,619.12 498,779.64 0.02 127.53 GYD -CT -CMS (1) 1,100.00 14.40 64.36 1,085.64 1,008.79 39.78 144.74 6,000,627.96 498,800.03 3.24 149.70 GYD -CT -CMS (1) 1,125.00 15.49 63.54 1,109.80 1,032.95 42.61 150.53 6,000,630.79 498,805.82 4.44 156.11 GYD -CT -CMS (1) 1,150.00 16.27 63.01 1,133.84 1,056.99 45.69 156.64 6,000,633.87 498,811.93 3.17 162.90 GYD - CT-CMS (1) 1,175.00 17.09 63.24 1,157.79 1,080.94 48.93 163.04 6,000,637.11 498,818.33 3.29 170.01 GYD-CT -CMS (1) 1. 1,200.00 18.44 63.86 1,181.60 1,104.75 52.33 169.87 6,000,640.50 498,825.16 5.45 177.59 GYD -CT -CMS (1) 1, ! 225.00 19.72 64.63 1,205.23 1,128.38 55.88 177.23 6,000,644.05 498,832.52 5.22 185.71 GYD -CT -CMS (1) �3 1,250.00 20.21 65.34 1,228.72 1,151.87 59.49 184.97 6,000,647.66 498,840.26 2.19 194.21 GYD -CT -CMS (1) I 1,275.00 20.28 65.46 1,252.18 1,175.33 63.09 192.83 6,000,651.26 498,848.12 0.33 202.83 GYD -CT -CMS (1) 1,300.00 20.29 65.63 1,275.63 1,198.78 66.68 200.72 6,000,654.84 498,856.01 0.24 211.46 GYD -CT -CMS (1) 1,325.00 20.13 65.84 1,299.09 1,222.24 70.23 208.60 6,000,658.39 498,863.88 0.70 220.07 GYD -CT -CMS (1) 1,350.00 19.11 66.55 1,322.64 1,245.79 73.61 216.28 6,000,661.78 498,871.56 4.19 228.44 GYD -CT -CMS (1) 1,375.00 18.19 67.24 1,346.32 1,269.47 76.75 223.63 6,000,664.92 498,878.92 3.78 236.42 GYD -CT -CMS (1) i 1,400.00 18.25 66.73 1,370.07 1,293.22 79.81 230.82 6,000,667.97 498,886.11 0.68 244.22 GYD -CT -CMS (1) 1,425.00 18.65 66.24 1,393.79 1,316.94 82.97 238.08 6,000,671.13 498,893.36 1.72 252.11 GYD -CT -CMS (1) 1,450.00 19.77 65.80 1,417.39 1,340.54 86.31 245.59 6,000,674.47 498,900.88 4.52 260.32 GYD -CT -CMS (1) j 1,475.00 20.71 66.36 1,440.85 1,364.00 89.82 253.50 6,000,677.97 498,908.79 3.84 268.94 GYD -CT -CMS (1) 1,500.00 21.65 67.66 1,464.16 1,387.31 93.34 261.81 6,000,681.50 498,917.10 4.20 277.96 GYD -CT -CMS (1) 1,525.00 22.43 69.28 1,487.33 1,410.48 96.78 270.54 6,000,684.93 498,925.83 3.96 287.33 GYD -CT -CMS (1) 1,550.00 23.64 70.07 1,510.34 1,433.49 100.18 279.71 6,000,688.33 498,935.00 5.00 297.11 GYD -CT -CMS (1) 11/3/2009 11:40:41AM Page 3 COMPASS 2003.16 Build 69 I ConocoPhillips Mei C OPhIII PS Definitive Survey Report Compa v Co noc oP h i ll i - ps(Alaska) I ,Local Ct- ordinate Reference: 3H -33 Project: Kuparuk River Unit TVD Reference: !r - 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) SitiiJ Kuparuk 3H Pad MD Reference: 1 'i 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well; -,,, 3H -33 North Reference: True = Weiibore: 3H -33 Survey Calculation Method: Minimum Curvature y Design; ` 3H -33 Database: 7 pEDM Alaska Prod v16 Suva r ig i , �- .'.. I 8 , Map Map'' =. v �' MD , Inc izi 1'VD " 1VDSS - "t`'" +NIS +E1 W Northing Easting �.. ' DL � Section ' () (°) :f (} is (tt) (ft) (ft} (ft} 0100) Survey' Toot Name Annotation � 1,575.00 24.76 70.71 1,533.14 1,456.29 103.62 289.37 6,000,691.76 498,944.65 4.60 307.36 GYD -CT -CMS (1) 1,600.00 25.68 71.20 1,555.76 1,478.91 107.09 299.44 6,000,695.24 498,954.72 3.77 318.01 GYD -CT -CMS (1) i 1,625.00 26.13 71.39 1,578.25 1,501.40 110.59 309.78 6,000,698.74 498,965.07 1.83 328.93 GYD -CT -CMS (1) 1,650.00 26.27 71.35 1,600.68 1,523.83 114.12 320.24 6,000,702.26 498,975.53 0.56 339.97 GYD -CT -CMS (1) 1,675.00 26.11 71.54 1,623.11 1,546.26 117.63 330.70 6,000,705.77 498,985.99 0.72 351.00 GYD -CT -CMS (1) 1,700.00 25.92 71.63 1,645.58 1,568.73 121.09 341.11 6,000,709.23 498,996.39 0.78 361.96 GYD -CT -CMS (1) 1,725.00 26.06 71.87 1,668.05 1,591.20 124.53 351.51 6,000,712.66 499,006.79 0.70 372.92 GYD -CT -CMS (1) 1,750.00 26.29 72.37 1,690.49 1,613.64 127.91 362.01 6,000,716.04 499,017.29 1.27 383.94 GYD -CT -CMS (1) 1,775.00 26.76 73.17 1,712.86 1,636.01 131.22 372.67 6,000,719.35 499,027.95 2.36 395.09 GYD -CT -CMS (1) 1,800.00 27.31 73.78 1,735.12 1,658.27 134.45 383.56 6,000,722.58 499,038.84 2.46 406.44 GYD -CT -CMS (1) 1,825.00 28.12 74.72 1,757.26 1,680.41 137.60 394.75 6,000,725.73 499,050.03 3.68 418.04 GYD -CT -CMS (1) 1,850.00 29.30 75.79 1,779.18 1,702.33 140.66 406.37 6,000,728.78 499,061.65 5.15 430.01 GYD -CT -CMS (1) 1,875.00 29.83 76.25 1,800.93 1,724.08 143.64 418.34 6,000,731.76 499,073.62 2.31 442.28 GYD -CT -CMS (1) 1,900.00 30.09 76.51 1,822.59 1,745.74 146.58 430.47 6,000,734.70 499,085.75 1.16 454.70 GYD -CT -CMS (1) 1,925.00 30.19 76.59 1,844.21 1,767.36 149.50 442.68 6,000,737.61 499,097.96 0.43 467.18 GYD -CT -CMS (1) 1,950.00 30.54 76.70 1,865.78 1,788.93 152.42 454.98 6,000,740.53 499,110.25 1.42 479.75 GYD -CT -CMS (1) 1,975.00 31.51 77.44 1,887.20 1,810.35 155.30 467.53 6,000,743.41 499,122.81 4.17 492.54 GYD -CT -CMS (1) F 2,000.00 32.43 78.05 1,908.41 1,831.56 158.11 480.47 6,000,746.22 499,135.75 3.90 505.67 GYD -CT -CMS (1) 2,025.00 33.68 78.36 1,929.36 1,852.51 160.89 493.82 6,000,749.00 499,149.09 5.05 519.18 GYD -CT -CMS (1) , 2,050.00 35.56 78.73 1,949.93 1,873.08 163.71 507.74 6,000,751.82 499,163.01 7.57 533.24 GYD -CT -CMS (1) E 2,075.00 36.32 78.95 1,970.17 1,893.32 166.55 522.13 6,000,754.65 499,177.41 3.08 547.76 GYD-CT -CMS (1) j l 2,100.00 36.70 79.19 1,990.27 1,913.42 169.37 536.74 6,000,757.47 499,192.01 1.62 562.46 GYD -CT -CMS (1) 2,125.00 36.79 79.35 2,010.30 1,933.45 172.16 551.43 6,000,760.25 499,206.70 0.53 577.24 GYD -CT -CMS (1) 2,150.00 36.82 79.37 2,030.32 1,953.47 174.92 566.15 6,000,763.01 499,221.42 0.13 592.04 GYD -CT -CMS (1) i 2,175.00 36.85 79.59 2,050.33 1,973.48 177.66 580.89 6,000,765.75 499,236.16 0.54 606.84 GYD -CT -CMS (1) 2,200.00 37.00 79.89 2,070.31 1,993.46 180.33 595.67 6,000,768.42 499,250.94 0.94 621.66 GYD -CT -CMS (1) 2,225.00 37.35 80.78 2,090.23 2,013.38 182.87 610.56 6,000,770.95 499,265.83 2.57 636.54 GYD -CT -CMS (1) 2,250.00 37.75 81.69 2,110.05 2,033.20 185.19 625.62 6,000,773.27 499,280.88 2.74 651.51 GYD -CT -CMS (1) 1 2,275.00 38.27 82.49 2,129.75 2,052.90 187.31 640.86 6,000,775.39 499,296.13 2.87 666.58 GYD -CT -CMS (1) 2,300.00 39.27 83.77 2,149.24 2,072.39 189.18 656.41 6,000,777.25 499,311.67 5.13 681.85 GYD -CT -CMS (1) 2,325.00 40.39 84.83 2,168.44 2,091.59 190.77 672.34 6,000,778.84 499,327.60 5.24 697.40 GYD CT CMS (1) 11/3/2009 11:40:41AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips 1411 Conoco Phillips Definitive Survey Report Alaska ili nES 1 c ompany ' ConocoPh Inc. Locat Co -ordin Reference: , 3H -33 Project °' Kuparuk River Unit Nb Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site ' 1 ''`'i Kuparuk 3H Pad MD - Reference: - 1 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) I Well: 3H -33 "North Reference; True I fl tare 3H -33 ill - Noy CatcUlatiOn Method: ,, Minimum Curvature Desigrtr ‘ 3H -33 Database EDM Alask Pr od v16 , Survey I Ii 4E'- � ! r• a . , } Map /,, Map . Vertical . .4 IIP IMD Inc l WD :>«, TVDSS , a + NI-S +E/-W Northing Easting DLL ` Section survey Tool Name Annotation n' � (ft) (1 ' () Ci) (t) (ft) : , - (t) (ft) (fo ( fo 2,350.00 41.51 85.85 2,187.32 2,110.47 192.10 688.67 6,000,780.17 499,343.93 5.22 713.23 GYD -CT -CMS (1) 2,375.00 42.06 86.42 2,205.96 2,129.11 193.22 705.29 6,000,781.28 499,360.55 2.67 729.26 GYD -CT -CMS (1) 2,400.00 42.20 86.63 2,224.51 2,147.66 194.24 722.03 6,000,782.30 499,377.29 0.79 745.38 GYD -CT -CMS (1) 2,425.00 41.87 86.82 2,243.07 2,166.22 195.19 738.74 6,000,783.25 499,394.00 1.41 761.44 GYD -CT -CMS (1) 2,450.00 41.45 86.96 2,261.75 2,184.90 196.09 755.33 6,000,784.15 499,410.59 1.72 777.38 GYD - CT-CMS (1) 2,475.00 41.20 87.05 2,280.53 2,203.68 196.96 771.82 6,000,785.01 499,427.07 1.03 793.20 GYD -CT -CMS (1) 2,500.00 41.07 87.30 2,299.35 2,222.50 197.77 788.25 6,000,785.82 499,443.50 0.84 808.95 GYD -CT -CMS (1) 2,525.00 41.19 87.40 2,318.18 2,241.33 198.53 804.67 6,000,786.57 499,459.92 0.55 824.68 GYD -CT -CMS (1) 2 41.41 87.41 2,336.97 2,260.12 199.28 821.16 6,000,787.32 499,476.41 0.88 840.46 GYD -CT -CMS (1) 2,575.00 41.78 87.55 2,355.66 2,278.81 200.00 837.74 6,000,788.04 499,492.98 1.53 856.33 GYD -CT -CMS (1) 2,600.00 42.24 87.67 2,374.24 2,297.39 200.70 854.45 6,000,788.74 499,509.70 1.87 872.32 GYD -CT -CMS (1) 2,625.00 43.10 87.66 2,392.62 2,315.77 201.39 871.38 6,000,789.43 499,526.63 3.44 888.50 GYD -CT -CMS (1) 2,650.00 43.67 87.60 2,410.79 2,333.94 202.10 888.54 6,000,790.13 499,543.78 2.29 904.90 GYD -CT -CMS (1) 2,675.00 43.96 87.60 2,428.83 2,351.98 202.83 905.83 6,000,790.86 499,561.08 1.16 921.44 GYD -CT -CMS (1) 2,700.00 44.09 87.59 2,446.80 2,369.95 203.56 923.19 6,000,791.58 499,578.43 0.52 938.04 GYD -CT -CMS (1) 2,725.00 44.14 87.59 2,464.75 2,387.90 204.29 940.58 6,000,792.31 499,595.82 0.20 954.67 GYD -CT -CMS (1) S 2,750.00 44.14 87.54 2,482.69 2,405.84 205.03 957.98 6,000,793.05 499,613.21 0.14 971.30 GYD -CT -CMS (1) 2,775.00 44.12 87.37 2,500.64 2,423.79 205.80 975.37 6,000,793.82 499,630.60 0.48 987.95 GYD -CT -CMS (1) 2,800.00 44.12 87.16 2,518.58 2,441.73 206.63 992.75 6,000,794.64 499,647.98 0.58 1,004.61 GYD -CT -CMS (1) 2,825.00 44.18 86.86 2,536.52 2,459.67 207.54 1,010.14 6,000,795.55 499,665.37 0.87 1,021.29 GYD -CT -CMS (1) 2,850.00 44.22 86.54 2,554.45 2,477.60 208.54 1,027.54 6,000,796.55 499,682.77 0.91 1,038.03 GYD -CT -CMS (1) 2,875.00 43.95 85.82 2,572.40 2,495.55 209.70 1,044.89 6,000,797.70 499,700.12 2.28 1,054.77 GYD -CT -CMS (1) 2,900.00 43.44 85.11 2,590.48 2,513.63 211.07 1,062.11 6,000,799.07 499,717.34 2.83 1,071.44 GYD -CT -CMS (1) 2,925.00 43.15 84.80 2,608.68 2,531.83 212.57 1,079.19 6,000,800.57 499,734.41 1.44 1,088.04 GYD -CT -CMS (1) t 2,950.00 42.77 84.72 2,626.97 2,550.12 214.13 1,096.15 6,000,802.12 499,751.38 1.54 1,104.55 GYD -CT -CMS (1) 2,975.00 42.67 84.66 2,645.34 2,568.49 215.70 1,113.04 6,000,803.69 499,768.26 0.43 1,120.98 GYD -CT -CMS (1) 3,000.00 42.69 84.64 2,663.72 2,586.87 217.28 1,129.91 6,000,805.27 499,785.14 0.10 1,137.41 GYD -CT -CMS (1) 3,025.00 42.77 84.67 2,682.08 2,605.23 218.86 1,146.80 6,000,806.84 499,802.02 0.33 1,153.85 GYD -CT -CMS (1) 3,050.00 42.55 84.90 2,700.47 2,623.62 220.40 1,163.68 6,000,808.38 499,818.89 1.08 1,170.27 GYD -CT -CMS (1) 3 42.28 85.22 2,718.92 2,642.07 221.85 1,180.48 6,000,809.83 499,835.69 1.38 1,186.58 GYD -CT -CMS (1) 3 42.27 85.36 2,737.42 2,660.57 223.23 1 6,000 499,852.45 0.38 1,202.84 GYD -CT -CMS (1) 11/3/2009 11:40:41AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Mall C0110001411111pS Definitive Survey Report BILICER Alaska 111.4141111g; Company s ConocoPhillip s (Alaska) Inc. Local Coot hate Reference 3H -33 I,Project Kuparuk River Unit 1V©�Reference: ,�� 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site �� Kuparuk 3H Pad MD Reference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well?' , 3H -33 NorthiReferetoe: , , True 1 Weilbore:" 3H -33 Survey Calculatiof M ethod: 6 1' Minimum Curvature �sstgn: 3H -33 Data'ase: EDM Alaska Prod v16 H- a .._ _ „,,, _,,„,,,,,,,_ tdi _ _,, , ,, , , - W ---, m .. Survey � ,� � � ' � , � Map �; Map � vertical ' ,, �� lnc Azt T ; ' . f4t4g +El_W k M . L , , , . i J hli'� tatting,:', DLS 1 Section ort _ m I . 9 � Surv@ Tool.Na Name � rti tStlon _ l� 3,125.00 42.24 85.47 2,755.92 2,679.07 224.58 1,213.99 6,000,812.55 499,869.21 0.32 1,219.08 GYD -CT -CMS (1) 3,150.00 42.22 85.74 2,774.44 2,697.59 225.86 1,230.75 6,000,813.83 499,885.96 0.73 1,235.29 GYD -CT -CMS (1) 3,175.00 42.33 85.92 2,792.93 2,716.08 227.09 1,247.52 6,000,815.05 499,902.73 0.65 1,251.51 GYD -CT -CMS (1) II 3,200.00 42.48 85.96 2,811.39 2,734.54 228.28 1,264.34 6,000,816.24 499,919.55 0.61 1,267.75 GYD -CT -CMS (1) 3,225.00 42.61 86.03 2,829.81 2,752.96 229.46 1,281.20 6,000,817.42 499,936.41 0.55 1,284.03 GYD -CT -CMS (1) 3,250.00 42.97 86.15 2,848.16 2,771.31 230.62 1,298.14 6,000,818.57 499,953.35 1.48 1,300.39 GYD -CT -CMS (1) 3,275.00 43.31 86.22 2,866.40 2,789.55 231.76 1,315.20 6,000,819.71 499,970.40 1.37 1,316.84 GYD -CT -CMS (1) 1 3,300.00 43.49 86.22 2,884.57 2,807.72 232.89 1,332.34 6,000,820.84 499,987.54 0.72 1,333.37 GYD -CT -CMS (1) 3,325.00 43.41 86.37 2,902.71 2,825.86 234.00 1,349.50 6,000,821.95 500,004.70 0.52 1,349.90 GYD - CT-CMS (1) 3,350.00 43.06 86.66 2,920.93 2,844.08 235.04 1,366.59 6,000,822.98 500,021.79 1.61 1,366.36 GYD -CT -CMS (1) 3,375.00 42.39 87.17 2,939.29 2,862.44 235.96 1,383.53 6,000,823.89 500,038.73 3.02 1,382.62 GYD -CT -CMS (1) 3,400.00 42.35 87.26 2,957.76 2,880.91 236.77 1,400.35 6,000,824.71 500,055.55 0.29 1,398.75 GYD -CT -CMS (1) 3,425.00 42.43 87.32 2,976.23 2,899.38 237.57 1,417.19 6,000,825.50 500,072.39 0.36 1,414.88 GYD -CT -CMS (1) 1 3,450.00 42.54 87.34 2,994.66 2,917.81 238.36 1,434.06 6,000,826.29 500,089.25 0.44 1,431.04 GYD -CT -CMS (1) I 3,475.00 42.62 87.36 3,013.07 2,936.22 239.14 1,450.95 6,000,827.06 500,106.15 0.32 1,447.22 GYD -CT -CMS (1) 3,500.00 42.79 87.39 3,031.44 2,954.59 239.92 1,467.89 6,000,827.84 500,123.08 0.68 1,463.44 GYD -CT -CMS (1) 3,525.00 43.13 87.44 3,049.74 2,972.89 240.68 1,484.91 6,000,828.60 500,140.10 1.37 1,479.73 GYD -CT -CMS (1) 3,550.00 43.51 87.52 3,067.93 2,991.08 241.44 1,502.05 6,000,829.35 500,157.23 1.54 1,496.13 GYD -CT -CMS (1) 3,575.00 43.76 87.47 3,086.02 3,009.17 242.19 1,519.28 6,000,830.11 500,174.47 1.01 1,512.62 GYD -CT -CMS (1) I 3,600.00 43.83 87.56 3,104.07 3,027.22 242.94 1,536.57 6,000,830.85 500,191.75 0.37 1,529.16 GYD -CT -CMS (1) 3,625.00 43.76 87.63 3,122.11 3,045.26 243.67 1,553.85 6,000,831.58 500,209.04 0.34 1,545.69 GYD -CT -CMS (1) 3,650.00 43.49 87.77 3,140.21 3,063.36 244.36 1,571.09 6,000,832.26 500,226.27 1.15 1,562.16 GYD -CT -CMS (1) 3,675.00 43.47 87.92 3,158.35 3,081.50 245.01 1,588.28 6,000,832.91 500,243.46 0.42 1,578.58 GYD -CT -CMS (1) 3,700.00 43.61 87.91 3,176.47 3,099.62 245.63 1,605.49 6,000,833.53 500,260.67 0.56 1,595.00 GYD -CT -CMS (1) 3,725.00 43.79 88.03 3,194.55 3,117.70 246.25 1,622.75 6,000,834.14 500,277.93 0.79 1,611.47 GYD -CT -CMS (1) 3,750.00 44.09 88.02 3,212.55 3,135.70 246.84 1,640.09 6,000,834.73 500,295.26 1.20 1,628.01 GYD -CT -CMS (1) 3,775.00 44.54 88.03 3,230.44 3,153.59 247.45 1,657.54 6,000,835.33 500,312.72 1.80 1,644.65 GYD -CT -CMS (1) 3,800.00 44.76 88.06 3,248.22 3,171.37 248.04 1,675.10 6,000,835.93 500,330.27 0.88 1,661.40 GYD -CT -CMS (1) 3,825.00 45.01 88.01 3,265.93 3,189.08 248.65 1,692.73 6,000,836.53 500,347.90 1.01 1,678.21 GYD -CT -CMS (1) 3,850.00 45.22 88.11 3,283.58 3,206.73 249.25 1,710.44 6,000,837.13 500,365.60 0.89 1,695.10 GYD CT CMS (1) 3,875.00 45.36 88.12 3,301.16 3,224.31 249.83 1,728.19 6,000,837.71 500,383.36 0.56 1,712.02 GYD CT CMS (1) 11/3/2009 11:40:41AM Page 6 COMPASS 2003.16 Build 69 N." ConocoPhillips IF4r CII Alaska Definitive Survey Report BAKEI MOMS Company;, ConocoPhillips(Alaska) Inc. t Deal Co-ordlna a Reference. 3H -33 t r=rojecti: W Kuparuk River Unit T Referenco ., 3H -33 Rig @ 76•85ft ( D15 (40'75+36'1)) ,Site: Kuparuk 3H Pad MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) W ell: ` 3H -33 North Reference: True Wellbore: 3H -33 "Surrey " Method: ` ' Minimum Curvature D§ign: 3H -33 ° Database: EDM Alaska Prod v16 „mom Survoy , _ 4 a g e , ., i �a! M ap Mep° , VencCal � 411-1:,;, MD r, inc , Azi ' ' VD TVDSS 444/..s. +rj:W Northing „, : Easting. D LS � Section unr e y Tool Name , A , rmot'Stion 1 O � ) ff (ft) Cft) (ft} t(ft) ( /100) (ft) . ; 3,900.00 45.23 88.33 3,318.75 3,241.90 250.38 1,745.95 6,000,838.26 500,401.12 0.79 1,728.94 GYD -C , - CMS (1) 3,925.00 44.46 88.55 3,336.48 3,259.63 250.86 • 1,763.58 6,000,838.73 500,418.74 3.14 1,745.71 GYD -CT -CMS (1) 1. 3,950.00 44.23 88.68 3,354.35 3,277.50 251.29 1,781.04 6,000,839.15 500,436.21 0.99 1,762.31 GYD -CT -CMS (1) 3,975.00 44.44 88.71 3,372.24 3,295.39 251.68 1,798.51 6,000,839.55 500,453.67 0.84 1,778.90 GYD -CT -CMS (1) 4,000.00 44.84 88.66 3,390.02 3,313.17 252.09 1,816.07 6,000,839.95 500,471.23 1.61 1,795.58 GYD -CT -CMS (1) 4,025.00 45.28 88.52 3,407.68 3,330.83 252.52 1,833.76 6,000,840.38 500,488.92 1.80 1,812.39 GYD -CT -CMS (1) 4,050.00 45.62 88.46 3,425.22 3,348.37 252.99 1,851.57 6,000,840.85 500,506.73 1.37 1,829.33 GYD -CT -CMS (1) 4,075.00 45.80 88.46 3,442.68 3,365.83 253.47 1,869.46 6,000,841.32 500,524.62 0.72 1,846.35 GYD -CT -CMS (1) 4,100.00 45.85 88.56 3,460.10 3,383.25 253.94 1,887.39 6,000,841.79 500,542.54 0.35 1,863.39 GYD -CT -CMS (1) 1 4,125.00 45.85 88.96 3,477.51 3,400.66 254.33 1,905.32 6,000,842.17 500,560.47 1.15 1,880.42 GYD -CT -CMS (1) 4,150.00 45.91 89.29 3,494.92 3,418.07 254.60 1,923.27 6,000,842.44 500,578.41 0.98 1,897.42 GYD -CT -CMS (1) 4,175.00 45.98 89.37 3,512.30 3,435.45 254.81 1,941.23 6,000,842.65 500,596.38 0.36 1,914.42 GYD -CT -CMS (1) - 4 45.84 89.59 3,529.70 3,452.85 254.98 1,959.19 6,000,842.81 500,614.33 0.84 1,931.39 GYD -CT -CMS (1) = 4,225.00 45.67 89.82 3,547.14 3,470.29 255.07 1,977.10 6,000,842.90 500,632.24 0.95 1,948.30 GYD - CT-CMS (1) 4,250.00 45.78 89.86 3,564.59 3,487.74 255.12 1,995.00 6,000,842.94 500,650.14 0.45 1,965.18 GYD -CT -CMS (1) 4,275.00 45.96 89.97 3,582.00 3,505.15 255.14 2,012.94 6,000,842.97 500,668.08 0.79 1,982.09 GYD -CT -CMS (1) 4,300.00 46.22 90.05 3,599.34 3,522.49 255.14 2,030.95 6,000,842.96 500,686.09 1.07 1,999.06 GYD -CT -CMS (1) 4,325.00 46.37 90.19 3,616.61 3,539.76 255.10 2,049.02 6,000,842.92 500,704.16 0.72 2,016.08 GYD -CT -CMS (1) 4,350.00 46.51 90.28 3,633.84 3,556.99 255.03 2,067.14 6,000,842.84 500,722.27 0.62 2,033.12 GYD -CT -CMS (1) 4,375.00 46.63 90.18 3,651.03 3,574.18 254.96 2,085.29 6,000,842.77 500,740.43 0.56 2,050.20 GYD -CT -CMS (1) 4,400.00 46.79 90.16 3,668.17 3,591.32 254.90 2,103.49 6,000,842.71 500,758.62 0.64 2,067.33 GYD -CT -CMS (1) 4,425.00 46.88 90.09 3,685.27 3,608.42 254.86 2,121.73 6,000,842.67 500,776.86 0.41 2,084.50 GYD -CT -CMS (1) 4,450.00 46.94 90.02 3,702.35 3,625.50 254.84 2,139.98 6,000,842.64 500,795.11 0.32 2,101.70 GYD -CT -CMS (1) 4,475.00 47.06 89.99 3,719.40 3,642.55 254.84 2,158.27 6,000,842.64 500,813.39 0.49 2,118.92 GYD -CT -CMS (1) 4,500.00 46.92 89.68 3,736.45 3,659.60 254.90 2,176.55 6,000,842.69 500,831.67 1.07 2,136.16 GYD -CT -CMS (1) 4,525.00 46.74 89.24 3,753.56 3,676.71 255.07 2,194.78 6,000,842.86 500,849.90 1.47 2,153.40 GYD -CT -CMS (1) 4,550.00 46.50 88.82 3,770.73 3,693.88 255.38 2,212.95 6,000,843.16 500,868.07 1.55 2,170.62 GYD -CT -CMS (1) 4,575.00 46.28 88.62 3,787.97 3,711.12 255.78 2,231.04 6,000,843.56 500,886.16 1.05 2,187.81 GYD -CT -CMS (1) 4,600.00 46.16 88.41 3,805.27 3,728.42 256.25 2,249.09 6,000,844.03 500,904.20 0.77 2,204.97 GYD -CT -CMS (1) 4,625.00 45.59 87.71 3,822.67 3,745.82 256.85 2,267.02 6,000,844.63 500,922.14 3.04 2,222.07 GYD -CT -CMS (1) 4,650.00 44.67 86.57 3,840.31 3,763.46 257.74 2,284.72 6,000,845.51 500,939.83 4.90 2,239.04 GYD -CT -CMS (1) 11/3/2009 11:40:41AM Page 7 COMPASS 2003.16 Build 69 r.-' ConocoPhillips Efd ConocoFilillips Definitive Survey Report Alaska WKS . i i i .._.._...... -, � �ii i9a! , i Company ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference , i , 3H -33 Project. Kuparuk River Unit TVD Reference � 3H 33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site:,; Kuparuk 3H Pad MD Refere'ece: 3H - Rig @ 76.85ft (D15 (40.75 +36.1)) WeIt. ,, To s ; 31-1-33 Nort ference: '': W81tbore: i 3H -33 Survey Cal ulatlon Method: "° Minimum Curvature iDeslgn 3H -33 ,. Database: °' EDM Alaska Prod v16 r ul!u y , ∎ @ �� i s r 4 @ i f� j ii H , ,,i i i IViap Map Ve rtical '' s, , ; . MD Inc ; Azi = w "ND TVDSS +N!-S +�-W Northing , Easting , Dt ` Section Survey TebI Name AnnotatiO i I' - {ft) u . ( ° ) (r (1 _- tft) (ft) (ft) (ft) (ft) ° . (ft) (1900) d'''-' ({ •. 1 '''' 4,675.00 44.48 86.13 3,858.12 3,781.27 258.85 2,302.23 6,000,846.62 500,957.34 1.45 2,255.91 GYD -CT -CMS (1) 4,700.00 44.38 85.99 3,875.97 3,799.12 260.06 2,319.69 6,000,847.82 500,974.80 0.56 2,272.76 GYD -CT -CMS (1) 4,725.00 44.33 86.10 3,893.85 3,817.00 261.26 2,337.12 6,000,849.03 500,992.23 0.37 2,289.59 GYD -CT -CMS (1) 4,750.00 44.28 86.08 3,911.74 3,834.89 262.45 2,354.54 6,000,850.21 501,009.65 0.21 2,306.41 GYD-CT -CMS (1) 4,775.00 44.31 86.10 3,929.63 3,852.78 263.64 2,371.96 6,000,851.40 501,027.07 0.13 2,323.22 GYD -CT -CMS (1) 4,800.00 44.47 86.17 3,947.50 3,870.65 264.82 2,389.41 6,000,852.58 501,044.52 0.67 2,340.05 GYD -CT -CMS (1) 4,825.00 44.57 86.16 3,965.32 3,888.47 265.99 2,406.90 6,000,853.74 501,062.00 0.40 2,356.92 GYD -CT -CMS (1) 4,850.00 44.63 86.11 3,983.12 3,906.27 267.18 2,424.42 6,000,854.92 501,079.52 0.28 2,373.82 GYD -CT -CMS (1) 4,875.00 44.72 86.03 4,000.90 3,924.05 268.38 2,441.95 6,000,856.13 501,097.05 0.42 2,390.75 GYD -CT -CMS (1) !! 4,900.00 44.44 85.96 4,018.71 3,941.86 269.61 2,459.46 6,000,857.35 501,114.55 1.14 2,407.65 GYD -CT -CMS (1) i 4,925.00 44.02 85.83 4,036.62 3,959.77 270.86 2,476.85 6,000,858.59 501,131.95 1.72 2,424.46 GYD -CT -CMS (1) 4,950.00 43.73 85.82 4,054.64 3,977.79 272.12 2,494.13 6,000,859.85 501,149.23 1.16 2,441.16 GYD -CT -CMS (1) 4,975.00 43.67 85.90 4,072.72 3,995.87 273.36 2,511.36 6,000,861.10 501,166.45 0.33 2,457.81 GYD -CT -CMS (1) 1 1 5,000.00 43.62 86.16 4,090.81 4,013.96 274.56 2,528.57 6,000,862.29 501,183.66 0.75 2,474.43 GYD -CT -CMS (1) t. 5,025.00 43.51 87.42 4,108.92 4,032.07 275.52 2,545.77 6,000,863.25 501,200.86 3.50 2,490.96 GYD -CT -CMS (1) 5,050.00 43.47 87.97 4,127.06 4,050.21 276.22 2,562.96 6,000,863.94 501,218.05 1.52 2,507.39 GYD -CT -CMS (1) Ankh : 5,075.00 43.35 88.26 4,145.22 4,068.37 276.78 2,580.14 6,000,864.50 501,235.22 0.93 2,523.76 GYD -CT -CMS (1) 5,100.00 43.12 88.27 4,163.44 4,086.59 277.30 2,597.25 6,000,865.01 501,252.34 0.92 2,540.06 GYD -CT -CMS (1) 5,125.00 43.05 88.34 4,181.69 4,104.84 277.80 2,614.32 6,000,865.52 501,269.41 0.34 2,556.32 GYD -CT -CMS (1) 1 5,150.00 42.96 88.35 4,199.98 4,123.13 278.30 2,631.37 6,000,866.01 501,286.45 0.36 2,572.54 GYD -CT -CMS (1) I a 5,175.00 43.12 88.50 4,218.25 4,141.40 278.77 2,648.42 6,000,866.47 501,303.50 0.76 2,588.77 GYD -CT -CMS (1) 5,200.00 43.39 88.64 4,236.46 4,159.61 279.19 2,665.55 6,000,866.90 501,320.63 1.15 2,605.05 GYD -CT -CMS (1) 5,225.00 43.94 88.92 4,254.54 4,177.69 279.56 2,682.81 6,000,867.26 501,337.88 2.33 2,621.43 GYD -CT -CMS (1) 5,250.00 44.21 89.15 4,272.50 4,195.65 279.85 2,700.19 6,000,867.55 501,355.27 1.26 2,637.91 GYD -CT -CMS (1) 5,275.00 44.49 89.50 4,290.38 4,213.53 280.06 2,717.67 6,000,867.75 501,372.74 1.49 2,654.44 GYD -CT -CMS (1) 5,300.00 44.82 89.57 4,308.16 4,231.31 280.20 2,735.24 6,000,867.89 501,390.31 1.33 2,671.05 GYD -CT -CMS (1) 5,325.00 44.94 89.67 4,325.88 4,249.03 280.32 2,752.88 6,000,868.01 501,407.95 0.56 2,687.71 GYD -CT -CMS (1) 5,350.00 44.92 89.84 4,343.58 4,266.73 280.39 2,770.53 6,000,868.08 501,425.60 0.49 2,704.37 GYD -CT -CMS (1) l 5,375.00 44.82 89.79 4,361.29 4,284.44 280.45 2,788.17 6,000,868.13 501,443.24 0.42 2,721.01 GYD -CT -CMS (1) 5,400.00 44.68 89.90 4,379.05 4,302.20 280.50 2,805.77 6,000,868.18 501,460.84 0.64 2,737.60 GYD -CT -CMS (1) 5,425.00 44.64 89.89 4,396.83 4,319.98 280.53 2,823.34 6,000,868.21 501,478.41 0.16 2,754.17 GYD -CT -CMS (1) 11/3/2009 11:40:41AM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips I IFS ConocoPhillips Definitive Survey Report Alaska BA MES I Compa y , ConocoPhillips(Alaska) Inc. 'Local Co- Ordinate t eference: 3H -33 , i' ojeo4 Kuparuk River Unit T1�13 Reference: 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) ite Kuparuk 3H Pad MD Referenoe:i 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) ,1,..., ell: '41 3H -33 North Reference: T WNeiibore: '3H . gSuvvey Calculation Method: Minimum Curvature Desf n 3H 33 Database: 1 EDM Alaska Prod v16 .Survey 1 � fih' iF �" - t ip i t TVDSS +N + -W Map Map DLS Vertical , i a MD In-- A zt _ D G 2.62'''' N o (( ft) Eastin , Section ' �nrey Tool t art►e rtn a tlorr � � i ' � � �� , (ft) ,t�) �-� �f�� \ ! t� '; � �'��� � (ft) r , i 5,450.00 89.96 4,414.62 4,337.77 280.55 2,840.91 6,000,868.23 501,495.97 0.21 2,770.73 GYD -CT -CMS (1) 5,475.00 44.59 90.02 4,432.42 4,355.57 280.56 2,858.46 6,000,868.23 501,513.52 0.21 2,787.27 GYD -CT -CMS (1) 5,500.00 44.79 90.08 4,450.19 4,373.34 280.54 2,876.04 6,000,868.21 501,531.10 0.82 2,803.83 GYD -CT -CMS (1) 5,525.00 45.06 90.26 4,467.90 4,391.05 280.49 2,893.70 6,000,868.15 501,548.76 1.19 2,820.45 GYD -CT -CMS (1) 5,550.00 45.11 90.51 4,485.55 4,408.70 280.37 2,911.40 6,000,868.03 501,566.46 0.74 2,837.09 GYD -CT -CMS (1) 5,575.00 45.04 90.57 4,503.20 4,426.35 280.20 2,929.10 6,000,867.86 501,584.16 0.33 2,853.71 GYD -CT -CMS (1) i 5,600.00 44.88 90.65 4,520.89 4,444.04 280.02 2,946.77 6,000,867.67 501,601.82 0.68 2,870.29 GYD -CT -CMS (1) 5,625.00 44.99 90.34 4,538.59 4,461.74 279.86 2,964.42 6,000,867.51 501,619.47 0.98 2,886.88 GYD -CT -CMS (1) 5,650.00 45.25 89.26 4,556.23 4,479.38 279.93 2,982.14 6,000,867.57 501,637.19 3.23 2,903.59 GYD -CT -CMS (1) 11 5,675.00 45.58 88.01 4,573.78 4,496.93 280.35 2,999.94 6,000,867.99 501,654.98 3.80 2,920.50 GYD -CT -CMS (1) II 5,700.00 45.81 87.40 4,591.24 4,514.39 281.07 3,017.81 6,000,868.71 501,672.86 1.97 2,937.58 GYD - CT-CMS (1) 5,725.00 45.72 87.14 4,608.68 4,531.83 281.92 3,035.71 6,000,869.56 501,690.75 0.83 2,954.73 GYD -CT -CMS (1) 5,750.00 45.54 87.14 4,626.16 4,549.31 282.81 3,053.55 6,000,870.44 501,708.60 0.72 2,971.84 GYD -CT -CMS (1) 5,775.00 45.36 87.12 4,643.70 4,566.85 283.70 3,071.35 6,000,871.33 501,726.39 0.72 2,988.91 GYD -CT -CMS (1) ■ 5,800.00 45.48 87.17 4,661.25 4,584.40 284.59 3,089.13 6,000,872.22 501,744.17 0.50 3,005.96 GYD -CT -CMS (1) 5,825.00 45.48 87.18 4,678.78 4,601.93 285.47 3,106.94 6,000,873.09 501,761.97 0.03 3,023.03 GYD -CT -CMS (1) 5,850.00 45.45 87.25 4,696.31 4,619.46 286.33 3,124.74 6,000,873.95 501,779.77 0.23 3,040.09 GYD -CT -CMS (1) • 5,875.00 45.22 87.16 4,713.89 4,637.04 287.20 3,142.49 6,000,874.82 501,797.53 0.95 3,057.11 GYD- CT- CMS(1) 5,900.00 45.13 87.19 4,731.51 4,654.66 288.08 3,160.20 6,000,875.69 501,815.24 0.37 3,074.09 GYD -CT -CMS (1) 5,925.00 44.99 87.15 4,749.17 4,672.32 288.95 3,177.88 6,000,876.56 501,832.91 0.57 3,091.04 GYD -CT -CMS (1) 5,950.00 45.01 87.18 4,766.85 4,690.00 289.82 3,195.54 6,000,877.43 501,850.56 0.12 3,107.97 GYD -CT -CMS (1) 5,975.00 44.98 87.12 4,784.53 4,707.68 290.70 3,213.19 6,000,878.31 501,868.22 0.21 3,124.90 GYD -CT -CMS (1) 6,000.00 44.95 86.97 4,802.21 4,725.36 291.61 3,230.83 6,000,879.21 501,885.86 0.44 3,141.83 GYD -CT -CMS (1) 6,025.00 44.95 86.95 4,819.91 4,743.06 292.55 3,248.47 6,000,880.15 501,903.49 0.06 3,158.76 GYD -CT -CMS (1) 6,050.00 44.92 86.99 4,837.61 4,760.76 293.48 3,266.10 6,000,881.08 501,921.13 0.16 3,175.68 GYD -CT -CMS (1) 6,075.00 44.92 86.94 4,855.31 4,778.46 294.42 3,283.73 6,000,882.01 501,938.75 0.14 3,192.61 GYD -CT -CMS (1) 6,100.00 44.97 86.95 4,873.00 4,796.15 295.36 3,301.37 6,000,882.95 501,956.39 0.20 3,209.54 GYD -CT -CMS (1) 6,125.00 44.98 86.95 4,890.69 4,813.84 296.30 3,319.01 6,000,883.88 501,974.03 0.04 3,226.48 GYD -CT -CMS (1) 6,150.00 45.02 87.28 4,908.37 4,831.52 297.19 3,336.67 6,000,884.77 501,991.68 0.95 3,243.41 GYD -CT -CMS (1) 6,175.00 44.90 87.87 4,926.06 4,849.21 297.94 3,354.32 6,000,885.51 502,009.33 1.74 3,260.29 GYD -CT -CMS (1) i 6,200.00 44.86 88.05 4,943.77 4,866.92 298.56 3,371.95 6,000,886.14 502,026.96 0.53 3,277.11 GYD -CT -CMS (1) 11/3/2009 11 :40 :41AM Page 9 COMPASS 2003.16 Build 69 ConocoPhillips Wahl CCOnOCOPhilliPS Definitive Survey Report BAKEL Alaska /MUGS �. ... Xis C ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference. 3H -33 Proj Kuparuk River Unit 'Tip Ref 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) s Site: Kuparuk 3H Pad M Refer`ene *� �' � '- 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Weti:, 3H -33 North Reference: True 1 WeIIbore : : -3H -33 Survey Calculation Method: Minimum Curvature I DesPgn;, '�� 3H 33 Database: EDM Alaska Prod v16 MD ' Inc ' + " i 1 T\/D TVDSS +N /-S +Il(W Northing EaSt ng; oil ow Section (f i ° ) i . "� 1 (ft) ( (ft) { i �.(ft) ( /� oo) (ft) survey 'TOW Name Ann�te 6,22 44.69 88.17 4,961. 4,884.67 299.15 3,389.54 6,000,886.72 502,044.56 0.76 3,293.89 GYD - CT-CMS (1) 6,250.00 44.76 88.11 4,979.28 4,902.43 299.72 3,407.13 6,000,887.28 502,062.14 0.33 3,310.65 GYD -CT -CMS (1) 6,275.00 44.77 87.95 4,997.03 4,920.18 300.32 3,424.72 6,000,887.89 502,079.73 0.45 3,327.43 GYD -CT -CMS (1) I 6,300.00 44.76 87.80 5,014.78 4,937.93 300.97 3,442.32 6,000,888.54 502,097.32 0.42 3,344.22 GYD -CT -CMS (1) 6,325.00 44.79 87.65 5,032.53 4,955.68 301.67 3,459.91 6,000,889.23 502,114.91 0.44 3,361.03 GYD -CT -CMS (1) 6,350.00 44.81 87.55 5,050.27 4,973.42 302.41 3,477.51 6,000,889.97 502,132.51 0.29 3,377.87 GYD -CT -CMS (1) 6,375.00 44.73 87.35 5,068.01 4,991.16 303.19 3,495.10 6,000,890.75 502,150.10 0.65 3,394.70 GYD -CT -CMS (1) 6,400.00 44.61 87.26 5,085.79 5,008.94 304.02 3,512.66 6,000,891.57 502,167.65 0.54 3,411.52 GYD -CT -CMS (1) 6,425.00 44.66 87.09 5,103.58 5,026.73 304.89 3,530.20 6,000,892.43 502,185.20 0.52 3,428.34 GYD -CT -CMS (1) 6,450.00 44.57 86.89 5,121.38 5,044.53 305.81 3,547.73 6,000,893.35 502,202.73 0.67 3,445.17 GYD -CT -CMS (1) 6,475.00 44.49 86.81 5,139.20 5,062.35 306.77 3,565.24 6,000,894.31 502,220.23 0.39 3,461.98 GYD -CT -CMS (1) 6,500.00 44.45 86.89 5,157.04 5,080.19 307.73 3,582.73 6,000,895.27 502,237.72 0.28 3,478.78 GYD -CT -CMS (1) 6,525.00 44.68 87.20 5,174.85 5,098.00 308.64 3,600.24 6,000,896.17 502,255.24 1.27 3,495.59 GYD CT CMS (1) 6,550.00 44.85 87.65 5,192.60 5,115.75 309.43 3,617.83 6,000,896.96 502,272.82 1.44 3,512.43 GYD -CT -CMS (1) 6,575.00 44.97 87.90 5,210.31 5,133.46 310.11 3,635.47 6,000,897.64 502,290.46 0.85 3,529.28 GYD -CT -CMS (1) 6,600.00 45.03 87.96 5,227.99 5,151.14 310.75 3,653.13 6,000,898.27 502,308.12 0.29 3,546.14 GYD -CT -CMS (1) 6,625.00 44.92 87.93 5,245.67 5,168.82 311.39 3,670.79 6,000,898.91 502,325.78 0.45 3,562.99 GYD -CT -CMS (1) 6,650.00 44.85 87.90 5,263.38 5,186.53 312.03 3,688.42 6,000,899.54 502,343.41 0.29 3,579.81 GYD -CT -CMS (1) 6,675.00 44.77 87.85 5,281.12 5,204.27 312.68 3,706.03 6,000,900.19 502,361.01 0.35 3,596.62 GYD -CT -CMS (1) 6,700.00 44.74 87.86 5,298.87 5,222.02 313.34 3,723.62 6,000,900.85 502,378.60 0.12 3,613.41 GYD -CT -CMS (1) 6,725.00 44.65 87.76 5,316.65 5,239.80 314.01 3,741.19 6,000,901.52 502,396.17 0.46 3,630.19 GYD -CT -CMS (1) 6,750.00 44.62 87.65 5,334.44 5,257.59 314.72 3,758.74 6,000,902.22 502,413.72 0.33 3,646.97 GYD -CT -CMS (1) 6,775.00 44.55 87.54 5,352.24 5,275.39 315.45 3,776.27 6,000,902.95 502,431.25 0.42 3,663.73 GYD -CT -CMS (1) 6,800.00 44.37 87.47 5,370.08 5,293.23 316.21 3,793.77 6,000,903.71 502,448.74 0.75 3,680.47 GYD -CT -CMS (1) 6,825.00 43.94 87.50 5,388.02 5,311.17 316.98 3,811.17 6,000,904.47 502,466.14 1.72 3,697.12 GYD -CT -CMS (1) 6,850.00 43.21 87.37 5,406.13 5,329.28 317.75 3,828.38 6,000,905.24 502,483.35 2.94 3,713.60 GYD -CT -CMS (1) I 6,875.00 42.91 87.25 5,424.40 5,347.55 318.55 3,845.43 6,000,906.04 502,500.40 1.24 3,729.93 GYD -CT -CMS (1) 1 6,900.00 42.76 87.16 5,442.73 5,365.88 319.38 3,862.41 6,000,906.86 502,517.38 0.65 3,746.21 GYD -CT -CMS (1) £ 6,925.00 42.40 87.19 5,461.14 5,384.29 320.21 3,879.30 6,000,907.69 502,534.27 1.44 3,762.40 GYD -CT -CMS (1) 6,950.00 41.75 87.04 5,479.70 5,402.85 321.06 3,896.04 6,000,908.53 502,551.00 2.63 3,778.45 GYD -CT -CMS (1) 6,975.00 41.57 86.90 5,498.37 5,421.52 321.93 3,912.63 6,000,909.41 502,567.59 0.81 3,794.38 GYD -CT -CMS (1) 11/3/2009 11 :40 :41AM Page 10 COMPASS 2003.16 Build 69 ConocoPhillips Iri tll 1 C ORlil Definitive Survey Report BAIGElt Alaska HUMUS Company '. , ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3H -33 ,,!. ) Project Kuparuk River Unit TVO Reference n 11 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: VT, Kuparuk 3H Pad MD ,3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) I Weld , ! '3H -33 North Reference: !True Wellbore: 3H -33 Survey Calculation Method :: Minimum Curvature Design 3H -33 D ^ EDM Alaska Prod v16 Surve� r ii * +__ Map' NMop DLS Vertical '= i, 1 MD Inc, '' Azi TVD * MOSS t / Northing Basting a ' Section J1�0') , ��uwey fiool Name Ahnotation #i 1 (ft) - (°) C) , i : ft) (ft) (ft (ft) (ft) (ft) ( (i't) 7,000.00 41.40 87.33 5,517.10 5,440.25 322.77 3,929.17 6,000,910.24 502,584.13 1.33 3,810.24 GYD -CT -CMS (1) 7,025.00 40.85 87.97 5,535.93 5,459.08 323.44 3,945.60 6,000,910.91 502,600.56 2.77 3,825.95 GYD -CT -CMS (1) 7,050.00 40.14 88.81 5,554.95 5,478.10 323.90 3,961.83 6,000,911.37 502,616.78 3.58 3,841.39 GYD -CT -CMS (1) 7,075.00 39.76 89.12 5,574.11 5,497.26 324.19 3,977.88 6,000,911.65 502,632.83 1.72 3,856.61 GYD -CT -CMS (1) ii 7,100.00 39.51 89.01 5,593.36 5,516.51 324.45 3,993.82 6,000,911.91 502,648.78 1.04 3,871.72 GYD -CT -CMS (1) 7,125.00 38.70 88.94 5,612.76 5,535.91 324.73 4,009.59 6,000,912.19 502,664.54 3.24 3,886.67 GYD -CT -CMS (1) 7,150.00 37.31 89.37 5,632.46 5,555.61 324.96 4,024.98 6,000,912.41 502,679.93 5.66 3,901.25 GYD -CT -CMS (1) a, 7,175.00 36.00 90.11 5,652.52 5,575.67 325.03 4,039.90 6,000,912.48 502,694.85 5.53 3,915.34 GYD -CT -CMS (1) 7,200.00 34.82 90.51 5,672.89 5,596.04 324.95 4,054.39 6,000,912.40 502,709.34 4.81 3,928.96 GYD -CT -CMS (1) 1' 7,225.00 34.06 90.89 5,693.51 5,616.66 324.78 4,068.52 6,000,912.23 502,723.47 3.16 3,942.22 GYD -CT -CMS (1) 7,250.00 33.66 90.85 5,714.27 5,637.42 324.57 4,082.45 6,000,912.01 502,737.40 1.60 3,955.27 GYD -CT -CMS (1) 7,275.00 33.22 90.59 5,735.13 5,658.28 324.39 4,096.23 6,000,911.84 502,751.17 1.85 3,968.19 GYD -CT -CMS (1) 7,300.00 32.23 89.94 5,756.16 5,679.31 324.33 4,109.74 6,000,911.77 502,764.69 4.20 3,980.91 GYD -CT -CMS (1) 7,325.00 31.60 89.47 5,777.38 5,700.53 324.40 4,122.96 6,000,911.83 502,777.90 2.71 3,993.38 GYD -CT -CMS (1) 7,350.00 31.14 89.41 5,798.73 5,721.88 324.53 4,135.97 6,000,911.96 502,790.91 1.84 4,005.68 GYD -CT -CMS (1) 7,375.00 30.86 89.51 5,820.16 5,743.31 324.65 4,148.85 6,000,912.08 502,803.79 1.14 4,017.86 GYD -CT -CMS (1) 0 7,400.00 30.61 89.54 5,841.65 5,764.80 324.75 4,161.62 6,000,912.18 502,816.56 1.00 4,029.93 GYD -CT -CMS (1) 7,425.00 30.46 89.55 5,863.18 5,786.33 324.85 4,174.32 6,000,912.28 502,829.26 0.60 4,041.93 GYD -CT -CMS (1) i1 7,450.00 30.33 89.72 5,884.74 5,807.89 324.93 4,186.97 6,000,912.36 502,841.91 0.62 4,053.88 GYD -CT -CMS (1) 7,475.00 30.34 89.72 5,906.32 5,829.47 325.00 4,199.60 6,000,912.42 502,854.53 0.04 4,065.79 GYD -CT -CMS (1) 7,500.00 30.00 89.83 5,927.94 5,851.09 325.05 4,212.16 6,000,912.47 502,867.10 1.38 4,077.65 GYD -CT -CMS (1) 7,525.00 29.49 89.92 5,949.64 5,872.79 325.07 4,224.57 6,000,912.49 502,879.50 2.05 4,089.34 GYD -CT -CMS (1) 7,550.00 28.92 90.22 5,971.46 5,894.61 325.06 4,236.77 6,000,912.47 502,891.70 2.35 4,100.83 GYD -CT -CMS (1) 7,575.00 28.25 90.40 5,993.42 5,916.57 324.99 4,248.73 6,000,912.41 502,903.66 2.70 4,112.08 GYD -CT -CMS (1) 7,600.00 27.78 90.57 6,015.49 5,938.64 324.89 4,260.47 6,000,912.31 502,915.40 1.91 4,123.11 GYD -CT -CMS (1) 7,625.00 27.48 90.87 6,037.64 5,960.79 324.75 4,272.06 6,000,912.16 502,926.99 1.32 4,133.99 GYD -CT -CMS (1) 7,650.00 27.18 91.11 6,059.84 5,982.99 324.55 4,283.54 6,000,911.96 502,938.46 1.28 4,144.73 GYD -CT -CMS (1) 7,665.00 27.02 91.32 6,073.20 5,996.35 324.41 4,290.37 6,000,911.81 502,945.29 1.24 4,151.12 MWD (2) 7,695.10 39.03 79.76 6,098.41 6,021.56 325.94 4,306.61 6,000,913.34 502,961.53 44.90 4,166.93 MWD (2) 7,725.69 51.39 72.96 6,119.94 6,043.09 331.18 4,327.61 6,000,918.58 502,982.53 43.33 4,188.47 MWD (2) L 7,754.60 63.61 68.48 6,135.44 6,058.59 339.27 4,350.55 6,000,926.67 503,005.47 44.23 4,212.80 MWD (2) li 11/3/2009 11:40:41AM Page 11 COMPASS 2003.16 Build 69 ConocoPhillips d� ConocoPtilllips Definitive Survey Report 1111111111t, , 1 Alaska PRIMES , iii a� � Cbrnp Con I , Local Co ordinate Reference 3H -33 I1;' Kuparuk River Unit TVb Refeernnce: , 3H -33 Ri Pro ct. g @ 76.85ft (D15 (40.75 +36.1)) Siiii = Kuparuk 3H Pad MD Reference �� A 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) W il: a 3H -33 North Reference ` True 'Wellb re , 3H -33 Survey Cal Method: � Minimum Curvature benign ,,, „ 3H-33 Database: w+' i.;,EDM Alaska Prod v16 6 TVDS M ap Ma ` Vertical �� 4'N!-$ +Ei 1N No rth i ng E Dl , Section = tu rvey' Tool Na ne ` ACtnotatl th � fE) C ° t t ° � '' ;' �t��,, �'� ' �� �a� (ft� � d "' (ft} � ��t�� (110 , (ft) ,�F i 7,784.16 76.24 56.51 6,145.60 6,068.75 352.14 4,375.01 ry 6,000,939.53 503,029.93 57.13 4,240.16 MWD (2) TIP 3H- 33AL1PB1 7,805.00 84.36 54.70 6,149.11 6,072.26 363.74 4,391.95 6,000,951.12 503,046.87 39.89 4,260.01 MWD (3) KOP 7,840.35 81.78 46.59 6,153.38 6,076.53 385.97 4,419.06 6,000,973.34 503,073.98 23.91 4,293.00 MWD (3) 7,870.51 85.76 40.44 6,156.66 6,079.81 407.70 4,439.68 6,000,995.07 503,094.61 24.18 4,319.71 MWD (3) 7,900.39 89.63 36.78 6,157.86 6,081.01 431.02 4,458.31 6,001,018.39 503,113.23 17.82 4,345.07 MWD (3) r 7,930.59 92.95 33.06 6,157.18 6,080.33 455.77 4,475.59 6,001,043.13 503,130.52 16.51 4,369.64 MWD (3) 7,960.78 95.78 28.71 6,154.88 6,078.03 481.59 4,491.03 6,001,068.95 503,145.97 17.15 4,392.85 MWD (3) 7,990.59 96.90 24.23 6,151.59 6,074.74 508.11 4,504.24 6,001,095.46 503,159.17 15.40 4,414.17 MWD (3) 8,020.50 96.37 18.94 6,148.13 6,071.28 535.72 4,515.16 6,001,123.07 503,170.10 17.66 4,433.72 MWD (3) 8,050.64 96.18 14.50 6,144.83 6,067.98 564.41 4,523.78 6,001,151.75 503,178.72 14.66 4,451.45 MWD (3) 8,080.62 93.84 11.10 6,142.22 6,065.37 593.53 4,530.39 6,001,180.86 503,185.34 13.73 4,467.43 MWD (3) 8,110.70 89.45 8.42 6,141.35 6,064.50 623.15 4,535.49 6,001,210.48 503,190.44 17.10 4,482.16 MWD (3) 8,140.64 87.61 4.33 6,142.12 6,065.27 652.89 4,538.81 6,001,240.21 503,193.77 14.97 4,495.25 MWD (3) 8,170.45 86.22 359.30 6,143.73 6,066.88 682.63 4,539.75 6,001,269.95 503,194.72 17.48 4,506.10 MWD (3) E 8,200.65 86.96 354.54 6,145.52 6,068.67 712.72 4,538.13 6,001,300.04 503,193.10 15.92 4,514.66 MWD (3) 8,230.67 86.41 349.78 6,147.26 6,070.41 742.40 4,534.05 6,001,329.72 503,189.02 15.94 4,520.75 MWD (3) 8,260.60 86.62 349.03 6,149.08 6,072.23 771.77 4,528.55 6,001,359.09 503,183.54 2.60 4,525.41 MWD (3) 8,290.80 90.21 353.57 6,149.92 6,073.07 801.60 4,523.99 6,001,388.91 503,178.98 19.16 4,531.11 MWD (3) 8,320.61 93.96 358.25 6,148.83 6,071.98 831.30 4,521.87 6,001,418.61 503,176.86 20.11 4,539.06 MWD (3) 8,350.44 94.27 2.69 6,146.69 6,069.84 861.04 4,522.11 6,001,448.35 503,177.11 14.88 4,549.25 MWD (3) 8,380.53 94.21 7.39 6,144.46 6,067.61 890.92 4,524.75 6,001,478.23 503,179.75 15.58 4,561.74 MWD (3) 8,410.58 93.16 12.16 6,142.53 6,065.68 920.47 4,529.84 6,001,507.77 503,184.84 16.22 4,576.44 MWD (3) 8,440.53 93.04 17.08 6,140.91 6,064.06 949.40 4,537.38 6,001,536.70 503,192.39 16.41 4,593.24 MWD (3) 8,470.55 91.63 22.30 6,139.69 6,062.84 977.63 4,547.48 6,001,564.92 503,202.50 18.00 4,612.22 MWD (3) 8,500.47 88.62 26.17 6,139.62 6,062.77 1,004.90 4,559.76 6,001,592.19 503,214.78 16.39 4,632.92 MWD (3) = 8,530.48 86.35 30.41 6,140.94 6,064.09 1,031.29 4,573.97 6,001,618.58 503,228.99 16.01 4,655.15 MWD (3) 8,560.64 87.64 35.94 6,142.52 6,065.67 1,056.49 4,590.44 6,001,643.77 503,245.47 18.80 4,679.11 MWD (3) 8,590.61 86.50 41.21 6,144.05 6,067.20 1,079.88 4,609.10 6,001,667.16 503,264.13 17.97 4,704.53 MWD (3) 1 8,620.41 87.21 46.95 6,145.69 6,068.84 1,101.25 4,629.79 6,001,688.52 503,284.82 19.38 4,731.18 MWD (3) 8,650.42 87.42 52.63 6,147.10 6,070.25 1,120.59 4,652.67 6,001,707.86 503,307.70 18.92 4,759.22 MWD (3) 8,680.47 88.13 58 07 6 148 26 6 071 41 1 4,677.36 6,001,724.92 503,332.40 18.24 4,788.20 MWD (3) 11/3/2009 11:40:41AM Page 12 COMPASS 2003.16 Build 69 ConocoPhillips Ir C QPhII� PS Definitive Survey Report BILKIElt IflICOIMES , ConocoPhillips(Alaska) Inc. Local Co-ordinate RRference: . 3H -33 N 3 P roj e c t : ,I P Kuparuk River Unit �TVD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad MCf Ref rence: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) i. Welh s� 3H -33 North Reference: . True Wellbore: i 3H -33 Survey Calculation Method: Minimum Curvature Design 3H 33 Database. EDM Alaska Prod vi6 , , Ma p Map vertical � ` I MCi -' nc 1zi : V D TVDSS +N1-S +E/-W . Northing Fasting . „. Sedtion , .Survey Tool Name Annotation r (if ( e ) `T 0) a; (f (ft) { ft) ) A / '' (ft); ° i /10 , ;l 3 � k 8 710.78 86.93 63.1 6,149.57 6,072.72 1,152.52 4,703.74 6,001,739.77 503,358.77 17.14 4,818.03 MWD ( h a 8,740.61 87.08 61.57 6,151.13 6,074.28 1,166.34 4,730.12 6,001,753.59 503,385.16 5.25 4,847.52 MWD (3) 8,770.64 88.89 57.06 6,152.19 6,075.34 1,181.66 4,755.92 6,001,768.89 503,410.96 16.17 4,876.96 MWD (3) 8,800.48 87.42 53.14 6,153.15 6,076.30 1,198.72 4,780.38 6,001,785.95 503,435.41 14.02 4,905.72 MWD (3) 8,836.48 89.02 47.43 6,154.27 6,077.42 1,221.70 4,808.05 6,001,808.92 503,463.08 16.46 4,939.49 MWD (3) 8,865.78 88.40 42.33 6,154.93 6,078.08 1,242.45 4,828.71 6,001,829.66 503,483.75 17.53 4,965.91 MWD (3) 8,895.86 88.43 36.96 6,155.76 6,078.91 1,265.59 4,847.89 6,001,852.80 503,502.93 17.85 4,991.73 MWD (3) 8,925.81 89.36 31.93 6,156.34 6,079.49 1,290.28 4,864.82 6,001,877.48 503,519.86 17.08 5,015.96 MWD (3) 8,955.90 89.20 26.47 6,156.72 6,079.87 1,316.53 4,879.49 6,001,903.73 503,534.54 18.15 5,038.58 MWD (3) 1 8,985.71 88.49 20.80 6,157.32 6,080.47 1,343.82 4,891.43 6,001,931.02 503,546.48 19.17 5,058.97 MWD (3) 9,015.66 90.12 16.08 6,157.68 6,080.83 1,372.23 W 4,900.90 6,001,959.42 503,555.96 16.67 5,077.41 MWD (3) 9,045.69 89.57 10.92 6,157.76 6,080.91 1,401.42 4,907.91 6,001,988.60 503,562.97 17.28 5,093.79 MWD (3) 9,075.79 89.39 7.16 6,158.03 6,081.18 1,431.14 4,912.64 6,002,018.32 503,567.70 12.51 5,108.20 MWD (3) 9,105.70 88.04 2.09 6,158.71 6,081.86 1,460.93 4,915.05 6,002,048.11 503,570.12 17.54 5,120.46 MWD (3) 9,135.76 88.90 356.25 6,159.51 6,082.66 1,490.96 4,914.62 6,002,078.14 503,569.69 19.63 5,130.11 MWD (3) 9,165.78 89.51 351.67 6,159.93 6,083.08 1,520.81 4,911.46 6,002,107.98 503,566.54 15.39 5,137.13 MWD (3) 9,195.87 87.45 348.05 6,160.72 6,083.87 1,550.41 4,906.16 6,002,137.58 503,561.25 13.84 5,142.06 MWD (3) 9,225.59 84.68 345.83 6,162.76 6,085.91 1,579.29 4,899.47 6,002,166.46 503,554.56 11.93 5,145.42 MWD (3) N I 9,255.64 81.47 344.60 6,166.39 6,089.54 1,608.13 4,891.86 6,002,195.30 503,546.95 11.43 5,147.92 MWD (3) 9,285.53 79.88 340.74 6,171.23 6,094.38 1,636.28 4,883.07 6,002,223.44 503,538.18 13.81 5,149.07 MWD (3) 9,315.53 80.38 335.74 6,176.38 6,099.53 1,663.72 4,872.12 6,002,250.88 503,527.23 16.50 5,147.94 MWD (3) i 9,342.65 79.79 330.70 6,181.05 6,104.20 1,687.56 4,860.09 6,002,274.73 503,515.20 18.44 5,144.59 MWD (3) 9,382.00 79.79 330.70 6,188.02 6,111.17 1,721.33 4,841.14 6,002,308.50 503,496.26 0.00 5,138.05 PROJECTED to TD 11/3/2009 11:40:41AM Page 13 COMPASS 2003.16 Build 69 n' ` pp gg c { ggp�Q SEAN PARNELL, GOVERNOR 4 1 h :4,e�' C.:.b L k v ..=:9 F:U . ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 " FAX (907) 276 -7542 Mr. V. Cawvey Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -33AL2 ConocoPhillips Alaska, Inc. Permit No: 209 -105 Surface Location: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 630' FSL, 182' FEL, Sec. 1, T12N, RO8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new welbore segment of existing well KRU 3H -33A, Permit No. 209103. API No. 50- 103 - 2057801 -00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Ca a 4F , . Fo erster Cossioner DATED this /GA- day of September, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. yA l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION • PERMIT TO DRILL • 20 AAC 25.005 la. Type of Woric 1b. Current Well Class: Exploratory ❑ Development OA l0 lc. Specify If well Is proposed for. Dm ❑ Re -drill El Strallgraphic Test ❑ Service n r , Development Gas • Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone Single Zone fq Shale Gas ❑ 2. Operator Name: 5. Band: 0 Blanket II Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59 - 180 3H - 33AL2 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9275' ' TVD: 6073' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM ADL 25531 Kuparuk River 011 Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 535' FNL, 463' FEL, Sec. 12, T12N, RO8E, UM 2657 10/15/2009 Total Depth: 9. Acres In Property: 14. Distance to 630' FSL, 182' FEL, Sec. 1, T12N, RO8E, UM 2580 Nearest Property: 18300' 4b. Location of Well (State Base Plane Coordinates - HAD 27): 10. KB Elevation above MSL: 77 feet 15. Distance to Nearest Well Open Surface: x - 498655 y - 6000588 Zone 4 KB Elevation above 01: 36 feet to Same Pool: 311-146 , 1200' 18. Deviated welts: Kickoff depth: 7665 ft. 17. Maximum Anticipated Pressures In prig (see 20 MC 25.035) Maximum Hole Angle: 94° deg Downhole: 4126 pslg Surface: 3473 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Including stage data) 3" 2.375" 4.7# L - 80 ST - L 1225' 8050' 6074' 9275' 6073' slotted / solid liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 8020' 6396' 7935' 6318' Casing Length Size Cement Volume MD TVD Conductor /Structural 113' 16" 97 sx AS 1 149' 149' Surface 4279' 9 - 5/8" 840 sxASLlte, 178 sx LiteCRETE 4315' 3614' Intermediate Production 7984' 7" 309 sx Class G 8020' 6396' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7740' -7760' 6140' -6158' 20. Attachments: Filing Fee ❑ BOP Sketch Drilling Program l0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch El Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 283 - 4172 Printed Nadi V. Cawve Title Wells Manager Signature 7, Phone: 265 -6306 Date 9'i y Commission Use Only / Permit to Drill API Number: Permit Approv I See cover letter Number. 4:2 ,?09 0 /QS loo /D 91 I Date: *? 4: . , R for other requirements produce hydrates, ry Conditions of approval : if box is checked, well may not be used to explore for, test or prod coklbeded mef ane ( , gas Y drates, or gas contained In shales: L7 L J � c ' 4 60 P 7cs�- Samples req'd: Yes ❑ No Mud log req'd: Yes El No p" Other: 1 V P H2S measures: Yes 1[ ' No ❑ Directional svy req'd: Yes Er No ❑ Z sea rs A h K T CM:",,) Q . e v, i A PPRO ED BY THE COMMISSION ONER DATE: /7 2 7/ Q -D Form 10-401 (Revised 1/2009) Submit in Duplicate 0 R I G t,! L j-e,___?:zci.c,7 • i KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Summary of Operations: Well 3H -33 is a 3'/2" tubing x 7" casing producer in the Kuparuk A -sand. Four proposed CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling, the existing A -Sand perfs in 3H -33 will be squeezed with cement to provide a means to kick out of the 7" casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 7725' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 3H -33A sidetrack will exit the 7" casing at 7685' MD and will target the A2 sand south of the existing well with a 2365' lateral. The hole will be completed with a 2W slotted liner to the TD of 10,050' MD with a liner top aluminum billet at 8100' MD. The 3H -33AL1 lateral will kick off from the aluminum billet at 8100' MD and will target the A3 sand south of the existing well with a 1950' lateral. The hole will be completed with a 2 slotted liner to the TD of 10,050' MD with the final liner top located just inside the 7" casing at 7680' MD. The 3H -33AL2 lateral will exit the 7" casing at 7665' MD via a second mechanical whipstock placed in the cement pilot hole. It will target the A2 sand north of the existing well with a 1610' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9275' MD with a liner top aluminum billet at 8050' MD. The 3H- 33AL2 -01 lateral will kick off from the aluminum billet at 8050' MD and will target the A3 sand north of the existing well with an 1225' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9275' MD with the final liner top located just inside the 3'/2" tubing at 7560' MD. CTD Drill and Complete 3H -33: October/November 2009 Pre -Rig Work 1. Test packoffs — T & IC. 2. Positive pressure and drawdown tests on MV, SV, & SSSV. 3. DGLV's, load tbg & IA. MIT -IA. MIT -OA. 4. Obtain updated static BHP on A -sand 5. Shoot tubing punches in 3'/2" tubing tail at 7575' MD. 6. Plug the A -Sand perfs with cement up to 7575' MD. 7. RU slickline. Tag cement top. 8. Prep site for Nabors CDR2 -AC. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7 -1/16" BOPE, test. 2. 3H -33A Lateral (A2 sand, south) a. Drill 2.74" high -side pilot hole through cement to 7725 MD'. b. Drift pilot hole with whipstock dummy. c. Set 3'/2" monobore whipstock at 7685' MD with high -side orientation. d. Mill 2.74" window with high -side orientation at 7685' MD. e. Drill 2.70" x 3" bi- center lateral to TD of 10,050' MD. f. Run 2 slotted liner with an aluminum liner -top billet from TD up to 8100' 3. 3H -33AL1 Lateral (A3 sand, south) a. Kick off of the aluminum billet at 8100' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,050' MD. c. Run 2 slotted liner from TD up to 7680' MD, up inside the 7" casing Page 1 of 4 ORIGINAL s September 16, 2009, FINAL • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling 4. 3H -33AL2 Lateral (A2 sand, north) a. Set 3'/2" monobore whipstock in cement pilot hole at 7665' MD with high -side orientation. b. Mill 2.74" window with high -side orientation at 7665' MD. ki5 c. Drill 2.70" x 3" bi- center lateral to TD of 9275' MD. d. Run 2 slotted liner with an aluminum liner -top billet from TD up to 8050' o 5. 3H- 33AL2 -01 Lateral (A3 sand, north) a. Kick off of the aluminum billet at 8050' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9275' MD. c. Run 2%" slotted liner from TD up to 7560' MD, up inside the 31/2" tubing tail 6. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Obtain static BHP 2. Run GLVs. 3. Return well to production. Mud Program: • Will use chloride -based Biozan brine or used drilling mud (8.6 ppg) for milling operations, and chloride - based Flo -Pro mud ( -10.0 ppg) for drilling operations. There is a SCSSV installed in 3H -33, so we should not have to kill the well to deploy 2 slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 3H -33A: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 8100' MD to 10,050' MD • 3H- 33AL1: 2 4.7 #, L -80, ST -L slotted /solid liner from 7680' MD to 10,050' MD • 3H- 33AL2: 2% ", 4.7 #, L -80, ST -L slotted/solid liner from 8050' MD to 9275' MD • 3H- 33AL2 -01: 2 ", 4.7 #, L -80, ST -L slotted/solid liner from 7560' MD to 9275' MD Existing Casing/Liner Information Surface: 9% ", L -80, 40 ppf Burst 5750 psi; Collapse 3090 psi Production: 7 ", L -80, 26 ppf Burst 7240 psi; Collapse 5410 psi Well Control: • Two well bore volumes (-200 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure in 3H -33 is 3473 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity, which is 4126 psi at 6156 TVD (i.e. 12.9 ppg) in offset injector 3A- 15 in January 2009. Well 3A -15 had been shut -in several months when this survey was taken. • The annular preventer will be tested to 250 psi and 2500 psi. Page 2 of 4 r 1N i \ L September 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 3H -33A, plan #1 2. 3H- 33AL1, plan #2 3. 3H- 33AL2, plan #1 4. 3H- 33AL2 -01, plan #2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3H -33 CTD southern laterals (A & AL1): —18,300' to property line, 1500' from well 3H -11 • 3H -33 CTD northern laterals (AL2 & AL2 -01): —18,300' to property line, 1200' from well 3H -14B Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 311-33 was taken June 2009 after a 72 -hour shut -in, which measured reservoir pressure of 3175 psi at 6010' TVD, corresponding to 10.2 ppg EMW. Expect to encounter increasing pressure as the laterals are drilled away from the mother well due to anticipated interaction with injection well 3A -15. 3A -15 was recently shut in to allow the area to de- pressurize. The most recent pressure survey in 3A -15 showed 4126 psi at 6156 TVD (12.9 ppg EMW) as of January 2009. Hazards • Lost circulation is not expected to be particularly troublesome. Expect to encounter increasing pressure as the laterals are drilled away from the mother well. • Over- pressured zones are a potential hazard in 3H -33. Even with 10.0 ppg mud, choke pressure will have to be maintained while drilling, both for maintaining well control and borehole stability. Use of the SSSV to deploy slotted liner should eliminate the need to spot heavy kill weight fluid, but if the SSSV fails then completion fluids in excess of 13.0 ppg will be needed to kill the well. • Shale stability is a potential problem, particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 60° hole angle, and by holding a constant 13.1 ppg EMW on the formation throughout drilling operations. • Well 3H -33 has 115 ppm H as measured on 5/6/06. Well 3H -17 is located 12.5' to the right side and 3H -18 is 12.5' to the left side of the 3H -33 surface location. Neither 3H -17 nor 3H -18 has any measured H since they are both injectors. The maximum H level on the pad is 390 ppm from well 3H -16 (2/24/09), which is 38' to the right of 311-33. All H monitoring equipment will be operational. Page 3 of 4 t September 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2 pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 3H -33 has a SCSSV, so the well should not have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Maximum expected reservoir pressure (i.e. formation pressure encountered from originally drilled 3H- 33): 4054 psi at 7685' MD (6091' TVD), or 12.8 ppg EMW. • Expected annular friction losses while circulating: 507 psi (assuming friction of 66 psi /1000 ft due to the 3'h" tubing) • Planned mud density of 10.0 ppg equates to 3167 psi hydrostatic bottom hole pressure at 6091' TVD • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 3674 psi or 11.6 ppg EMW without holding any additional surface pressure. This alone is insufficient to overbalance expected formation pressure in 3H -33, so as much as 380 psi choke pressure will be required while drilling to maintain overbalance. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, —900 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Page 4 of 4 OP j ` 1 G f Ni September 16, 2009, FINAL • C onocoPhilli ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33 3H -33AL2 Plan: Plan 1, 3H -33AL2 Standard Planning Report 11 September, 2009 13AKER HUGHES r°` P, • • ConocoPhillips Conoc©Phillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H -33 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level 1 Project: Kuparuk River Unit MD Reference: 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: = True Well: 31-1-33 Survey Calculation Method: Minimum Curvature Wellbore: : 3H -33AL2 Design: Plan 1, 3H -33AL2 ; Project Kuparuk River Unit, North Slope Alaska United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor r Site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73ft Latitude: 70° 24' 41.531 N From: Map Easting: 498,655.44ft Longitude: 150° 0' 39.416 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well , 3H-33 Well Position +N / -S 0.00 ft Northing: 6,000,588.21 ft Latitude: 70° 24' 46.228 N +E/ -W 0.00 ft Easting: 498,655.30 ft Longitude: 150° 0' 39.423 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 36.10ft Welibore '- 3H -33AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength f (°) (1 (nT) BGGM2009 11/4/2009 17.26 79.81 57,352 Design Plan 1, 3H -33AL2 ,. . Audit Notes: ! Version: Phase: PLAN Tie On Depth: 7,650.00 Vertical Sectiorc Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) -36.10 0.00 0.00 20.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +t4/-S +E/ -W Rate Rate Rate TFO (ft) r) r) (ft) (ft) (ft) r /loofa r/1ooft) ( °MOOft) r) Target 7,650.00 27.18 91.11 5,982.99 324.55 4,283.54 0.00 0.00 0.00 0.00 7,665.00 27.02 91.32 5,996.35 324.41 4,290.37 1.24 -1.07 1.40 149.22 7,680.00 28.37 91.32 6,009.63 324.25 4,297.34 9.00 9.00 0.00 0.00 I 7,710.00 41.87 91.32 6,034.11 323.85 4,314.55 45.00 45.00 0.00 0.00 7,740.00 53.90 83.01 6,054.21 325.10 4,336.70 45.00 40.11 -27.69 330.00 7,859.33 94.00 44.78 6,087.69 377.07 4,433.67 45.00 33.60 -32.04 310.00 8,159.33 94.00 8.69 6,066.05 639.90 4,566.07 12.00 0.00 -12.03 271.30 i 8,309.33 89.98 351.13 6,060.80 789.19 4,565.81 12.00 -2.68 -11.71 257.50 8,509.33 83.94 14.40 6,071.56 987.21 4,575.27 12.00 -3.02 11.64 105.00 8,709.33 90.08 37.65 6,082.15 1,165.32 4,662.36 12.00 3.07 11.62 76.00 9,034.33 91.26 358.66 6,078.21 1,468.18 4,761.69 12.00 0.36 -12.00 271.90 9,275.00 91.10 27.55 6,073.16 1,700.06 4,815.67 12.00 -0.06 12.00 90.00 9/11/2009 8 :05 :35AM Page 2 COMPASS 2003.16 Build 69 l 1 t, z4 I ConocoPhillips rsau Conoco Phillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3H - 33 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: True Welt: 3H -33 Survey Calculation Method.. Minimum Curvature Welibore: 3H - 33AL2 D gn; Plan 1, 3H -33AL2 Planned Survey - _ Measured TVD Below Vertical Dogleg u . " Tootface M ap Map Depth Inclination Azimuth System +W3 +E!-W S Rate Ilz t o ) Northing Eastt (ft) (•) l°) ( f t ) ( (ft) (ft) ( °I1 C) (ft) (ft 7,650.00 27.18 91.11 5,982.99 324.55 4,283.54 1,770.03 0.00 0.00 6,000,911.96 502,938.46 TIP 3H - 33 • 7,665.00 27.02 91.32 5,996.35 324.41 4,290.37 1,772.23 1.24 149.22 6,000,911.81 502,945.29 KOP 7,680.00 28.37 91.32 6,009.63 324.25 4,297.34 1,774.47 9.00 0.00 6,000,911.65 502,952.26 i End of DLS 9 1 7,700.00 37.37 91.32 6,026.41 324.00 4,308.18 1,777.94 45.00 0.00 6,000,911.40 502,963.10 7,710.00 41.87 91.32 6,034.11 323.85 4,314.55 1,779.98 45.00 0.00 6,000,911.25 502,969.48 4 7,740.00 53.90 83.01 6,054.21 325.10 4,336.70 1,788.73 45.00 -30.00 6,000,912.50 502,991.62 5 7,800.00 73.19 61.71 6,081.06 341.97 4,386.98 1,821.78 45.00 -50.00 6,000,929.36 503,041.90 7,859.33 94.00 44.78 6,087.69 377.07 4,433.67 1,870.73 45.00 -40.29 6,000,964.44 503,088.60 End of DLS 45 7,900.00 94.10 39.89 6,084.81 407.05 4,460.99 1,908.25 12.00 -88.70 6,000,994.42 503,115.91 8,000.00 94.20 27.86 6,077.55 489.70 4,516.48 2,004.90 12.00 -89.05 6,001,077.05 503,171.41 8,100.00 94.13 15.83 6,070.26 582.11 4,553.52 2,104.40 12.00 -89.92 6,001,169.44 503,208.46 8,159.33 94.00 8.69 6,066.05 639.90 4,566.07 2,163.00 12.00 -90.80 6,001,227.22 503,221.03 7 8,200.00 92.93 3.92 6,063.59 680.24 4,570.53 2,202.43 12.00 - 102.50 6,001,267.56 503,225.49 8,300.00 90.23 352.22 6,060.82 779.96 4,567.16 2,294.99 12.00 - 102.79 6,001,367.27 503,222.14 8,309.33 89.98 351.13 6,060.80 789.19 4,565.81 2,303.20 12.00 - 103.11 6,001,376.50 503,220.79 8 8,400.00 87.18 1.65 6,063.06 879.52 4,560.11 2,386.13 12.00 105.00 6,001,466.82 503,215.11 8,500.00 84.20 13.31 6070.60 978.21 4,573.05 2,483.29 12.00 104.74 6,001,565.50 503,228.06 8,509.33 83.94 14.40 6, 987.21 4,575.27 2,492.51 12.00 103.86 6,001,574.50 503,230.29 9 8,600.00 86.66 24.98 6,079.02 1,072.16 4,605.69 2,582.74 12.00 76.00 6,001,659.44 503,260.71 8,700.00 89.78 36.57 6,082.14 1,157.88 4,656.74 2,680.75 12.00 75.13 6,001,745.14 503,311.77 8,709.33 90.08 37.65 6,082.15 1,165.32 4,662.36 2,689.66 12.00 74.77 6,001,752.57 503,317.40 10 8,800.00 90.43 26.77 6,081.74 1,241.92 4,710.62 2,778.15 12.00 -88.10 6,001,829.16 503,365.67 ■ 8,900.00 90.81 14.78 6,080.65 1,335.24 4,746.02 2,877.95 12.00 -88.15 6,001,922.47 503,401.09 9,000.00 91.15 2.78 6,078.94 1,433.88 4,761.26 2,975.85 12.00 -88.28 6,002,021.09 503,416.33 9,034.33 91.26 358.66 6,078.21 1,468.18 4,761.69 3,008.24 12.00 -88.49 6,002,055.39 503,416.77 11 9,100.00 91.24 6.54 6,076.78 1,533.72 4,764.67 3,070.84 12.00 90.00 6,002,120.92 503,419.76 9,200.00 91.18 18.55 6,074.66 1,631.14 4,786.35 3,169.79 12.00 90.17 6,002,218.32 503,441.46 9,275.00 91.10 27.55 6,073.16 1,700.06 4,815.67 3,244.59 12.00 90.43 6,002,287.23 503,470.79 TD 9/11/2009 8.05.35AM Page 3 COMPASS 2003.16 Build 69 0 R /.. ConocoPhillips Vat ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3H Company: ' ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: ' 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: i True Well: 3H - 33 Survey Calculation Method: a Minimum Curvature Wellborn: 3H - 33AL2 Design; " _ Plan 1, 31 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting - = " ShaP• ; r) ` (*) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3H - A2 N t4.1 (cop) 0.00 0.00 6,073.15 1,687.46 4,822.06 6,002,274.64 503,477.18 70° 25' 2.808 N 149° 58' 18.036 W - plan misses target center by 11.44ft at 9265.90ft MD (6073.34 TVD, 1691.96 N, 4811.54 E) - Point 3H -33 A2 N t1.1 (cop) 0.00 0.00 6,105.15 475.29 4,401.21 6,001,062.66 503,056.16 70° 24' 50.889 N 149° 58' 30.397 W - plan misses target center by 92.11 ft at 7921.84ft MD (6083.25 TVD, 424.07 N, 4474.57 E) - Point 3H -33 A2 N t3.1 (cop) 0.00 0.00 6,082.15 1,177.39 4,657.13 6,001,764.65 503,312.17 70° 24' 57.793 N 149° 58' 22.882 W - plan misses target center by 11.51ft at 8716.76ft MD (6082.13 TVD, 1171.24 N, 4666.86 E) - Point 3H -33 A2 N t2.1 (cop) 0.00 0.00 6,061.15 793.34 4,523.18 6,001,380.65 503,178.16 70° 24' 54.017 N 149° 58' 26.816 W - plan misses target center by 41.71ft at 8316.17ft MD (6060.82 TVD, 795.96 N, 4564.81 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name r) . " (") 4,315.06 3,532.90 9 5/8" 9 -5/8 12 -1/4 9,275.00 6,073.16 2 3/8" 2 -3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +W$ +EI-W (ft) (ft) (ft) (ft) Comment 7,650.00 5,982.99 324.55 4,283.54 TIP 31-1-33 7,665.00 5,996.35 324.41 4,290.37 KOP 7,680.00 6,009.63 324.25 4,297.34 End of DLS 9 7,710.00 6,034.11 323.85 4,314.55 4 7,740.00 6,054.21 325.10 4,336.70 5 7,859.33 6,087.69 377.07 4,433.67 End of DLS 45 8,159.33 6,066.05 639.90 4,566.07 7 8,309.33 6,060.80 789.19 4,565.81 8 8,509.33 6,071.56 987.21 4,575.27 9 8,709.33 6,082.15 1,165.32 4,662.36 10 9,034.33 6,078.21 1,468.18 4,761.69 11 9,275.00 6,073.16 1,700.06 4,815.67 TD 9/11/2009 8:05.35AM Page 4 COMPASS 2003.16 Build 69 6maa,tn.0T9,eNerm WELLBORE DETAILS: 3H -33AL2 REFERENCE INFORMATION ^- Project: Kuparuk River Unit Magnetic Norm 1726° y . Site: Kuparuk 3H Pad M.9nehc Field Wellbore: 311 Co-ordinate (WE) Reference. Well 3H-33, True North If +. • �+/J Well: 311-33 Strengt5 57352.409 Tie on MD: 7650.00 Vertical (TVD) Reference: Mean Sea Level � �� Coco i i y"� ^!!A/^^t1� � [ [p`�rL" Wellbore: 3H( 3AL2 Plan: Plan 1, 3H33AL2 3H 33/3H.13AL2 ' DD Angle: 281 Measured (VS) Re Slot • ( R19 5 76.850 o Dare 11/4/20 : 79.8 • Do eccMZ Measured Depth Reference: 3H-33 Rig 78.S5R (D15 (40.75 +36.1)) HUGHES r Calculation Method: Minimum Curvaure Alaska 1800- .. 311-33/3H -33AL2 'I'D WELL DETAILS: 3H -33 1700 ',_. _.. __.. _._ _.. Ground Level: 36.10 +N / -S +E / -W Northing Easting Latittude Longitude Slot 1600- 0.00 0.00 6000588.21 498655.30 70° 24' 46.228 N 150° 0' 39.423 W SECTION DETAILS ANNOTATIONS 1500 Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec T. get Annotation 1400 1 l 1 7650.00 27.18 91.11 5982.99 324.55 4283.54 0.00 0.00 1770.03 TIP 3H-33 2 7665.00 27.02 91.32 5996.35 324.41 4290.37 1.24 149.22 1772.23 KOP 1300- 3 7680.00 28.37 91.32 6009.63 324.25 4297.34 9.00 0.00 1774.47 End of DLS 9 i 4 7710.00 41.87 91.32 6034.11 323.85 4314.55 45.00 0.00 1779.98 4 5 7740.00 53.90 83.01 6054.21 325.10 4336.70 45.00 330.00 1788.73 5 1 200 6 7859.33 94.00 44.78 6087.69 377.07 4433.67 45.00 310.00 1870.73 End of DLS 45 p 7 8159.33 94.00 8.69 6066.05 639.90 4566.07 12.00 271.30 2163.00 7 .1100 10 8 8309.33 89.98 351.13 6060,80 789.19 4565.81 12.00 257.50 230320 8 • 9 8509.33 83.94 14.40 6071.56 987.21 4575.27 12.00 105.00 2492.51 9 000 10 8709.33 90.08 37.65 6082.15 1165.32 4662.36 12.00 76.00 2689.66 10 11 9034.33 91.26 358.66 6078.21 1468.18 4761.69 12.00 271.90 3008.24 11 0 900 9 12 9275.00 91.10 27.55 6073.18 1700.06 4815.67 12.00 90.00 3244.59 TD C ` 800 � O _.... -» fn 700 .. 600 ,'. 7 ......' End of DLS 9 --.� 500 + I,. KOP End of DLS 45 400 TIP 3H -33 '., 4 5 311 ;11 3 ?. ?H 11-33A 3H- 33/3H -33AL1 _ 300 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5206 5400 5500 5600 West( -) /East( +) (100 ft /in) 5800 -. _- ._ _.. _...... _. 5850- p 5900 - T IP 311-33 ' KOP O 5950. End of DLS 9 6000 -. y m 3H 31/3H -33ALI A _ 6050. : a 5 End of DLS 45 7 8 10 N -1 11 Pii TD O m 6100 • + '- ' ?;1 31 -34/3 H -33AL2 6]50 - _ CD .. -. ......... _....... _. -.._. _....... _.... __._ ......... 6200 6250- - .. 6300 -i -11 311 -;; 6350 -- 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 31 00 3150 3200 3250. 3300 3350 3400 Vertical Section at 20.00° (50 ft/in) Azimuths to True North WELLBORE DETAILS: 31-I-33AL2 REFERENCE INFORMATION Project: Kuparuk River Unit Magnetic North: 21.85° Site: Kuparuk 3H Pad Magrre6c F Parent Wellbore: 3H -33 Coordinate (WE) Reference. Well 3H-33, True North Well: 3H-33 Strength 57642.3807 TIe on MD: 7650 V ( ND ) R e f erence. 3H-33 Ri @ 76 (D15 (40 +36 BAKER "� Dip Angle eo.e7° Section (VS) Reference: Slot - (0.008, 0.00E) Welibore: 3HJ3 Date.. 11/4/2009 Measured Depth Reference: 311-33 Rig @ 76.851/ (015 (40.75 +36.11) COCIUCOPh ilipS Plan: Plan 7, 3H33AL2 (3H Dip eGGM2006 HUGHES Calculation Mellad: Minimum Curvature 3 H- 14/311- 1413L1, 6r6 /11- 14`.±16 - 1 41314 3450 -_. _... _._ ......_ _.._ _._ ....... ..... _.. ... 3300- 3150-.. . I,,... 3000- : s 3H- 14/1H -14 6 /0 0 , . .. 2850- s -0 31-1- 14'3H -14APB 1 2700 3H- 14/4H -14A � 7 1g N) 311- 14/311 -14B 2 • 550 :c - - , 6, 2400_ : : OD G 2250- .. 2100- C 1 950 - 1800 _....... _...... _... _.. ....._ _... :. _.. ...... -. ___. ___. 0 3H -33/3H -33AL2 kr) ,.__. -..,. X1650- 5, /y.0. X1500- 1. 01350- 1200- _... 1050 900 • 750 600 450 E S 0 a e . 313- 33/31 300- - ', '.. __. _. __... _. __... _ __ .. ...... .......... __. _.... 0. +1111311-11 ' - 150 - -300- _- --' 1 = ,.. -_ .— 311- 33/311 -33A 3H- 33/3H -33AL1 - 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 - 3300 3450 3600 3750 3900 4050 4200 4350 4500 4650 4800 4950 5100 5250 5400 5550 5700 5850 6000 6150 6300 6450 6600 6750 6900 7050 7200 3H - 33 Rig @ 76.85ft (D15 (40.75 +36.1)) West( -) /East( +) (150 ft /in) 3H - 33 Proposed CTD Sidetrack 3 -1/2" Cameo TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) L 3 -1/2 ", 9.3#, L -80 EUE 8rd Tubing to surface 16 ", 62#, H -40 conductor 3 -112" Camco MMG gas lift mandrels at 2735, 4444', 5710', 6789', & 7453' shoe 149' MD 9 -58 ", 40#,. L -80 casing „mils shoe at 4315' MD • X- nipple at 7504' MD (2.813" min ID) Baker Premier packer at 7547' MD. No sealbore or seal assembly. Cameo D- nipple @ 7594 MD (2.75" min ID, No -Go) Nipple milled out to 2.80" ID - - 1 3-1/2" tubing tail at 7606' MD (7602' ELM) - °-.... Top of cement at tubing tail at T. "-r„ 7606' MD i KOP #2 at 7665 MD 1_,� ,,,Y , w^� d AL2-01 Lateral (A3 sand, north) KOP 61 at 7685' MD ,.� / /ice. —� TD =9275' MINI • Baker monobore whipstock trays on �� w .. M ''i, /, — — — — Liner top at 7560' openhole anchors at 7665 & 7685' / — / y AL2 Lateral (A2 sand, borth) 2.80" pilot hole in cement drilled to //� — ' _ —_ — _ — ) TD = 9275` 7725' MD MN / Billet at 8050' AL1 Lateral (A3 sand, south) A -sand perfs (sgz'd) a TD = 10,050' 7740' - 776V MD / Liner top at 7680'. 2 A , \ A Sidetrack (A2 sand, south) — .�� V C ` ( \ �l y 3) TD = 10,050' 7 ", 266, L -80 casing arse . Billet at 8100' shoe at 8020' MD =` 1 • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser r J Annular Blind / Shear 2" Pipe / Slip (CT) _ • Pump into Lubricator J above BHA rams ■ - i ■ Choke 1 2 -3/8" Pipe / Slip (BHA) Choke Equalize Manifold 2 -3/8" Pipe / 1 Slip (BHA) Kill • >i<> < L • ► l r Blind / Shear 2" Pipe / Slip (CT) . Choke 2 1 Swab Valves J ,_1 L. Wing Valves I Tree Flow Cross 1 r Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi Master valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union , \i 11ii • Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 12:07 PM To: Foerster, Catherine P (DOA) Cc: Ramirez, Darlene V (DOA); Norman, John K (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA) Subject: Re: 209 -105 Approved Sent from my iPhone On Sep 28, 2009, at 11:10 AM, "Foerster, Catherine P (DOA)" <cathy.foerster @alaska.gov > wrote: > Dan, > I just took my first look at the permit and have the same problem with > it. The different laterals in the well will each be targeting a > particular stringer of the Kuparuk A Sand (for some it will be the A2 > and for others the A3), but each lateral will be targeting only one > stringer and all stringers are in the Kuparuk A Sand. Perhaps it > slipped through the cracks because both Roby and Steve Davies were out > and Guy is still learning. I'll get that check box fixed. Otherwise > it's pretty straightforward. > Thanks, Eagle Eye. > Cathy > Original Message > From: Seamount, Dan T (DOA) > Sent: Monday, September 28, 2009 9:34 AM > To: Ramirez, Darlene V (DOA) > Cc: Foerster, Catherine P (DOA); Norman, John K (DOA); Davies, Stephen > F > (DOA) > Subject: Re: 209 -105 > Why is this multiple zone? > Sent from my iPhone > On Sep 25, 2009, at 4:02 PM, "Ramirez, Darlene V (DOA)" > <darlene.ramirez @alaska.gov » wrote: » «S45C- 209092513480.pdf» » The message is ready to be sent with the following file or link » attachments: » S45C- 209092513480.pdf 1 • • Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 9:34 AM To: Ramirez, Darlene V (DOA) Cc: Foerster, Catherine P (DOA); Norman, John K (DOA); Davies, Stephen F (DOA) Subject: Re: 209 -105 Why is this multiple zone? Sent from my iPhone On Sep 25, 2009, at 4:02 PM, "Ramirez, Darlene V (DOA)" <darlene.ramirez@alaska.gov > wrote: > «S45C- 209092513480.pdf» > The message is ready to be sent with the following file or link > attachments: > 545C- 209092513480.pdf > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C- 209092513480.pdf> 1 Alaska Department of Natural sources Land Administration System • Page 1 of, Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources i Alaska DNR Case Summary File Type: ADL File Number: 25531 Printable Case File Summary See Township, Range, Section and Acreage? O Yes O No New Search LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract File: ADL 25531 ; 41ap _ Search for Status Plat Updates As of 09/24/2009 Customer: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 01/28/1965 Total Acres: 2560.000 Date Initiated: 11/02/1964 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/07/2005 Case Subtype: NS NORTH SLOPE Last Transaction: DR DOCUMENT RECORDED Meridian: U Township: 012N Range: 008E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 008E Section: 02 Section Acres: 640 Meridian: U Township: 012N Range: 008E Section: 11 Section Acres: 640 Meridian: U Township: 012N Range: 008E Section: 12 Section Acres: 640 Legal Description 11 -02 -1964 * * * SALE NOTICE LEGAL DESCRIPTION U -3 -5 -1 ALL SECTION 1, T12N, R8E, UM 640 ALL SECTION 2, " " " 640 ALL SECTION 11, " " " 640 ALL SECTION 12, " " " 640 CONTAINING 2,560 ACRES, MORE OR LESS. 11 -10 -1982 * ** PARTICIPATING AREA LEGAL DESCRIPTION * ** http: / /dnr.alaska.gov /proj ects /1as/ Case_ Summary .cfm ?FileType= ADL &FileNumber= 2553... 9/24/2009 • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME //e4' J, $3 & ? PTD# c7'7O9 /OS I/ Development Service Exploratory Stratigraphic Test Non - Conventional Well • FIELD: ! / / / Q c o y , - / POOL: )41',", '4 4 O/G Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a newwweellbore segment of existing well x- (If last two digits in permit , API No. 50- Ie2r - OSAW- API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 3H-33AL2 Program DEV Well bore seg El PTD#: 2091050 Company CONOCOPHILLIPSALASKA INC - -_ Initial Class/Type DEV / PEND GeoArea 890 _ Unit 11160 - -_ On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 15 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2657 acres. 1 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond #59 -52- 180. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA ACS 9/24/2009 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre- produced injector: duration of pre- production less than 3 months (For service well only) NA 117 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 3H -33 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 3H -33 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 3H -33 22 CMT will cover all known productive horizons No 01-I slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with Steel pits. 125 If a re- drill, has a 1.0 -403 for abandonment been approved Yes 309 -331 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Closest wellbore is P & A portion of 3H -33 & paths diverge. 1 27 If diverter required, does it meet regulations NA Wellhead in place. BOP on top of tree. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure 4126 psi. (12.9 ppg) Will drill with Managed Pressure. GLS 9/24/2009 129 BOPEs, do they meet regulation Yes Using 10ppg mud combined with surface pressure and wellbore friciton to balance fm pressure 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 3855 psi. Will test BOP to 4500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on 3H pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S 390ppm for well 3H -16 (2/24/09). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic anal of shallow gas zones NA ACS 9/24/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering Public Commissioner: D Commissioner: Date Commissioner Date JJe 5 '- 0 , 2
