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209-104
• • 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. c o -La `- Well History File Identifier Organizing (done) ❑ Two -sided III II I III ❑ Rescan Needed 1111111111111111111 R ESC N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: Y P41-.1 ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals .,,,y _S OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: ,M BY: c Maria ) Date: 3 I / /s/ (' Project Proofing III I III I BY: Date: 1 f ai J 1 I /s/ p Scanning Preparation a., x 3 = 1 170 + g = TOTAL PAGES 10 5 (Count does not include cover sheet) yyl BY: ( 1aria) Date: 31 /s/ Production Scanning III 111111 I I 111 I I III Stage 1 Page Count from Scanned File: __ (Count does include cov sheet) Page Count Matches Number in Sca ning Preparation: YES NO BY: 1- Date: 1 31 J il /s/ / p Stage 1 If NO in stage 1, page(s) discrepancies were found: - YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ill I III II 11 III ReScanned 111 IIIIIIIIIII 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III I 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091040 Well Name /No. KUPARUK RIV UNIT 3H -33AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -60 -00 MD 10100 TVD 6108 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: none (data taken from Logs Portion of Master Well Data Maint ID Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ['ED C Lis 19145 duction /Resistivity 7529 10101 Open 1/13/2010 MPR plus logs in PDF, Tiff, & cgm graphics D C Lis 19146Induction /Resistivity 7529 9607 Open 1/13/2010 PB1 MPR plus logs in PDF, Tiff, & cgm graphics og Induction /Resistivity 2 Col 7665 10100 Open 1/13/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7665 10100 Open 1/13/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7665 10100 Open 1/13/2010 TVD MPR, GR og Induction /Resistivity 2 Col 7665 9607 Open 1/13/2010 PB1 MD MPR, GR og Induction /Resistivity 5 Col 7665 9607 Open 1/13/2010 PB1 MD MPR, GR oVog Induction /Resistivity 5 Col 7665 9607 Open 1/13/2010 PB1 TVD MPR, GR • D C Asc P Directional Survey 40 10100 Open Directional Survey 40 10100 Open D C Asc Directional Survey 40 9607 Open PB1 Rpt Directional Survey 40 9607 Open PB1 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANC E REPORT 1/25/2011 Permit to Drill 2091040 Well Name /No. KUPARUK RIV UNIT 3H -33AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -60 -00 MD 10100 TVD 6108 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION k' Well Cored? Y / Daily History Received? ( l `.Y N Chips Received? YfPf -- Formation Tops lY / N Analysis R • eceived? Comments: Compliance Reviewed By: Date: k • Company ConocoPhillips, Alaska, Inc. ) / i (!� � � - r l I BA KER Well Name 3H -33AL1 c} I L 15 � ,, ?t j `; HUGHES Date 1/6/2010 INTE() ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribution RECIPIENTS No other distribution is allowed without , OH FINAL OH FINAL ;), ; ' "' written approval from ConocoPhillips Image files and /or Digital Data contact: Lisa Wri • ht, 907 263 -4823 ( hardco • prints ConocoPhillips Alaska, Inc. ' 4 • Sharon Allsup -Drake i Drilling Tech, ATO -1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ` iC : ATTN: MAIL ROOM i 700 G Street, c i '? Anchorage, AK 99501 i � `� ConocoPhillips Alaska, Inc. 4 4 w Ricky Elgarico i 1 Graphic Image 1 Disk * / i ' - -' • ? File * * / * ** Electronic i i r, t tSt,1{r k 7-00-6-Street, CGM / TIFF LIS A t r ftp: / /b2bftp.conocophillips.com * * ** AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk */ ' : 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic i ,t ` i 7 ; Anchorage, Alaska 99501 CGM / TIFF LIS ';''''t'',. BP 1 Hardcopy Print, ,�T• ,� Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk`/ �*, i David Douglas in lieu of sepia ** Electronic '� ` X41'' P.Q. Box 196612 CGM / TIFF LIS Alaska 99519 -6612 y "� i ' � . Anchorage, � CHEVRON /KRU REP 1 Hardcopy Print, ' "i's tt : e) if Glenn Fredrick 1 Graphic image file 1 Disk * / . N)i. , g� , P.O.Box 196247 in lieu of sepia ** Electronic �[ " 1 :I.':".:,°, • 1 Anchorage, Alaska 99519 CGM / TIFF LIS ,'4 55pp Brandon Tucker, NRT k State of Alaska; DNR, Div. of Oil and Gas 1 Disk'/ V � t ��° ,,4 `' 550 W. 7th Ave, Suite 800 Electronic f ■,, ` I(ifrs•r,!" Anchorage, Alaska 99501 -3510 LIS 4'Y DS Engineer / Rig Foreman + r o z dte TOTAL Page 1 of 4 Company ConocoPhillips, Alaska, Inc. 4 , \,1,,1 ,,: ?..,,o,/,: ::,,,,_. FA 11 EIAKEIR 10 HUGHES Well Name 3H-33AL1PB1 C; 1 .... , i -.z i (..'.cr■, 9 ( q 11-1(7 AliotsV , (A ,- - --- 1 Date 1/6/2010 ‘ Ani,z3-,17,40.r., MTTEQ ConocoPhillips Alaska Greater Kuparuk Area Data Distribution RECIPIENTS , No other distribution is allowed without OH FINAL OH FINAL . 'l 1 written approval from ConocoPhillips Image files and/or Digital Data , contact: Lisa Wrie ht, 907 263-4823 hardco • prints 1 , A sk ConocoPhillips Alaska, Inc. 4 , , lip Sharon Allsup-Drake Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, . Anchorage, AK 99501 - J --, I ConocoPhillips Alaska, Inc. • Ricky Elgarico 1 Graphic Image 1 Disk*/ . -- •,., ..1 , File**/*** Electronic Y 700 G Street, CGM / TIFF LIS ... Anshcoage,,414-,99504. • 4„. , ftp://b2bftp.conocophillips.com AOGCC 1 Hardcopy Print, - • '., i :,:,-,-,../ 7%17/ I Christine Mahnken 1 Graphic image file 1 Disk*/ - .., , . 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS i Ilk BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic • ,—,. . ,„, ,. P.O. Box 196612 CGM / TIFF LIS • ' .... , •,, .r• i f•'''44 Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Lis 'f1 _'::;:::'";.:?._._,•:,'':'' ,; -:' Glenn Fredrick 1 Graphic image file 1 Disk*/ ., . , ,... P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM/TIFF Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS ;r7,.....,_.....,....,..,..,....;=,,,,,,,,m DS Engineer / Rig Foreman `i.-: • ,_,..,..,...„,,,,,..,:i;:421 TOTAL r ' - '''-'777-77,1•31 Hardco. Prints 4 - i: Page 1 of 4 • RECEIV STATE OF ALASKA • A V 2 0 LASKA OIL AND GAS CONSERVATION COMMISSION NU 2009 WELL COMPLETION OR RECOMPLETION REPORLANDAAS.Commission 1a. Well Status: Oil 0 Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: AnchOr8ge 20AAC 25.105 20AAC 25.110 Development El Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: • ConocoPhillips Alaska, Inc. \ orAband.: October 30, 2009 209 - 104 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 16, 2009 50 103 - 20578 - 60 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM \ October 23, 2009 3H - 33AL1 Top of Productive Horizon: 8. KB (ft above MSL): 77 ' RKB 15. Field /Pool(s): 739' FNL, 671' FEL, Sec. 12, T12N, R8E, UM GL (ft above MSL): 36' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2603' FSL, 741' FEL, Sec. 12, T12N, R8E, UM 10100' MD / 6108' 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 10100' MD / 6108' TVD ADL 25531 TPI: x - 502983 y - 6000919 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 502913 y 5998981 Zone 4 2110' MD / 1998' TVD 2657 18. Directional Survey: Yes El 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 7665' MD / 6073' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE Wr. 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 7804' 10100' 6148' 6108' 3" slotted liner 24. Open to production or injection? Yes 0 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 7812' -8660' MD 6150' -6125' TVD 8662' - 8851' MD 6125 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8976 MD 6111' - 6109' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9179' - 10098' MD 6117' - 6108' TVD none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 7, 2009 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 11/11/2009 24 hours Test Period - -> 1179 1631 499 176 Bean 1383 Flow Tubing Casing Pressure Calculated OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - API (corr) Press. 145 psi 1319 24 - Hour Rate - 1179 1631 _ 499 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE " 'IFIED Form 10-407 Revised 7/2009 CONTINUED ON REVERSEWM/ t 1 0 ilubmit original o 28. GEOLOGIC MARKERS (List all formations and markers en countered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1738' 1680' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk A3 7726' 6120' Top Kuparuk A2 7770' 6140' Top Kuparuk A2 7918' 6142' Top Kuparuk A3 8855' 6124' Top Kuparuk A3 9220' 6118' 3H -33AL1 PB1 N/A Total depth 9607' 6118' Formation at total depth: Kuparuk A3 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional surveys e - 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Gary Eller @ 263 - 4172 Printed NaX Vo Ca Title: CT Drilling Manager ;� Signature Phone 265 - 6306 Date 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 vv ., _ KUP I 3H -33AL1 o CoE ocoPhiltips ' WJ1 Attributes __ Max Angle & MD TD AI V "': i, Wellbore APUUWI Field Name Well Status loci ( °) MD (f1613) Act Btm (ftKB) L,o,�OCr.}1 ; i i i 501032057860 KUPARUK RIVER UNIT _ JPROD 98.16 I 8,900 26 _ 10,1000 - "' Comment I H2S (ppm) Dale IAn otetion'End Date KB -Grd (ft) Rig Release Date Well Conte DDEVIAT J- 3H -33AL 7,2209 2]11 PM SSSV: Last WO' 2/14/2009 Flapper Locked Out 0 1/1/2009 _ Schematic Ac.uai Annotation Depth (ftKB) End Date [Annotation Lest Mod ... End Date Last Tag: ' I Rev Reason: GLV C/O _ _ 1 Imosbor 11/7/2009 - -- ■ - .. Casing Strings HANGER, 37 - - - -- 7 Casing Description String 0... String ID ... I Top (ftKB) ption . [String ... String Top Thrd 1., _., fl I Set Depth (6. Set Depth (TVD) _. String Wt. 11 LINER AL1 2 3/8 1 995 7, 803.7 10,100.0 6,107.7 4.60 L-80 STL Liner Details Top Depth - .. - _ (TVD) Top Inc! Noml... "� _ - Top (ftKB) (ftKB) (1 Item Description Comment ID (In) 7,803.7 6,148.9 85.40 BILLET 2.625" aluminum billet (2.70" G FN) 1.995 8,661.5 6,125.2 88.38 DEPLOY 2.7" GS Baker Deployment Sleeve 1.995 Other In Hole jWireline retrievable plugs, valves, pumps, fish, etc. Top Depth 1 (TVD) Top Inc! CONDUCTOR, _ Top (ftKB) (ftKB) ( °) Description Comment R Date ID (in) 40 -169 -. - .. 7,804 6,148 9 85.40 WHIPSTOCK; WHIPSTOCK - LINER BILLET 10/25/2009 1.000 Perforations & Slots snot Top (TVD) Btm (TVD) Dens SAFETY VLV, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh- Type Comment 2,110 , 7 8,660 6,149.6 6,125.2 10/24/2009 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid /slotted pipe - 0.125 "x2.5" @ 4 circumferential I GAS LIFT, _ adjacent rows, 3" centers staggered Il 2,735 18 deg, 3' non - slotted ends I t 8,662 8,851 6,1252 6,125.4 10/24/2009 32.0 SLOTS 8,976 9,040 6,111.2 6,109 3' -. -. -.- 10/24/2009 32.0 SLOTS 9,179 10,098 6,116.6 6,107.7 10/24/2009 32.0 SLOTS 1 Notes: General & Safety SURFACE,_ End Date Annotation 62 - 6,315 2/1 7/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 11,2/2009 INOTE WELL SIDETRACKED - A, ALI, AL2, AL2- 01� ~~ �� - � GASLIFT, r= I - _:... ..._.:w .,V.W.. 4, dk GAS LIFT, 1 5,710 GAS LIFT, 6,789 GAS LIFT, 7,453 - Ili NIPPLE,7,504 P PACKER, 7,547 NIPPLE, 7,594 i -. WLEG,7,606 WINDOW AL1, -... ;... 7,660 -7,665 WHIPSTOCK, 7,665 WHIPSTOCK, 7,804 NTERMEDIATE, 39 -8,020 L II -__ 6 SLOTS, 7,812 -8,660 SLOTS,_ 8,662 3,851 Mandrel Details I ''Top Depth Top Port (TVD) Inc/ OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make. Model (!n) sere Type Type (in) (pal) Run Date Com... 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 8,976 _.. 2 4,444.2 3,698.4 46 93 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,303.0 11/6/2009 3 5,709.7 4,598.0 45 83 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,282.0 11/4/2009 4 6,789.1 5,362.3 44 45 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,263.0 11/4/2009 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 SLOTS, -- - 9,179- 10,098 LINER AL1, 7,804 - 10,100 TD (3H- 33AL1), 10,100 3H -33 Actual CTD Sidetrack Schematic Updated: 11/2/2009 3 -1/2" Camco TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) _...,._� 3 -1/2 ", 9.38, L -80 EUE 8rd Tubing to surface kiiiitx- 16 ", 628, H -40 conductor 3 -1/2" Camco MMG gas lift mandrels at 2735', 4444', 5710', 6789', & 7453' shoe 149' MD ` 4 9-5/8", 40#, L -80 casing shoe at 4315' MD .......0101 Nm r • 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 I "` BELOW 2.318" LINER TOP at 7583' MD *". Camco D- nipple @ 7594 MD (2.75" min ID, No-Go) I Nipple milled out to 2.80" ID 3 -1/2" tubing tail. at 7606' MD (7602" ELM) Top of cement at tubing tail at 7606' MD s;, ,, \ \ N AL2-01 Lateral (7974' - 92751 KOP #2 at 7665' MD M • 2 -3/8" liner 7583 - 9275' MD KOP #1 at 7685' MD M, — ) Blank liner 7679' -7762' � /i — — Baker monobore whipstock trays on _ ,...,..2,,... openhole anchors at 7665' & 7685' M AL2 Lateral (7803' - 9382') µ it \ \ / — \ 2 -30' slotted liner 7984 - 9382' MD 2.80" pilot hole in cement drilled to � �j _ \ I IIII)h' — ' - - _ — \ ) Anchor - Billet at 7974' • 7715' MD vµ ��� " �"�'�'' M �"� � ALY AL1 Lateral {7665' - 10.100`) P61 (8810' - 960T) 2 -3 /8" liner 7803'- 10,100' A -sand perfs (sgz'd) \ � ® Anchor - Billet at 8810' 7740' - 7760' MD M � ^' ,,, M: hilik...:: h Blank liner 8851' -89710 & "- \ — — — — — 9040' -9178' °" " °- -- \ — � — — — — — _ — _ — Liner junction @ 8662' MD � Aluminum billet at 7803' 7 ", 268, L -80 casing _ _ — _ _ _ _ — shoe at 8020' MD i — — - - - - - A Sidetrack (7685' - 10.307') 2 -3/8" slotted liner 7673' -9944 Unlined hole 9944'- 10,307' 1 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ` Comment 11:45 13:15 1.50 0 0 COMPZ CASING PULD T Deploy BHA #12 13:15 15:45 2.50 0 7,500 COMPZ CASING TRIP T RIH displacing KCL from well to TT. 15:45 16:00 0.25 7,500 7,550 COMPZ CASING DLOG T Tie in, +0.5' 16:00 16:45 0.75 7,550 7,665 COMPZ CASING MILL T Tag billet at 7665', PU and close EDC. 1.44 BPM, 3700 CTP, 4050 BHP, 200 WHP, 13.1 ECD 22K PUW, 8K RIW Time milling at 1 FPH to remove enough billet to set next whipstock. 16:45 17:36 0.85 7,665 7,666 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 FPH 17:36 18:33 0.95 7,666 7,668 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2FPH 18:33 19:18 0.75 7,668 7,669 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2FPH 19:18 20:18 1.00 7,669 7,670 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2 FPH 20:18 22:03 1.75 7,670 7,671 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2 FPH 22:03 22:18 0.25 7,671 7,550 COMPZ CASING WPRT T Milled down 8' of billet, PUH to tie in 7550'. PUW =21 K. 22:18 22:27 0.15 7,550 7,570 COMPZ CASING DLOG T Tie in depth to gamma. Correction +1'. 22:27 22:42 0.25 7,570 7,674 COMPZ CASING WPRT T Offline with pumps. RIH to dry tag top of liner. Tag TOL 7674'. POOH to TT pumping minimum rate. 22:42 00:00 1.30 7,674 800 COMPZ CASING TRIP T Open EDC in TT, POOH, 800' MM and choke plug off. Stop blow back, RIH 1000' pumping 1.4BPM using choke to keep BHP constant, Cleaning hole. 10/15/2009 Pack off surface lines during POOH from milling Allum. Billet. Circulate to free all debris from surface lines. RIH for Clean Out run to assure hole clean. RIH with Whipstock setting at 7673, TOW = 7665'. 00:00 01:00 1.00 937 937 COMPZ CASING TRIP T ChokeA plugged off. ChokeA is not holding pressure, possible wash out. Shut in well on tree. Open up well to MP line to monitor WHP. Shut in well on stack. Blow back choke A. 01:00 01:39 0.65 937 0 COMPZ CASING TRIP T Choke clear of debris. Cont. POOH. Plugging still going on. 01:39 02 :00 0.35 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA, Choke is plugged, once undeployed need to flush choke manifold /choke A and choke B & MicroMotion. 02:00 02:45 0.75 0 0 COMPZ CASING CIRC T Stop undeploying operations. BHA is in 2 3/8" P/S deployment rams. Pressure bleed off above deployment rams. Having problems bleeding off during undeploying. Change operations to flushing surface lines and choke to free all lines of Aluminum. Undetermined if hole is clean of aluminum. Possible rerun BHA in rams for clean out run. Page 13 of 27 • Time Logs Date From To Dur S. Depth _ E Depth Phase Code Subcode T Comment 02:45 03:15 0.50 0 0 COMPZ CASING CIRC T Choke B is washed out. Choke A is flushed out. Lots of aluminum across shakers. 03:15 04:30 1.25 0 0 COMPZ CASING RGRP T Rebuilding Choke B 04:30 06:00 1.50 0 0 COMPZ CASING RGRP T Cannot get choke B to work properly. Call electrician out to calibrate choke B. 1.5 hours of Nabors rig repair time. 06:00 06:30 0.50 0 0 COMPZ CASING SFTY T Crew change, PJSM 06:30 09:00 2.50 0 7,673 COMPZ CASING TRIP T RIH with EDC open, pumping 0.7 BPM 09:00 11:18 2.30 7,673 0 COMPZ CASING TRIP T Close EDC, pump 0.7 BPM. Tag liner top. POOH, increase rate to 1.5 BPM through the bit. Started plugging up the choke around 2000', RIH and swap to choke A. Clear choke and go back to choke B. Continue POOH, tag stripper and _ RIH 300'. POOH 11:18 13:18 2.00 0 0 COMPZ CASING PULD T Undeploy BHA, bit is still 2.73" go/ 2.72" no go. 13:18 15:30 2.20 0 0 PROD2 RPEQP1PULD P Deploy whipstock, BHA #13. 15:30 17:30 2.00 0 7,560 PROD2 RPEQP1TRIP P RIH. Kept anchor orientation sideways to minimize chance of _ _ hanging up on aluminum debris. 17:30 17:45 0.25 7,560 7,575 PROD2 RPEQPI DLOG P Tie in, +1.5', Close EDC and continue RIH Holding 900 WHP 17:45 18:00 0.25 7,575 7,673 PROD2 RPEQPI WPST P RIH to 7673.7', stacking 1K WOB. PU to 7670 and RIH to 7673.2', 0 WOB. Top of whipstock 7664.5'. Orient whipstock to high side. Pump down coil at 0.25 BPM. Sheared at 4500 CTP to set anchor. 18:00 19:30 1.50 7,673 0 PROD2 RPEQPITRIP P POOH 19:30 23:00 3.50 0 0 PROD2 RPEQPI PULD P PJSM, Undeploy whipstock BHA. Deploy milling BHA #14. 23:00 00:00 1.00 0 PROD2 WHPST TRIP P RIH with milling BHA to mill window #2 -- TU71 67 Mill window TOW= 7665', BOW= 7670', Drill 10' of rat hole to 7680'. POOH, Perform BOP test. 00:00 00:30 0.50 6,700 7,550 PROD2 WHPST TRIP P Cont. RIH 00:30 00:45 0.25 7,550 7,583 PROD2 WHPST DLOG P Tie in Depth. Correction +4' 12NV 00:45 01:15 0.50 7,666 7,666 PROD2 WHPST MILL P RIH for dry tag, Dry tag 7666'. PUH 7657'. Online with pumps 1.3BPM, 3700psi CTP, 399 diff psi. off bottom. RIH to 7665.7. Start to see motor work 450 diff psi. Stop CT let it mill off. 01:15 06:00 4.75 7,666 7,669 PROD2 WHPST MILL P Set auto driller to 1 FPH, Mill ahead 9K CTW, 3600 CTP, 500 DHWOB, 162psi WHP, 487 diff psi. 06:00 10:18 4.30 7,669 7,670 PROD2 WHPST MILL P Milling with 2000 to 2500 WOB. This is about 100 PSI of motor work. Page 14 of 27 • • Time Logs Date From To Dur S. Depth_ E. Depth Phase _Code ''' Subcode T '? Comment 10:18 11:18 1.00 7,670 7,672 PROD2 WHPST DRLG P Appear to have exited casing, mill at 1 FPH. 2000 WOB, 50 -100 PSI motor work 11:18 13:54 2.60 7,672 7,680 PROD2 WHPST DRLG P Milling formation at 3 FPH, 2000 WOB, 100 PSI motor work 13:54 14:42 0.$0 7,680 7,660 PROD2 WHPST REAM P Ream window at 1 FPM up and down. 14:42 14:54 0.20 7,660 7,680 PROD2 WHPST REAM P Shut down pump and drift through window. No indication of WOB. 14:54 15:18 0.40 7,680 7,575 PROD2 WHPST DLOG P Tie in from 7550', -1' correction 15:18 15:42 0.40 7,575 7,580 PROD2 WHPST CIRC P RIH and swap well to new mud. 15:42 17:42 2.00 7,580 0 PROD2 WHPST TRIP P POOH 17:42 17:57 0.25 0 0 PROD2 WHPST PULD P Undeploy milling BHA 17:57 18:27 0.50 0 0 PROD2 WHPST SFTY P Crew change, PJSM. 18:27 19:42 1.25 0 0 PROD2 WHPST PULD P Continue Undeploying milling BHA 19:42 20:45 1.05 0 0 PROD2 WHPST CIRC P MU nozzle to CT, Flush BOP's and choke. 20:45 21:45 1.00 0 0 PROD2 DRILL BOPE P Grease Tree and stack valves, PU _ test joint. 21:45 22:00 0.25 0 0 PROD2 DRILL BOPE P Hold PJSM for BOP testing. State witness. (Lou Grimaldi) 22:00 00:00 2.00 0 0 PROD2 DRILL BOPE P Start BOP testing. 10/17/2009 Q Perform full BOP test. Deploy Build section BHA #15, 2.6AKO. Drill build section 7680' - 7970'. 00:00 05:00 5.00 0 0 PROD2 DRILL BOPE P BOP testing complete in 7 hours. State witnessed. Tested to 250/4500 psi, annular to 250/2500 psi. All components passed. 05:00 06:00 1.00 0 0 PROD2 DRILL BOPE P Displace reel back to new mud. 06:00 06:30 0.50 0 0 PROD2 DRILL SFTY P PJSM for deploying BHA 06:30 09:00 2.50 0 0 PROD2 DRILL PULD P Start deployment procedure. Confirm adustment on AKO on motor to 2.6 deg. Tool string hung up below master valve, worked free and then worked down past with aggressive SL action. 09:00 11:12 2.20 0 7,550 PROD2 DRILL TRIP P RIH - 11:12 11:24 0.20 7,550 7,575 PROD2 DRILL DLOG P Tie in, +1.5' 11:24 11:42 0.30 7,575 7,680 PROD2 DRILL TRIP P RIH to drill 11:42 18:42 7.00 7,680 7,830 PROD2 DRILL DRLG P Drilling ahead„ 1.3 BPM, 3700 CTP, 41140 BHP, 50 WHP (wide open choke). 19K PUW, 8K RIW 18:42 19:12 0.50 7,830 7,685 PROD2 DRILL WPRT P Wiper trip back to 7685'. 21K CTW. 19:12 00:00 4.80 7,830 7,949 PROD2 DRILL DRLG P Drill ahead 1.3 BPM, 3800psi CTP, 4170 BHP, 50psi WHP, fully opened choke. 10/18/2009 Land build section AL1 with 51.58 deg dogleg average. POOH, Undeploy BHA #15, Service injector head, Deploy BHA #16, Drill AL1 lateral section from 7970' to 8559'. Page 15 of 27 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 00:00 00:45 0.75 7,949 7,970 PROD2 DRILL DRLG P Drilling Ahead 00:45 02:45 2.00 7,970 0 PROD2 DRILL TRIP P Land Build section AL1, 51.58 deg dogleg average for build section. PUH wiping hole back to window. Looks good. PUH through window, Open EDC, POOH 1.5BPM following MP trip schedule. 02:45 03:00 0.25 0 0 PROD2 DRILL SFTY P At surface, Hold PJSM for undeploy 03:00 04:30 1.50 0 0 PROD2 DRILL PULD P Undeploy BHA #15 04:30 06:00 1.50 0 0 PROD2 DRILL SVRG P Service injector head 06:00 06:18 0.30 0 0 PROD2 DRILL SFTY P PJSM for deployment 06:18 07:18 1.00 0 0 PROD2 DRILL PULD P Deploy BHA #16 for drilling lateral 07:18 08:48 1.50 0 7,550 PROD2 DRILL TRIP P RIH 08:48 09:18 0.50 7,550 7,720 PROD2 DRILL DLOG P Tie in, +1' correction. Log RA, RA depth is 7670.5', this makes TOW 7665.2', BOW 7670.0 09:18 09:30 0.20 7,720 7,970 PROD2 DRILL WPRT P Continue RIH 09:30 14:18 4.80 7,970 8,120 PROD2 DRILL DRLG P Tag at 7970 and drill ahead. 3800 CTP, 50 WHP, 4230 BHP, 21K _ PUW, 9K RIW 14:18 14:30 0.20 8,120 7,840 PROD2 DRILL WPRT P Wiper trip to window 14:30 15:30 1.00 8,070 7,690 PROD2 DRILL DLOG P MAD pass from 8070 to 7690 15:30 15:42 0.20 7,690 8,120 PROD2 DRILL WPRT P Continue Wiper to bottom 15 :42 17:57 2.25 8,120 8,270 PROD2 DRILL DRLG P Drilling ahead, 3650 CTP, 56 WHP, 4152 BHP, 21K PUW, 9K RIW 17:57 18:48 0.85 8,270 7,690 PROD2 DRILL WPRT P Wiper trip to 7690', 21K CTW 18:48 20:48 2.00 8,270 8,420 PROD2 DRILL DRLG P Drill Ahead 90 FPH, .9K DHWOB, 1.35BPM, 3950psi CTP. Fully open choke 20:48 22:00 1.20 7,690 8,420 PROD2 DRILL WPRT P Wiper trip to 7690', 21K CTW. Trap pressure tie in depth to RA marker. 0 correction, RBIH 22:00 00:00 2.00 8,420 8,570 PROD2 DRILL DRLG P Drill Ahead 100FPH, 8K CTW, 1.2K DHWOB, 1.4BPM, 4000psi CTP. Fully Open choke 10/19/2009 Drill AL1 from 8559' to 9319'. 00:00 01:30 1.50 8,570 7,695 PROD2 DRILL WPRT P Wiper trip to 7695'. 21 K CTW 01:30 04:15 2.75 8,570 8,720 PROD2 DRILL DRLG P Drill Ahead 50- 60FPH, 1.3K DHWOB, 1.3BPM, 3850psi CTP 04:15 05:45 1.50 8,720 8,720 PROD2 DRILL WPRT P Wiper trip. 05:45 08:30 2.75 8,720 8,870 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3800 CTP, 4200 BHP, 50 WHP (wide open choke), 21K PUW, 8K RIW 08:30 10:00 1.50 8,870 8,870 PROD2 DRILL WPRT P Wiper trip to window with tie in at RA, -0.5' 10:00 13:30 3.50 8,870 9,020 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3800 CTP, 4200 BHP, 50 WHP (wide open choke), 21K PUW, 8K RIW Page 16 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:30 2.00 9,020 9,020 PROD2 DRILL WPRT P Wiper trip to window 15:30 19:00 3.50 9,020 9,170 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3800 CTP, 4170 BHP, 25 WHP (wide open choke), 21K PUW, 8K RIW 19:00 20:45 1.75 9,170 7,690 PROD2 DRILL WPRT P Wiper trip to window, 21K CTW 20:45 00:00 3.25 9,170 9,319 PROD2 DRILL DRLG P Drill Ahead 2K DHWOB, 40 FPH, 1.3BPM, 4100psi CTP, 4170psi BHP, 13.3ECD, 0 WHP, fully open choke. 10/20/2009 ' 1 TD lateral AL1 @ 9607'. POOH and P/U 2.625" anchored Al. Billet BHA. RIH pumping . 2 bpm through EDC. LkT a/4L, Tie in above window with 1.5 ft correction. 00:00 01:09 1.15 9,319 7,670 PROD2 DRILL WPRT P Wiper trip back to window, Bypass Micro Motion to repair choke B. 01:09 01:15 0.10 7,695 7,709 PROD2 DRILL DLOG P Tie in depth to RA marker. No correction 01:15 02:15 1.00 7,709 9,319 PROD2 DRILL WPRT P RIH to drill 02:15 04:45 2.50 9,319 9,457 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM, 3700 CTP, 4163 BHP, 21 WHP with wide open choke. 21K PUW, 4.5K WOB, 1:1 returns. Last mud check still good, 1650' on mud system. 04:45 08:00 3.25 9,457 7,692 PROD2 DRILL WPRT P Wiper for a geologist time out. Choke B acting up again. 08:00 11:51 3.85 9,457 9,607 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM, 3750 CTP, A 4180 BHP, 30 WHP with wide open e choke. 21K PUW, 4.5K WO: . returns. Swa• d. 11:51 14:51 3.00 9,607 0 PROD2 DRILL TRIP X TD called AM POOH for open hole geo- sidetrack. POOH. 14:51 15:06 0.25 0 0 PROD2 DRILL SFTY X At surface, PJSM undeploying BHA. 15:06 18:06 3.00 0 0 PROD2 DRILL PULD X Undeploy BHA #16, Orient anchor on billet 20R, face 20L. Service injector head, clean gripper blocks, check stripper rubber. 18:06 19:36 1.50 74 74 PROD2 STK PULD X Deploy BHA #17 with 2.625" OH Anchored Billet. 19:36 23:36 4.00 74 7,560 PROD2 STK TRIP X Equalize pressure and open EDC. RIH 250 ft. BHI comp[uter locked up, stop RIH to re -set computers to read BHA. fixed. Continue RIH 40 fpm pumping @ .2 bpm through EDC holding back pressure on the choke. 23:36 00:00 0.40 7,560 7,570 PROD2 STK DLOG X Tie in depth - + 1.5 ft correction. Weight check before out window 22K. Stop pumping, Close EDC, Continue RIH. 10/21/2009 Set top of Anchored Billet A 8810. P/U BHA #18 with 1.0 AKO & 2.73 Bi- center. Tag TOB 8810.2', Hard • time getting Ko started. Numerous stalls, started to improve after 2 ft drilled, 100' wiper trip due to shaving balling up near bit. Completed Billet KO from 8810 - 8815'. Page 17 of 27 • 1 Time Logs Date From To Dui S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:48 0.80 7,570 8,821 PROD2 STK WPST X RIH, no weight bobbles through window or build section. Orient tool face to 20 left. Pressure up to 4100 psi, tool set. Set down 5K on tool. Looked good. P/U weight 23.5K. Top of Billet t 8810' , 00:48 03:48 3.00 8,821 0 PROD2 STK TRIP X POOH pumping 1/2 bpm. up to window. Shut down open EDC and - POOH as per pressure schedule. 03:48 06:57 3.15 0 0 PROD2 STK PULD X Lay down BHA # 17, P/U BHA # 18 with 1.0 AKO & 2.70" Bi- center. 06:57 08:27 1.50 0 7,550 PROD2 DRILL TRIP X RIH with BHA #18. 08:27 08:42 0.25 7,550 7,670 PROD2 DRILL DLOG X Tie in depth with gamma, +1 correction 08:42 09:42 1.00 7,670 8,811 PROD2 DRILL TRIP X R1H to Billet 09:42 09:57 0.25 8,811 8,801 PROD2 STK TRIP X Dry tag billet PUH 10' online c14?)1\' ry g with pumps. 1.3BPM, 3550psi CTP set auto driller for 1 FPH 09:57 10:42 0.75 8,810 8,811 PROD2 STK KOST X Start time milling 20L TF 1 FPH with auto driller. 396psi diff psi, 0 DHWOB 10:42 11:42 1.00 8,811 8,811 PROD2 STK KOST X Stall X 2 offline with pumps, PUH, RtH time mill 1 FPH 11:42 12:42 1.00 8,811 8,811 PROD2 STK KOST X Stall x 2, PUH, RIH time drill 1 FPH 12:42 12:48 0.10 8,811 8,811 PROD2 STK KOST X Restart time drilling .1 /6min. trying to get started pump 5bbrls 776 4 Lj. 12:48 15:03 2.25 8,811 8,811 PROD2 STK KOST X Stall PUH try working down time drilling .05 /6min, pump 5 bbrls 776 15:03 16:18 1.25 8,810 8,811 PROD2 STK KOST X Time mill down trying to get started Stall,X2 16:18 16 :48 0.50 8,811 8,811 PROD2 STK KOST X PUH 50', RtH 2OFPM stop at 8810.5' time mill in hole trying to get started, 16:48 17:48 1.00 8,811 8,810 PROD2 STK KOST X Stall x2 PUH, RIH try to get started.. Total of 10 stalls since trying to get started. 17:48 19:12 1.40 8,811 8,812 PROD2 STK KOST X Slowed down Drill speed to 1/2 fpm, taking .1 every 5 min. Starting to get light Al. returns to surface. Continue KO with .1 incriments every 5 min. had 8 advancements then a stall. WOB zero, CT weight 7K. Choke B starting to plug off. Work through by -pass and blow back. ECD & Annular increased by 200 psi. 19:12 20:12 1.00 8,812 8,812 PROD2 STK WPRT X Choke is clean, P/U weight 24 K, pressure went back to normal during 100ft wiper. WOB is greater on bottom now. back to normal. 20:12 21:30 1.30 8,812 8,812 PROD2 STK KOST X Back on bottom milling. WOB 1.0, ECD 13.1, BHP 4100, WHP 100, CT weight 10K, Circ 3800 psi, 1.48 bpm. Stall @ 8812.1. Heavy Al. returns to surface. P/U 70 ft weight & pressure is stacking out again. Page 18 of 27 • • Time Logs Date ` From To Dur S. Degth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 8,812 8,814 PROD2 STK KOST X BOBD - 8811.5 - motor work detected. Continue time drilling up to 8812.2 then set auto drill 1.5 fph to 8813, Al. filing are slowing down, increase to 2 fph to 8814.3, increase to 3 fph to 8815.4, then 10 fph. Gained 2 bbls. 10/22/2009 KO billet from 8810 - 8815'. Continue drilling Lateral as per plan, starting to lose CT weight while drilling @ 9450'. 00:00 02:00 2.00 8,814 8,840 PROD2 STK KOST X Drill 10 fph for 1 ft, then 20 fph for 30 ft. WOB 1 K, Ct weight 9K, circ press 3800 @ 1.46 bpm, BHP 4100, ECD 13.1, ROP 20 fph. Light Al and _ formation in returns. 02:00 03:42 1.70 8,840 8,840 PROD2 STK WPRT X P/U weight 27K, wiper up to window, flush choke B. Then RIH & dry through billet. Total of 2 bbl gain since midnight. Dry tags looked clean through billet. 03:42 05:57 2.25 8,840 8,901 PROD2 DRILL DRLG X Drilling ahead - CT weight 8k, circ press 3800, 1.45 bpm, ROP 40 fph, _ WHP 150, BHP 4150, ECD 13.2. 05:57 08:12 2.25 8,901 7,690 PROD2 DRILL WPRT X P/U to window for geo wiper. Waiting on Geo from town. 08:12 10:27 2.25 8,901 9,055 PROD2 DRILL DRLG X On bottom drilling following plan 10:27 11:57 1.50 9,055 7,690 PROD2 DRILL WPRT X Wiper trip back to the window 11:57 14:12 2.25 9,055 9,205 PROD2 DRILL DRLG X Drill ahead, 1.8K DHWOB, 100FPH, 1.4BPM, 4000psi CTP, 150psi WHP, 13.2ECD, 4150psi BHP. 14:12 15:24 1.20 9,205 7,695 PROD2 DRILL WPRT X Wiper trip to window 15:24 15:30 0.10 7,695 7,712 PROD2 DRILL DLOG X Tie in depth with RA marker. +2 correction 15:30 16:15 0.75 7,712 9,205 PROD2 DRILL WPRT X RIH to Drill 16:15 18:15 2.00 9,205 9,355 PROD2 DRILL DRLG X Drill Ahead 60FPH 1.2K DHWOB, 1.4BPM 3880psi CTP, 90psi WHP, 4128psi BHP. 18:15 20:15 2.00 9,355 9,355 PROD2 DRILL WPRT X Wiper trip to window. CT weight 22K off bottom 20:15 22:00 1.75 9,355 9,505 PROD2 DRILL DRLG X BOBD - Ct weight 2k, Circ - 3900, 1.45 bpm, WHP 100, BHP 4170, ECD 13.3, ROP 75, Hit good sand (A -3) at 9480'. 22:00 00:00 2.00 9,505 9,505 PROD2 DRILL WPRT X Wiper trip to window, Ct weight 23k off bottom. Setting up pits for a mud swap. 10/23/2009 Continue drilling lateral to TD of 10,100'. Wiper trip, prepare KWF & liner pills. 00:00 00:30 0.50 9,505 9,505 PROD2 DRILL WPRT X Complete Wiper trip, set up pits for mud swap. 00:30 02:00 1.50 9,505 9,588 PROD2 DRILL DRLG X BOBD - CT weight 2k, circ - 4000 psi, 1.44 bpm, WHP 60, BHP 4160, ECD 13.2, ROP 80 fph, WOB 1.7 - in good sand. Start pumping new mud when on bottom drilling. Page 19 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:18 1.30 9,588 9,655 PROD2 DRILL DRLG X New Mud B /U, Drilling pressures - Circ 4000 psi, 1.44 bpm, BHP 4150, WHP 50, ECD 13.2, WOB .83, Ct weight 1 K, ROP 50. Continue drilling ahead and watch for change. 03:18 04:54 1.60 9,655 7,660 PROD2 DRILL WPRT P Wiper trip to window. P/U weight 22k off bottom. Perfrom Static test & Tie on wiper. 04:54 05:24 0.50 7,660 7,660 PROD2 DRILL OWFF P Perfrom static test for 30 min. Started pressures WHP 930 psi, BHP 4170, ECD 13.4./ 15 minutes - WHP 867, BHP 4030, ECD 13.04./ 30 minute - WHP 848, BHP 4020, ECD 13.0. 05:24 06:45 1.35 7,660 9,655 PROD2 DRILL WPRT P RIH Tie -in, trip to bottom. 06:45 08:00 1.25 9,655 9,805 PROD2 DRILL DRLG P Drill Ahead .25K DHWOB, 75- 100FPH, 1.4BPM, 3800psi CTP, 08:00 11:00 3.00 9,805 7,690 PROD2 DRILL WPRT P Wiper trip to window 21K CTW 11:00 12:21 1.35 9,805 9,955 PROD2 DRILL DRLG P Drill ahead, 1.6K DHWOB 80 -100 FPH, 1.4BPM 3931psi CTP 12:21 15:21 3.00 9,955 7,690 PROD2 DRILL WPRT P Wiper trip to window, 23K CTW 15:21 16:06 0.75 9,955 10,050 PROD2 DRILL DRLG P Drill Ahead 16:06 16:36 0.50 9,900 10,050 PROD2 DRILL WPRT P BHA Wiper 16:36 18:06 1.50 10,050 10,100 PROD2 DRILL DRLG P Drill Ahead, TD AL1 lateral at 10,100' _ MD. 18:06 21:36 3.50 10,100 9,110 PROD2 DRILL WPRT P P/U weight off bottom - 22k, Wiper to window, perform Tie -in. ( +2.5), mixing up pill pits & swapping pits for liner run. 21:36 22:06 0.50 9,110 9,250 PROD2 DRILL WPRT P While RIH tagged up @ 9110'. P/U weight 22k at first then starting to see tool drag, up to 30 K at surface, leveled out after 30 ft. Toolface was HS, POOH 200 ft and stabilize conditions. RIH and watch area & TF, RIH small weight bobbles, run dow to 9250 & wipe up through area again. 22:06 23:36 1.50 9,250 10,100 PROD2 DRILL WPRT P P/U weight 22k, Slight drag up to 24 k @ 9170', continue POOH up to 8830' to ensure the hole is clean. Looks good, continue RIH. Tag bottom @ 10100.4' Start pumping beads down through CT. 23:36 00:00 0.40 10,100 10,100 PROD2 DRILL DISP P Begin pumping beads down CT, bypass high presssure screens. Pumped 22 bbls, wait on KWF pill, have to swap pits to weight up a little more. Trap pressure on well and slowly move pipe. 10/24/2009 Lay in liner pill from 10100 up to 7800' lay in KW bead pill up to 7200' then KWF to surface killing the well. Monitor well, P/U lower liner assembly spot from 10100 to 8661'. POOH pumping KWF. P/U upper liner assembly. Page 20 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase _Code ` Subcode T Comment 00:00 01:00 1.00 10,100 10,100 PROD2 DRILL DISP P Weighing up KWF - slowly moving CT up /down while pumping 5 bbl KWF beads in CT. 01:00 02:30 1.50 10,100 7,300 PROD2 DRILL TRIP P Start POOH flag pipe 8474' laying in liner pill 1:1 up to 7800' then KWF pill to 7300'. Stop pumping and Open EDC. 02:30 04:30 2.00 7,300 0 PROD2 DRILL TRIP P POOH laying in KWF follwing MP. EOP flag 6083'. Good KWM to surface @ 1100', Stop POOH and change screens on shaker. Continue POOH to surface. 04:30 05:00 0.50 0 0 PROD2 DRILL OWFF P Monitor well for 20 minutes. Have tool box talk on laying down BHA & Top drive maint. 05:00 06:00 1.00 0 0 PROD2 DRILL PULD P lay down BHA, prepare to P/U Liner BHA. 06:00 08:45 2.75 0 COMPZ CASING SVRG P Inspect derrick and PDL lifting slings and shackles, service injector head, Thaw top drive of ice and operate up and down. Prepare floor to run liner 08:45 09:00 0.25 0 0 COMPZ CASING SFTY P PJSM to run liner 09:00 12:00 3.00 0 0 COMPZ CASING PUTB P Start picking up first segment of liner 12:00 13:30 1.50 1,483 7,561 COMPZ CASING RUNL P RIH with liner 13:30 13:36 0.10 7,561 7,563 COMPZ CASING DLOG P Tie in depth to EOP flag +2' correction 13:36 13:42 0.10 7,563 7,600 COMPZ CASING RUNL P Continue RIH to top of window. Record up and down weights 21 K up and 8K down. 13:42 14:12 0.50 7,600 10,100 COMPZ CASING RUNL P RIH through window 5 -10 FPM. Once through window RIH 60 FPM, slowing down 20FPM at the billet at 8810'. 14:12 14:27 0.25 10,100 8,659 COMPZ CASING RUNL P 1st segment of liner on Bottom, tag at 10107.8'. Calling 10100' bottom. PUH to record pick up weight. 31 K CTW. RIH placing CT into compression. Come online with pumps .75 BPM 2890 psi CTP. PUH to release off of liner. Released off of liner 21 K pick up weight. Line up to pump across top of stack. Subtract 1440' out of BHA length. 14:27 17:27 3.00 8,642 7,742 COMPZ CASING RUNL P POOH, pumping across the top. Paint EOP flag at 7743.2MD, EOP 7700'. Continue POOH through window. Tie in depth with RA marker. -3' correction. Line up to pump down the CT. POOH 17:27 19:27 2.00 0 0 COMPZ CASING SFTY P CT @ surface, monitor well during hand -over. Hold safety meeting for P/U liner #2 assembly. Perfrom Safety Stand drill with night crew. 19:27 21:27 2.00 0 903 COMPZ CASING PUTB P Start P/U liner assembly. Page 21 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code ' Subcode T Comment 21:27 22:27 1.00 903 903 COMPZ CASING RGRP T While P/U Coiltrac the safety lock out pins on the top drive came out. System is disabled but not working correctly. Stop and repair. (By -pass hydraulic override manually) 22:27 23:27 1.00 903 903 COMPZ CASING PULD P Complete lowering in Coiltrack and inspect injector prepare to RIH. 23:27 00:00 0.55 903 903 COMPZ CASING RUNL P RIH with BHA # 20: 2nd segment of liner. 10/25/2009 RIH set upper liner & billet top @ 7804.4', POOH. P/U BHA # 21 - 1.3 AKO with Bi- center - RIh swap to 10 # drilling mud. Kick off Top of Billet from 7803 - 7808'. Continue drilling lateral in A -2 formation. 00:00 02:00 2.00 8,662 8,662 COMPZ CASING RUNL P RIH from 2000' EOP flag on depth @ 6000', continue RIH with liner. Perform weight check prior to exiting window. 22k, RIH slowly 20 fpm through window, no problems, RIH tag liner top from 1st segment @ 8662.4 - sat down 5k at surface. Start pumping . 1 bpm, build pressure to 3000 psi & release from liner. 02:00 04:00 2.00 7,804 0 COMPZ CASING RUNL P Top of billet is 7803.7, POOH pumping down CT to keep hole full of KWF while POOH 04:00 05:30 1.50 0 0 COMPZ CASING PULD P At surface, Check the well for flow (15 min.) lay down BHA #20. 05:30 06:45 1.25 0 0 PROD3 DRILL PULD P Service injector head, check stripper rubber, PU BHA #21. 1.3deg AKO, 06:45 08:54 2.15 0 7,565 PROD3 DRILL TRIP P RIH with lateral BHA #21 with EDC open, pumping 0.4 BPM to sidetrack AL2 08:54 09:03 0.15 7,565 7,582 PROD3 DRILL DLOG P Tie in depth to gamma +3' correction 09:03 09:12 0.15 7,582 7,806 PROD3 DRILL TRIP P Close EDC RIH through window no pumps. Online with pumps RIH hrough build section. Offline with pumps tag billet 7806'. 09:12 10:12 1.00 7,806 7,350 PROD3 DRILL CIRC P PUH circulating 13.1 ppg KWM out of hole. 10:12 11:24 1.20 7,350 780 PROD3 DRILL TRIP P RIH to mill 11:24 14:24 3.00 7,803 7,805 PROD3 STK KOST P Start time milling .03 /6min. Aluminum over the shakers 14:24 15:00 0.60 7,805 7,806 PROD3 STK KOST P Increase ROP to .05' /6min 15:00 15:39 0.65 7,806 7,807 PROD3 STK KOST P Increase ROP to 2' /hour 3� 15:39 16:09 0.50 7,807 7,808 PROD3 STK KOST P Increase ROP to 3' /hour L1 16:09 16:30 0.35 7,808 7,825 PROD3 DRILL DRLG P Confirmed Sidetrack with near bit ('1 inclination. 7806- 7808'. PUH through sidetrack and 10' above, did not see anything. Offline with pumps, RIH through sidetrack dry, did not see anything. 16:30 18:30 2.00 7,825 7,955 PROD3 DRILL DRLG P Drill ahead 1K DHWOB, 30- 50FPH, 1.4BPM 3990psi CTP, 4100psi BHP, 13.1 ECD, 240psi WHP Page 22 of 27 ConocoPhilhips ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33AL1 501032057860 Z 0 0 GO • Baker Hughes INTEQ Definitive Survey Report ort BAS R HUGHES 03 November, 2009 Iri, 141111111 , Conoccfti Ilips Definitive Survey Report „ ..1 1 Alaska i f .,v-. _..... -. ..... .. ry ..,.«««_..._. ':1'''' •, a ,fi al «...._. �., n . k •---w .� ,.:..W{.. _ i ...,_. «- 3 4' Cootnpatf ,,, ConocoPhillips(Alaska) Inc. L� , �rdirrate RefOr irce: l Prole Kuparuk River Unit TVD Re ferene� 1 � ��Kuparuk 3H Pad Mt Referee: �� , ' 1 3H -33 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) ,�3 -33 Rig @ 76.85ft (D15 (40.75 +36.1)) 1 4i f, l 3H -33 � No Reference : %w True We1l re 3H-33 Survet Cal latiotl Method Minimum Curvature Des gn . 31-1-33 bafa ase ii p u. ` 144 ,„, EDM Alaska Prod v16 III r n1 , S U U t , vey 4i` - tt - rNN _. .I e p i a k -kg f _ '' '- �xi �i c i i i - t ..� '� l' �' tF p M O Map Vertical MD ,, ,�tV1C � ' A TVD . m " TVDSS +N/ S +I"/?W NaNhir g Easting= ' S Sgct�an Survey Taal Nartfe nrtitltetl its � 40.75 0.00 0.00 40.75 -36.10 0.00 0.00 6,000,588.21 498,655.30 0.00 0.00 UNDEFINED 100.50 0.57 321.50 100.50 23.65 0.23 -0.19 6,000,588.44 498,655.11 0.95 -0.26 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 -0.45 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 3.09 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 12.90 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 26.41 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 41.61 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 57.88 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 74.86 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 90.65 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 0.02 105.42 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 3.24 121.38 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 4.44 125.79 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 3.17 130.42 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 3.29 135.27 GYD -CT -CMS (1) 1,200.00 18.44 63.86 1,181.60 1,104.75 52.33 169.87 6,000,640.50 498,825.16 5.45 140.46 GYD -CT -CMS (1) 411 1,225.00 19.72 64.63 1,205.23 1,128.38 55.88 177.23 6,000,644.05 498,832.52 5.22 146.09 GYD -CT -CMS (1) 1,250.00 20.21 65.34 1,228.72 1,151.87 59.49 184.97 6,000,647.66 498,840.26 2.19 152.06 GYD -CT -CMS (1) 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 0.33 158.14 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 0.24 164.26 GYD-CT -CMS (1) 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 0.70 170.37 GYD -CT -CMS (1) 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 4.19 176.36 GYD -CT -CMS (1) e 1,375.00 18.19 67.24 1,346.32 1,269.47 76.75 223.63 6,000,664.92 498,878.92 3.78 182.13 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 0.68 187.78 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 1.72 193.46 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 4.52 199.31 GYD -CT -CMS (1) 1,475.00 20.71 66.36 1,440.85 1,364.00 89.82 253.50 6,000,677.97 498,908.79 3.84 205.47 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 4.20 212.00 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 3.96 218.95 GYD -CT -CMS (1) 1,550.00 23.64 70.07 1,510.34 1,433.49 100.18 279.71 6,000,688.33 498,935.00 5.00 226.34 GYD -CT -CMS (1) 11/3/2009 11:34:27AM Page 3 COMPASS 2003.16 Build 69 lir' t� ! ConocoPhillips [a CoPhilli� Definitive Survey Report - Alaska . 1-, Cottrpa` - ConocoPhillips(Alaska) I nc . Local C o ordina{e 1 3H -33 Ni Proje Kuparuk River Unit ,'`FAD Reference I � r d 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) iSiteL' 1 . Kuparuk 3H Pad WID fie rence 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Velh1 3H -33 Northtkeo nce; '111 ' : 1 Viellt ore: ' 3H -33 Survey Calcutatlon Method gt Minimum Curvature �° � EDM Alaska Prod v16 Deign i 3H 33 Database ....._..�._.. ti s z _ ........ .:nm r SCihrey a � R � •c ; l I r � 'i � t � � t r �� �'° ' 'Ma � � .�J� nha "� � ;\/ @rtiCaF �� Ii tD (: ii . A i - � - '° , , {s 7V 6ss +i41 +Eim * P i i D , , 1111 g ft 4 a i r tftj a ^ N i j ng (� /10o' S oo 'on Survey N ame i , } Arirtotat „,,,,,g.,,,,...,,,:, * ,i ( 1,575.00 24.76 70.71 1,533.14 1,456.29 103.62 289.37 6,000,691.76 498,944.65 4.60 234.15 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 3.77 242.35 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 1.83 250.79 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 0.56 259.33 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 0.72 267.88 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 0.78 276.39 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 0.70 284.91 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 1.27 293.54 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 2.36 302.35 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 2.46 311.40 GYD -CT -CMS (1) 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 3.68 320.75 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 5.15 330.54 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 2.31 340.69 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 1.16 351.00 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 0.43 361.39 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 1.42 371.87 GYD -CT -CMS (1) 0 1,975.00 31.51 77.44 1,887.20 1,810.35 155.30 467.53 6,000,743.41 499,122.81 4.17 382.60 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 3.90 393.71 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 5.05 405.22 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 7.57 417.24 GYD -CT -CMS (1) 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 3.08 429.71 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 1.62 442.38 GYD - CT-CMS (1) I. 2,125.00 36.79 79.35 2,010.30 1,933.45 172.16 551.43 6,000,760.25 499,206.70 0.53 455.14 GYD - CT-CMS (1) 2,150.00 36.82 79.37 2,030.32 1,953.47 174.92 566.15 6,000,763.01 499,221.42 0.13 467.94 GYD -CT -CMS (1) 2,175.00 36.85 79.59 2,050.33 1,973.48 177.66 580.89 6,000,765.75 499,236.16 0.54 480.76 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 0.94 493.64 GYD -CT -CMS (1) a 2,225.00 37.35 80.78 2,090.23 2,013.38 182.87 610.56 6,000,770.95 499,265.83 2.57 506.68 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 2.74 519.95 GYD-CT -CMS (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 2.87 533.47 GYD -CT -CMS (1) z 2,300.00 39.27 83.77 2,149.24 2,072.39 189.18 656.41 6,000,777.25 499,311.67 5.13 547.35 GYD -CT -CMS (1) ) 2 325 00 40 39 84 83 2,168.44 2,091.59 190.77 672.34 6,000,778.84 499,327 60 5.24 561.70 GYD -CT -CMS (1) 11/3/2009 11:34:27AM Page 4 COMPASS 2003.16 Build 69 y ConocoPhillips f'# � ill ps Definitive Survey Report 4 1 � I"r e .. ,__ ._ ... ...._ _.. , ._._...;. s;1 : 111'' ._....._._ ` Compa 14"- .. ConocoPhillips(Alaska) .=`Local ordin Re i nc Al 3 H - pin hA �t i Prol li Kuparuk River Unit TND Refbrence' '', 7 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Sfte, ' ,ice Kuparuk 3H Pad M D Re enc 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) I Wet . 4 _ li 3H -33 ° North R± wren #e: True ) We11bore l " 3H-33 i Sunray loula on Method: Minimum Curvature Alaska Prod v16 i e gr1t 3H -33 _.,„k','1.„ r atatr EDM Surve ■ 1 +�� :0'4 �I, �i�, ■ , Map: ,Map YeT� cat s � � � , ' P 7�-, �i _, DLS MD Inc 1zr TWD ` `{ 'DSS +N1-S +S1-W Northing E a s tln ° M- Seetion Su r ve )r Tool blame Annotation 41 ( ft i .00 41.51 85.8 .`'( °) (°) ` f; (ft). (ft) 110.47 IlAft) 192.10 688.67 6,000,780.17 (ft) (ft), �H., 499 (ft) 9 (4!100`) ) 343.93 5.22 576.50 GYD -CT -CM vF 2,350 2,187.32 2, (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 2.67 591.66 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 0.79 606.96 GYD -CT -CMS (1) 2,425.00 41.87 86.82 2,243.07 2,166.22 195.19 738.74 6,000,783.25 499,394.00 1.41 622.26 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 1.72 637.47 GYD -CT -CMS (1) i 2,475.00 41.20 87.05 2,280.53 2,203.68 196.96 771.82 6,000,785.01 499,427.07 1.03 652.59 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 0.84 667.67 GYD -CT -CMS (1) 2,525.00 41.19 87.40 2,318.18 2,241.33 198.53 804.67 6,000,786.57 499,459.92 0.55 682.77 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 0.88 697.93 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 1.53 713.18 GYD -CT -CMS (1) 2,600.00 42.24 87.67 2,374.24 2,297.39 200.70 854.45 6,000,788.74 499,509.70 1.87 728.58 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 3.44 744.17 GYD - CT-CMS (1) 2,650.00 43.67 87.60 2,410.79 2,333.94 202.10 888.54 6,000,790.13 499,543.78 2.29 759.97 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 1.16 775.90 GYD -CT -CMS (1) 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 0.52 791.88 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 0.20 807.89 GYD -CT -CMS (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 0.14 823.90 GYD-CT -CMS (1) g fifi 2,775.00 44.12 87.37 2,500.64 2,423.79 205.80 975.37 6,000,793.82 499,630.60 0.48 839.90 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 0.58 855.87 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 0.87 871.82 GYD -CT -CMS (1) a 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 0.91 887.75 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 2.28 903.58 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 2.83 919.20 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 1.44 934.65 GYD - CT-CMS (1) 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 1.54 949.97 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 0.43 965.22 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 0.10 980.45 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 0.33 995.69 GYD - CT-CMS (1) 3,050.00 42.55 84.90 2,700.47 2,623.62 220.40 1,163.68 6,000,808.38 499,818.89 1.08 1,010.93 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 1,026.14 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 1,041.33 GYD -CT -CMS (1) 11/3/2009 11:34 :27AM Page 5 COMPASS 2003.16 Build 69 1•' ConocoPhillips reiiiii Grmlocc4:'hillips Definitive Survey Report ILlItillillW; Aleeka Company Conoco Phillips(Alaska) Inc. L a1 Co- v rdiflate=Reference 3H -33 1 Project. , ; Kuparuk River Un TVD + fever e. ' irY 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Sit r P Kuparuk 3H Pad Md Reterer y 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Wel 3H -33 y Caicuiat , Nor t h Re True Veiib re,y 7 3H -33 ; ' Survey io t Method 4 Minimum Curvature d#� tf 31 ' EDM Alaska Prod v16 ,�' C)atabaee _ r. �tk Au:. i. w ww ....... ��.s:i Mary �uuu�x .. nu�n nw =EV. w wiwk0.,m'r ,' L mm x......_. ...w...._.....___,""'""n'''' - tv. w .�»e. ---. .e ..s � o W urveji� :I , ---,-;-1,f'''' r -w - i '( '1 (4 '; . "' 4-4,),,, r r -mss 1! i � p Vertu 1, h , i Id inc Rz_ , - - N ©SS + /S +EI=W '_ , Northing E a s ti n (J `e (ft) { ' f 1A9-- C') 1 (ft) . ' (ft) (t) y Art) 9_ ( _, ,,. Survey To I Name Annotation 3,125.00 42. 85.47 2,755.92 2,679.07 224.58 1,213.99 6,000,812.55 499,869.21 0.32 1,056.53 GYD -CT -CMS (1) 3,150.00 42.22 85.74 2,774.44 2,697.59 225.86 1,230.75 6,000,813.83 499,885.96 0.73 1,071.75 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 1,087.01 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 1,102.33 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 1,117.69 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 1,133.13 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 1,148.69 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 1,164.32 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 1,179.98 GYD-CT-CMS (1) 3,350.00 43.06 86.66 2,920.93 2,844.08 235.04 1,366.59 6,000,822.98 500,021.79 1.61 1,195.61 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 1,211.13 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 1,226.59 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 1,242.06 GYD -CT -CMS (1) 3,450.00 42.54 87.34 2,994.66 2,917.81 238.36 1,434.06 6,000,826.29 500,089.25 0.44 1,257.56 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 1,273.09 GYD -CT - 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 1,288.67 GYD -CT CM S (1) (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 1,304.32 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 1,320.09 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 1,335.94 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 1,351.85 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 1,367.77 GYD -CT -CMS (1) 3,650.00 43.49 87.77 3,140.21 3,063.36 244.36 1,571.09 6,000,832.26 500,226.27 1.15 1,383.65 GYD -CT -CMS (1) 3,675.00 43.47 87.92 3,158.35 3,081.50 245.01 1,588.28 6,000,832.91 500,243.46 0.42 1,399.51 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 1,415.39 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 1,431.32 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 1,447.33 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, 1, (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 1.80 1,479.66 463.45 GYD GYD -CT CT C -CM S ( 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 1,495.95 GYD -CT -CMS (1) 3,850.00 45.22 88.11 3 283.58 3,206.73 249 25 1,710. 44 6,000,837.1 3 500,365.60 0.89 1,512..30 GYD-CT-CMS (1) 3,875.00 45 36 88.12 3 3 224 31 249 83 1 728.19 6,000,837.71 500,383.36 0.56 1 528.71 GYD-CT-CMS (1) 11/3/2009 11:34:27AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips anoccftillips Definitive Survey Report Alaska 'damp igiiri ConocoPhillips(Alaska) Inc. Locait C oordinate ReferO1ce� r 3H - 33 iP O't. Kuparuk River Unit Tlt Retere`nre t 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) t0 Kuparuk 3H Pad MD Reference 3H - Rig @ 76.85ft (D15 (40.75 +36.1)) V t eill ,. yo3H -33 (firth Re ttce: ` i True 1 Webb 'i 3H-33 . Sut'vey C , Minimum Curvature •6esign 1 � t 3H-33 �riabe.64 ° 1: -. ,'-„ "EDM Alaska Prod v16 i Surtiwy a r E _ I � Pia is "i � ' y 1 ( ¢ _ _ '06- ,',I !I: -- ' ,_ ' - - ' , ' ',, , ,,:, fl #- 1 ` i � 1 i,a K t Matt vertiCai _ 1 ,..' !IL' "- = (f I Inc Azi iV TE, , +N1S + / Northing , Fasting , ( O j 00 `) t Sec :n " S u rvey ; To o l tamest, A nnata c)nt � a -1,4 T. _; . s (1t} r " (ft) , a ( 1 MET- 3,900.00 45.23 88.33 3,318.75 3,241.90 250.38 1,745.95 6,000,838.26 500,401.12 0.79 1,545.13 GYD - CT-CMS (1) 3,925.00 44.46 88.55 3,336.48 3,259.63 250.86 1,763.58 6,000,838.73 500,418.74 3.14 1,561.45 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 1,577.64 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 1,593.84 GYD -CT -CMS (1) 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 1,610.13 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 1,626.53 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 1,643.03 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 1,659.59 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 1,676.20 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 1,692.84 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 1,709.53 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 1,726.27 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 1,743.01 GYD -CT -CMS (1) 4,225.00 45.67 89.82 3,547.14 3,470.29 255.07 1,977.10 6,000,842.90 500,632.24 0.95 1,759.73 GYD -CT -CMS (1) 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 1,776.46 GYD -CT -CMS (1) 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 1,793.24 GYD -CT -CMS (1) ` 4,300.00 46.22 90.05 3,599.34 3,522.49 255.14 2,030.95 6,000,842.96 500,686.09 1.07 1,810.09 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 1,827.02 GYD -CT -CMS (1) 1 4 46.51 90.28 3,633.84 3,556.99 255.03 2,067.14 6,000,842.84 500,722.27 0.62 1,843.99 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 1,861.00 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 1,878.05 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 1,895.12 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 1,912.21 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 1,929.32 GYD -CT -CMS (1) j 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 1,946.40 GYD -CT -CMS (1) E , 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 1,963.40 GYD -CT -CMS (1) 4,550.00 46.50 88.82 3,770.73 3,693.88 255.38 2,212.95 6,000,843.16 500,868.07 1.55 1,980.29 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 1,997.08 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 2,013.80 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 2,030.36 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 2,046.61 GYD CT CMS (1) i 11/3/2009 11:34:27AM Page 7 COMPASS 2003.16 Build 69 Ir ,. ConocoPhillips Val II corhilhps Definitive Survey Report . a Alaska ' 1, h _ d ConocoPhillips(Alaska) Inc. , Local Co_ ,, .Reference ..� 3H -33 Pr j ' Kuparuk River Unit RefOref'i' is 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Sitoe' I Kuparuk 3H Pad ' R %e nce `� � 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Well:, ,, s .� 3H - 33 Nor Refer0 o ki, True Weilbo 3H -33 0 Survey -Cai uiatioi t Method "Minimum Curvature ' i n 3H -33 Database EDM Alaska Prod v16 , 1, urvey r 4' � t' � ■yr i 1.. VI I I I r,- T .1 I» i fi , ,, . " nl$p ` Map r P' [1L$' 'i i t't i 4 a HID lnc, A z1, �, 1 V D TVDS l / +E/ -W Noiiihin Eattm edtion N ( (o C) (ft) / ) '� (ft) ,00----- h / " I 0v') . y Survey Tdot Name Ariihotetion ' ` 4,675.00 44.48 86.13 3,858.12 3,781.27 258.85 2,302.23 6,000,846.62 500,957.34 1.45 2,062.59 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 2,078.50 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 2,094.39 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 2,110.27 GYD - CT-CMS (1) I 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 2,126.15 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 2,142.06 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 2,158.01 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 2,173.97 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 2,189.96 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 2,205.90 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 2,221.73 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 2,237.46 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 2,253.13 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 2,268.82 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 2,284.57 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 2,300.41 GYD-CT -CMS (1) S I 5,075.00 43.35 88.26 4,145.22 4,068.37 276.78 2,580.14 6,000,864.50 501,235.22 0.93 2,316.28 GYD -CT -CMS (1) Mi 5,100.00 43.12 88.27 4,163.44 4,086.59 277.30 2,597.25 6,000,865.01 501,252.34 0.92 2,332.11 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 2,347.90 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 2,363.67 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 2,379.47 GYD-CT -CMS (1) 5,200.00 43.39 88.64 4,236.46 4,159.61 279.19 2,665.55 6,000,866.90 501,320.63 1.15 2,395.34 GYD -CT -CMS (1) 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 2,411.35 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 2,427.52 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 2,443.80 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 2,460.18 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 2,476.65 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 2,493.14 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 2,509.62 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 2,526.07 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 2,542.50 GYD -CT -CMS (1) 11/3/2009 11:34:27AM Page 8 COMPASS 2003.16 Build 69 ✓ Conoco Phillips liriliiii Conoccehillips Definitive Survey Report .. 4 1 - . Co perry 11 „ ConocoPhillips(Alaska) Inc. g Co= ordinate Refeireflce 3H -33 ! Proj Kuparuk River Unit TVD efe . 1 r 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) to ( Ku paruk 3H Pa M Reference ��� r 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) 1 Wet ,; 43H -33 North Ft ren , ' 5° , True Vefl ie,, 3H-33 `ttr'vey Ca1c+ddatio"f Meth Minimum Curvature Deign - A r'ata se � � o „ '� �� ' „ ` EDM Alaska Prod v16 F _ # Sur ly II F i � II i i Y 7` ; ;� i i1 '" ' i �,,'" '� Y ' i '�, � � �+ ''� � ' i � �i�x t � , � t i :OF, 1 i i� 4 z .i r" � ax bi 4 6 I � � ? t _ is - ( _ ( �) „ ` 4 Map M V '' 1 ' In d , / � ' ' „ TV DSS ' +N -; +E i 1111 North , . " Er in g , , , - � �� !Secrion n Surve oollName - � inotat on , { r) C) 13 (ft) 1 'h 4` {ft) t , M I" (fif �, oty ° i r1o0 r t.) ,, 5,450.00 44.62 89.96 4,414.62 4,337.77 280.55 2,840.91 6,000,868.23 501,495.97 0.21 2,558.92 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 2,575.35 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 2,591.80 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 2,608.34 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 2,624.94 GYD - CT-CMS (1) 5,575.00 45.04 90.57 4,503.20 4,426.35 280.20 2,929.10 6,000,867.86 501,584.16 0.33 2,641.56 GYD -CT -CMS (1) g 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 2,658.16 GYD -CT -CMS (1) I 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 2,674.73 GYD -CT -CMS (1) 5,650.00 45.25 89.26 4,556.23 4,479.38 279.93 2,982.14 6,000,867.57 501,637.19 3.23 2,691.28 GYD -CT -CMS (1) 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 2,707.79 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 2,724.26 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 2,740.70 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 2,757.08 GYD -CT -CMS (1) 5,775.00 45.36 87.12 4,643.70 4,566.85 283.70 3,071.35 6,000,871.33 501,726.39 0.72 2,773.41 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 2,789.74 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 2,806.09 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 2,822.43 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 2,838.74 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 2,855.01 GYD -CT -CMS (1) i 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 2,871.23 GYD - CT-CMS (1) a 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 2,887.44 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 2,903.65 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 2,919.84 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 2,936.01 GYD -CT -CMS (1) g g 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 2,952.18 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 2,968.34 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 2,984.51 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 3,000.68 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 3,016.89 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 3,033.14 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 3,049.41 GYD-CT-CMS (1) 11/3/2009 11:34:27AM Page 9 COMPASS 2003.16 Build 69 N 1: ConocoPhillips E co r' fillips Definitive Survey Report Atm *a ISSEUS 1 rmpaby� ,Cono coPhillips(Alaska) Inc. ' ,Lo a1 o r On c e7 3H - r Proje ��� ' Kuparuk River Unit 'JD Reference: , � -33 Rig © 76.85ft (D15 (40.75 +36.1)) L it Kuparuk 3H Pad MD Reference ,, 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) well: 3H-33 INor h eo tee: True WeIIbor+ ` 0i 3H -33 ur y Caleul#tlt�tt Meth d: Minimum Curvature Deign 3H -33 4, Datdbaee^ EDM Alaska Prod v16 .. rv._... e< _,. . S i ; tzi 3' Yk- -'7.74,,': tl w ,� �E Map Map _ Vertical , -� MD, Inc 1 VD . TVDSS +N /-s + W NNerthit g Fasting D ` Sedtion Survey I Name Arinotatidn M " ; r < ai' _ , it' s } �r (ft} { 5 4 .. { } I 1 � 1 ?1 ,- (ft) tft} { I10Q }, {#t 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 3,065.67 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 3,081.92 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 3,098.17 GYD -CT -CMS (1) i 6,300.00 44.76 87.80 5,014.78 4,937.93 300.97 3,442.32 6,000,888.54 502,097.32 0.42 3,114.40 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 3,130.61 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 3,146.82 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 3,163.00 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 3,179.13 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 3,195.24 GYD -CT -CMS (1) 6,450.00 44.57 86.89 5,121.38 5,044.53 305.81 3,547.73 6,000,893.35 502,202.73 0.67 3,211.32 GYD -CT -CMS (1) i 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 3,227.36 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 3,243.38 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 3,259.45 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 3,275.63 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 3,291.88 GYD -CT -CMS (1) 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 3,308.19 GYD -CT -CMS (1) i lk 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 3,324.49 GYD -CT -CMS (1) glir 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 3,340.75 GYD - CT-CMS (1) 3 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 3,357.00 GYD-CT -CMS (1) I 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 3,373.22 GYD -CT -CMS (1) 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 3,389.42 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 3,405.60 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 3,421.74 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 3,437.84 GYD - CT-CMS (1) 3 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 3,453.85 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 3,469.68 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 3,485.35 GYD -CT -CMS (1) 1 6,900.00 42.76 87.16 5,442.73 5,365.88 319.38 3,862.41 6,000,906.86 502,517.38 0.65 3,500.94 GYD -CT -CMS (1) l 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 3,516.45 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 3,531.81 GYD -CT -CMS (1) 6,975.00 41.57 86.90 5,498.37 5,421.52 321.93 3,912.63 6,000,909A1 502,567.59 0.81 3,547.03 G YD CT CMS (1) 11/3/2009 1 1:34:27AM Page 10 COMPASS 2003.16 Build 69 ✓ Conoco Phillips MEM COMCOPhilhpS Definitive Survey Report , 4 i -r-- Company ConocoPhillip Inc. „ L - aI Co-'68 ri iUfer ce " T H - 3 Pc roje Kuparuk River Unit ` 'VD eferonce �' �,' 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) i Site I Kuparuk 3H Pad . MD Reference. 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) 11 e11; .3H -33 .4NoFth Rren "True Weflhore: ' ! 3H-33 'U'vty''Calc elation Method Minimum Curvature 1l lgn 'G 3H-33 Database.! � EDM Alaska Prod v16 �� 33 4 r �rV s� '�' :a :., IM (N UT , : - ' 'IT' '114, 7,1i, T i. "TI i AI, -WI, .ti I NT i A ' � �� � � � �� Map � Map � � et'ltc�l n. `0 � M o Iris Azl TVC T1� S`S 14 +N + , W . DC.S r 1 Northing Fasti ` , , tics , , S aur vey'fbol I4ame Annotation ` (ft ' (') _ °) � s "� X10 ,, i � " - ,I ft) () () i li00 S ' l 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 3,562.21 GYD -CT -CMS (1) 7,025.00 40.85 87.97 5,535.93 5,459.08 323.44 3,945.60 6,000,910.91 502,600.56 2.77 3,577.34 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 3,592.36 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 3,607.27 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 3,622.10 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 3,636.75 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 3,651.07 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 3,665.01 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 3,678.59 GYD - CT-CMS (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 3,691.88 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 3,704.98 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 3,717.93 GYD -CT -CMS (1) 7,300.00 32.23 89.94 5,756.16 5,679.31 324.33 4,109.74 6,000,911.77 502,764.69 4.20 3,730.60 GYD -CT -CMS (1) 7,325.00 31.60 89.47 5,777.38 5,700.53 324.40 4,122.96 6,000,911.83 502,777.90 2.71 3,742.94 GYD -CT -CMS (1) M 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 3,755.07 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 3,767.07 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 3,778.99 GYD -CT -CMS (1) i 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 3,790.84 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 3,802.64 GYD -CT -CMS (1) 7,475.00 30.34 89.72 5,906.32 5,829.47 325.00 4,199.60 6,000,912.42 502,854.53 0.04 3,814.44 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 3,826.17 GYD -CT -CMS (1) t fd 4 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 3,837.77 GYD -CT -CMS (1) 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 3,849.19 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 3,860.40 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 3,871.42 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 3,882.32 GYD -CT -CMS (1) 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 3,893.13 GYD -CT -CMS (1) i 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 3,899.57 MWD (2) 7,695.10 39.03 79.76 6,098.41 6,021.56 325.94 4,306.61 6,000,913.34 502,961.53 44.90 3,914.22 MWD (2) 1 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 3,932.02 MWD (2) 7,754.60 63.61 68.48 6,135.44 6,058.59 339.27 4,350.55 6,000,926.67 503,005.47 44.23 3,950.62 MWD (2) 11/3/2009 11:34:27AM Page 11 COMPASS 2003.16 Build 69 p�. ConocoPhillips iii 1ocoPhul Definitive Survey Report Alaska R WIES Company CorocoPhillips(Alaska) Inc. * l L©C tCo ordinate!teference 3H -33 Project Kuparuk River Unit S e TVD Reece , 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Kuparuk 3H Pad M Referene 3H -33 Ri g © 76.85ft (D15 (40.75 +36.1)) l il�ell 1 , ilt 3H -33 No ,Reference True Wetlbore �� 3H-33 Survc Calculation If ethod: Minimum Curvature �1 sign' "� 3H 33 e� . EDM Alaska Prod v16 t, afabs . � � Ne L � i 'iii u�4( w" ` � f i� �nz 4 t 4 . MD Inc AZII]Fs . '-till D . TNDSS 4N1-S +Et- DLS "v"" T ' 'a §tir. ° Coon purvey oot Dame ar r 1not Rion (it) ' ( °) 1 I , (ft) ( ' (ft) , (f) , (ft), (, Dd) (ft) ; 7,784.16 76.24 56.51 6,145.60 6,068.75 352.14 4,375.01 6,000,939.53 503,029.93 57.13 3,968.97 MWD (2) 7,814.18 87.94 53.92 6,149.73 6,072.88 369.08 4,399.38 6,000,956.47 503,054.31 39.90 3,985.79 MWD (2) 7,844.35 95.26 66.04 6,148.88 6,072.03 384.14 4,425.43 6,000,971.51 503,080.35 46.89 4,004.84 MWD (2) 7,874.13 95.56 83.65 6,146.05 6,069.20 391.86 4,453.93 6,000,979.23 503,108.85 58.88 4,028.78 MWD (2) 7,904.34 93.75 100.56 6,143.58 6,066.73 390.75 4,483.91 6,000,978.12 503,138.82 56.11 4,057.22 MWD (2) 7,934.39 93.53 118.00 6,141.66 6,064.81 380.89 4,512.10 6,000,968.25 503,167.02 57.92 4,087.08 MWD (2) 7,972.47 94.30 136.46 6,139.04 6,062.19 358.00 4,542.22 6,000,945.36 503,197.13 48.40 4,123.34 MWD (2) 8,005.43 94.00 141.21 6,136.65 6,059.80 333.26 4,563.85 6,000,920.62 503,218.75 14.40 4,152.32 MWD (2) 8,035.24 93.84 144.89 6,134.61 6,057.76 309.50 4,581.73 6,000,896.86 503,236.62 12.33 4,177.43 MWD (2) 8,065.22 93.50 148.66 6,132.69 6,055.84 284.48 4,598.12 6,000,871.83 503,253.01 12.60 4,201.60 MWD (2) 8,095.40 93.78 153.06 6,130.78 6,053.93 258.18 4,612.78 6,000,845.53 503,267.66 14.58 4,224.60 MWD (2) ii 8,125.70 93.72 157.47 6,128.79 6,051.94 230.72 4,625.43 6,000,818.08 503,280.30 14.52 4,246.13 MWD (2) 8,155.18 94.46 161.64 6,126.69 6,049.84 203.18 4,635.70 6,000,790.53 503,290.57 14.33 4,265.46 MWD (2) 8,185.68 95.66 166.11 6,124.00 6,047.15 174.00 4,644.14 6,000,761.36 503,299.00 15.12 4,283.66 MWD (2) j 8,215.50 95.54 170.46 6,121.09 6,044.24 144.95 4,650.16 6,000,732.31 503,305.02 14.52 4,299.55 MWD (2) 8,245.55 94.64 174.12 6,118.42 6,041.57 115.29 4,654.17 6,000,702.65 503,309.03 12.50 4,313.77 MWD (2) 8,275.55 93.32 177.53 6,116.34 6,039.49 85.45 4,656.35 6,000,672.81 503,311.20 12.16 4,326.35 MWD (2) 8,305.54 91.01 180.61 6,115.21 6,038.36 55.49 4,656.84 6,000,642.86 503,311.68 12.83 4,337.38 MWD (2) 1 8,335.70 88.37 182.97 6,115.37 6,038.52 25.35 4,655.90 6,000,612.72 503,310.73 11.74 4,347.14 MWD (2) 8,365.59 89.75 186.43 6,115.86 6,039.01 -4.43 4,653.45 6,000,582.94 503,308.28 12.46 4,355.36 MWD (2) 8,395.35 91.87 189.97 6,115.44 6,038.59 -33.88 4,649.20 6,000,553.50 503,304.03 13.86 4,361.79 MWD (2) 8,425.45 90.71 193.13 6,114.76 6,037.91 -63.36 4,643.18 6,000,524.02 503,298.00 11.18 4,366.56 MWD (2) i 8,455.25 89.66 196.33 6,114.66 6,037.81 -92.17 4,635.60 6,000,495.21 503,290.42 11.30 4,369.64 MWD (2) 8,485.34 89.48 199.70 6,114.89 6,038.04 - 120.78 4,626.30 6,000,466.61 503,281.11 11.22 4,371.04 MWD (2) 8,515.40 88.80 204.27 6,115.34 6,038.49 - 148.65 4,615.05 6,000,438.75 503,269.86 15.37 4,370.35 MWD (2) 8,545.33 85.11 205.28 6,116.93 6,040.08 - 175.78 4,602.53 6,000,411.62 503,257.33 12.78 4,368.21 MWD (2) z 8,575.70 83.11 206.65 6,120.05 6,043.20 - 202.94 4,589.30 6,000,384.47 503,244.10 7.97 4,365.43 MWD (2) 8,605.70 85.85 209.70 6,122.93 6,046.08 - 229.25 4,575.21 6,000,358.16 503,230.00 13.63 4,361.53 MWD (2) 8,635.41 88.25 213.83 6,124.46 6,047.61 - 254.47 4,559.59 6,000,332.94 503,214.38 16.06 4,355.82 MWD (2) I 8,665.38 88.40 218.41 6,125.34 6,048.49 - 278.66 4,541.94 6,000,308.76 503,196.73 15.28 4,347.85 MWD (2) 3 8,695.27 87.61 217.93 6,126.38 6,049.53 -302.15 4 6,000,285.28 503,178.26 W 178.26 3 09 4,338.86 MD (2) 11/3/2009 11:34:27AM Page 12 COMPASS 2003.16 Build 69 Ire' ConocoPhillips U C�coPhilhips Definitive Survey Report , Atatka Comb' ConocoPhillips(Alaska) Inc. Local o°rdl l ate' RO erence 3H -33 f , Kuparuk River Unit „. TUb Refere 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) 'Site: - ` Kuparuk 3H Pad MD RcFer Lice' ; ak r 3H -33 Rig @ 76 (D15 (40.75 +36.1)) We ∎ ' ; � 3H -33 North Reference° , " True � Ulfe Ib re: 3H -33 '`Survey- Calcutatlofr Method: 4 M Curvature ; n' � 3H -33 1' atabaee: EDM Alaska Prod v16 , ti� �' � it ,, 1 I r _ i ; &.. , , 1 ' l j s i� r Sri �I -n �� � � � Y '� `� � A � ` '� MO �a �� ^ Vertrcal ��` Al r I. TVD ,' TVDSS + N1 +ET -W T.. , DLS t � j M inc A i ft lift), (ft} ;, 1 -ft) i� Northing ' 1= acting ( ° /1d it;) Se n M "Survey 7oa1 Name Rnt�otat }on i € } " } '} t c } , i t t} t} 8,725.60 88.83 213.80 6,127.32 6 ,050.47 -326.71 4,505. 6 ,000,260.72 503,160.50 14.19 4,330.92 M W D (2) 8,755.44 90.12 210.11 6,127.60 6,050.75 - 352.02 4,489.93 6,000,235.42 503,144.71 13.10 4,325.09 MWD (2) 8,785.17 90.95 205.98 6,127.32 6,050.47 - 378.25 4,475.95 6,000,209.19 503,130.73 14.17 4,321.27 MWD (2) TIP 3H- 33AL1PB1 8,810.00 90.60 202.57 6,126.98 6,050.13 - 400.88 4,465.75 6,000,186.56 503,120 13.80 4,319.71 MWD (3) KOP 8,840.38 93.50 203.22 6,125.90 6,049.05 - 428.85 4,453.94 6,000,158.60 503,108.71 9.78 4,318.54 MWD (3) 8,870.30 97.33 203.07 6,123.07 6,046.22 - 456.23 4,442.23 6,000,131.22 503,097.00 12.81 4,317.25 MWD (3) 8,900.25 98.16 201.07 6,119.04 6,042.19 - 483.73 4,431.08 6,000,103.73 503,085.85 7.17 4,316.53 MWD (3) 8,930.23 95.90 199.06 6,115.37 6,038.52 - 511.68 4,420.88 6,000,075.79 503,075.64 10.05 4,316.85 MWD (3) 8,960.16 95.87 196.61 6,112.30 6,035.45 - 540.02 4,411.76 6,000,047.45 503,066.52 8.14 4,318.32 MWD (3) 8,990.36 93.66 195.33 6,109.79 6,032 - 568.95 4,403.48 6,000,018.52 503,058.23 8.45 4,320.79 MWD (3) 9,020.24 89.60 193.36 6,108.94 6,032.09 - 597.88 4,396.08 5,999,989.60 503,050.83 15.10 4,324.08 MWD (3) 9,050.12 87.45 191.74 6,109.71 6,. 627.03 4,389.59 5,999,960.45 503,044.34 9.01 4,328.30 MWD (3) 9,080.05 86.59 188.63 6,111.26 6, 86 656.45 4,384.31 5,999,931.04 503,039.05 10.77 4,333.74 MWD (3) 9,110.36 85.54 185.93 6,113.35 6,036.50 - 686.44 4,380.48 5,999,901.05 503,035.21 9.54 4,340.75 MWD (3) 9,140.61 87.85 183.63 6,115 6,038.24 -716.53 4,377.96 5,,870 503,032.69 10.77 4,349.02 MWD (3) 9,170.01 87.73 180.52 6,116.22 6,039.37 - 745.89 4,376.90 5,999,841.61 503,031.62 10.58 4,358.38 MWD (3) 9,200.01 88.00 177.43 6,117.34 6,040.49 775.86 4,377.43 5, 503,032.15 10.33 4,369.47 MWD (3) • 9,230.11 87.91 174.56 6,118.42 6,041.57 - 805.86 4,379 5,,781.64 503,034.25 9.53 4,382.02 MWD (3) 9,260.31 90.71 172.41 6,118.78 6,041.93 - 835.86 4,382.96 53 5,999 503,037.67 11.69 4,395.82 MWD (3) 9,290.29 91.29 169.37 6,118.26 6,041.41 865.45 4,387.70 5,999,722.06 503,042.41 10.32 4,410.71 MWD (3) 9,320.10 91.78 166.53 6,117.46 6,040.61 - 894.59 4,393.92 5,999,692.92 503,048.62 9.66 4,426.82 MWD (3) 9,350.16 91.11 163.89 6,116.70 6,039.85 - 923.64 4,401.60 5,999,663.87 503,056.28 9.06 4,444.25 MWD (3) 9, 410 380. 04 10 90.89 89.72 160.41 6,116.02 6,039.17 161.30 6,116.18 6,039.33 - 952.21 4,410.55 5,999,635.31 503,065.23 8.68 4,462.71 MWD (3) a 9,. - 980. 009.11 4,429.85 5,999,578.41 5034 4.91 4,481.88 MWD (3) 9,440.19 89.08 162.94 6,116.33 6,48 49 4,420.37 5,999,607.02 503,075.0 1,,52 8.66 4,500.85 MWD (3) 9,470.23 89.45 166.04 6,116.72 6,039.87 039. 1,038.05 4,437.88 5,999,549.47 503,092.54 084. 10.39 4,518.58 MWD (3) 9,500.28 89.82 169.22 6,116.91 6,040.06 - 1,067.39 4,444.31 5,999,520.12 503,098.97 10.65 4,534.97 MWD (3) i 9,531.64 89.63 171.69 6,117.06 6,040 1,098.32 4,449.51 5,999,489.20 503,104.17 7.90 4,550.75 MWD (3) 9,560.04 89.08 173.55 6,117.38 6,040.53 - 1,126.48 4,453.16 5,999,461.04 503,107.81 6.83 4,564.10 MWD (3) 9,590.20 89.48 177.76 6,117.76 6,040.91 - 1,156.54 4,455.44 5,999,430.98 503,110.09 14.02 4,576.85 MWD (3) 9,620.43 90.89 179.94 6,117.66 6,040.81 - 1,186.76 4,456.05 5,999,400.76 503,110.69 8.59 4,588.09 MWD (3) 11/3/2009 11:34:27AM Page 13 COMPASS 2003. 16 Build 69 ConocoPhillips � ��'� Definitive Survey Report ' V(- . co mpa n ConocoPhillips(Al Inc. L ocal Db rd '` feren . ,u ' ,,, 1 5ft (D15 (40.75 +36.1)) Project: �� Kuparuk River Unit ° UD R efe re e . 3H -33 Rig © 76.8 Sit Kuparuk 3H Pad ' MD I t'ererice to '3H Rig @ 76.85ft (D15 (40.75 +36.1)) Wei 3H -3 North Reference= ` r 4 ` ' , ' Tru e �Ilbrsre > 3H -33 Survey, Calculation` Method Minimum Curvature �� Deslgn ���, 3H 33 Database: �� „,EDM Alaska Prod v16 t �w � <.. main _ '''' i �. 7 i ) ,� ,' -"' ` ass L+',. id .fi , 117 1 'r t ire i� � ) = � i ( k 3` �' N' - as +Ei -W Ma 8p DI $ vertical A a �' Inc AzI T F TU DSS + N 1 7 ° ' k 5 i i : ` fasting . , F se�ti "n Sorvey'" -7'001 Na 411not ti 5rt a,,i (. T; (tt} : 4 t ° } r) (ft) ( 04 (t (ft) (�t ° (ft) , ( r 10� } T (l t) 9, 650.50 91.20 183.30 6,117.1 6,040.26 1,216.81 4 5,999,370.72 503,109.83 11.22 4,597 00 .91 MWD (3) 9,680.52 90.55 186.76 6 6,039.80 1,246.71 4,452.57 5,999,340.83 503,107.20 11.73 4,606. MWD (3) 9,710.24 92.09 189.67 6,115.97 6,039.12 1,276.11 4,448.33 5,999,311.43 503,102.95 11.08 4,612.41 MWD (3) 9,740.50 91.32 191.97 6,115.07 6,038.22 1,305.82 4,442.65 5,999,281.72 503,097.26 8.01 4,617.58 MWD (3) 9,770.22 89.97 194.74 6,114.73 6,037.88 1,334.73 4,435.78 5,999,252.82 503,090.40 10.37 4,621.37 MWD (3) 9,800.53 91.01 197.88 6 68: , 11 1 11 14 33.. .4 3958 8 6,037.63 1,363.81 4,427.27 5,999,223.74 503,081.88 10.91 4,623.67 MWD 9 90.95 201.63 6,037.11 1,392.02 4,417.14 5,999,195 503,071.75 12.51 4,624.15 MWD (3) (3) 3) 9,860.62 91.38 205.51 6,036.50 1,419.61 4,405.11 5,999,167.95 503,059.71 12.96 4,622.63 MWD ( 9,890.78 92.00 209.20 6,112.46 6,035.61 1,446.38 4,391.26 5,999,141.19 503,045.85 12.40 4,619.13 MWD (3) 9 , 92 0.53 92.73 212.88 6,111.23 6 ,034.38 1,471.84 4,375 5,999,115.73 503,030.53 12.60 4,613.78 MWD (3) 9,950.56 92.58 216.48 6 ,109.84 6,032.99 1,496.51 4 , 358 .87 5,999,091.07 503,013.46 09 9 11.99 4,606.52 MWD (3) 9,980.47 92.24 219.36 6,108.58 6,031.73 1 , 52 0.08 4,340.51 5,999,067.50 502 ,995..69 4,597.66 MWD (3) 10,010.26 91.81 222.38 6,107.53 6,030.68 57 - 1,542.59 4,321.03 5,999,045.00 502,975.61 10.23 4,587.38 MWD (3) ( 10,040.49 88.62 223.26 6,107.42 6,030. 1,564.76 4,300.48 5,999,022.83 502,955.07 10.95 4,575.99 MWD (3) 10,061.27 89.94 225.26 6,107.68 6,030.83 1,579.64 4,285.98 5,999,007.96 502,940.56 111001...259353 1.53 4,567.68 MWD (3) g 10 , 10 0.00 89.94 225.26 6,107.72 6,030.87 1,606.90 4,258.47 5,998,980 502,913.05 0.00 4,551.56 PROJECTED to TD 11/3/2009 11:34:27AM Page 14 COMPASS 2003.16 Build 69 • T ConocoPh Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33AL1 PB1 501032057870 0 • Baker Hughes I NTEQ Frail Definitive Survey Report BAKER HUGHES 03 November, 2009 . , ConocoPhillips Pj COnOCoPh1IIIps Definitive Survey Report Alaska Ba nES Company ConocoPhill ps(Alaska) Inc. Local Co- ordinate Reference 3H -33 Projec Kuparuk River Unit T1 D Referenda:: I ,i 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site x Kuparuk 3H Pad €fil)'Reference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) ell:; 3H -33 North Reference True , Wellbore. w ` 3H -33 s r- Siv ey Calculation Method: ' Minimum Curvature Ded gtt 3H -33 Database - ' � - ;4 DM Alas Prod v16 i 77 r :4' f � 3 a E . Map ^( 0�Map Vertical ' M p I nc A z i _ , = ND i TVDSS t +N /- S,, +E/- Na rthin Easting 1 1 Section 9 Survey V ii i Nails Annotation i ( ) °) ( � (ft) , k ,„ : . jft (ft) (ft) ( (ft) (/ " ,(ft)' ' . 40.75 0.00 0.00 40.75 -36.10 0.00 0.00 6,000,588.21 498,655.30 0.00 0.00 UNDEFINED 100.50 0.57 321.50 100.50 23.65 0.23 -0.19 6,000,588.44 498,655.11 0.95 -0.24 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 -0.40 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 3.26 GYD-CT -CMS (1) 400.20 8.33 83.73 399.50 322.65 1.40 14.32 6,000,589.61 498,669.62 4.26 13.50 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 27.68 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 43.72 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 61.12 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 79.38 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 96.44 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 0.02 112.49 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 3.24 129.99 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 4.44 134.87 GYD - CT-CMS (1) € i 1,150.00 16.27 63.01 1,133.84 1,056.99 45.69 156.64 6,000,633.87 498,811.93 3.17 140.01 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 3.29 145.38 GYD -CT -CMS (1) 1,200.00 18.44 63.86 1,181.60 1,104.75 52.33 169.87 6,000,640.50 498,825.16 5.45 151.13 GYD -CT -CMS (1) i 1,225.00 19.72 64.63 1,205.23 1,128.38 55.88 177.23 6,000,644.05 498,832.52 5.22 157.36 GYD -CT -CMS (1) 1,250.00 20.21 65.34 1,228.72 1,151.87 59.49 184.97 6,000,647.66 498,840.26 2.19 163.93 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 0.33 170.63 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 0.24 177.35 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 0.70 184.08 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 4.19 190.65 GYD - CT-CMS (1) 1,375.00 18.19 67.24 1,346.32 1,269.47 76.75 223.63 6,000,664.92 498,878.92 3.78 196.97 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 0.68 203.16 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 1.72 209.38 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 4.52 215.81 GYD -CT -CMS (1) 1,475.00 20.71 66.36 1,440.85 1,364.00 89.82 253.50 6,000,677.97 498,908.79 3.84 222.57 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 4.20 229.72 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 3.96 237.30 GYD -CT -CMS (1) 1,550.00 23.64 70.07 1,510.34 1,433.49 100.18 279.71 6,000,688.33 498,935.00 5.00 245.31 GYD - CT-CMS (1) 1 11/3/2009 11:39:03AM Page 3 COMPASS 2003.16 Build 69 tom. ConocoPhillipsft COnoCOPhdhps Definitive Survey Report B Alas lat MOMS I Com G� ConocoPhillips( Inc. Lo cal Coordinate F eferetice 3H -33 ( iPrOJOCt, Kuparuk River Unit TVD Reference. = :3H-33 Rig © 76.85ft (D15 (40.75 +36.1)) �te: -', Kuparuk 3H Pad 4 'I(�ID i eferencd�` ' , , �� . : 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) I i0eII: 3H -33 N ortb Reference: 0 i True Wetlbefe. =_' , 3H -33 Survey C alculation Methods Minimum Curvature b esign 3H -33 Database.;„ EDM Alaska Prod v16 �. UPVe,� P'I� 7 i i i' i F I i �i i r�� �� iI� i ,I..,:,,,- ( i h ffl � al Ma MOP V , MD InC ,Azr�'� TVD TVDSS +N1-S +EI W Nbrthin Eastirrg DLS tr action An, not on ' (R) i t ( °) (°) i i (ft)v (ft) (ft) $" , ' eft) 1(ft) g (ft) e,_ ("'/100') (ft) Survey Toot Name : 1,575.00 24.76 70.71 1,533.14 1,456.29 103.62 289.37 6,000,691.76 498,944.65 4.60 253.79 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 3.77 262.65 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 1.83 271.77 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 0.56 281.00 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 0.72 290.24 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 0.78 299.43 GYD -CT -CMS (1) I! 1,725.00 26.06 71.87 1,668.05 1,591.20 124.53 351.51 6,000,712.66 499,006.79 0.70 308.63 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 1.27 317.92 GYD -CT -CMS (1) I 1,775.00 26.76 73.17 1,712.86 1,636.01 131.22 372.67 6,000,719.35 499,027.95 2.36 327.41 GYD -CT -CMS (1) i 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 2.46 337.13 GYD -CT -CMS (1) 6 1,825.00 28.12 74.72 1,757.26 1,680.41 137.60 394.75 6,000,725.73 499,050.03 3.68 347.16 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 5.15 357.62 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 2.31 368.45 GYD -CT -CMS (1) ``I 1,900.00 30.09 76.51 1,822.59 1,745.74 146.58 430.47 6,000,734.70 499,085.75 1.16 379.45 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 0.43 390.52 GYD - CT-CMS (1) iI 1,950.00 30.54 76.70 1,865.78 1,788.93 152.42 454.98 6,000,740.53 499,110.25 1.42 401.68 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 4.17 413.10 GYD-CT -CMS (1) I 2,000.00 32.43 78.05 1,908.41 1,831.56 158.11 480.47 6,000,746.22 499,135.75 3.90 424.91 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 5.05 437.12 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 7.57 449.88 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 3.08 463.09 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 1.62 476.50 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 0.53 490.02 GYD -CT -CMS (1) 2,150.00 36.82 79.37 2,030.32 1,953.47 174.92 566.15 6,000,763.01 499,221.42 0.13 503.56 GYD -CT -CMS (1) 2,175.00 36.85 79.59 2,050.33 1,973.48 177.66 580.89 6,000,765.75 499,236.16 0.54 517.13 GYD -CT -CMS (1) 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 0.94 530.75 GYD -CT -CMS (1) I 2,225.00 37.35 80.78 2,090.23 2,013.38 182.87 610.56 6,000,770.95 499,265.83 2.57 544.52 GYD -CT -CMS (1) I 2,250.00 37.75 81.69 2,110.05 2,033.20 185.19 625.62 6,000,773.27 499,280.88 2.74 558.50 GYD -CT -CMS (1) c 2,275.00 38.27 82.49 2,129.75 2,052.90 187.31 640.86 6,000,775.39 499,296.13 2.87 572.72 GYD -CT -CMS (1) I 2,300.00 39.27 83.77 2,149.24 2,072.39 189.18 656.41 6,000,777.25 499,311.67 5.13 587.28 GYD -CT -CMS (1) II 2,325.00 40.39 84.83 2,168.44 2,091.59 190.77 672.34 6,000,778.84 499,327.60 5.24 602.30 GYD -CT -CMS (1) 4 11/3/2009 11:39:03AM Page 4 COMPASS 2003.16 Build 69 . r ConocoPhillips «� Conoco Phillips p' Definitive Survey Report BAMES Compa4: `_" .ConocoPhillip Inc. Local Co=ordinate Reference: 3H -33 Prdjeet: !Kuparuk River Unit "Mb Reference: 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site: i Kuparuk 3H Pad MD eference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) r Weiblii 3H - 33 North Reference: True Weiibbre: 3H -33 purvey Calculation Method: Minimum Curvature [De, sigfl ��_, 3H 33 Database: EDM Alaska Prod v16 -- Map - PMap Vetticei MD Inc Azi ��_ , ` °T1TD ° TVDSS +N /-S +E/ -W Northing tasting DL , Section" survey Tool Name Annotation fo - , (a) el ;1 (ft) (ft) f0 eft) ; (ft) (ft) (. /1 , (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 5.22 617.76 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 2.67 633.56 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 0.79 649.50 GYD -CT -CMS (1) 1 2,425.00 41.87 86.82 2,243.07 2,166.22 195.19 738.74 6,000,783.25 499,394.00 1.41 665.42 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 1.72 681.25 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 1.03 696.98 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 0.84 712.67 GYD -CT -CMS (1) 2,525.00 41.19 87.40 2,318.18 2,241.33 198.53 804.67 6,000,786.57 499,459.92 0.55 728.37 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 0.88 744.13 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 1.53 759.99 GYD -CT -CMS (1) 2,600.00 42.24 87.67 2,374.24 2,297.39 200.70 854.45 6,000,788.74 499,509.70 1.87 775.99 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 3.44 792.19 GYD -CT -CMS (1) 2,650.00 43.67 87.60 2,410.79 2,333.94 202.10 888.54 6,000,790.13 499,543.78 2.29 808.61 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 1.16 825.16 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 0.52 841.77 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 0.20 858.41 GYD-CT -CMS (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 0.14 875.05 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 0.48 891.68 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 0.58 908.29 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 0.87 924.89 GYD -CT -CMS (1) T T. 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 0.91 941.47 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 2.28 957.97 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 2.83 974.28 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 1.44 990.42 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 1,006.45 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 1,022.39 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 1,038.31 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 1,054.26 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 1,070.19 GYD -CT -CMS (1) i i 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 1,086.08 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 1,101.95 GYD -CT -CMS (1) i i . .... _ ___ _ _... _... _... . _ ... ®.... 11/3/2009 11 :39 :03AM Page 5 COMPASS 2003.16 Build 69 Iv' ` ConocoPhillips FAi1I C i`� ' Definitive Survey Report BAlelat Alaska IMMINIES Company , ConocoPhillips(Alaska) Inc. 'Local Co- ordinate Reference: 3H -33 Project Kuparuk River Unit 1V]) Reference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site: �fi Kuparuk 3H Pad MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) i Well: ; " 3H -33 North Reference: True " Wellbd�re: 3H -33 Survey Dalculation Method: Minimum Curvature Design 3H-33 ,Database EDM Alaska Prod v16 :iurvey ,., 1 Map Map Vertical Ali 1 MD • Inc Azi T VD .' TVDSS : +NI-S . +E on Survey Tool Name !-W Northing Easting DLL, Secti Annotation (ft r) ( °) " •'" , (ft ;,, (ft) (ft) (ft) (ft , (ft) (*moo) . (ft) d 3, 125.00 42.24 85.47 2,755.92 2,679.07 224.58 1,213.99 6,000,812.55 499,869.21 0.32 1,117.82 GYD -CT -CMS (1) y 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 1,133.70 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 1,149.62 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 1,165.59 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 1,181.61 GYD - CT-CMS (1) i 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 1,197.71 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 1,213.92 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 1,230.22 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 1,246.54 GYD -CT -CMS (1) 3,350.00 43.06 86.66 2,920.93 2,844.08 235.04 1,366.59 6,000,822.98 500,021.79 1.61 1,262.82 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 1,278.97 GYD -CT -CMS (1) 3,400.00 42.35 87.26 2,957.76 2,880.91 3,425.00 42.43 87.32 2,976.23 2,899.38 236.77 1,400.35 6,000,824.71 500,055.55 0.29 1,295.05 GYD -CT -CMS (1) 237.57 1,417.19 6,000,825.50 500,072.39 0.36 1,311.13 GYD -CT -CMS (1) 3,450.00 42.54 87.34 2,994.66 2,917.81 238.36 1,434.06 6,000,826.29 500,089.25 0.44 1,327.25 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 1,343.41 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 1,359.60 GYD -CT -CMS (1) 40 ; 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 1,375.87 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 1,392.26 GYD -CT -CMS (1) 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 1,408.74 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 1,425.28 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 1,441.82 GYD -CT -CMS (1) 3,650.00 43.49 87.77 3,140.21 3,063.36 244.36 1,571.09 6,000,832.26 500,226.27 1.15 1,458.32 GYD -CT -CMS (1) 1 0 3,675.00 43.47 87.92 3,158.35 3,081.50 245.01 1,588.28 6,000,832.91 500,243.46 0.42 1,474.79 GYD -CT -CMS (1) e 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 1,491.28 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 1,507.83 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 1,524.45 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 1,541.19 GYD -CT -CMS (1) 1 l 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 1,558.02 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 1,574.93 GYD -CT -CMS (1) 3,850.00 45.22 88.11 3,283.58 3,206.73 249 25 1,710.44 6,000,837 13 500,365.60 0.89 1,591.91 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 1,608.94 GYD -CT -CMS (1) 11/3/2009 11 :39 :03AM Page 6 COMPASS 2003.16 Build 69 N." ConocoPhillips 1311 C OPhill PS Definitive Survey Report Bilifillt Company: ConocoPhillips(Alaska) Inc. 7 `Local Co- ordinate Reference: 3H -33 Project :' Kuparuk River Unit TVD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad = `MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: 3H -33 North , Reference: , 1, True Wellbore: 31-1-33 Survey Celeulation Method: ',Minimum Curvature Design: 3H -33 Database � EDM Alaska Prod v16 Sunray ill 1 [1 , i MaP Ma , „, Ueitical x w,= MD Inc �4zi' VD : TVDSS +N / + ' . Northing ' Easting D� � Section Survey fool - Name Annotation c (ft) . ( *) ( (ft) lf � ( � . � ft� (f MOO ( , ( ' 3,900.00 45.23 88.33 3,318.75 3,241.90 250.38 1,745.95 6,000,838.26 500,401.12 0.79 1,625.98 GYD -CT -CMS (1) 3,925.00 44.46 88.55 3,336.48 3,259.63 250.86 1,763.58 6,000,838.73 500,418.74 3.14 1,642.91 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 1,659.71 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 1,676.51 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 1,693.40 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 1,710.40 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 1,727.52 GYD -CT -CMS (1) 4,075.00 45.80 88.46 3,442.68 3,365.83 253.47 1,869.46 6,000,841.32 500,524.62 0.72 1,744.70 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 1,761.93 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 1,779.18 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 1,796.48 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 1,813.80 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 1,831.14 GYD -CT -CMS (1) 4,225.00 45.67 89.82 3,547.14 3,470.29 255.07 1,977.10 6,000,842.90 500,632.24 0.95 1,848.44 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 1,865.75 GYD -CT -CMS (1) 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 1,883.10 GYD -CT -CMS (1) Aikl 4,300.00 46.22 90.05 3,599.34 3,522.49 255.14 2,030.95 6,000,842.96 500,686.09 1.07 1,900.53 GYD -CT -CMS (1) Imp 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 1,918.02 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 1,935.57 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 1,953.15 GYD -CT -CMS (1) 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 1,970.77 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 1,988.43 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 2,006.10 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 2,023.79 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 2,041.46 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 2,059.06 GYD -CT -CMS (1) I 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 2,076.56 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 2,093.96 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 2,111.30 GYD -CT -CMS (1) 4 45.59 87.71 3,822.67 3,745.82 256.85 2,267.02 6,000,844.63 500,922.14 3.04 2,128.50 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 2,145.40 GYD -CT -CMS (1) 11/3/2009 11 :39 :03AM Page 7 COMPASS 2003.16 Build 69 . ✓ ConocoPhillips rr C COP"II � Definitive Survey Report BK E Company. ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: 3H -33 Project , Kuparuk River Unit "ND Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) site: Kuparuk 3H Pad MDReference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) 1 Well: 3H -33 4 North" Reference: , True 'V 3H - 33 s Snrvey Calculation Method Minimum Curvature 3H -33 Database: ref EDM Alaska Prod v16 ''Survey/ a . 74 , w; A,' 9 °Map Map Vertical � 1 M D Inc " A l TvD TVDSS +Nt-S +EI W Northing Eastrng' Des section SurveyiTool Name Annotation i : (ft) (1, - r) ift) (ft) (ft1 (ft) (f ��. j {t1 /1001 '' eft) 4,675.00 44.48 86.13 3,858.12 3,781.27 258.85 2,302.23 6,000,846.62 500,957.34 1.45 2,162.06 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 2,178.65 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 2,195.21 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 2,211.77 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 2,228.32 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 2,244.90 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 2,261.53 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 2,278.18 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 2,294.84 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 2,311.47 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 2,327.98 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 2,344.38 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 2,360.73 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 2,377.09 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 2,393.48 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 2,409.94 GYD -CT -CMS (1) 5,075.00 43.35 88.26 4,145.22 4,068.37 276.78 2,580.14 6,000,864.50 501,235.22 0.93 2,426.41 GYD -CT -CMS (1) �a 5,100.00 43.12 88.27 4,163.44 4,086.59 277.30 2,597.25 6,000,865.01 501,252.34 0.92 2,442.84 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 2,459.23 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 2,475.60 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 2,491.98 GYD - CT-CMS (1) 5,200.00 43.39 88.64 4,236.46 4,159.61 279.19 2,665.55 6,000,866.90 501,320.63 1.15 2,508.44 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 2,525.05 GYD -CT -CMS (1) fl 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 2,541.80 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 2,558.65 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 2,575.62 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 2,592.65 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 2,609.72 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 2,626.77 GYD -CT -CMS (1) E 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 2,643.78 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 2,660.78 GYD-CT -CMS (1) 11/3/2009 11 :39 :03AM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips 1111 Conoco Phillips E Definitive Survey Report BAK INJOIMES Company, ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3H -33 f pojecb - Kuparuk River Unit TVD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site; Kuparuk 3H Pad MD Reference: 31-1-33 Rig @ 76.85ft (D15 (40.75 +36.1)) = Welt: 3H -33 North Reference: True Weilbore: 3H -33 Survey Calculation Method: Minimum Curvature i Design: 3H -33 Database: EDM Alaska Prod v16 Map Map Vertical MD Inc Azi TVA 1VDSS +N/S +El -W DLS , _ Northing Eastiing Section Survey Tool Name Annotation 11 ;�,, (d ( ° ) ) i , , .,. (ft) , (its, ( " � V (ft) (f) t ,lon� (ft) ' ' -1 ' - , , ,,''' ,' ' , 5,450.00 44.62 89.96 4,414.62 4,337.77 280.55 2,840.91 6,000,868.23 501,495.97 0.21 2,677.77 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 2,694.75 GYD - CT-CMS (1) h 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 2,711.77 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 2,728.86 GYD - CT-CMS (1) r 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 2,746.02 GYD -CT -CMS (1) 5,575.00 45.04 90.57 4,503.20 4,426.35 280.20 2,929.10 6,000,867.86 501,584.16 0.33 2,763.19 GYD - CT-CMS (1) 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 2,780.32 GYD -CT -CMS (1) 1 5,625.00 44.99 90.34 4,538.59 4,461.74 279.86 2,964.42 6,000,867.51 501,619.47 0.98 2,797.45 GYD -CT -CMS (1) 5,650.00 45.25 89.26 4,556.23 4,479.38 279.93 2,982.14 6,000,867.57 501,637.19 3.23 2,814.57 GYD -CT -CMS (1) G 1 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 2,831.68 GYD -CT -CMS (1) 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 2,848.80 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 2,865.89 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 2,882.94 GYD -CT -CMS (1) 5,775.00 45.36 87.12 4,643.70 4,566.85 283.70 3,071.35 6,000,871.33 501,726.39 0.72 2,899.93 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 2,916.91 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 2,933.91 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 2,950.92 GYD -CT -CMS (1) 5,875.00 45.22 87.16 4 4,637.04 287.20 3,142.49 6,000,874.82 501,797.53 0.95 2,967.88 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 2,984.80 GYD -CT -CMS (1) I 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 3,001.68 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 3,018.54 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 3,035.40 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 3,052.24 GYD -CT -CMS (1) i 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 3,069.06 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 3,085.89 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 3,102.71 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 3,119.53 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 3,136.37 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 3,153.23 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 3,170.11 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 3,187.01 GYD -CT -CMS (1) 11/3/2009 11:39:03AM Page 9 COMPASS 2003.16 Build 69 w ' t roc S ConocoPhillips Ff 1I ConocoPhillips Definitive Survey Report WirES Alaska �onnpany U ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference 3H -33 Project: Kuparuk River Unit TVD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: 3H -33 North Reference: True Wellbore: 3H -33 Survey Calculation Met Minimum Curvature De 3H 33 Database:, EDM Alaska Prod v16 Surve�r 5 Map Map V"ertical � 1 D Ina ' ARI, Ti/D . +N/ S 4El W DLS i ' No rthing Ea sting�� � S e�fion - Survey Tool Flame 'Annotation 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 3,203.89 GYD -CT -CMS (1) 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 3,220.76 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 3,237.63 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 3,254.49 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 3,271.33 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 3,288.18 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 3,305.00 GYD -CT -CMS (1) 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 3,321.77 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 3,338.53 GYD -CT -CMS (1) F 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 3,355.26 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 3,371.95 GYD -CT -CMS (1) 6 44.45 86.89 5,157.04 5,080.19 307.73 3,582.73 6,000,895.27 502,237.72 0.28 3,388.63 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 3,405.35 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 3,422.17 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 3,439.06 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 3,455.99 GYD -CT -CMS (1) 1110 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 3,472.92 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 3,489.81 GYD -CT -CMS (1) 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 3,506.68 GYD-CT -CMS (1) N 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 3,523.53 GYD -CT -CMS (1) s g 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 3,540.36 GYD -CT -CMS (1) _ i 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 3,557.17 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 3,573.94 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 3,590.68 GYD -CT -CMS (1) 6,825.00 43.94 87.50 5,388.02 5,311.17 316.98 3,811.17 6,000,904.47 502,466.14 1.72 3,607.32 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 3,623.78 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 3,640.07 GYD -CT -CMS (1) 1 6,900.00 42.76 87.16 5,442.73 5,365.88 319.38 3,862.41 6,000,906.86 502,517.38 0.65 3,656.29 GYD -CT -CMS (1) 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 3,672.43 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 3,688.40 GYD-CT -CMS (1) 1 ■ 6,975.00 41.57 86.90 5,498.37 5,421.52 321.93 3,912.63 6,000,909.41 502,567.59 0.81 3,704.23 GYD -CT -CMS (1) 11/3/2009 11:39:03AM Page 10 COMPASS 2003.16 Build 69 ConocoPhillips Erie COnOCOPtlilliPS Definitive Survey Report BAKER M s Company: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: 3H -33 rojecc: Kuparuk River Unit TVD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site:. Kuparuk 3H Pad MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well '` jh 3H -33 North Reference: True Nellbore:I 3H -33 'Survey Calculation Methods ; Minimum Curvature [' 7estgn:, 3H Database: EDM Alaska Prod v16 Survi y Map Map Vertical ab MD ,,,� Inc Az' TVD 1VDSS + /-S +Ef W Northing Easting , DLS � Section Surve Tool Name Annotation � t ((t) `r) r) (ft) (ft) _ (ft) (ft) (ft) (ft) f /100) (ft) , y I 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 3,720.03 GYD-CT -CMS (1) 7,025.00 40.85 87.97 5,535.93 5,459.08 323.44 3,945.60 6,000,910.91 502,600.56 2.77 3,735.75 GYD-CT -CMS (1) I 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 3,751.34 GYD -CT -CMS (1) 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 3,766.79 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 3,782.15 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 3,797.34 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 3,812.17 GYD -CT -CMS (1) I 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 3,826.59 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 3,840.63 GYD -CT -CMS (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 3,854.35 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 3,867.88 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 3,881.25 GYD -CT -CMS (1) 7,300.00 32.23 89.94 5,756.16 5,679.31 324.33 4,109.74 6,000,911.77 502,764.69 4.20 3,894.34 GYD -CT -CMS (1) 7,325.00 31.60 89.47 5,777.38 5,700.53 324.40 4,122.96 6,000,911.83 502,777.90 2.71 3,907.11 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 3,919.67 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 3,932.10 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 3,944.43 GYD -CT -CMS (1) 111, i 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 3,956.70 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 3,968.91 GYD-CT -CMS (1) = 7,475.00 30.34 89.72 5,906.32 5,829.47 325.00 4,199.60 6,000,912.42 502,854.53 0.04 3,981.11 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 3,993.26 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 4,005.25 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 4,017.06 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 4,028.65 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 4,040.03 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 4,051.29 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 4,062.44 GYD -CT -CMS (1) TIP 3H -33 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 4,069.09 MWD (2) KOP 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 4,084.41 MWD (2) Interpolated AZI 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 4,103 40 MWD (2) Interpolated AZI 7,754.60 63.61 68.48 6,135.44 6,058.59 339.27 4,350 55 6,000,926.67 503,005.47 44.23 4,123 55 MWD (2) 11/3/2009 11:39:03AM Page 11 COMPASS 2003.16 Build 69 `r' ConocoPhillips FA itI Cotic)coPhiiiips Definitive Survey Report BAKE C ConocoPhillips(Al Inc. L ocal Co- ordinate 3H -33 Project: Kuparuk River Unit , nici Reference: 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site Kuparuk 3H Pad MD Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well 3H - 33 " North Reference: True Wellbore:' 3H -33 Survey Calculation Method: j Minimum Curvature = Design: 3H -33 Database : ,,,;EDM Alaska Prod v16 ._ _ „,„ ' 1 s_ „ti „o. x m =„M .> -.. ,'nom,' a _ _. Survey Map Map Vertical lip In : , Ail i� TVD 7VDSS ° +N/'S + E ) - W Northing '' ;Easting DI ' Section (ft) (I r) (ft) (ft) ! (ft : (ft) (ft) 1ft) ( ( Survey Tool Name Annotation I 7,784.16 76.24 56.51 6,145.60 6,068.75 352.14 4,375.01 6,000,939.53 503,029.93 57.13 4,143.97 MWD (2) 7,814.18 87.94 53.92 6,149.73 6,072.88 369.08 4,399.38 6,000,956.47 503,054.31 39.90 4,163.27 MWD (2) 7,844.35 95.26 66.04 6,148.88 6,072.03 384.14 4,425.43 6,000,971.51 503,080.35 46.89 4,184.66 MWD (2) 7,874.13 95.56 83.65 6,146.05 6,069.20 391.86 4,453.93 6,000,979.23 503,108.85 58.88 4,210.29 MWD (2) 7,904.34 93.75 100.56 6,143.58 6,066.73 390.75 4,483.91 6,000,978.12 503,138.82 56.11 4,239.57 MWD (2) 7,934.39 93.53 118.00 6,141.66 6,064.81 380.89 4,512.10 6,000,968.25 503,167.02 57.92 4,269.35 MWD (2) 1 7,972.47 94.30 136.46 6,139.04 6,062.19 358.00 4,542.22 6,000,945.36 503,197.13 48.40 4,304.27 MWD (2) 8,005.43 94.00 141.21 6,136.65 6,059.80 333.26 4,563.85 6,000,920.62 503,218.75 14.40 4,331.45 MWD (2) 8,035.24 93.84 144.89 6,134.61 6,057.76 309.50 4,581.73 6,000,896.86 503,236.62 12.33 4,354.75 MWD (2) I 8,065.22 93.50 148.66 6,132.69 6,055.84 284.48 4,598.12 6,000,871.83 503,253.01 12.60 4,376.94 MWD (2) 8,095.40 93.78 153.06 6,130.78 6,053.93 258.18 4,612.78 6,000,845.53 503,267.66 14.58 4,397.77 MWD (2) 8,125.70 93.72 157.47 6,128.79 6,051.94 230.72 4,625.43 6,000,818.08 503,280.30 14.52 4,416.95 MWD (2) 8,155.18 94.46 161.64 6,126.69 6,049.84 203.18 4,635.70 6,000,790.53 503,290.57 14.33 4,433.84 MWD (2) 8,185.68 95.66 166.11 6,124.00 6,047.15 174.00 4,644.14 6,000,761.36 503,299.00 15.12 4,449.38 MWD (2) l 8,215.50 95.54 170.46 6,121.09 6,044.24 144.95 4,650.16 6,000,732.31 503,305.02 14.52 4,462.55 MWD (2) 8,245.55 94.64 174.12 6,118.42 6,041.57 115.29 4,654.17 6,000,702.65 503,309.03 12.50 4,473.93 MWD (2) ill 8,275.55 93.32 177.53 6,116.34 6,039.49 85.45 4,656.35 6,000,672.81 503,311.20 12.16 4,483.58 MWD (2) 8,305.54 91.01 180.61 6,115.21 6,038.36 55.49 4,656.84 6,000,642.86 503,311.68 12.83 4,491.62 MWD (2) 8,335.70 88.37 182.97 6,115.37 6,038.52 25.35 4,655.90 6,000,612.72 503,310.73 11.74 4,498.33 MWD (2) 8,365.59 89.75 186.43 6,115.86 6,039.01 -4.43 4,653.45 6,000,582.94 503,308.28 12.46 4,503.49 MWD (2) 8,395.35 91.87 189.97 6,115.44 6,038.59 -33.88 4,649.20 6,000,553.50 503,304.03 13.86 4,506.82 MWD (2) 8,425.45 90.71 193.13 6,114.76 6,037.91 -63.36 4,643.18 6,000,524.02 503,298.00 11.18 4,508.45 MWD (2) i 8,455.25 89.66 196.33 6,114.66 6,037.81 -92.17 4,635.60 6,000,495.21 503,290.42 11.30 4,508.40 MWD (2) 8,485.34 89.48 199.70 6,114.89 6,038.04 - 120.78 4,626.30 6,000,466.61 503,281.11 11.22 4,506.63 MWD (2) 8,515.40 88.80 204.27 6,115.34 6,038.49 - 148.65 4,615.05 6,000,438.75 503,269.86 15.37 4,502.79 MWD (2) 8,545.33 85.11 205.28 6,116.93 6,040.08 - 175.78 4,602.53 6,000,411.62 503,257.33 12.78 4,497.53 MWD (2) 8,575.70 83.11 206.65 6,120.05 6,043.20 - 202.94 4,589.30 6,000,384.47 503,244.10 7.97 4,491.60 MWD (2) 8,605.70 85.85 209.70 6,122.93 6,046.08 - 229.25 4,575.21 6,000,358.16 503,230.00 13.63 4,484.61 MWD (2) 8,635.41 88.25 213.83 6,124.46 6,047.61 - 254.47 4,559.59 6,000,332.94 503,214.38 16.06 4,475.87 MWD (2) 8,665.38 88.40 218.41 6,125.34 6,048.49 - 278.66 4,541.94 6,000,308.76 503,196.73 15.28 4,464.91 MWD (2) 8 695.27 87 61 217 93 6,126.38 6,049.53 - 302.15 4,523 47 6,000,285.28 503,178.26 3 09 4 452 98 MWD (2) 11/3/2009 11 :39 :03AM Page 12 COMPASS 2003.16 Build 69 1 ConocoPhillips IF/4'1111 ConocoPtiillips Definitive Survey Report Alaska -- - ainfiL5 C C o noc o Ph i llips(Alaska) Inc. Local Co- ordinate i efe n e 3H -33 Project l ,, Kuparuk River Unit ', TVD Reference l 3H -33 Rig @ 76 (D15 (40.75 +36.1)) Site: '� Kuparuk 3H Pad ' Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) W - 1 3H - 33 North Reference: - .,, True Wollbore ; 3H -33 Survey Calculation Method: ,, Minimum Curvature I Design: 3H Database EDM Alaska Prod v16 unr8yl . _ Map Map vertical ii• MD . Inc' Ali TVD TVDss ` +NI +El W Northing Easting; 1 section survey Tool Name. ,,. Annotation, (ft ' ( ° (")1' (ft) (g) (ft) ( (f ( 1100) ) 8,725.60 88.83 213.80 6,127.32 6,050.47 - 326.71 4,505.72 6,000,260.72 503,160.50 14.19 4,442.01 MWD (2) 8,755.44 90.12 210.11 6,127.60 6,050.75 - 352.02 4,489.93 6,000,235.42 503,144.71 13.10 4,433.13 MWD (2) I 8,785.17 90.95 205.98 6,127.32 6,050.47 - 378.25 4,475.95 6,000,209.19 503,130.73 14.17 4,426.24 MWD (2) 8,815.28 90.52 201.85 6,126.93 6,050.08 - 405.77 4,463.75 6,000,181.68 503,118.53 13.79 4,421.39 MWD (2) 8,845.33 89.91 197.54 6,126.82 6,049.97 - 434.06 4,453.63 6,000,153.40 503,108.40 14.49 4,418.74 MWD (2) 8,875.27 89.85 193.57 6,126.88 6,050.03 - 462.89 4,445.60 6,000,124.56 503,100.37 13.26 4,418.26 MWD (2) 8,905.20 90.92 189.22 6,126.68 6,049.83 -492.23 4,439.69 6,000,095.24 503,094.45 14.97 4,419.95 MWD (2) 8,935.28 90.28 185.32 6,126.37 6,049.52 - 522.06 4,435.88 6,000,065.41 503,090.64 13.14 4,423.81 MWD (2) 8,965.37 91.50 180.65 6,125.90 6,049.05 - 552.09 4,434.32 6,000,035.37 503,089.07 16.04 4,429.89 MWD (2) 8,995.24 90.55 176.70 6,125.36 6,048.51 - 581.94 4,435.01 6,000,005.53 503,089.75 13.60 4,438.10 MWD (2) 9,025.40 90.06 172.78 6,125.20 6,048.35 - 611.97 4,437.77 5,999,975.50 503,092.51 13.10 4,448.36 MWD (2) 9,055.41 91.97 168.85 6,124.67 6,047.82 - 641.58 4,442.56 5,999,945.89 503,097.30 14.56 4,460.48 MWD (2) 9,085.14 91.60 165.17 6,123.74 6,046.89 - 670.53 4,449.24 5,999,916.94 503,103.97 12.43 4,474.26 MWD (2) 9,115.27 91.32 161.27 6,122.98 6,046.13 - 699.37 4,457.93 5,999,888.11 503,112.66 12.97 4,489.96 MWD (2) , 9,145.31 91.69 157.15 6,122.19 6,045.34 - 727.43 4,468.59 5,999,860.04 503,123.31 13.77 4,507.36 MWD (2) 9,176.47 91.63 153.42 6,121.28 6,044.43 - 755.72 4,481.61 5,999,831.76 503,136.32 11.97 4,527.11 MWD (2) ( 1 ill 9,205.43 92.24 155.36 6,120.31 6,043.46 - 781.82 4,494.12 5,999,805.66 503,148.82 7.02 4,545.81 MWD (2) 9,235.21 92.30 159.56 6,119.13 6,042.28 - 809.30 4,505.52 5,999,778.18 503,160.22 14.09 4,563.79 MWD (2) 9,265.36 91.63 164.03 6,118.09 6,041.24 - 837.92 4,514.93 5,999,749.57 503,169.63 14.98 4,580.13 MWD (2) 9,295.38 90.95 168.52 6,117.42 6,040.57 - 867.06 4,522.05 5,999,720.42 503,176.74 15.12 4,594.38 MWD (2) 9,325.24 93.44 171.72 6,116.27 6,039.42 - 896.45 4,527.17 5,999,691.03 503,181.85 13.57 4,606.76 MWD (2) 9,355.31 93.04 176.57 6,114.57 6,037.72 -926.31 4,530.23 5,999,661.18 503,184.91 16.16 4,617.27 MWD (2) 9,385.34 94.09 181.04 6,112.70 6,035.85 - 956.27 4,530.86 5,999,631.22 503,185.53 15.26 4,625.45 MWD (2) 9,415.32 94.24 185.83 6,110.52 6,033.67 - 986.10 4,529.07 5,999,601.39 503,183.73 15.94 4,631.26 MWD (2) 9,445.39 93.65 190.38 6,108.45 6,031.60 - 1,015.80 4,524.84 5,999,571.70 503,179.50 15.22 4,634.67 MWD (2) 9,475.16 92.00 192.57 6,106.99 6,030.14 - 1,044.93 4,518.92 5,999,542.57 503,173.58 9.20 4,636.31 MWD (2) 9,505.09 88.86 192.90 6,106.76 6,029.91 - 1,074.12 4,512.33 5,999,513.38 503,166.98 10.55 4,637.30 MWD (2) 9,535.26 85.36 193.16 6,108.28 6,031.43 - 1,103.47 4,505.54 5,999,484.04 503,160.18 11.63 4,638.15 MWD (2) 9,565.17 81.81 192.94 6,111.62 6,034.77 - 1,132.42 4,498.82 5,999,455.09 503,153.47 11.89 4,638.98 MWD (2) 9,607.00 81.81 192.94 6,117.58 6,040.73 - 1,172.78 4,489.55 5,999,414.74 503,144.19 0.00 4,640.20 PROJECTED to TD 11/3/2009 11:39:03AM Page 13 COMPASS 2003.16 Build 69 • Page 1 of 1 Schwartz, Guy L (DOA) From: Eller, J Gary [ J.Gary.Eller @conocophillips.com] Sent: Tuesday, January 05, 2010 1:18 PM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA); Gantt, Lamar L Subject: RE: 3H -33A / 3H -33AL1 Scope change followup (PTD 209 -103/ 104) Guy — Good eye! Yes, the liner in 3H -33A got stuck high enough that we were unable to sidetrack the AL1 lateral out of the 'A' borehole as originally planned. We were fortunate that we barely had enough room to set a whipstock and kick out of the original 3H -33 casing. In other words, we kicked off the AL1 lateral out of the 3H -33 original completion instead of further down in the 3H -33A lateral. We've had similar occurrences before in the Kuparuk CTD world but it never been suggested that we should notify the AOGCC of such. I'll convey to my CTD counterparts that in the future we should advise the AOGCC if our kickoff point changes substantially from the drilling permit even if the ultimate reservoir target and TD remain unchanged. I agree that renaming the laterals would be a very bad idea. Thanks much and please call if you'd like to discuss more. -Gary From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 05, 2010 10:01 AM To: Eller, 3 Gary Cc: Maunder, Thomas E (DOA) Subject: 3H -33A / 3H -33AL1 Scope change followup (PTD 209 -103/ 104) Gary, I was reviewing the well records and noticed the liner was set very high in 3H- 33A... to the point the ST aluminum billet ended up in the cement pilot hole. This changed the well completion somewhat for the following lateral (3H- 33AL1). The kickoff point changed less the 500 ft. but caused you to set a whipstock in the pilot hole to start the window. Can you elaborate on this so I can put this in the well file. Technically we could have changed the well names to reflect this but I don't think that would have been a good idea. I don't remember getting any notification on this change but I could be wrong. Be sure and keep me in the loop in the future for well construction changes that come up. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/5/2010 • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, October 20, 2009 3:40 PM To: Maunder, Thomas E (DOA); 'Eller, J Gary' Subject: RE: Plugback in 3H -33AL1 (209 -104) Gary, As Tom stated.... no problem with this. You are just pulling back to stay in the better quality A sand. Thanks for the update. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 20, 2009 3:33 PM To: Eller, 3 Gary Cc: Schwartz, Guy L (DOA) Subject: RE: Plugback in 3H -33AL1 (209 -104) Gary, Guy is your contact man for well issues. I have copied him on this message. I don't see any issue here. Tom Maunder, PE AOGCC From: Eller, 3 Gary [mailto:J.Gary.Eller @conocophillips.com] Sent: Tuesday, October 20, 2009 3:30 PM To: Maunder, Thomas E (DOA) Subject: Plugback in 3H -33AL1 Tom — We have drilled lateral KRU 3H -33AL1 (permit #209 -104) to a total depth of 9607' MD. The last several hundred feet has been non - productive A -sand, so we are currently planning a plugback to redrill in better quality pay. We'll sidetrack from 8810' MD, so that unproductive and unlined hole from 8810' — 9607' MD will be renamed 3H- 33AL1 -PB1. Please let me know if you have any questions or need any further information from me. Thanks. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907- 263 -4172 cell: 907 -529 -1979 fax: 907 -265 -1535 IP 0 tit ( 1 ! ' ! 4 s '`\ i s j ) SEAN PARNELL, GOVERNOR ALASKA OIL AND GAs 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 I 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 -33AL1 ConocoPhillips Alaska, Inc. Permit No: 209 -104 Surface Location: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 2481' FSL, 788' FEL, Sec. 12, 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 (50103205780100) KPR 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). Sincer ly, Cat y . Fo rster ���11 Com issioner DATED this day of September, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of Work: 1 b. Current Well Class: Exploratory ❑ gg Development Oil 12 10. Specify if well Is proposed for Drill ❑ Re-drill El SUatigraphlc Test ❑ Service n] Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zorn Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. • Bond No. 59 -52 -180 3H -33AL1 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 -0380 MD: 10050' TVD: 8035' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1089' FNL, 281' FWL, Sec. 12, T12N, R8E, UM ADL 25531 Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit 13. Approximate Spud Date: 746' FNL, 701' FEL, Sec. 12, T12N, RO8E, UM 2657 10/10/2009 Total Depth: 9. Acres in Property: 14. Distance to 2481' FSL, 788' FEL, Sec. 12, T12N, RO8E, UM 2560 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 - 6000588 Zone 4 KB Elevation above GL 36 feet to Same Pool: 3H-11 , 1500' 18. Deviated wells: Kickoff depth: 8100 ft. 17. Maximum Anticipated Pressures in psig (see 20 MC 25,035) Maximum Hole Angle: 106° deg Downhole: 4126 psig Surface: 3473 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2.375" 4.7# 1 ST - L 2370' - 7680' 6010' 10050' 6035' slotted / solid liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redril and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) 8020' 6396' 7935' 6318' Casing •- Length Size Cement Volume MD TVD Conductor /Structural 113' 16" 97 sx AS 1 149' 149' Surface 4279' 9 -5/8" 840 sxASLlte, 178 ax LIteCRETE 4315' 3614' Intermediate Production 7984' 7" 309 sx Class G 8020' 6396' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7740' -7760' 6140' -6158' 20. Attachments: Filing Fee ❑ BOP Sketch FS Drilling Program gg Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program El • 20 AAC 25.050 requirements El ' 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing Is true and correct. Contact J. Gary Eller ( 263-4172 Printed Na e V. Cawve • Title Wells Manager ppp Signature '� V Phone: 265 -6306 Date , /, // Jf . Commission Use Only 1! / / Permit to Drill API Nu • : Permit Ar:Irort See cover letter Number: aD91D# 60 /O3aOS > I Date: /Q7 Ibor 0th5r requirements Conditions of approval : If box Is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: q coo ,D 4) O j7 '-- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [/ Other: / H2S measures: Yes le No ❑ Directional svy req'd: Yes (a' No ❑ 2Sob psi 4 -h' 7Tf b..._) APPROVED BY THE COMMISSION DATE: � — / ,2 /....9J16‘..4.4....-- ,COMMISSIONER Form 10-401 (Revised 1/2009) / Submit in Duplicate ORIGINAL A 2`/- • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Summary of Operations: Well 3H-33 is a 3'/2" tubing x 7" casing producer in the Kuparuk A -sand. Four proposed CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling, the existing A -Sand perfs in 3H -33 will be squeezed with cement to provide a means to kick out of the 7" casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 7725' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 3H -33A sidetrack will exit the 7" casing at 7685' MD and will target the A2 sand south of the existing well with a 2365' lateral. The hole will be completed with a 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'h" tubing at 7560' MD. CTD Drill and Complete 3H -33: October/November 2009 Pre -Rig Work 1. Test packoffs — T & IC. 2. Positive pressure and drawdown tests on MV, SV, & SSSV. 3. DGLV's, load tbg & IA. MIT -IA. MIT -OA. 4. Obtain updated static BHP on A -sand 5. Shoot tubing punches in 3'/2" tubing tail at 7575' MD. 6. Plug the A -Sand perfs with cement up to 7575' MD. 7. RU slickline. Tag cement top. 8. Prep site for Nabors CDR2 -AC. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 3H -33A Lateral (A2 sand, south) a. Drill 2.74" high -side pilot hole through cement to 7725 MD'. b. Drift pilot hole with whipstock dummy. c. Set 3'h" 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_IL-up to 8100' i--- -- 3. 3H -33AL1 Lateral (A3 sand, south) -7461-104 a. Kick off of the aluminum billet at 8100' MD 1 ,t - b. Drill 2.70" x 3" bi- center lateral to TD of 10,050' MD. � c. Run 2%" slotted liner from TD up to 7680' MD, up inside the 7" casing • Page 1 of 4 !! `` September 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling 4. 3H -33AL2 Lateral (A2 sand, north) a. Set 3'/2" monobore whipstock in cement pilot hole at 7665' MD with high -side orientation. b. Mill 2.74" window with high -side orientation at 7665' MD. 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. 3H- 33AL2 -01 Lateral (A3 sand, north) a. Kick off of the aluminum billet at 8050' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9275' MD. c. Run 2%" slotted liner from TD up to 7560' MD, up inside the 3'/2" tubing tail 6. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Obtain static BHP 2. Run GLVs. 3. Return well to production. Mud Program: • Will use chloride -based Biozan brine or used drilling mud (8.6 ppg) for milling operations, and chloride - based Flo -Pro mud ( -10.0 ppg) for drilling operations. There is a SCSSV installed in 3H -33, so we should not have to kill the well to deploy 2%" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 3H -33A: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 8100' MD to 10,050' MD • 3H- 33AL1: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 7680' MD to 10,050' MD • 3H- 33AL2: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 8050' MD to 9275' MD • 3H- 33AL2 -01: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 7560' MD to 9275' MD Existing Casing/Liner Information Surface: 9% ", L -80, 40 ppf Burst 5750 psi; Collapse 3090 psi Production: 7 ", L -80, 26 ppf Burst 7240 psi; Collapse 5410 psi Well Control: • Two well bore volumes (-200 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure in 3H -33 is 3473 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity, which is 4126 psi at 6156 TVD (i.e. 12.9 ppg) in offset injector 3A- 15 in January 2009. Well 3A -15 had been shut -in several months when this survey was taken. • The annular preventer will be tested to 250 psi and 2500 psi. Page 2 of 4 1G1NAL September 16, 2009, FINAL • IP KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 3H -33A, plan #1 2. 311- 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. • 311-33 CTD southern laterals (A & AL 1): —18,300' to property line, —4500' from well 3H -11 • 3H -33 CTD northern laterals (AL2 & AL2 -01): 18,300' to property line, 1200' from well 3H -14B Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 311-33 was taken June 2009 after a 72 -hour shut -in, which measured reservoir pressure of 3175 psi at 6010' TVD, corresponding to 10.2 ppg EMW. Expect to encounter increasing pressure as the laterals are drilled away from the mother well due to anticipated interaction with injection well 3A -15. 3A -15 was recently shut in to allow the area to de- pressurize. The most recent pressure survey in 3A -15 showed 4126 psi at 6156 TVD (12.9 ppg EMW) as of January 2009. Hazards • Lost circulation is not expected to be particularly troublesome. Expect to encounter increasing pressure as the laterals are drilled away from the mother well. • Over- pressured zones are a potential hazard in 311 -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 112S 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 311-18 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. Page 3 of 4 ORIGINAL September 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 3H -33 has a SCSSV, so the well should not have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Maximum expected reservoir pressure (i.e. formation pressure encountered from originally drilled 3H- 33): 4054 psi at 7685' MD (6091' TVD), or 12.8 ppg EMW. • Expected annular friction losses while circulating: 507 psi (assuming friction of 66 psi /1000 ft due to the 3''A" 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 September 16, 2009, FINAL ORIGINA1 • • c onocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33 3H -33AL1 Plan: Plan 2, 3H -33AL1 Standard Planning Report 11 September, 2009 BAKER HUGHES ORIGINAL • • ConocoPhillips FARM ConocaPilillips S Planning Report H1 ER HES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3H - 33 Company: : ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference:_ 3H -33 Rig Q 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: True Weil.- 3H - 33 Survey Calculation Method: Minimum Curvature Welibore: - 3H -33AL1 Desk - Plan 2, 3H -33AL1 Project i_Kuparuk River Unit, North Slope Alaska United States .. .., ,, , Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 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 +NI -S 0.00 ft Northing: 6,000,588.21 ft Latitude: 70° 24' 46.228 N +EI -W 0.00 ft Easting: 498,655.30 ft Longitude: 150° 0' 39.423 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 36.10ft Weilbore 3H - 33AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) ( °) (nT) BGGM2009 11/4/2009 17.26 79.81 57,352 Design Plan 2, 3H -33AL1 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,100.00 Vertical Section: D epth From (TVD) +W-S +E/-W Direction (ft) (ft) (ft) ( °) - 36.10 0.00 0.00 190.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination . Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) ( °) (°) (ft ) (ft) (ft) (1100ft) r /100ft) ( ° /1001t) r Target 8,100.00 93.87 170.02 6,084.77 117.43 4,555.77 0.00 0.00 0.00 0.00 8,120.00 97.87 170.02 6,082.73 97.84 4,559.22 20.00 20.00 0.00 0.00 8,160.00 105.87 170.02 6,074.51 59.32 4,566.00 20.00 20.00 0.00 0.00 8,220.00 105.99 162.53 6,058.03 3.32 4,579.68 12.00 0.20 -12.48 272.00 8,390.00 90.08 175.48 6,034.23 - 161.10 4,611.25 12.00 -9.36 7.62 140.00 8,540.00 87.62 193.31 6,037.27 -310.02 4,599.82 12.00 -1.65 11.89 98.00 8,640.00 89.53 205.16 6,039.77 - 404.23 4,566.94 12.00 1.91 11.85 81.00 8,815.00 89.56 184.16 6,041.17 - 572.58 4,522.89 12.00 0.02 -12.00 270.00 9,040.00 90.02 211.16 6,042.01 - 785.00 4,455.26 12.00 0.20 12.00 89.10 9,415.00 90.58 166.16 6,039.95 - 1,146.26 4,400.24 12.00 0.15 -12.00 270.80 9,865.00 90.34 220.16 6,036.05 - 1,568.38 4,301.53 12.00 -0.05 12.00 90.00 10,050.00 90.31 197.96 6,034.98 - 1,729.08 4,212.23 12.00 -0.01 -12.00 270.00 9/11/2009 7:50:45AM Page 2 COMPASS 2003.16 Build 69 ORIGINS 1L • • ve ConocoPhillips ConocoPhillips 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: ' 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 Welibore: - 3H - 33AL1 Design: Plan 2, 3H - 33AL1 Planned Survey Measured < TVD Below Vertical Dogleg ; Toolface Map Map De Inclination Azimuth ? item +N/ S +E/-W ` Section Rate " Azimuth Northing Easting (it) • °) r) (ft) (ft) (ft) ` (ft) ( °/100f) r) (ft) (ft) 8,100.00 93.87 170.02 6,084.77 117.43 4,555.77 - 906.75 0.00 0.00 6,000,704.81 503,210.64 ■ TIP /KOP 8,120.00 97.87 170.02 6,082.73 97.84 4,559.22 - 888.05 20.00 0.00 6,000,685.22 503,214.08 2 8,160.00 105.87 170.02 6,074.51 59.32 4,566.00 - 851.30 20.00 0.00 6,000,646.70 503,220.85 End of DLS 20 8,200.00 105.98 165.03 6,063.53 21.77 4,574.31 - 815.77 12.00 -88.00 6,000,609.16 503,229.15 8,220.00 105.99 162.53 6,058.03 3.32 4,579.68 - 798.52 12.00 -89.37 6,000,590.70 503,234.52 4 8,300.00 98.56 168.75 6,041.02 -72.34 4,598.99 - 727.37 12.00 140.00 6,000,515.05 503,253.81 8,390.00 90.08 175.48 6,034.23 - 161.10 4,611.25 - 642.08 12.00 141.33 6,000,426.29 503,266.06 5 8,400.00 89.92 176.67 6,034.23 - 171.08 4,611.94 - 632.37 12.00 98.00 6,000,416.32 503,266.74 8,500.00 88.26 188.55 6,035.83 - 270.78 4,607.40 - 533.40 12.00 98.00 6,000,316.63 503,262.18 8,540.00 87.62 193.31 6,037.27 - 310.02 4,599.82 - 493.44 12.00 97.81 6,000,277.40 503,254.60 6 8,600.00 88.76 200.42 6,039.17 - 367.37 4,582.43 - 433.94 12.00 81.00 6,000,220.05 503,237.20 8,640.00 89.53 205.16 6,039.77 - 404.23 4,566.94 - 394.95 12.00 80.77 6,000,183.20 503,221.70 7 8,700.00 89.53 197.96 6,040.26 - 459.99 4,544.90 - 336.21 12.00 -90.00 6,000,127.45 503,199.66 8,800.00 89.56 185.96 6,041.05 - 557.64 4,524.21 - 236.45 12.00 -89.94 6,000,029.81 503,178.96 8,815.00 89.56 184.16 6,041.17 - 572.58 4,522.89 - 221.51 12.00 -89.85 6,000,014.87 503,177.63 8 8,900.00 89.73 194.36 6,041.70 - 656.36 4,509.23 - 136.63 12.00 89.10 5,999,931.10 503,163.96 9,000.00 89.93 206.36 6,041.99 - 749.94 4,474.50 -38.44 12.00 89.04 5,999,837.54 503,129.22 9,040.00 90.02 211.16 6,042.01 - 785.00 4,455.26 -0.58 12.00 89.00 5,999,802.49 503,109.97 9 9,100.00 90.12 203.96 6,041.94 - 838.15 4,427.52 56.59 12.00 -89.20 5,999,749.34 503,082.23 9,200.00 90.28 191.96 6,041.59 - 933.11 4,396.75 155.45 12.00 -89.21 5,999,654.40 503,051.43 9,300.00 90.43 179.96 6,040.97 - 1,032.38 4,386.38 255.01 12.00 89.25 5,999,555.14 503,041.051 9,400.00 90.56 167.96 6,040.10 - 1,131.64 4,396.88 350.94 12.00 -89.33 5,999,455.89 503,051.54 9,415.00 90.58 166.16 6,039.95 - 1,146.26 4,400.24 364.75 12.00 -89.43 5,999,441.27 503,054.89 10 9,500.00 90.57 176.36 6,039.10 - 1,230.16 4,413.14 445.14 12.00 90.00 5,999,357.38 503,067.77 I 9,600.00 90.54 188.36 6,038.13 - 1,329.89 4,409.03 544.06 12.00 90.10 5,999,257.66 503,063.64 9,700.00 90.48 200.36 6,037.24 - 1,426.58 4,384.27 643.59 12.00 90.22 5,999,160.98 503,038.87 9,800.00 90.40 212.36 6,036.47 - 1,516.02 4,339.95 739.36 12.00 90.33 5,999,071.57 502,994.54 9,865.00 90.34 220.16 6,036.05 - 1,568.38 4,301.53 797.60 12.00 90.42 5,999,019.21 502,956.11 11 9,900.00 90.34 215.96 6,035.84 - 1,595.94 4,279.96 828.48 12.00 -90.00 5,998,991.66 502,934.54 10,000.00 90.33 203.96 6,035.26 - 1,682.41 4,230.11 922.30 12.00 -90.02 5,998,905.21 502,884.68 10,050.00 90.31 197.96 6,034.98 - 1,729.08 4,212.23 971.37 12.00 -90.09 5,998,858.55 502,866.79 TD 23/8" 9/11/2009 7 :50.45AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL • • ConocoPhillips , Conoco Ptiillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3H - 33 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project! - Kuparuk River Unit M D Reference: = 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) Site Kuparuk 3H Pad North Reference: True Well: = 31 Survey Calculation Method:- Minimum Curvature Wellbore: = 3H - 33AL1 sign: Plan 2, 3H - 33AL1 Target Target Name, - hiamiss target Dip Angie Dip.Dir- TVD +N/$ +EI W Northing Easting Shape. ( °) l°) (ft) ( (ft) ' (g) l l Latitude Long itude 3H-33 A3 S t3.1 (copy 0.00 0.00 6,042.15 - 775.82 4,407.41 5,999,811.68 503,062.13 70° 24' 38.585 N 149° 58' 30.237 W - plan misses target center by 46.00ft at 9054.01ft MD (6042.00 TVD, - 797.09 N, 4448.19 E) - Point 3H -33 A3 S t1.1 (copy 0.00 0.00 6,040.15 -51.74 4,529.31 6,000,535.66 503,184.14 70° 24' 45.705 N 149° 58' 26.651 W - plan misses target center by 63.91ft at 8263.81ft MD (6047.45 TVD, -37.59 N, 4591.20 E) - Point 3H -33 A3 S 12.1 (copy 0.00 0.00 6,040.15 - 365.77 4,481.35 6,000,221.67 503,136.14 70° 24' 42.617 N 149° 58' 28.062 W - plan misses target center by 93.89ft at 8637.71ft MD (6039.75 TVD, - 402.15 N, 4567.91 E) - Point 31-1 -33 A3 S t4.1 (copy 0.00 0.00 6,035.15 - 1,743.94 4,188.54 5,998,843.69 502,843.10 70° 24' 29.065 N 149° 58' 36.668 W 1 - plan misses target center by 27.96ft at 10050.00ft MD (6034.98 TVD, - 1729.08 N, 4212.23 E) ■ - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) . (f» Name (1 (°') 4,315.06 3,532.90 9 5/8" 9 -5/8 12 -1/4 10,050.00 6,034.98 2 3/8" 2 -3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-s +EI W (ft) (ft) (ft) (ft) Comment 8,100.00 6,084.77 117.43 4,555.77 TIP / KOP 8,120.00 6,082.73 97.84 4,559.22 2 8,160.00 6,074.51 59.32 4,566.00 End of DLS 20 8,220.00 6,058.03 3.32 4,579.68 4 8,390.00 6,034.23 - 161.10 4,611.25 5 8,540.00 6,037.27 - 310.02 4,599.82 6 8,640.00 6,039.77 - 404.23 4,566.94 7 8,815.00 6,041.17 - 572.58 4,522.89 8 9,040.00 6,042.01 - 785.00 4,455.26 9 9,415.00 6,039.95 - 1,146.26 4,400.24 10 9,865.00 6,036.05 - 1,568.38 4,301.53 11 , 10,050.00 6,034.98 - 1,729.08 4,212.23 TD 9/11/2009 7 :50:45AM Page 4 COMPASS 2003.16 Build 69 , Aamume to True North WELLBORE DETAILS: 31-1-33AL1 REFERENCE INFORMATION Irk Project: Kuparuk River Unit Magnetic North 21.8n Site: Kuparuk 3H Pad Magnetic Field Parent Wellbore: 3H -33A Coordinate (NIE) Reference: Well 3H True North 'W,.-'' Well: 3H-33 Strength: 57642aenr Tie on MD: 8100.00 .' Vertical (N CQnQL.VrD) Reference: Mean Sea Level BAICER • ` Wellborn:. 3H Dro Angle: ever Section (VS) Reference: Slot - (SOON 0,00E) Dam. 1114/2009 r41114/2009 09 3H fi 5 15 40.75 36.1 I 1�1� P an: P an 2 3H33AL1 3H 33 /3HJ3AL7 Measured Depth Reference: 3H Rig @ 7 b tl (D ( )) PS I I ( ) Moeet: sccMxooe Calculation Method: Minimum Curvature HUGHES 800 WELL DETAILS: 3H -33 600 Ground Level: 36.10 __ _ _.... .. __._ +N / -5 +E/ -W Northing Easting Latittude Longitude Slot 0.00 0,00 6000588.21 498855.30 70° 24' 46.228 N 150° 0' 39.423 W 31 1.33/3H -33 SECTION DETAILS ANNOTATIONS 200 TIP /ICOP Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec T. get Annotation 2 End of DLS 20 1 8100.00 93.87 170.02 6084.77 117.43 4555.77 0.00 0.00 - 906.75 TIP I KOP 0 4 2 8120.00 97.87 170.02 6082.73 97.84 4559.22 20.00 0.00 - 888.05 2 5 3 8160.00 105.87 170.02 6074.51 59.32 4566.00 20.00 0.00 - 851.30 End of DLS 20 p - 200 4 8220.00 105.99 162.53 6058.03 3.32 4579.68 12.00 272.00 - 798.52 4 6 5 8390.00 90.08 175.48 6034.23 - 161.10 4611.25 12.00 140.00 - 642.08 5 O aoo 7 6 8540,00 87.62 193.31 6037.27 -310.02 4599.82 12.00 98.00 - 493.44 6 7 8640.00 89.53 205.16 6039.77 - 404.23 4566.94 12.00 81.00 - 394.95 7 CA 8 8815.00 89.56 184.16 6041.17 - 572.58 4522.89 12.00 270.00 - 221.51 8 - 600 g 9 9040.00 90.02 211.16 6042.01 - 785.00 4455.26 12.00 89.10 -0.58 9 +. ' ' 1 `< .0° � 10 9415.00 90.58 166.16 6039.95 -1146.26 4400.24 12.00 270.80 364.75 10 - 000 - 11 9865.00 90.34 220.16 6036.05 - 1568.38 4301.53 12.00 90.00 797.60 11 00 ll 12 10050.00 90.31 197.96 6034.98 - 1729.08 4212.23 12.00 270.00 971.37 TD - c_tnnn ...,. - 10 ' 50O -1200 ,,o„M.wrr -1400 3H-33/3H-13A ,-*+ ,.�,��,, -1600 1 1 1800 31-1-33/3 H -33AL1 TD -2000 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 West( -) /East( +) (200 ft/in) 5760 -. _... -. .. _..... _... _ _.... _..... 5820 5880- End of DLS 20 IC 5940- TIP / KO O P 31-1 3 /3H 33AL1 6000 - 5 6 7 8 9, 10 11 � 4 + t 4- TD A m 6060 . 2 ` -:,,p, 4 - rd 6120_ !. 3H-31/i11-37A .V. c 6180 - N '.. E 6240_. _._... __.. __- _...... _. __... 6300- 3H- 33/3H -33 '.. 6360 6420 -1140 -1080 -1020 -960 -900 -840 -780 -720 -660 -600 -540 -480 -420 -360 -300 240 -180 -120 -60 0 6 120 180 240 300 360 420 480 540 0_ _ 40 600 660 720 780 840 900 960 1020 1080 1140 Vertical Section at 190.00° (60 ft/in) , Azimuths to True North. WELLBORE DETAILS: 31-1-33AL1 REFERENCE INFORMATION Kai - Project: Kuparuk River Unit Magnetic North 21.85 Site: Kuparuk 3H Pad Magnetic Field Wellbore: 3H - 33A Co-ordinate (Na) Reference: WeII 3H•33, True North - ..� Well: 3H Strength: 57542Janr Tie on MD: 8100.00 Vertical (ND) Reference: 3H-33 Rig @ 76.65ft (015 (40.75 +36.1)) BAKER Co o Q t]� ( Wellbore; 3H33AL1 ode Angle: 80.07 Section (VS) Reference: Slut - (0.005, 0E0E) IT 1 I��I'. .rS Plan: Plan 2, 3H33AL1 (3H33/3H- 33AL1) Model: B00142009 11/4/200S Measured Depth Reference: 34-33 Rig 76.855 (015 (40.75 +36.ip HUGHES Calculation Method. Minimum Curvature 2000 - . 1800 -. .. '... ! ... 1600 - ',., 1400 -' 1200 : ',, 1000 - - -_. ._.__. ......_.. _.I. _..._._ __._ __.. _.... .. _..... - -_. .. 800 - '' . y�. 600 .. _ :. .. P (. 1 . 400 3H- 33/311 -33 __. -... 200- 0 - �� - 200 - - - -- - o -400 + - 600 , / -800 - . 1000- - 1200 -- '., 0 -1400 ... -1600- 3H -3 3/3 H -33A • 3H- 33/3H -33AL1 -1800- 6(32.__ 6772 - 2000 -. _ : ',. -2200 _. __.... ...... _.... ....._. _. __ __... _...... __ ._ -. _.._ - 2400 -. -2600- .. o o - 2800 - 311- 04/311 -04 -3000- _.. i.. - 3400. . . 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 38004000 4200 4400 400 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 311-33 Rig @ 76.850 (D15 (40.75 +36.1)) West( -) /East( +) (200 ft /in) 3H -33 Proposed CTD Sidetrack 1 3 -1/2" Cameo TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) 3.1/2 ", 9.34, L -80 EUE 8rd Tubing to surface MOW 16", 62 #, H•40 conductor UMW 3.1/2" Carnco MMG gas lift mandrels at 2735', 4444', 5710', 6789', & 7453' shoe 149' MD _ MUM 9.5/8 ", 404,. L -80 casing shoe at 4315' MD • CD 70 G X- nipple at 7504' MD (2.813" min ID) V ! : Baker Premier packer at 7547' MD. No sealbore or seal assembly. -- Camco D- nipple @ 7594 MO (2.75" min ID, No-Go) Nipple milted out to 2.80" ID 3-1/2" tubing tail at 7608' MD (7602' ELM) r _ Top of cement at tubing tail at 4 _ 7606' MD KOP 42 at 7665' MD ... i AL2.01 Lateral (A3 sand, north) KOP #1 of 7685' MD ��� - -�-� — _ - TD = 9275' - ■ m I / Liner top of 7560' • Baker onobore whipstock trays on I r openhole anchors at 7665' & 7685' _ / AL2 Lateral (A2 sand, borth) — 2.80" pilot hole in cement drilled to // — . — — — ) TD = 9275' 7725' Mt Billet at 8050' AL1 Lateral (A3 sand, south) TD= 10,050' A -sand parts (sgz'd) ��� — Liner top at 7680'. 2 — 7740' - 7760' MD ; .. sm. 7 / — � / A Sidetrack (A2 sand, south) `� —� — — — — TD = 10,050' 7 ", 26 #, L - 80 casing ^ ^^ ^ ^^ ^ Billet at 8100' it shoe at 8020' MD ^,^^ ^ ^M,. ^^^ ^ ' . . Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator s Riser r Annular Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator �/� above BHA rams Ri Choke 1 2 -3/8" Pipe / Slip (BHA) Choke Equalize Manifold 2 -3/8" Pipe / Slip (BHA) Kill ► >4C'>G L ■ • ■ � r Blind / Shear — 2" Pipe / Slip (CT) Swab Valves Choke 2 Wing Valves ® ®®® Tree Flow Cross Surface Safety Vaive BOPE: 7- 1/16 ", 5M psi, TOT r C Choke Line: 2- 1/16 ", 5M psi Y Master Valve Kill Line: 2- 1/16 ", 5M psi y Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union C t% A t Alaska Department of Naturaasources Land Administration System Page 1 of i Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 25531 d1 Printable Case File Summary See Township, Range, Section and Acreage? New search 0 Yes 0 No LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract . File: ADL 25531 �" Search for Status Plat Updates As of 09/23/2009 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.cfin ?FileType= ADL &FileNumber = 2553... 9/23/2009 Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 9:30 AM To: Ramirez, Darlene V (DOA) Subject: Re: 209 -104 Approved Sent from my iPhone On Sep 25, 2009, at 4:03 PM, "Ramirez, Darlene V (DOA)" <darlene.ramirez @alaska.gov > wrote: > «S45C- 209092513471.pdf» > The message is ready to be sent with the following file or link > attachments: > S45C- 209092513471.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- 209092513471.pdf> IC I 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME , '4" PTD# a0q /40 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: l��Ai g,ew ,,x,i/�',8 POOL: l�� /i0geM ,' /!/E„C' 0,4 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The p rmit is for a new wellbore segme t of existing well cS010 01.5 7,07/ i4 J% , (If last two digits in Permit No. aO99Q3, API No. 50, OS- G.Vt 0 / 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(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 & , Well Name: KUPARUK RIV UNIT 3H -33AL1 Program DEV Well bore seg ❑ PTD#: 2091040 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 7 Sufficient acreage available in drilling unit Yes 2657 acres. I 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 59 -52 -180. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 9/23/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in 31-1-33 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 01-I slotted liner completion 23 Casing designs adequate for C, T, B & permafrost Yes 1 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -331 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Closest wellbore is P & A protion of 3H -33 & paths diverge. 27 If diverter required, does it meet regulations NA Wellhead in place.. BOP stack on top of tree. Appr Date 28 Drilling fluid fluid program schematic & equip list adequate Yes Max formation pressure 4126 psi ( 12..9 ppg) Will drill with Managed Pressure.... GLS 9/24/2009 29 BOPEs, do they meet regulation Yes will use 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. ill 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S 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 31-1-16 (2/24/09)._ Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/23/2009 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering Public Co miss' ner: D te: Commissioner: Date Commissioner Date J r 9 6' i J 9
