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209-106
• • 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. Q 0 q - 1 Q Well History File identifier Organizing (done) ❑ Two -sided 111 1111111111 II 1 1 ❑ Rescan Needed 111 I!IIIJ 11 ij HI 111 RE CAN DIGITAL DATA OVERSIZED (Scannable) 1 Color Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: i Pd ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: 1 " OVERSIZED Non - Scannable 0 Other: ( ) ❑ Logs of various kinds: NOTES: ❑ Other:: ni p BY: Maria Date: I 3 � � /s/ J Project Proofing 11111111111 i I 111 BY: Maria Date: ( 31 11 /s/ m F Scanning Preparation 1 x 30 = 3 + 10,.., = TOTAL PAGES BY: Maria Date: r �i , r 1 (Count does not include cover sheet) Production Scanning III VIII I I III I I 111 Stage 1 Page Count from Scanned File: `'T 3 (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: 1/3f 11 /s/ m13 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. 1111 111 1 11 Ill ReScanned 111 IIIJIIJIIII 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 IIIIII III IIII III r 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091060 Well Name /No. KUPARUK RIV UNIT 3H- 33AL2 -01 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -62 -00 MD 9275 TVD 6200 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 01-1/ Typ Med /Frmt Number me Scale Media No Start Stop CH Received Comments D C Lis 19148 nduction /Resistivity 7529 9275 Open 1/13/2010 MPR logs in CGM and TIFF graphics o Induction /Resistivity 5 Col 7665 9275 Open 1/13/2010 MD MPR, GR og Induction /Resistivity 2 Col 7665 9275 Open 1/13/2010 MD MPR, GR o Induction /Resistivity 5 Col 7665 9275 Open 1/13/2010 TVD MPR, GR D C Asc Directional Survey 40 9275 Open D irectional Survey 40 9275 Open Well Cores /Samples Information: Sample - Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y b Daily History Received? Y N Chips Received? .—Y-444 Formation Tops / N Analysis 'rfN Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091060 Well Name /No. KUPARUK RIV UNIT 3H- 33AL2 -01 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -62 -00 MD 9275 TVD 6200 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: Date: _arVNr.� - -1 • R F C Er \117: i 7‘.' Company ConocoPhillips, Alaska, Inc. JAN 13 201g Well Name 3H-33AL2-01 909--A0 b BAKES! HUGHES Date 1/6/2010 lhi TE ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribut RECIPIENTS f - 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 • rints' dik ConocoPhillips Alaska, Inc. lopr Sharon Allsup -Drake , , Drilling Tech, ATO -1530 ,74 ConocoPhillips Alaska, Inc. 1 Hardcopy Print i :,(7';', NSK Wells Aide, NSK 69 ATTN: MAIL ROOM ' "� - 700 G Street, Anchorage, AK 99501 ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk * / File * * / * ** Electronic 700 G Street, CGM / TIFF LIS 1 z � ftp: / /b2bftp.conocophillips.com * * ** AOGCC 1 Hardcopy Print, ; ' /�r�,, ,. ,- ; Christine Mahnken 1 Graphic image file 1 Disk * / 14 � . 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic ,, ; r 3,� ; Anchorage, Alaska 99501 CGM / TIFF LIS I BP 1 Hardcopy Print, � , , n:4®hTI F. Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / .. David Douglas in lieu of sepia ** Electronic ��x� P.O. Box 196612 CGM / TIFF LIS h Anchorage, Alaska 99519 - 6612 CHEVRON /KRU REP 1 Hardcopy Print, , -, A Glenn Fredrick 1 Graphic image file 1 Disk / : P.O.Box 196247 in lieu of sepia ** Electronic ,��� Anchorage, Alaska 99519 CGM / TIFF LIS4�. Brandon Tucker, NRT • 21,. • State of Alaska; DNR, Div. of Oil and Gas 1 Disk * / � 550 W. 7th Ave, Suite 800 Electronic r , Anchorage, Alaska 99501 -3510 LIS ' DS Engineer / Rig Foreman ■_ 2 TOTAL fir.' Hardcop Prints 4 ' , ate - Page 1 of 4 • • # 0 RECEIVED STATE OF ALASKA WELL ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 2 0 2009 ELL COMPLETION OR RECOMPLETION REPORT O la. Well Status: oil G 0 , Gas El SPLUG ❑ Plugged El Abandoned El Suspended 4 Suspended an . ommtSSI019 20AAC 25.105 20AAC 25.110 Development fth0r geExplorator ❑ 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. or Aband.: October 30, 2009 209 - 106 / 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510 - 0360 October 28, 2009 50- 103 - 20578 - 62 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 30, 2009 3H 33AL2 - 01 Top of Productive Horizon: 8. KB (ft above MSL): 77 ' RKB 15. Field /Pool(s): 525' FNL, 469' FEL, Sec. 12, T12N, R8E, UM GL (ft above MSL): 36' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 545' FSL, 40' FEL, Sec. 1, T12N, R8E, UM 9275' MO / 6200' 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 9275' MD / 6200' TVD I ADL 25531 TPI: x - 503184 y - 6001133 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 503613 y 6002203 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 7967' MD / 6154' 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 7583' 9275' 6000' 6200' 3" slotted liner 24. Open to production or injection? Yes • 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 7583` -7679' MD 6000.5' -6085' TVD 7761' - 9274' MD 6137' - 6200' 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 1319 24 - Hour Rate - 1179 1631 499 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No in 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. NONE 111 37 .r iElp Form 10-407 Revised 7/2009 / CONTINUED ON REVERSE , `� mit original only • 28. GEOLOGIC MARKERS (List all formations and markeruntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes is 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 A2 8035' 6153' N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey t ��\ p YyRR 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Gary Eller @ 263 - 4172 1 � /c Printed Na Von C v Title: CT Drilling Manager Signature � ,� Phone 265 - 6306 Date 11 / 7 6/ 0 9 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 • $" ^ "`1 KUP 3H- 33AL2 -01 ConocoPhilhhps g \ Well Attributes Max Angle & MD 1TD i�IQ14a ),� i' Wallb0 APU UWI Field Name Well Status Incl( °) MD (ftKB) Act Btm (ftKB) T' S.Rx+at+MNi4ltt 50103205/862 KUPARUK WVLI2 UNIT PROD 96.06 /968171 92/50 Comment H2S (ppm) Date 'Annotation End Date KB-Grd (H) Rig Release Date Win COrjg__tEVV.7E,Q, ,3H -33p, }2 oL ttRt2g0813t,G9 P(3 SSSV R apper L0050d Out 0 102006 Last WO 2/142009 ' A notation Depth ftKB End Data Annotation Last Mod ._ End Date IA S. g -91. P ( 1 Last Tag: R ev Reason: GLV C/O Imosbor 1 11/7/2009 -.. - - - Casing r pI S 'Strip 0... !String ID ... To ftKB Set Depth f Set Depth (TVD) I I C 9 Description g g p (ftKB) p (... p ( ) .. !String Wt... String ._ Siring Top Thrd 9 9 H63009, 37 - - - - -- 1 LINER AL2 01 23/8 1.995 I 7,583.1 I 9,275.0 I _I 4.70 ' /80 STL Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) r) item Description Comment ID (in) . - 7,583.1 6,000.6 28.10 Deployment 2.625" Baker deployment sleeve 1.995 sleeve Perforations & Slots Shot Top (TVD) Ban (TVD) Dens �' Top(ftKB) BtmjftKB) (ftKB) (ftKB) Zone Date i Type Comment 7,583 7,679 6,000.5 6,085.0 10/24/2009 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid /slotted pipe - CONDUCTOR, 40 - 149 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 7,761 9,274 6,136.6 6,200.3 10/24/2009 32.0 SLOTS =,. Notes: General & Safety End Date I Annotation SAFETY VLV, 2/17/2009 NOTE VIEW SCHEMATIC w /Alaska Schematic90 11/2/2009 NOTE: WELL SIDETRACKED - A, AL1, AL2, AL2 -01 GAS LIFT, ;` ` .e:. 2,735 j : 1 SURFACE, 42 -4,315 GAS LIFT, K... 4,444 GAS LIFT, ' -' GAS 5,710 ,78 69 GAS LIFT, 53 1 7,4 NIPPLE 7,504 T it- PACKER, 7,547 -- - , NIPPLE, 7,594 -- WLEG, 7,606 SLOTS, 7,583 -7,679 - WINDOW AL7, _ - 7 60 -7,66 WHI 7,665 WHIPSTOCK, 7,974 NTERM _ 39 -8,020 ---_._ - -=. -° Mandrel Details I TOp Depth Top _.__ -- - - - -- - -._ Details ..., Port I (TVD) Inc' OD Valve Latch Size TRO Run Stn T�jftKB) (ftKB) 1') Make Model NO Sere Type Type NO (Psi) Run Date Con... SLOTS, 1 2,735.0 2,471 9 44 14 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,327.0 11/6/2009 7,761 - 9,274 LINER AL2 2 4,444.2 - 3,6984 4693 CAMCO MMG 112 GAS LIFT GLV RK 0.188 1,303.0 11/6/2009 7,583 _ - - - --- -- TD - - 3 - 5,709.7 4,598.0 45.83 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,282.0 11/4/2009 (31 334/2 - 01), 9,275 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 LINER AL2, ' - 7,9735,383 - 5 7,453.3 5,887.6 30.64 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 11/3/2009 3H -33 Actual CTD Sidetrack Schematic Updated: 11/2/2009 3.1/2" Camco TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) immelr: Mi -1/2 ", 9.3 #, L -80 EUE 8rd Tubing to surface lllllllllllE- 16 ", 624, H-40 conductor 3 -1/2" Camco MMG gas lift mandrels at 2735', 4444', 5710', 6789', & 7453' shoe 149' MD 9 -5/8 ", 404, L -80 casing Sir shoe at 431V MD �� '' 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 - 3/8" LINER TOP at 7583' MD'*" Camco D nipple @ 7594 MD (2.75" min ID, No I Nipple milled out to 2.80" ID I . 3 - 1/2" tubing tail at 7606' MD (7602' ELM) Top of cement at tubing tail at 7606' MD ^ .. \ AL2 -01 Lateral (7974' - 9275') KOP #2 at 7665' MD i, 2.3/8" liner 7583 - 9275' MD KOP 41 at 7685' MD _ — 1 Blank liner 7679' -7762' =G.'I — — / Baker monobore whipstock trays on �� openhole anchors at 7665' & 7685' AL2 Lateral (7803' - 9382'1 i \ I \ \ , 2.3/8" slotted liner 7984 - 9382' MD a. • cex ��/ \ 'IIII11I1. �� ) Anchor - Billet at 7974' 2.80" pilot hole in cement drilled to 7715' MD I _ \\ \ ■ M. \ p.L1 Lateral (7665' - 10.100') AL1 -PB1 (8810' - 9607') A -sand perfs (sgz'd) N. \‘‘ ® Anchor- Billet at 8810' 2 -3t8" liner 7803'-10,900' Blank liner 885V -8977' & 7740' - 7760' MD ^� - — — — — — \ — — — — — — — — — ) er Jun ton —.��. Liner juncfio @ 8662' MD �� Aluminum billet at 7803' 7 ", 264, L -80 casing — — _ _ — shoe at 8020' MD \ — — — — — — A Sidetrack (7685' - 10.307') 2.3/8" slotted liner 7673' -9944 Unlined hole 9944'- 10,307' 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, tuming 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 lenght 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 Ca) 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 (a) 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. Page 24 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 71 0 PROD4 STK PULD P Tagged up at surface. Monitor well, PJSM. RD anchor and billet BHA. MU milling /drilling BHA #23. 06:30 07:30 1.00 72 72 PROD4 DRILL SVRG P Injector maintenance and safety meeting 07:30 11:00 3.50 72 7,650 PROD4 DRILL TRIP P Start RIH, slowly pumping through EDC. P/U weight 21 k, 7565' tie in ( +2) Circulate out KWM. 11:00 11:42 0.70 7,650 7,969 PROD4 STK KOST P RIH & dry tag top of billet @ 7969.4'. P/U weight 23k, to 7962'. Bring pumps online © 1.45 bpm. Trough up hole slowly 80 ft on low -side © 5 fpm. RIH troughing, tag @ 7969.3' v P/U 10 ft and start time drilling. 11:42 17:54 6.20 7,969 7,995 PROD4 STK KOST P Start time drilling @ 7967.3' CT �2 H - 3 3 weight 8.5K, circ 3700, BHP 4125, J ECD 13.1, WHP 100, WOB 0, AL2 1 moving a tenth every 5 min. Actual motor work detected 7968.5' - B/U samples have light Alum. over shakers. 17:54 18:29 0.59 7,995 7,995 PROD4 STK KOST P Back ream billet. PUH 5 fpm to 7900'. PU wt 23K #. RIH 18:29 19:29 1.00 7,995 8,033 PROD4 DRILL DRLG P Drilling AL2 -01 later. Pumping 1.4 bpm, 13.2 ECD, ann press 4193, 100 psi motor work, 1.1K WOB, ROP 85 fph. 19:29 20:29 1.00 8,033 8,048 PROD4 DRILL DRLG P ROP slowed down to 6 fph, 1.8K WOB, 91 psi motor work. 20:29 21:29 1.00 8,048 8,145 PROD4 DRILL DRLG P ROP increased to 90 fph. 1.8K WOB, 225 psi motor work. 21:29 22:29 1.00 8,145 8,145 PROD4 DRILL WPRT P Wiper trip #1. PU wt 26K. PUH to 7682', RIH. 22:29 23:59 1.50 8,145 8,264 PROD4 DRILL DRLG P Continue drilling. 1.3K WOB, CT wt 7K, 150 psi motor work, ROP 90 fph. 10/29/2009 Drilled AL2 -01 lateral to 9203'. 00:00 00:15 0.25 8,264 8,296 PROD4 DRILL DRLG P Continue drilling AL2 -01 lateral. ROP 110 fpm, 1.6 WOB, 190 psi motor work. 00:15 01:05 0.84 8,296 8,296 PROD4 DRILL WPRT P Wiper trip #2. PU wt 26K. 35 fpm pumping 1.5 bpm 3800 psi (20 fpm 0.3 bpm through billet sections). PUH to 7685'. RIH 01:05 03:10 2.09 8,296 8,445 PROD4 DRILL DRLG P Drilling ahead. CT wt 7K, WOB 1K, ECD 13.2, 1.4 bpm 185 psi motor work. 03:10 04:10 1.00 8,445 8,445 PROD4 DRILL WPRT P Wiper trip #3. PU wt 28K. PUH to 7680'. RIH and tie in to RA maker, +1.5' correction. 04:10 06:34 2.40 8,445 8,595 PROD4 DRILL DRLG P Drilling ahead. CT wt 6.7K, WOB 1.9, ECD 13.2, 1.35 bpm, 240 ppsi motor work. 06:34 08:04 1.50 8,595 8,595 PROD4 DRILL WPRT P Wiper trip to window - CT weight 26,000 - Perfrom mud swap at the end of the wiper trip. 08:04 09:04 1.00 8,595 8,687 PROD4 DRILL DRLG P BOBD - new mud at bit, ROP 60 fpm, ECD 13.15 Page 25 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:04 09:34 0.50 8,687 8,687 PROD4 DRILL WPRT T New mud came around and had to change shakers screens, new mud was rolling off the end. - Pull a 200 ft wiper trip. P/U weight 26,000#. 09:34 11:04 1.50 8,687 8,745 PROD4 DRILL DRLG P BOBD - CT weight 5K, circ 4000psi, 1.4 bpm, ECD 13.1, BHP 4184, WHP 100, ROP - 70 11:04 12:28 1.40 8,745 8,745 PROD4 DRILL WPRT P Wiper trip to window - CT weight 26,000 off bottom. 12:28 14:28 2.00 8,895 8,895 PROD4 DRILL DRLG P BOBD - circ 3800, 1.43 bpm, CT weight 5000, WOB 1.1, ROP 68, ECD 13.18, BHP 4180. 14:28 16:16 1.80 8,895 8,895 PROD4 DRILL WPRT P Wiper trip to window - tie in +1 ft. 16:16 18:19 2.06 8,895 9,045 PROD4 DRILL DRLG P BOBD - CT weight 5500, circ - 3890, 1.45 bpm, ECD 13.16, BHP 4170, WOB 1.4, ROP 91, WHP 100. 18:19 19:38 1.33 9,045 9,045 PROD4 DRILL WPRT P Wiper trip to window - CT weight 26K #. RIH to bottom. 19:38 21:27 1.83 9,045 9,195 PROD4 DRILL DRLG P BOBD - CT weight 2.4K, 1.4 bpm, circ 4000 psi, motor work 145 psi, WOB 1.2K. 21:27 23:52 2.42 9,195 9,197 PROD4 DRILL WPRT P Wiper trip - PUH into tubing. Static test for 12.9 ppg KWF. Start test with 4040 psi BHP with TVD gauge depth at 6022'. Observe BHP for 30 min, final BHP 4012 psi. RIH and tie in RA, +2' correction. RIH to TD. 23:52 23:56 0.08 9,197 9,203 PROD4 DRILL DRLG P BOBD - CT weight 2.7K, 1.4 bpm, circ 3900 psi, motor work 260 psi, WOB 1.6K. 10/30/2009 TD AL2 -01 lateral to 9275'. Run liner, and freeze protect well. 00:00 01:00 1.00 9,203 9,275 PROD4 DRILL DRLG P BOBD - CT weight 3.2K, 1.4 bpm, circ 3900 psi, motor work 255 psi, WOB 1.35K. TD lateral at 9275' MD. 01:00 03:00 2.00 9,275 9,275 PROD4 DRILL DLOG P PUH to 7685'. CT weight 30K. RIH and tie in to RA, 0 ft correction. Tag bottom @ 9275' pumping min rate. 03:00 06:30 3.50 9,275 72 PROD4 DRILL TRIP P PJSM. Start pumping 13.1 ppg fluid with alpine beads and laying in while PUH. Continue to displace well with 13.1 ppg fluid in the tubing while POOH. Flag CT EOP 7482' ( -20 above TD) and 5877' ( -20 above TOW) 06:30 07:30 1.00 72 0 PROD4 DRILL SFTY P CT @ surface - flo -test & safety meeting with the crew 07:30 08:30 1.00 0 0 PROD4 DRILL PULD P Lay down BHA and prepare rig floor for liner running assembly 08:30 09:30 1.00 0 0 COMPZ CASING SFTY P Safety / Rig meeting with crews. 09:30 12:00 2.50 0 0 COMPZ CASING PUTB P Start picking up liner 12:00 13:00 1.00 0 0 COMPZ CASING SFTY P Crew change and Rig Safety Meeting 13:00 14:00 1.00 0 1,736 COMPZ CASING PUTB P Finish P/U liner & BHA assembly Page 26 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 14:00 16:30 2.50 1,736 5,000 COMPZ CASING RUNL P RIH, EOP flag on depth, continue RIH. Tag TD @ 9275' ft. EOP Set down, 10K, Pump 1 bpm, Released off liner. P/U 60 ft CT weight 23K, RIH , string weight changed by 8000 #, looked good. Top of liner at 7583' MD. Stop open EDC. PUH 16:30 19:00 2.50 5,000 5,000 COMPZ CASING DISP P Circulate out KWF with 9.8# brine. Recover 13.1 K- formate KWF at surface. Close EDC. Crew change out. PJSM 19:00 21:00 2.00 5,000 44 COMPZ CASING DISP P PUH to 2500' while filling CT with diesel. With diesel at the nozzle, freeze protect well from 2500' to surface while POOH 21:00 23:45 2.75 44 0 COMPZ CASING PULD P Tag up BHA. Static wellhead pressure 1015 psi. PJSM. Press undeploy BHA. 23:45 00:00 0.25 0 0 DEMOB WHDBO NUND P PJSM. MU jetting nozzle to CT and wash across BOPE and wellhead down the master valve. 10/31/2009 Set BPV. Rigged down BOPE and test tree cap to 4000 psi. CDR2 Rig released from 3H -33 @ 13:00 on 10/31/2009 00:00 01:00 1.00 0 0 DEMOB WHDBO NUND P Completed washing across BOPE and tree down to the mastervalve. Blow down lines. 01:00 02:00 1.00 0 0 DEMOB WHDBO NUND P PJSM. PU and MU BPV lubricator, test to 2000 psi. 02:00 03:30 1.50 0 0 DEMOB WHDBO NUND T Set BVP, would not seal. Pull and inspect, found debris on popit seal. 03:30 04:30 1.00 0 DEMOB WHDBO NUND P Clean seal and re -run BPV. Bleed pressure, BPV holding. 04:30 05:00 0.50 0 0 DEMOB WHDBO NUND P Rig down and lay down lubricator. 05:00 08:00 3.00 0 0 DEMOB WHDBO NUND P Blow down surface lines and WH. 08:00 10:30 2.50 0 0 DEMOB WHDBO DISP P Rig up Foaming system on CT blow -down. Purge CT string, total volume recovered 22.5 bbl out of 29 bbl reel capacity. 10:30 13:00 2.50 0 0 DEMOB WHDBO NUND P Rig down BOP & test tree cap to 4000 psi using diesel. Rig released @ 13:00 hrs from 3H -33 Page 27 of 27 C onocoPhillips Alaska • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H- 33AL2 -01 501032057862 Cb • Baker Hughes INTEQ TSAI Definitive Survey Report BAKER HUGHES 03 November, 2009 fit,. ConocoPhillips Faso ul Definitive Survey Report Alasic2 MOMS Company ConocoPhillips k (Ala Inc. Local Ccs- ordinate F(eference ' , 3H -33 f Project , Kuparuk River Unit TVD Reference 3H -33 Rig @ 76.85ft (DI5 (40.75 +36.1)) Ait� : Kuparuk 3H Pad MO Reference ° , . m= 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) ►ell` 3H-33 `North Reference* True Wellb�ore 3H 33 Survey ' Calculation Method: Minimum Curvature tioiign ' .3H-33 Daiabase. EDM Alaska Prod v16 �,, ',�st d , � � � ��m Map ,is Map ,4 vertical ,; " i� 11MMD ���Ihc ' � Azi ' ,� T i D TVDSS +N f- W , Northing �aStiri D S y section S urv e y T Name W did (t) () r (R) , � ('ft) (ft} a ( ft) eft} (ft) ( 1100) (}} .J a 40.75 0.00 0.00 40.75 -36.10 0.00 0.00 6,000,588.21 498,6 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 -0.06 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 3.53 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 14.05 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 29.01 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 46.41 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 66.34 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 87.81 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 1.26 108.17 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 0.02 127.82 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 3.24 149.94 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 4.44 156.33 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 3.17 163.09 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 3.29 170.18 GYD -CT -CMS (1) E 1,200.00 18.44 63.86 1,181.60 1,104.75 52.33 169.87 6,000,640.50 498,825.16 5.45 177.72 GYD -CT -CMS (1) 41 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 5.22 185.82 GYD -CT -CMS (1) i 1,250.00 20.21 65.34 1,228.72 1,151.87 59.49 184.97 6,000,647.66 498,840.26 2.19 194.30 GYD - CT-CMS (1) 1,275.00 20.28 65.46 1,252.18 1,175.33 63.09 192.83 6,000,651.26 498,848.12 0.33 202.89 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 0.24 211.50 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 0.70 220.09 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) 3 1,375.00 18.19 67.24 1,346.32 1,269.47 76.75 223.63 6,000,664.92 498,878.92 3.78 236.40 GYD -CT -CMS (1) 1,400.00 18.25 66.73 1,370.07 1,293.22 79.81 230.82 6,000,667.97 498,886.11 0.68 244.19 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 1.72 252.07 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 4.52 260.25 GYD -CT -CMS (1) l 1,475.00 20.71 66.36 1,440.85 1,364.00 89.82 253.50 6,000,677.97 498,908.79 3.84 268.85 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 4.20 277.85 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 3.96 287.21 GYD -CT -CMS (1) i 1,550.00 23 64 70.07 1,510.34 1,433.49 100.18 279.71 6,000,688.33 498,935.00 5.00 296.99 GYD CT CMS (1) 11/3/2009 11:42:49AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips 'ail COriOCOPhilliPS Definitive Survey Report Y p BAMiffe, Alaska; Compan 1 ConocoPhillips(Alaska) Inc. LocatCo ordinate Referencet 3H -33 Project Kuparuk River Unit TVD Reference ,3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) S {e , ;I - r Kuparuk 3H Pad '�MD Reference: ° , , 3H - Rig @ 76.85ft (D15 (40.75 +36.1)) • Well: 44 . 3H -33 North Reference: ,a True W libore 3H -33 Survey`C alculatiOn Method Minimum Curvature 'De'gn a ,, 3H -33 Database , € g `EDM A laska Prod v16 11rve�( ° iii 4 „ i �P ( Azi ,= T �/D w - 7VDSS +NI +Ef V thi _ D Vertical No InC t (*) C) . %I j (ft) (ft) (ft) tft) NOrtt ing r Eas ng (0/100,) , i a Survey Tool Name RCinotat 1,575.00 24.76 70.71 1,533.14 1,456.29 103.62 289.37 6,000,691.76 498,944.65 4.60 307.23 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 3.77 317.88 GYD -CT -CMS (1) 1,625.00 26.13 71.39 1,578.25 1,501.40 110.59 309.78 6,000,698.74 498,965.07 1.83 328.80 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 0.56 339.84 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 0.72 350.87 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 0.78 361.84 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 0.70 372.79 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 1.27 383.82 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 2.36 394.99 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 2.46 406.35 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 3.68 417.96 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 5.15 429.95 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 2.31 442.25 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 0.43 467.21 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 1.42 479.81 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 4.17 492.64 GYD -CT -CMS (1) • 2,000.00 32.43 78.05 1,908.41 1,831.56 158.11 480.47 6,000,746.22 499,135.75 3.90 505.81 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 5.05 519.37 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 7.57 533.48 GYD -CT -CMS (1) 2,075.00 36.32 78.95 1,970.17 1,893.32 166.55 522.13 6,000,754.65 499,177.41 3.08 548.04 GYD -CT -CMS (1) 2,100.00 36.70 79.19 1,990.27 1,913.42 169.37 536.74 6,000,757.47 499,192.01 1.62 562.80 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 0.53 577.64 GYD - CT-CMS (1) 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 0.13 592.49 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 0.54 607.35 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 0.94 622.23 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 2.57 637.17 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 2.74 652.21 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 2.87 667.36 GYD -CT -CMS (1) L._ 2,300.00 39.27 83.77 2,149.24 2,072.39 189.18 656.41 6,000,777.25 499,311.67 5.13 682.72 GYD -CT -CMS (1) 2,325.00 40.39 84 83 2,168.44 2 091 5 190.77 672.34 6,000,778 84 499 327 60 5 24 698 36 GYD -CT -CMS (1) 11/3/2009 11:42:49AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Valli ConocoPhiiiips Definitive Survey Report Alaska BAKIM IMIES " i •---. �..._ ...««««- ___._�.._. � ,"F =, Com �y, ConocoPhillips(Alaska) Ina ,, ordina Reference. 3H -33 I'ihojeat. 4 Kuparuk River Unit . t6VD 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)) 1111e)Itd 3H -33 Narth Reference = rE True V1 ellboi " 3H - 33 'eS1irisy Ca `Ulatlon Method: Minimum Curvature 1 Design: 3H 33 Database: ,, v r „EDM Alaska Prod v16 ! ;. a "!, -, ' „,„ ,, ,, :.a 1K„ - _ S6vey 490: *'' WIC � ' id DEL :� Map , `' � 'Map Vertical . a T, . -, i 1 ' MD d�,,, Mc i3 T 1jb �� TVD SS E + S +E1 Nottnin Easting DLS' a Se eYion Surve �`p4t Name Annotation • t°) , t) � ft ot) (ft)-- _ e ft) (ft) I „,a, (ft) 2,350.00 41.51 85.85 2,187.32 2,110.47 192.10 688.67 6,000,780.17 499,343.93 5.22 714.30 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 2.67 730.45 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 0.79 746.68 GYD -CT -CMS (1) j 2,425.00 41.87 86.82 2,243.07 2,166.22 195.19 738.74 6,000,783.25 499,394.00 1.41 762.87 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 1.72 778.92 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 1.03 794.86 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 0.84 810.73 GYD -CT -CMS (1) I 2,525.00 41.19 87.40 2,318.18 2,241.33 198.53 804.67 6,000,786.57 499,459.92 0.55 826.59 GYD -CT -CMS (1) 2,550.00 41.41 87.41 2,336.97 2,260.12 199.28 821.16 6,000,787.32 499,476.41 0.88 842.49 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 1.53 858.48 GYD -CT -CMS (1) j 2,600.00 42.24 87.67 2,374.24 2,297.39 200.70 854.45 6,000,788.74 499,509.70 1.87 874.59 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 3.44 890.90 GYD -CT -CMS (1) 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 2.29 907.43 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 1.16 924.10 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 0.52 940.83 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 0.20 957.59 GYD -CT -CMS (1) 40 1 2,750.00 44.14 87.54 2,482.69 2,405.84 205.03 957.98 6,000,793.05 499,613.21 0.14 974.36 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 0.48 991.13 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 1,007.92 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 1,024.73 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 1,041.59 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 1,058.45 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 1,075.24 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 1,091.94 GYD -CT -CMS (1) 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 1,108.56 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 1,125.10 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 1,141.63 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 , 1,158.18 GYD -CT -CMS (1) 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 1,174.70 GYD -CT -CMS (1) 3,075.00 42.28 85.22 2,718.92 2,642.07 221.85 1,180.48 6,000,809.83 499,835.69 1.38 1,191.12 GYD-CT-CMS (1) 3,100.00 42.27 85.36 2,737.42 2,660.57 223.23 1 197.24 6,000,811.21 499 852.45 0.38 1,207.48 GYD -CT -CMS (1) 11/3/2009 11:42:49AM Page 5 COMPASS 2003.16 Build 69 j ConocoPhillips Far" Conoco Phillips Definitive Survey Report %SKS Alaska Co „ ConocoPhillips(Alaska) Inca f' Lo Co - ordinate Reference 3H -33 11 > r �� Kuparuk River Unit TVD Re erenc ., ,4 r e 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Si e: _ 1 � Kuparuk 3H Pad MD ReI''Irence. 11 '' 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Wall: ∎ 3H -33 North Reference: True iit I 1Veli re .: 3H -33 I Surve Calculation Method: " , Minimum Curvature Desi n� �,. 3H -33 Database DM Alaska Prod v16 Sur`y �i iy all MD . Inc Azi '" TV D TW +N /-S +E/ W Map Male it :BLS Sermon Survey TO l .Name Anfl �trtiOfl Northing Basting Lib (}t� ( °) { ° }° j� . „lfit} i�P� 21 (ft), (ft} 'Aft) � >'.' (ft}�G,= �( °I10bg k (ft) nw !�� a 35.00 42.24 85.47 ,755.92 ' 2,679.07 224.58 1,213.99 6,000,812.55 499,869. 0.32 1,223.83 GYD -CT -CMS (1) 1 , 12 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 1,240.16 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 1,256.49 GYD -CT -CMS (1) 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 1,272.85 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 1,289.25 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 1,305.71 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 1,322.28 GYD -CT -CMS (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 1,338.93 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 1,355.59 GYD- CT-CMS (1) 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 1,372.16 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 1,388.55 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 1,404.80 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 1,421.06 GYD -CT -CMS (1) 1 3 42.54 87.34 2,994.66 2,917.81 238.36 1,434.06 6,000,826.29 500,089.25 0.44 1,437.34 GYD -CT -CMS (1) 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 1,453.64 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 1,469.99 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 1,486.41 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 1,502.94 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 1,519.56 GYD - CT-CMS (1) 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 1,536.22 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 1,552.88 GYD -CT -CMS (1) i 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 0.42 11,586569.49 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 ,.03 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 1,602.59 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 1,619.19 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 1,635.86 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 1,652.64 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 1,669.52 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 1,686.47 GYD -CT -CMS (1) 3850.00 45.22 88.11 3,283.58 3,206.73 249.25 1,710.44 6,000,837.13 500,365.60 0.89 1703.49 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 , 720.55 GYD CT CMS (1) 11/3/2009 11:42:49AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (341111 conoc•Phil Definitive Survey Report BAICEI! C ompany ConocoPhillips(Alaska) Inc. �.o caI Co- ordin R , erence 3H -33 Proje ;' Kuparuk River Unit 'ND Referonice 3H 33 Rig @ 76.85ft (D15 (40.75 +36.1)) .k + 1 7 . ft D15 40.75 36. ��i � 3H-33 Rig 685 _3 33 Site�� � `Kuparuk 3H Pad IVIC! Reference. 9 @ ( ( )) 1 Well't, , 3H -33 L North Re onca. .,, , True lNelllrare °s _ 3H-33 SurverCalcP1a)ticirfMethod Minimum Curvature Deal n ' .$ 3H -33 Database EDM Alaska Prod v16 tlrrvey u �x� ro Ar r , `. , Map . ` M ap V ertical c -r I • H s MD (ft> a( ") Inc, f ^ Az; TVD ,i ( } , ' f TVDSS +N /-S +E /W Norh;ng Easting D L LY , S tfto n surve)1'oot,Name Annotation `�r ° ' 4 . 900.00 45.23 ;( (ft) �` (o7 ° ,,, 3, 88.33 3,318.75 3,241.90 250.38 1,745.95 6,000,838.26 500,401.12 0.79 1,737.61 GYD -CT -CMS (1) t 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 1,754.52 GYD -CT -CMS (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 1,771.26 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 1,787.99 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 1,804.81 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 1,821.76 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 1,838.84 GYD -CT -CMS (1) 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 1,856.00 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 1,873.19 GYD -CT -CMS (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 1,890.36 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 1,907.51 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 1,924.65 GYD -CT -CMS (1) 4,200.00 45.84 89.59 3,529.70 3,452.85 254.98 1,959.19 6,000,842.81 500,614.33 0.84 1,941.77 GYD -CT -CMS (1) ii 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 1,958.83 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 1,975.86 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 1,992.93 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 2,010.06 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 2,027.23 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 2,044.43 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 2,061.67 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 2,078.95 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 2,096.28 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 2,113.63 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 2,131.02 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 2,148.41 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 2,165.80 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 2,183.17 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 2,200.50 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 2,217.80 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 2,235.04 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 2,252.14 GYD -CT -CMS (1) 11/3/2009 11:42:49AM Page 7 COMPASS 2003.16 Build 69 IV ConocoPhillips nag COnOCOPhillipS Definitive Survey Report Alaska MOMS C ompany: ConocoPhillips(Alaska) Inc Local Co- ordinate Re # fence ,,, 3H -33 4 m Prole ' ,Kuparuk River Unit NI} et: 3H -33 Ri @ ..7)) Stte X11 Kuparuk 3H Pad M Refer ce ce �' 3H -33 Rig g @ 76 (D15 (D15 (40.75 (405 + +36. 36.1 1)) Weft' i 3H -33 No I R eferen ce True We11bc" e: 3H -33 Survey Calcutahonn Method: _21' Minimum Curvature esi`gh - 3H 33 F I �D D 1, ' DM k E Alaska Prod v16 �sClrlfB i x � ,Map � Map � vertical MD � , , In-c,„:„1- Az1, TvD T%. S `, +N15 +E/ -W `..- Northing Fasting DLS� ` Section Survey ool N ame ' , aO t ( °) ( ft) (+t) (ftl (ft) Aft) (ft) (M y t , 4, 44.48 86.13 3,858.12 3,781.27 258.85 2,302.23 6,000,846.62 500,957.34 1.45 2,269.14 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 2,286.11 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 2,303.06 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 2,319.99 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 2,336.92 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 2,353.88 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 2,370.87 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 2,387.89 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 2,404.94 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 2,421.96 GYD -CT -CMS (1) 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 2,438.88 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 2,455.70 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 2,472.47 GYD -CT -CMS (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 2,489.21 GYD - CT-CMS (1) 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 2,505.86 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 2,522.42 GYD -CT -CMS (1) • 5,075.00 43.35 88.26 4,145.22 4,068.37 5,100.00 43.12 88.27 4,163.44 4,086.59 276.78 2,580.14 6,000,864.50 501,235.22 0.93 2,538.92 GYD -CT -CMS (1) 277.30 2,597.25 6,000,865.01 501,252.34 0.92 2,555.36 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 2,571.74 GYD -CT -CMS (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 2,588.10 GYD -CT -CMS (1) 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 2,604.46 GYD -CT -CMS (1) I II 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 2,620.88 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 2,637.40 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 2,654.02 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 2,670.70 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 2,687.45 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 2,704.26 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 2,721.07 GYD - CT-CMS (1) 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 2,737.86 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 2,754.61 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 2,771.32 GYD -CT -CMS (1) i 11/3/2009 11:42:49AM Page 8 COMPASS 2003.16 Build 69 l►' ConocoPhillips l COnOCOPhillipS Definitive Survey Report BAICER Alaska Company ConocoPhillips Inc. L `Co- orriinate Reference 3H -33 1 Kuparuk River Unit TVC Reference: 3H -33 Rig 76.85ft (DI5 (40.75 +36.1)) ite „Kuparuk 3H Pad MD Reference * 3H -33 Rig @ @ 76.85ft (D15 (40.75 +36.1)) WeIIJ; iO3H -33 North Reference. 'r True I Alailbore 3H -33 '''Survey Calculation Method , Minimum Curvature 1 I Clesi is 3H -33 Da lsaSd " EDM Alaska Prod v16 A m Sgrvey i 1 .'; i:; Y�I , . L is S' I i i P JiSS6'',, � _ --, , Map Allap - iie 'rti � , lip �1'� 11iD Inc ; �kz TVD ,_ TVDSSS 4N +E1 W N orthing Fasting Dom Se Stirve Tool Name �� °Ann4tatiOn , � i. i )` '3 ( � tft) t '� 1Cft1 C, (f) ( t /lotr y C �r 5,450.00 44.62 89.96 4,414.62 4,337.77 280.55 2,840.91 6,000,868.23 501,4 0.21 2,788.03 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 2,804.72 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 2,821.43 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 2,838.20 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 2,855.00 GYD -CT -CMS (1) it 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 2,871.78 GYD -CT -CMS (1) 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 2,888.51 GYD -CT -CMS (1) II II 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 2,905.25 GYD -CT -CMS (1) 14 6 000 867.57 501 637.19 3.23 2 922.11 GYD -CT -CMS 1 5,650.00 45.25 89.26 4,556.23 4,479.38 279.93 2,982.14 ( ) 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 2,939.17 GYD -CT -CMS (1) 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 2,956.39 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 2,973.66 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 2,990.91 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 3,008.11 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 3,025.29 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 3,042.49 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 3,059.68 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 3,076.83 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 3,093.94 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 3,111.02 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 3,128.08 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 3,145.14 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 3,162.19 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 3,179.25 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 3,196.31 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 3,213.36 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 3,230.42 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 3,247.48 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 3,264.55 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 3,281.56 GYD -CT -CMS (1) 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 3,298.52 GYD CT CMS (1) 11/3/2009 11:42:49AM Page 9 COMPASS 2003.16 Build 69 ConocoPhillips FANG ConOCOPhilliPS Definitive Survey Report BAKER Alaska IfiJCOHES i kcoMPit 11 ConocoPhillips(Alaska) Inc. .aE t-ocat Co=ordtnate Re#`erence . , 3H -33 rPro]ect: Kuparuk River Unit TVD Re ereribe, 1i' -4„, 1 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)) Welh ;" 3H -33 North Referenc, True 1 '1W011hore 3H -33 ';,Survey.Calculation Method.; Minimum Curvature , Destgn ''3H -33 Database EDM Alaska Prod v16 Survey � ., �, err � i X11 F tai �� �� ,, � �� i � � ,� � Map Map ver�ica1 � � MI7. I nc" ,,RZ1 „� TUD-,, - ' +N /-S +EI - Northing tastifiS Sed - fta gamey Tool Name n lon i i (ft) ,' (°);ai °) (ft) (ft) "« (ft) (ft) (ft) fit) (1100 i , , . , 6,225.00 44.69 88.17 4,961.52 4,884.67 299.15 3,389.54 6,000,886.72 502,044.56 0.76 3,315.43 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 3,332.32 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 3,349.24 GYD -CT -CMS (1) 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 3,366.17 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 3,383.11 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 3,400.08 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 3,417.04 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 3,433.99 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 3,450.94 GYD -CT -CMS (1) II 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 3,467.90 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 3,484.84 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 3,501.76 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 3,518.70 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 3,535.67 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 3,552.65 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 3,569.64 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 3,586.63 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 3,603.59 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 3,620.53 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 3,637.46 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 3,654.38 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 3,671.28 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 3,688.18 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 3,705.05 GYD -CT -CMS (1) I 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 3,721.83 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 3,738.43 GYD -CT -CMS (1) 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 3,754.89 GYD -CT -CMS (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 3,771.29 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 3,787.61 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 3,803.78 GYD -CT -CMS (1) 5 6 41.57 96'99...... 5,498.37 5,421.52 321.93 3,912.63 6,000,909.41 592'567:59 0.81 3,819.83 GYD CT CMS (1) 1113/2009 11:42:49AM Page 10 COMPASS 2003.16 Build 69 Y ConocoPhillips C Fail C II ps Definitive Survey Report BIUKER company: � Inc. *' ::Local o- ordinate l eferetl „, 3H -33 prdjtfi: Kuparuk River Unit TUD Reference ; 3 H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site" Kuparuk 3H Pad , ,I MD Reference: O r a 1' 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)). VIie11� 31 North Refence: True Wellbo e. 3H -33 Survey Calculation Met Minimum Curvature Design . , 3H -33 Database:' EDM Alaska Prod v16 it �.i i 4 r,` ca E E .... ... .._ ... . .... .._____ e - a, " ...,. I mm m Im pat ' .. ±, °`."rtman mix�. 12Y ___, - ..,Q1: - -' o 1mitm � 4i 1 I r, s 4 10 1, l � M rr; I nc ,4zr �i tvco TUDSS +Nps E [W Map Map DUS Vert "` .� Nort , as no_, Section Survey Tool Name r ,, $ w Annotation {u t °I 4r4 � { ft ) (L) tn� tft) (ft) (ft) { r�no) , (ft � k, ; . ,, 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 3,835.82 GYD -CT -CMS (1) 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 3,851.65 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 3,867.22 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 3,882.57 GYD -CT -CMS (1) 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 3,897.81 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 3,912.89 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 3,927.59 GYD -CT -CMS (1) 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 3,941.80 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 3,955.55 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 3,968.94 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 3,982.11 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 3,995.16 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 4,007.99 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 4,020.57 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 4,032.99 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 4,045.27 GYD -CT -CMS (1) 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 4,057.45 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 4,069.55 GYD - CT-CMS (1) 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 4,081.60 GYD -CT -CMS (1) 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 4,093.63 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 4,105.59 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 4,117.39 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 4,128.98 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 4,140.34 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 4,151.47 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 4,162.45 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 4,173.30 GYD -CT -CMS (1) 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 4,179.75 MVVD (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 4,195.66 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 4,217.25 MWD (2) 7,754.60 63.61 68.48 6,135 44 6,058.59 W 058 59 339 27 4 350.55 6,000,926.67 503 005.47 44.23 4,241.57 MD (2) 11/3/2009 11:42:49AM Page 11 COMPASS 2003.16 Build 69 Y ConocoPhillips FAIN! C CO 11 �I Definitive Survey Report BAKER Co _ ConocoPhillips(Alaska) Inca Loea( Co' dinate Refe ren c e ° 3H -33 ? pr o j e c t e, Kuparuk River Unit Tt/D Reference: 6i ° 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) ' l � � 41 i ' 3H-33 Rig 76.85ft (D15 40.75 +36.1 T ri „rite. Kuparuk 3H Pad MD Reference 9 @ ( ( )) IWelf�. 3H -33 Su h�orth Re ference : True `o Wellborn: �� 3H -33 Survey Ca[c ii anon Method= Minimum Curvature design 3H -33 Databas EDM Alaska Prod v16 ten,,, ,,, » u i _ _ �, «��, - , «,,,�� ,1� ,,m, ' _ UrVe �. - i^ r F , r� �r �i , , x _ - t T i Map ! M rt ical , r " r 11 :: find r *ti Azi r ND ,'' 1VDSS +NI +E► N o rt hi n g East 0 Se Surrey oa t Nam annotation low IG �, ����." ) {ft ft (ft) �� (its' C i°t1 7,784.16 76.24 56.51 6,145.60 6,068.75 352.14 4,375.01 6,000,939.53 503, 57.13 4,268.82 MWD (2) 7,805.00 84.36 54.70 6,149.11 6,072.26 363.74 4,391.95 419.06 6 6,00000,973.34 51.12 503, 39.89 23.91 4,288.51 MWD (3) 7,840.35 81.78 46.59 ,., 385.97 44,,439181..0985 ,,0,9 503,073.98 , 7,870.51 85.76 40.44 66,156153.66 38 6 6, 076.53 079.81 407.70 4 4,439.68 6,000,995.07 503,094.61 24.18 ve 4 321.18 MWD M WD (3) (3) 7,900.39 89.63 36.78 6,157.86 6,081.01 431.02 4,458.31 6,001,018.39 503503,113.23 14597 17.82 4, M MWD ( 7,968.00 96.06 7,930.59 92.95 33.06 6,157.18 6,080.33 455.77 4,475.,, 503,130.52 16.51 17.15 4,396.55 24 MWD (3) 7,960.78 95.78 28.71 6,154.88 6,078.03 481.59 4,491.03 59 6 043.13 ,.,. WD () TIP 3H -33AL2 27.63 487.92 4,494 52 6 6, 07 Interpolated AZI 8,026.61 88.00 ,1 4,443 MWD KOP 7,995.22 90.64 30.00 6,152.55 6,075.70 6,154.14 6,077.29 511.72 ,.,,. 503 49.36 21.72 4 24. MWD (4) (4) .,.,.07 538.38 4,524.07 6,001,125.72 503,179.01 14.43 15.38 4,468.25 MWD (4) 8,060.39 85.08 37 68 6 92 6,078.11 565.86 4,543.59 6,001,153.20 503,198.53 13.25 4,495.32 MWD (4) 43.45 6,156.63 6 076 589.62 4,563.71 6,001,176.95 503,218.66 22 23.57 4,521.81 554 MWD (4) 4 8,128.41 88.96 44.48 6,15 6,080.51 616.12 4,589.27 6,001,203.44 8,091.59 88.77 503,.,. MWD 8,160.49 90.74 640.08 38.79 6,157.45 6,080.60 4,610.57 6,001,227.40 503,265 18.58 2.84 444:,585882421:.038021 4 ,582.00 32 MWD (4) (4) 8,192.46 89.08 32.14 6,157.50 6,080.65 666.10 4,629.11 6,001,253.41 503,284.06 21.44 4,607.69 MWD ( 4) 8,220.84 88.65 27.92 6,158.06 6,081.21 690.66 4,643.31 6,001,277.97 503,298.26 14.94 4,.80 M WD (4) 8,253.73 86.69 22.88 6,159.40 6,082.55 720.34 4,657.40 6,001,307.64 503,312.36 16.43 4,651.39 628 MWD (4) • § 8,279.78 82.86 18.77 6,161.77 6,084.92 744.57 4,666.62 6,001,331.87 503,321.58 21.52 4,667.67 MWD (4) 8,310. 82.40 14.63 6,165.75 6,088.90 774.02 4,675.46 6,001,361.32 503,330.42 13.32 4,685.19 MWD (4) I 8,340.80 84.10 9.98 6,169.28 6, 803.13 4,681.80 6,001,390.42 503,336.78 16.40 4,700.25 MWD (4) 8,370.07 83.91 5.32 6,172.34 6,095.4 9 831.98 4,685.68 6,001,419.26 503,340.65 15.85 4,712.87 M WD (4) 8,400.20 84.68 0.93 6,175.34 6,098.49 861.90 4,687.31 6,001,449.18 503,342.29 14.72 4,723.69 MWD (4) 8,430.34 85.67 356.76 6,177.87 6,101.02 891.92 4,686.70 6,001,479.20 503,341.69 14.17 4,732.42 MWD (4) 8,460.28 86.28 352.45 6,179.97 6,103.12 348.41 921.65 4,683.90 6,001,508.93 503,338.89 14.50 4,738.96 MWD (4) 8,491.44 87.88 ,, 952.33 4,678.72 6,001,539.60 503,333.72 13.93 4,743.55 MWD (4) 8,520.30 88.28 343.83 6 181.56 6 104.71 980.32 4,671.81 6,001,567.60 503,326.81 15.92 4,745.64 MWD (4) 8,550.23 90.00 343.12 6,182.98 6,106.13 1,009.01 4,663.29 6,, 503,318.31 6.22 4,746.44 MWD (4) 8,580.55 90.74 347.54 6, 6,105.93 1,038 127 .34 4,655.62 6,001 596.28 14.78 MWD (4) 8 91.47 351.21 6,182.21 182.78 6,105.36 1,067.62 4,650.12 6,001,654.89 53,305.15 12.55 52.0 MWD (4) 8,640.30 91.23 354.74 6,181.50 6,104.65 1,097.33 4, 6,,. 555-:0333,,,3320.19019...469931 1 44:7465785...2682: MWD ( 8 670 47 92.21 359.22 6 180.60 6 1 43 4 6,001001,714684.69 59 11:1451...718981 5 19 1.81 MWD (4) 4) 11/3/1009 11:42:49AM Page 12 COMPASS 2003.16 Build 69 r►� ConocoPhillips COnOCOPhillipS Definitive Survey Report BAKER Alaska IMENIELS ompa4 a ConocoPhillips(Alaska) Inc. Local Co- ordinate Referenc+ 3H -33 Proj Kuparuk River Unit TI/D Reference: 13H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) ft lte '' Kuparuk 3H Pad MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: 31-1-33 Worth Reference • ,! True = Wellborn ri t � 3H -33 Survey, Calculation ethod:' ;.Minimum Curvature D'esi n g 3H 33 EDM Alaska Prod v16 41 �� C1a�base �, � r Survey Map Map Ve � MTi !nc Azi „ T D �TVDSS fN / - S +Ei-W Northing Pasting Section Survey' Tool Name��� Annoi t n (ft) ( ` (°) '() fax ( «`(R) . (ft) (fo f j (/100)- (fO : 8,700.49 91.87 3.62 6,179.53 6,102.68 1,157.42 4,645.62 6,001,744.68 503,300.66 14.69 4,775.62 MWD (4) 8,730.38 91.90 7.59 6,178.54 6,101.69 1,187.14 4,648.53 6,001,774.40 503,303.58 13.28 4,787.60 MWD (4) 8,760.34 91.17 11.36 6,177.74 6,100.89 1,216.68 4,653.46 6,001,803.93 503,308.51 12.81 4,801.44 MWD (4) 8,792.53 90.28 15.58 6,177.33 6,100.48 1,247.97 4,660.96 6,001,835.22 503,316.01 13.40 4,818.26 MWD (4) 8,829.09 89.17 19.88 6,177.51 6,100.66 1,282.79 4,672.09 6,001,870.03 503,327.15 12.15 4,839.63 MWD (4) 8,868.22 90.28 24.87 6,177.70 6,100.85 1,318.96 4,686.98 6,001,906.19 503,342.05 13.06 4,865.00 MWD (4) 8,900.42 90.28 28.82 6,177.54 6,100.69 1,347.68 4,701.52 6,001,934.91 503,356.59 12.27 4,887.72 MWD (4) 8,930.48 90.21 32.91 6,177.41 6,100.56 1,373.48 4,716.94 6,001,960.70 503,372.01 13.61 4,910.37 MWD (4) 8,960.39 89.91 37.40 6,177.38 6,100.53 1,397.93 4,734.15 6,001,985.15 503,389.23 15.05 4,934.31 MWD (4) 8,990.16 88.00 40.83 6,177.92 6,101.07 1,421.02 4,752.93 6,002,008.23 503,408.01 13.19 4,959.32 MWD (4) 9,020.57 87.18 45.66 6,179.20 6,102.35 1,443.14 4,773.74 6,002,030.35 503,428.82 16.10 4,985.96 MWD (4) 9,050.49 87.57 48.94 6,180.57 6,103.72 1,463.41 4,795.70 6,002,050.61 503,450.78 11.03 5,013.12 MWD (4) 9,080.66 88.16 54.89 6,181.70 6,104.85 1,482.00 4,819.42 6,002,069.19 503,474.50 19.80 5,041.43 MWD (4) 9,110.44 86.28 55.18 6,183.14 6,106.29 1,499.04 4,843.80 6,002,086.23 503,498.88 6.39 5,069.89 MWD (4) 9,140.31 84.62 50.92 6,185.51 6,108.66 1,516.94 4,867.59 6,002,104.12 503,522.67 15.26 5,098.05 MWD (4) 9,170.65 83.76 46.92 6,188.58 6,111.73 1,536.76 4,890.33 6,002,123.94 503,545.42 13.42 5,125.83 MWD (4) 9,200.25 83.82 42.85 6,191.79 6,114.94 1,557.61 4,911.09 6,002,144.78 503,566.18 13.67 5,152.02 MWD (4) 9,231.41 83.21 38.22 W 6,195.31 6,118.46 1,581.13 4,931.21 6,002,168.30 503,586.30 14.89 5,178.44 MWD (4) 9,237.59 83.20 37.31 6,196.04 6,119.19 1,585.98 4,934.97 6,002,173.15 503,590.06 14.62 5,183.51 MWD (4) 9,275.00 83.20 37.31 6,200.47 6,123.62 1,615.53 4,957.49 6,002,202.69 503,612.58 0.00 5,214.08 PROJECTED to TD 11/3/2009 11:42:49AM Page 13 COMPASS 2003.16 Build 69 6 1 l p i h t k i SEAN PARNELL, GOVERNOR , L; ti n. ALASKA OIL AND ` =A 333 W. 7th AVENUE, SUITE 100 CONSERVATION r COMMISSION ANCHORAGE, ALASKA 99501 -3539 ii 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 -01 ConocoPhillips Alaska, Inc. Permit No: 209 -106 Surface Location: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 631' FSL, 172' 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, /4 Cath P. Foerster Commissioner DATED this GU" _ day of September, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • 4 ��, , ,,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1b. Current Wed Class: Exploratory ❑ Development 011 IS lc. Specify if well 13 proposed for. Drill ❑ Re -drill El Strallgraphic Test 0 Service El Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone[ , Single Zone ❑ Shale Gas ❑ 2. Operator Name: 6. Bond: U Blanket U Single Well 11. Well Name and Number. , ConocoPhillips Alaska, Inc. Bond No. 59 - 180 311 33AL2 - 01 3. Address: 8. Proposed Depth: 12. Field /Pool(s): ' P.O. Box 100360 Anchorage, AK 99510 MD: 9275' TVD: 6050' 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 OH Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 746' FNL, 701' FEL, Sec. 12, T12N, RO8E, UM 2657 10/20/2009 Total Depth: 9, Acres In Property: 14. Distance to 631' FSL, 172' FEL, Sec. 1, T12N, ROBE, UM 2580 Nearest Property: 18300' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 77 feet 15. Distance to Nearest Well Open Surface: x - 498655 y - 6000688 Zone 4 KB Elevation above GL: 38 feet to Same Pool: 3H -14B , 1200' 18. Deviated wells: Kickoff depth: 8050 ft. 17. Maximum Anticipated Pressures In psig (see 20 AAC 25.035) Maximum Hole Angle: 102.8 deg Downhole: 4126 psig Surface: 3473 psig 18. Casing Program s eciftcatlone Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2.375" 4.7# L - 80 ST - L 1715' 7560' 5980' 9275' 6060' slotted / solid liner - 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrid and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth - iVD (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' 9-6/8" 540 sx Mite, 178 sx LiteCRETE 4315' 3614' Intermediate Production 7984' 7" 309 sx Class 0 8020' 6396' Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 7740' -7760' 6140' -6158' 20. Attachments: Filing Fee ❑ BOP Sketch Er Drilling Program SI lime v. Depth Plot ❑ Shadow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 MC 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 @ 263 - 4172 Printed Name V. Cawvey Tiue Wells Manager ) Signature 1.. Phone: 265 -6306 Date 9//y07 . Commission Use Only Permit to Drill API Numb • PermitApp See cover letter Number. ��,Q�j 60, y O57ff 'OO) Date: 9 Df for other requirements Conditions of approval : If box is checked, well may not be used to explore for, teat, or produce coalbed m ane, gas hydrates, or gas contained In shales: d - j'b(.) Inc: SOP 71i_ Samples req'd: Yes ❑ No Mud tog req'd: Yes ❑ No lig Other: H2S measures: Yes No El Directional svy req'd: Yes V No ❑ ZJ�a ps c. f f h n. 141 A , L ' �f - 111,Let. J . - OVE' :YTHECO . .ION DATE: 4 )f L i " , COMMISSIONER Form 10-401 (Revised 1/2009) Submit in Duplicate O 9 • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Summary of Operations: Well 311 -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 2%" 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 31/2" 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 IGINAL September 1 of 4 ptember 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling 4. 3H -33AL2 Lateral (A2 sand, north) a. Set 3'h" 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. 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' 5. 31-1- 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 3Y2" tubing tail 6. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Obtain static BHP 2. Run GLV s. 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. IN! Page 2 of 4 '' September 16, 2009, FINAL i • 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 311-14B 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 3H -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 3H -33. All H monitoring equipment will be operational. " 1 Page 3 of 4 j , A 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 311- 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'/2" 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 �* 8. r ; tit September 16, 2009, FINAL • Conoco Phillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-33 3H-33AL2-01 Plan: Plan 2, 3H-33AL2-01 Standard Planning Report 10 September, 2009 mows 1AKER HUGHES flp • ConocoPhillips • FaiS Conoco Phillips Planning Report BAKER Alaska HUGIUS Database: ' EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H -33 Company: : ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: i Kuparuk River Unit MD Reference: _ 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: = Kuparuk 3H Pad North Reference: - True Well: 3H - 33 Survey Calculation Method: Minimum Curvature Wellbore: ' 3H- 33AL2 - 01 Design: Plan 2, 3H- 33AL2 -01 - ' .Project 2 _Kuparuk River Unit, North Slope Alaska Unted States _ R. -„ , . _ �. _ 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 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 0.00ft Wellhead Elevation: ft Ground Level: 36.10ft Wellbore 3H- 33AL2 -01 Magnetice Model Name Sample Date Declination Dip Angle Field Strength r) ( ° ) i (FIT) BGGM2009 11/4/2009 17.26 79.81 57,352 Deslgn = Plan 2, 3H- 33AL2 -01 _ Audit Notes: Version: Phase: PLAN Tie On Depth: 8,050.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) -36.10 0.00 0.00 20.00 Plan Sectlons Measured TVD Below Dogleg Build Turn Depth ;, inclination Azimuth System +WS +E/ -W Rate Rate Rate TFO (ft) r) r) ( ft ) (ft) (ft) r ooft) ( 7100ft) (°I100ft) r) Target 8,050.00 94.19 21.84 6,073.89 534.93 4,537.43 0.00 0.00 0.00 0.00 8,070.00 98.19 21.84 6,071.73 553.38 4,544.82 20.00 20.00 0.00 0.00 8,100.00 101.30 23.68 6,066.65 580.65 4,556.26 12.00 10.38 6.12 30.00 8,130.00 102.81 27.02 6,060.38 607.16 4,568.81 12.00 5.01 11.15 65.00 8,230.00 93.53 19.33 6,046.18 698.01 4,607.62 12.00 -9.28 -7.69 220.00 8,380.00 92.43 1.34 6,038.33 844.77 4,634.37 12.00 -0.73 -11.99 267.00 8,500.00 90.12 15.56 6,035.64 963.13 4,651.95 12.00 -1.92 11.85 99.00 8,650.00 88.70 33.50 6,037.20 1,099.03 4,713.96 12.00 -0.95 11.96 94.60 9,000.00 89.03 351.49 6,044.47 1,433.06 4,787.98 12.00 0.10 -12.00 270.00 9,275.00 88.64 24.50 6,050.21 1,701.58 4,825.69 12.00 -0.14 12.00 91.00 9/10/2009 11:00:02PM Page 2 COMPASS 2003.16 Build 69 f-'' 1 1 A L • ConocoPhillips • ConocoPhdlips Planning Report BAKER 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 Reformat 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: True Well: 3H - 33 Survey Calculation Method: Minimum Curvature Weilbore 311- 33AL2 -01 - Design: Plan 2, 3H- 33AL2 -01 Planned Survey Measured - TVD Below Vertic . Dogleg Tooke Map , -_ .. Map. - = �t Inclination Azimuth hr� = +E/ w +w-s Section Rate- : Azimuth Northi Easti - (t) 11 (1 (ft) ( ft ) (f) (ft) 1 - C) (ft) 8,050.00 94.19 21.84 6,073.89 534.93 4,537.43 2,054.56 0.00 0.00 6,001,122.27 503,192.36 TIP /KOP 8,070.00 98.19 21.84 6,071.73 553.38 4,544.82 2,074.43 20.00 0.00 6,001,140.72 503,199.76 End of DLS 20 8,100.00 101.30 23.68 6,066.65 580.65 4,556.26 2,103.96 12.00 30.00 6,001,167.98 503,211.20 3 8,130.00 102.81 27.02 6,060.38 607.16 4,568.81 2,133.17 12.00 65.00 6,001,194.48 503,223.76 4 8,200.00 96.32 21.60 6,048.75 670.02 4,597.18 2,201.94 12.00 - 140.00 6,001,257.33 503,252.13 8,230.00 93.53 19.33 6,046.18 698.01 4,607.62 2,231.82 12.00 - 140.90 6,001,285.33 503,262.58 5 8,300.00 93.05 10.93 6,042.16 765.42 4,625.84 2,301.39 12.00 -93.00 6,001,352.72 503,280.81 8,380.00 92.43 1.34 6,038.33 844.77 4,634.37 2,378.88 12.00 -93.48 6,001,432.07 503,289.35 6 8,400.00 92.05 3.71 6,037.54 864.74 4,635.25 2,397.94 12.00 99.00 6,001,452.03 503,290.24 8,500.00 90.12 15.56 6,035.64 963.13 4,651.95 2,496.11 12.00 99.09 6,001,550.41 503,306.95 7 8,600.00 89.16 27.52 6,036.27 1,055.98 4,688.59 2,595.89 12.00 94.60 6,001,643.24 503,343.61 8,650.00 88.70 33.50 6,037.20 1,099.03 4,713.96 2,645.02 12.00 94.53 6,001,686.28 503,368.98 8 8,700.00 88.70 27.50 6,038.34 1,142.08 4,739.32 2,694.14 12.00 -90.00 6,001,729.32 503,394.34 8,800.00 88.76 15.50 6,040.56 1,234.93 4,775.89 2,793.90 12.00 -89.86 6,001,822.16 503,430.93 8,900.00 88.87 3.49 6,042.63 1,333.36 4,792.35 2,892.03 12.00 -89.60 6,001,920.57 503,447.40 9,000.00 89.03 351.49 6,044.47 1,433.06 4,787.98 2,984.22 12.00 -89.35 6,002,020.27 503,443.06 9 9,100.00 88.84 3.49 6,046.33 1,532.77 4,783.62 3,076.42 12.00 91.00 6,002,119.96 503,438.71 9,200.00 88.71 15.50 6,048.48 1,631.19 4,800.08 3,174.54 12.00 90.78 6,002,218.38 503,455.19 9,275.00 88.64 24.50 6,050.21 1,701.58 4,825.69 3,249.45 12.00 90.52 6,002,288.75 503,480.81 TD- 23/8" Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/ -W Northing Easting -Shape (') ( °) (ft (ft) (ft) (ft) (fU Latitude Longitude 3H -33 A3 N t3.1 (copy 0.00 0.00 6,036.15 958.36 4,582.16 6,001,545.65 503,237.17 70° 24' 55.639 N 149° 58' 25.084 W - plan misses target center by 66.60ft at 8483.58ft MD (6035.72 TVD, 947.24 N, 4647.81 E) - Point 3H -33 A3 N t4.1 (copy 0.00 0.00 6,050.15 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 2.35ft at 9260.48ft MD (6049.87 TVD, 1688.28 N, 4819.87 E) - Point 3H -33 A3 N t2.1 (copy 0.00 0.00 6,058.15 719.33 4,513.19 6,001,306.65 503,168.16 70° 24' 53.289 N 149° 58' 27.110 W - plan misses target center by 96.70ft at 8215.97ft MD (6047.20 TVD, 684.86 N, 4602.87 E) - Point 3H -33 A3 N t1.1 (copy 0.00 0.00 6,090.15 570.30 4,455.20 6,001,157.66 503,110.16 70° 24' 51.824 N 149° 58' 28.812 W - plan misses target center by 90.97ft at 8050.48ft MD (6073.85 TVD, 535.37 N, 4537.60 E) - Point 9/10/2009 11:00:02PM COMPASS 2003.16 Build 69 - f tE''. ! A L ' • ConocoPhillips • Con©coPh flips Planning Report BAKER 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: ; 31 Rig © 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: = True Welt: 3H - 33 Survey Calculation Method M inimum Curvature Welibore: 3H 33AL2 - 01 Design: Plan 2, 3H 33AL2 -01 1 Casing PolMs Measured Vertical Casing Hole D Depth Diairretsr Diame (tt) (ft) Name () ("1 4,315.06 3,532.90 95/8" 9-5/8 12 -1/4 9,275.00 6,050.21 2 3/8" 2 -3/8 3 Pain Annotations Measured Vertices ' Local Coordinates Depth Depth +W +E/-W (ft) (ft) (ft) (ft) comment 8,050.00 6,073.89 534.93 4,537.43 TIP / KOP 8,070.00 6,071.73 553.38 4,544.82 End of DLS 20 8,100.00 6,066.65 580.65 4,556.26 3 8,130.00 6,060.38 607.16 4,568.81 4 8,230.00 6,046.18 698.01 4,607.62 5 8,380.00 6,038.33 844.77 4,634.37 6 8,500.00 6,035.64 963.13 4,651.95 7 8,650.00 6,037.20 1,099.03 4,713.96 8 9,000.00 6,044.47 1,433.06 4,787.98 9 9,275.00 6,050.21 1,701.58 4,825.69 TD 9/10/2009 11:00:02PM Page 4 COMPASS 2003.16 Build 69 Azimuma to Tme Norm WELLBORE DETAILS: 3H- 33AL2 -01 REFERENCE INFORMATION �- Project: Kuparuk River Unit Magnetic North 1728° �. Site: Kuparuk 3H Pad Mag o Field P aren Ti t Wellbore: 3H -33AL2 Coordinate (NIE) Reference Well 3H-33, True Nonh Well: 3H-33 Strength 57352.407 e on MD: 80 50 . 00 Vertirel (TVD) Reference: Mean Sea Level BAKER ConocoPhillips 1CC3P�ti1lipS Wellbore: 3H 33AL2 -01 DDMg1e72 a1° Secto Reference 38- 33915@ O.OgE) L {✓ V 1 Date. 11/4/29 9. Measured Depth Reference: Minimum Rig @ velure (015 (40.75 +36.1)) ' i �,,,aa Plan: Plan 2, 3H -03AL2 -01 (3H33/3H33AL2 -01) M ooe1. BOG f il 7 i i Alaska - - -- Cakua pn Netted: Mnimum CurvaWre 1800 - WELL DETAILS: 3H -33 - 3H -33/3H -33AL2 TD Ground Level: 36.10 170!1 +N/-S +E / -W Northing Easting Latittude Longitude Slot 311- 33/314- 33AL2 -01 0.00 0.00 6000588.21 498655.30 70° 24' 46.228 N 150° 0' 39.423 W 1600- - - - SECTION DETAILS ANN TAO TIONS 1500 Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec T. get Annotation 1 8050.00 94.19 21.84 6073.69 534.93 4537.43 0.00 0.00 2054.56 TIP I KOP 1400 9 2 8070.00 98.19 21.84 6071.73 553.38 4544.82 20.00 0.00 2074.43 End of DLS 20 3 8100.00 101.30 23.68 6066.65 580.65 4556.26 12.00 30.00 2103.96 3 1300 4 8130.00 102.81 27.02 6060.38 607.16 4568.81 12.00 65.00 2133.17 4 ^p 5 8230.00 93.53 19.33 6D46.18 698.01 4607.62 12.00 220.00 2231.82 5 6 8380.00 92.43 1.34 6038.33 844.77 4634.37 12.00 267.00 2378.88 6 ` `"1200 7 8500.00 90.12 15.56 6035.64 963.13 4651.95 12.00 99.00 2496.11 7 • 8 8650.00 88.70 33.50 6037.20 1099.03 4713.96 12.00 94.60 2645.02 8 (:.) 100 9 9000.00 89.03 351.49 6044.47 1433.06 4787.98 12.00 270.00 2984.22 9 8 _ 10 9275.00 88.64 24.50 6050.21 1701.58 4825.69 12.00 91.00 3249.45 TD O00 7 -__ - - -- --- - -.- -- o 900 - 800 6. Cr) T „tea..+.. rn 700 + 600 a y 500 _.... -... End of DLS 20 .. -. 400- TIP / KOP '.. 211 -3 111-3 3H 1] ; ?A_ 313- 33/3H -33AL( 300- 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 West(-)/East( +) (100 ft/in) 58001.. _. ..... ___ _..... _.. 5850 5900- : 5950 3H-33/3H-33AL1 End of DLS 20 3H- 33/3H- 33AL2 -01 6000 a ' m TIP / KOP 3 5 6 7 8 9 _. __ . CI, 11,1 6050; - TD to • .O c 6100- t y 8 11 - - ,11-1 -1 \ 311- 33/31( -31AL2 6150 d) � 6200.. _. _ ..... _ ._._ __ __ ......._. _- _...... 6250 '', 6300 - ,� ... 1 i . , H1-11 ',. 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 3100 3150 3200 3250 3300 3350 3400 Vertical Section at 20.00° (50 ft/in) a PamirMa to Trim Norm WELLBORE DETAILS: 3H- 33AL2 -01 REFERENCE INFORMATION Mr""" Project: Kuparuk River Unit Magnetic Nam. 21.85° Slte: Kuparuk 311 Pad Coordinate (WE) Reference: Wet 3H-33. True North Maki P arent Wellbore: 3H33AL2 Meg 4 N Rig Fre BAKER Well: 311 Strength 57842,300T Vertical (D) Reference: 311.33 @ 76.8551 (D15 (40.75 +36,1)) D Angie: 80.87° Tie o1r MD: 8050.00 Section (VS) Reference: Slot - (0.00N, 0.00E) p Wellbore: 311 33AL2 - Date: 11/4/2009 Measured Depth Reference: 31133 Rig @ 76.8551 (015 (40.75 +36.1)) HUGHES Conoco Phillips Plan: Plan 2, 3H (3H33/3H 33AL2 - 01) M o eel er0 3MS0o9 Calculation Method: Minimum Curvature 3H- 14/311 -1413L) 6y6 311- 14,7}1- (4131,4 . . 3450 __.. _.. _.._.... _. ... _... _...... ....... __. 3300 .. 3150 - 3000- 3H- )4/3H -14 2850 c � y oo .._ ° O O 311- )4r3H- 14APB1 311 -14A / 'p 2700- 311-14/' c ,794 o il 6 ! - - -- 311- 14/311.14B 2400- ., ° 0 ° : ',, , .... .. -... 2250 - 2100- .. .. ... .. x.1950- .,,e,,.a,.<,a 1800. _... _. _._. ......_ _...... __ _- ._ _.... �. 0 311- 31/311- 33AL2 -01 "'.» X1650- 6/27 4." X1500- ,. ... 71350 / 1200- ... ,. ,� ... _.. ,.... ° 1050 -. !,. .. ... • + ■ 900. 750- + 600- . 450- ... .. c o a b b . 314- 33/3H -33 '... 300 - --��\ 150 _..... ......_ _....._ _.... , -_ _..... __. _.. _. _ . _.._ ____- 0- ', .\ -150 .. :11 -L1 +11 -11.. / -300- � _�f -- _ '., • .. / -450- �� _ = - 311- 33/311 -33A )II_.' 44 _,; \il 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3 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" Camco TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) ■ ..mmener. ■ 3 -1/2 ", 9.3#, L -80 EUE 8rd Tubing to surface 16 ", 62 #, H -40 conductor 111111111.. 3 -1/2" Camco MMG gas lift mandrels at 2735', 4444', 5710', 6789', & 7453' shoe 149' MD NNW SOW 9.5/8 ", 408, L -80 casing ,,- ■ ■ shoe of 4315' MD NNW I al . �V -- n O ' X- nipple at 7504' MD (2.813" min ID) -,3 l Baker Premier packer at 7547' MD. No sealbore or seal assembly. 7 Camco D- nipple @ 7594 MD (2.75" min ID, No -Go) Nipple milled out to 2.80" ID t C 3 -1/2" tubing tail at 7606' MD (7602' ELM) Top of cement at tubing tail at A1Z 7606' MD KOP #2 at 7665' MD AL2 -01 Lateral (A3 sand, north) KOP #1 at 7685' MD �= _ _ TD = 9275' • Baker monobore whipstock trays on i — Liner top at 7560' openhole anchors at 7665' & 7685' `: — ' y 7 / / / AL2 Lateral (A2 sand, borth) 2.80" pilot hole in cement drilled to �;; 44� _ _ _ _ TD = 9275' 7725' MD 111 _— — �� Billet at 8050' AL1 Lateral (A3 sand, south) A -sand parts (sgz'd) - 0 TD = 10,050' 7740' - 7760' MD _= / / Liner top at 7680'. 2 — 7 _ �\ A Sidetrack (A2 sand, south) �.. — �, /) TD = 10,050' ' 7 ", 268, L -80 casing Billet at 6100' shoe at 8020' MD J _ • • • Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator E!.=3 Riser Annular/ Blind / Shear 2" Pipe / Slip (CT) • Pump into Lubricator 11.- above BHA rams — I I Choke 1 2 Pipe / Slip (BHA) Choke Equalize Manifold 2-3/8" Pipe / Slip (BHA) _J L Kill ■1><>< 1 E Blind / Shear 2" Pipe / Slip (CT) Choke 2 -i l l- Swab Valves Wing Valves ■4IP■ ■4111k Tree Flow Cross • prdipiu 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 ift Alaska Department of Natural esources Land Administration System Page 1 of,/ • t. R Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources 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 '''aP_. 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 /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2553... 9/24/2009 • • Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 9:29 AM To: Ramirez, Darlene V (DOA) Subject: Re: 209 -106 Approved Sent from my iPhone On Sep 25, 2009, at 4:03 PM, "Ramirez, Darlene V (DOA)" <darlene.ramirez @alaska.gov > wrote: > «S45C- 209092513470.pdf» > The message is ready to be sent with the following file or link > attachments: > S45C- 209092513470.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- 209092513470.pdf> 1 S TRANSMITTAL LETTER CHECKLIST WELL NAME j2I/ J. FS,4Iv? PTD# 0?0 9/0:6 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: POOL: 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 new wellbore segment of existing / well ,,ed 0,44J�A 1/ (If last two digits in Permit No „29Q/&? API No. 50-,VS f0/ -00. 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(f), 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-33AL2-01 Program DEV Well bore seg ❑ PTD#: 2091060 Company CONOCOPHILLIPS ALASKA 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 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes I7 Sufficient acreage available in drilling unit Yes 2657 acres. 8 If deviated, is welibore plat included Yes 9 Operator only affected party Yes 1 10 Operator has appropriate bond in force Yes Blanket Bond #59 -52 -180. 111 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative appro Yes Yes 1 13 Can ermit be ACS 9/24/2009 ' Well located with n area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA • 1 116 Pre - produced injector: duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA_ 18 Conductor string provided NA Conductor set in 3H -33 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 OH slotted liner completion 23 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage or reserve pit Yes Rig equipped with Steel pits. 25 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 welibore is 3H -33 P &A portion. & paths diverge. 27 If diverter required, does it meet regulations NA Wellhead in place with BOP stack. A r Date 128 Drilling fluid program schematic & equip list adequate Yes Max formation pressure 4126 psi (12.9ppg) Will drill with Managed Pressure. GLS 9/24/2009 29 BOPEs, do they meet regulation Yes Using 10 ppg mud combined with surface pressure and wellbore friction 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 132 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S reported 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 analysis of shallow gas zones NA ACS 9/24/2009 38 Seabed condition survey (if off- shore) NA 139 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering Public C m sion Date: Commissioner: Date Commissioner Date Ly0709
