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210-076
New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 • • 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 10 - 0 7 Well History File Identifier Organizing (done) ❑ Two -sided JJI IIIIII1111111111 ❑ Rescan Needed III IIIIIIIIII RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: tre r Quality Originals: scale Items: ❑Other, No/Type: Li Other Items Scannable by a Large Scanner oo i y OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: 412D Date: g r I /s/ r,,,p 1 Project Proofing III 1[1111111111 BY: (Maria? Date: g 4/11 /5/ rn P Scanning Preparation ( x 30 = 3 0 + 1 ` = TOTAL PAGES LH BY: Date: a _ (Count does not include cover sheet /s/ Production Scanning III Ell I I III I I I I Stage 1 Page Count from Scanned File: 4.a... (Count does include cov sheet) Page Count Matches Number in Scanning Pre aration: include NO BY: Date: ! 1 f /s/ 1 I Fi Stage 1 If NO in stage 1, page(s) discrepancies were ound: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II 111 II 11 I I ReScanned 1 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2100760 Well Name /No. KUPARUK RIV UNIT 31 -11AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21932 -64 -00 MD 9279 TVD 6204 Completion Date 8/5/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION III Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments C, ,. D � 7 C Asc Directional Survey 7910 9279 Open -R•t Directional Survey 7910 8279 Open ED C Asc Directional Survey 7405 8500 Open PB1 'pt ^ Dir ional Survey 7405 8500 Open PB1 ED C Lis 20246 Induction /Resistivity 6620 9279 Open 11/1/2010 Well and PB1 MPR logs in PDS and Tiff ''L•• Induction /Resistivity 2 Col 6394 9279 Open 11/1/2010 MD MPR, GR og Induction /Resistivity 5 Col 6394 9279 Open 11/1/2010 MD MPR, GR s. pg Induction /Resistivity 5 Col 6394 9279 Open 11/1/2010 TVD MPR, GR Induction /Resistivity 2 Col 6394 8500 Open 11/1/2010 PB1 MD MPR, GR Log Induction /Resistivity 5 Col 6394 8500 Open 11/1/2010 PB1 MD MPR, GR Log Induction /Resistivity 5 Col 6394 8500 Open 11/1/2010 PB1 TVD MPR, GR Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2100760 Well Name /No. KUPARUK RIV UNIT 31 -11AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21932 -64 -00 MD 9279 TVD 6204 Completion Date 8/5/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION (. Well Cored? Y / I Daily History Received? CX ' N -. _ Chips Received? fir Formation Tops al' / N Analysis Received? • Comments: 1 7 '\ Compliance Reviewed By: _.)- Date: `�+ l '^t/ • Company ConocoPhillips, Alaska, Inc. BAKER Well Name 3I- 11AL2PB1 /v 49 (� HUGHES Date 10/12/2010 g' t MITE() ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribution RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL K� iciri , written approval from ConocoPhillips Image files and /or Digital Data !, , ,T ; contact: Lisa Wri • ht, 907 263 -4823 hardcop prints gib ConocoPhillips Alaska, Inc. Sharon Allsup Drake : `Q�' r Drilling Tech, ATO -1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ' #f { i ATTN: MAIL ROOM i 700 G Street, . Anchorage, AK 99501 ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk * / i , � .1 • , ' ! _ ` File * * / * ** Electronic r ''.7-,'.::.4-",...',,l,';,'!\°,-,/'-'!'",, - 700 G Street, CGM / TIFF LIS �p p M x Y , ftp : / /b2bftp.conocophillips.com * * ** AOGCC 1 Hardcopy Print, ," g ®m g r Christine Mahnken 1 Graphic image file 1 Disk * / �- 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic ". � � � r, Anchorage, Alaska 99501 CGM / TIFF LIS c ' fi • ,LA.,I• BP 1 Hardcopy Print, YA '• • ° 4; ( Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk " / ; f-,, David Douglas in lieu of sepia ** Electronic . m P.O. Box 196612 CGM / TIFF LIS % Anchorage, Alaska 99519- 6612�'�, CHEVRON /KRU REP 1 Hardcopy Print, 7` ; a Glenn Fredrick 1 Graphic image file 1 Disk * / t #, P.O.Box 196247 in lieu of sepia ** Electronic • ' Anchorage, Alaska 99519 CGM / TIFF LIS '`, Bsas�don Tucker, NRT �i • a State of Alaska; DNR, Div. of Oil and Gas 1 Disl< */ 550 W. 7th Ave, Suite 800 El ectronic *`„ Anchorage, Alaska 99501 -3510 LI ° DS Engineer / Rig Foreman TOTAL i Hardcop. Prints 4 Page 1 of 4 Company ConocoPhillips, Alaska, Inc. / 0 � R BAKER Well Name 3I -11AL2 �U 7..,(D HUGHES Date 10/12/2010 MITEQ ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribution RECIPIENTS �b r 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 har d cop prints ��,.,�„ --�� ConocoPhillips Alaska, Inc. R • Sharon Allsup -Drake n Drilling Tech, ATO -1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print 1e ,$* NSK Wells Aide, NSK 69�k� ATTN: MAIL ROOM • , 700 G Street, z Anchorage, AK 99501 , ' 'F,''-i ,., '7.1.7, . ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk * / 1 File .* / * ** Electronic ` ����, G Street, CGM / TIFF LIS { ftp: / /b2bftp.conocophillips.com r, AOGCC 1 Hardcopy Punt, �d ® Christine Mahnken 1 Graphic image file 1 Disk / i ,� � '; 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic ��' Anchorage, Alaska 99501 CGM / TIF LIS `s • BP 1 Hardcopy Print, e W Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk " / > �s David Douglas in lieu of sepia ** Electronic ® ,Y, P.O. Box 196612 CGM / TIFF LIS �,- k` , , Anchorage, Alaska 99519 - 6612• c.4 u' CHEVRON /KRU REP • 1 Hardcopy Print., arm ® , Glenn Fredrick 1 Graphic image file 1 Disk */ �,f�i }' P.O.Box 196247 in lieu of sepia ** Electronic s, Anchorage, Alaska 99519 CGM / TIFF LISx* " Brandon Tucker, �iRT r- e State of Alaska; DNR, Div. of Oil and Gas 1 Disk * / �� �� 550 W. 7th Ave, Suite 800 Electronic 1:' Anchorage, Alaska 99501 -3510 LIS :. , s x �. �; DS Engineer / Rig Foreman TOTAL x. _. x... Hardcop Prints 4 t. Page 1 of 4 • • • C $ R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 3 2010 WELL COMPLETION OR RECOMPLETION REPORALANDELOGLammission la. Well Status: Oil is Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: f #e 4 , ;p6. 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 12. Permit to Drill Number. 5. Date Comp., Susp., ConocoPhillips Alaska, Inc. orAband.: August 5, 2010 210 - 0760 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 July 22, 2010 50 029 - 21932 - 64 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM August 4, 2010 31 - 11AL2 Top of Productive Horizon: 8. KB (ft above MSL): 76' RKB 15. Field /Pool(s): 1326' FNL, 2234' FEL, Sec. 6, T12N, R9E, UM GL (ft above MSL): 40' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2631' FNL, 2358' FEL, Sec. 6, T12N, R9E, UM 9079' MD / 6210' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 507830 y 6007088 Zone 4 9279' MD / 6204' TVD ADL 25523, 25631 TPI: x - 506174 y - 6005613 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 506056 y 6004308 Zone 4 2212' MD / 2212' TVD 2559, 2564 18. Directional Survey: Yes Q 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) 1650' MD / 1650' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drilULateral Top Window MD/TVD GR/Res 7930' MD / 6203' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 116' Surf. 116' 24" 250 sx CS II 9.625" 36# J -55 Surf. 3383' Surf. 3383' 12.25" 330 sx Class G, 544 sx AS III, 175 sx AS L I 7" 26# J -55 Surf. 6408' Surf. 6141' 8.5" 250 sx Class G, 175 sx AS I 2.375" 4.7# L -80 6180' 9079' 6008' 6210' 3" slotted liner 24. Open to production or injection? Yes Q No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 6143' 6146' MD / 5977' TVD slotted liner: 6422' MD / 6230' TVD 6243' - 9077' MD 6066 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1 COMPLETION DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED . r g , d ' ; IA none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 11, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 8/28/2010 17.5 hours Test Period - -> 256 899 1123 104 Bean 3922 Flow Tubing Casing Pressure Calculated OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - API (corr) Press. 168 psi_ 1303 24 - Hour Rate - 315 1234 1481 24 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 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 RBDMS SEP 0 7101;) 7 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only // -3 ./0 // 0 G • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? 111 Yes El 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 1650' 1650' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk A3 7930' 6203' 3I- 11AL2PB1 Total Depth 8500' 6178' N/A Formation at total depth: Kuparuk A3 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263 - 4093 JQ.y 04 101 Printed N e V. Ca v Title: Alaska Wells Manager Signature 7 Phone 265 - 6306 Date 9// zq v Sharon Allsu P- 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 1 a: 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 12/2009 ° ,.. �KU 3 • I -11AL2 III .- ConocoPhi hips Well Attributes Max Angle & MD ' TD Alu4)K£ in, t , , - Wellbore APW WI (Feld Name Well Status Ind (°) MD (ftKB) Act Bt (ftKB) pN• sr. 500292193264 I KUPARUK RIVER UNIT PROD 9,090 .0 4CAac - ________ _ - _ Comment 625 (ppm) Dab Annotation End Date KB (ft) Rig Release Date ell Can6 3t - 1 a- 2.. 677rza10 9 57:13 AM SSSV: TRDP I 150 6/22/2009 Last WO: I 35 91 4/4/1989 Sd�etc AccWal � 'TAn odfion (Depth (a K6) End Date Annot tion Last Mod ... End Dale Last Tag Rev Reason: SIDETRACKS Imosbor 1 8/7/2010 HANGER, 31 !' tf?• Casing Strings Casing Description String 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrd ` � AL2 SLOTTED 2 3/8 1.995 6,180 0 9,079.0 4 43 L-80 STL - 1 Ms. LINER Liner Details Top Dap h 1 t ITVD) Top Incl I Nom'... ToD fe el (ftKB) ( °) Item Description Comment I ID (in) ' " - 6,180.0 DEPLOY SHORTY DEPLOYMENT SLEE , 1.995 CONDUCTOR, __ -_. - ___ _. _. .__.___ - - - __.- _ _L- 36 -116 Perforations & Slots Shot SAFETY VLV, Top (TVO) Btm (TVD) Dens 2,212 To• ftKB Btm ftKB) OMB) (ftKB) Zone Date (sh••• Type Comment t 6,243 9,078 A -5, A -4, A -2, 8/5/2010 32.0 SLOTS SLOTTED LINER - 0.125 "02.5" @ 4 lit A -1, A -2, A-3, circumferential adjacent rows, 3" ',_- A -1, A -2, A -3, centers staggered 18 deg, 3' GAS LIFT, 31 -11AL2 non - slotted ends 2,512 °` Notes: General & Safety a. End Date Annotation j - ,j;, r 8/6/2010 NOTE: VIEW MULTI - LATERAL SCHEMATIC w /Alaska Schemat'c9.0 I SURFACE, 35 -3,383 VW GAS LIFT, 3,702 ii GAS LIFT, 4,760 IV GAS LIFT, 5,668 I Ur It GAS LIFT, WI 6,074 illt NIPPLE, 6,123 - 4. SEAL ASSY, - 6,131 _ _ ._ PBR, 6,132 :., I SEAL ASSY, J 6,145 - PACKER, 6,148 NIPPLE, 6,156 WHIPSTOCK, 6,396 WINDOW A, 6,396 -6,406 PLUG, 6,406 CEMENT SOZ, 6,213 r... SEAL ASSY, 6,420 .,e. PACKER, ;_: PACKER, 6,422 SBE,6,425 -- 1 NIPPLE,6,433 - SOS,6,437 _ j .ee ser� Mandrel Details Mar ` Top Depth Top Wv Port PRODUCTION, - (TVD) Inc' OD Valve Latch Si.. TRO Run 33 -6.761 ..7 Stn Top (MO) (ftKB) ( Make Model (n) SON TYPe TYD. ('n) (Psi) Run Date Com... "' - 1 2,511.6 Camco MMG 1 1/2 GAS LIFT DMY R -20 0.000 0.0 6/18/2010 2 3,702.1 Camco MMG 1 1/2 GAS LIFT DMY R -20 0.000 0.0 2/19/2010 SLOTS, 6,243 3 4,760.5 Camco MMG 1 12 GAS LIFT DMY R - 20 0.000 0.0 6/19/2010 SLOTS, - 7,814 - 6,096 4 5,667.8 Camco MMG 1 12 GAS LIFT DMY R -20 0.000 0.0 6/21/2010 .k. '. 5 6,074.0 Camco MMG 112 GAS LIFT DMY RDO... 0.000 0.0 6/20/2010 SLOTS, 8,097 -9,490 AL2 SLOTTED LINER, -,.._ 6,180 -9,079 A LINER, 7,600 -9,490 TD(31- 11A1.2), \ - I 9,500 31 -11A, AL1, & AL2 CTD Sidetrack Schematic Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) Updated: 9 - Aug - 10 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface • IN KEY 3 1/2" Camco MMG gas lift mandrels (5) @ Equipment and perforations set in 2512', 3702', 4760', 5668', & 6074' parent wellbore ! Equipment set and lateral drilled 16" 62# H-40 shoe during first CTD project @ 116' MD X' landing nipple @ 6123' MD (2.813" min ID) Baker 3 -1/2" seal assembly 6131' - 6143' MD Equipment set and laterals drilled —.oda I li■- _ 80 -40 PBR at 6132' - 6145' during second CTD project 9 -5/8" 36# J -55 Baker KBH Anchor Seal Assy at 6145' MD shoe @ 3383' MD ■ Baker SAB 40 -32 packer @ 6146' MD III Liner landing nipple @ 6156' MD (2.813" min ID) Liner top @ 6180' MD - - -. 31 - 110 L2PB1 Holes shot in 3-1/2" straddle at - 6408' -6413' & 6213' MD (A3 sand) 31 -11A L2 Nmipstock @ 6396' Baker F1 permanent packer 6422' MD (e - line set) Kickoff from 31 -11 A @ 7423' (A3 sand) MD P P @ ( (Baker monobore . - } - 80 - Sealbore extension (6425' 6430') TD @ 8500' Kickoff from 31 t sleeve eB1 © 7930' whin` nrtr 10 - 75 Anchored billet @7930' Shorty deployment sleeve @ 6180' 'ID' landing nipple 0 6433' MD (2.750" min ID) Slotted liner r from 6243' o • 3 -1/2" straddle cemented in place TD @ 9279' kii:1 wG 6438' 0 438 MD Cast Iron Bridge Plug @ -6406' _ !i N. monobore 31-11A whipstock at 6422' n ' (A2 sand) �. p �-- --e - _. .....- . ........... ......... ..... ... Kickoff from 31 - 11 @ 6394.2' (Tows) .i •-• • . ...... ............ ,;; Anchored billet @ 7600' FISH: 3 - 1/2' Slotted liner from 7600 to 9490 whipstock @ unknown depth A sand perfs E 31 -11AL1 A3: 6437' - 6454' 31 -11 L1 (Al sand) A2: 6457' - 6486' G C - IGcL from 3I-11A 7597' Kickoff from om 31 1-11 11 0 6409' Liner top p billet t 7 @ 7423' Al: 6494' - 6503' Openhole from 6409' -7590' Slotted liner from 7423' to TD Shorty deployment sleeve 0 7590' TD 0 8071' Slotted liner from 7590' to TD TD @ 9437' • 7" 26# J -55 shoe @ 6761' MD Conoco Phillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 31 Pad 31 -11AL2 50- 029 - 21932 -64 Baker Hughes INTEQ BAKER e Definitive Survey Report HUGHES 11 August, 2010 ConocoPhillips MRS ConocoPh lli s BARER • Definitive Survey Report HUGHES Alaska Company: . ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Project :, .. Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well :, 31 - 11 North Reference: TRUE Weilbore::' 31 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 Project Kuparuk River Unit 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 Well 31 Well Position +141/-S 0.00 ft Northing: 6,007,088.16ft Latitude: 70° 25' 50.121 N +E/ - 0.00 ft Easting: 507,830.23ft Longitude: 149° 56 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft 1 Wellbore ' > 31 -11AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) ( °) (nT) BGGM2009 8/1/2010 17.04 79.85 57,390 Design, 31 -11AL2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,910.52 Vertical Section: Depth From (TVD) +N4S +E/4/V ' Direction (ft) (ft) (ft) r) ill 76.00 0.00 0.00 212.61 Survey Program Date 4 s :,' From To. Surre Survey (ft) (ft) , S (Well Tool Name Description Start Date End Date 100.00 6,300.00 31 -11 (31 -11) BOSS -GYRO Sperry-Sun BOSS gyro multishot 1/12/2001 6,394.00 7,405.30 31 -11A (31 -11A) MWD MWD - Standard 7/25/2010 7/28/2010 7,423.00 7,910.52 31- 11AL2PB1 (3I- 11AL2PB1) MWD MWD - Standard 8/1/2010 8/1/2010 7,931.00 9,230.29 31 -11AL2 (31- 11AL2) MWD MWD - Standard 8/3/2010 8/4/2010 8/11/2010 8 :57 :44AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips ledrAU ConocoPhillips B (l:R Definitive Survey Report HUGHES Alaska Company. ConocoPh Inc. Local Co- ordinate Reference: 31 - 11 project: Kuparuk River Unit 1VD Reference: = 31 -11 © 76.00ft (3I -11) Site: Kuparuk 3I Pad MD Reference: 31 -11 © 76.00ft (3I -11) Well 3I -11 North Reference: TRUE 11Vell oro 3I - 11 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 Survey Map MaP Vo klcal MD Inc AzI TVD TVDSS +N/'S +EJ-W Northing Easting , Section . Servey Tool Name Annotation O () (ft) (ft) (ft) (ft) (ft) (ft) t° ►190") . (ft) 7,910.52 94.33 191.10 6,204.23 6,128.23 - 1,454.64 - 1,654.18 6,005,631.93 506,177.74 20.17 2,116.83 MWD (3) TIP 7,931.00 95.89 187.58 6,202.41 6,126.41 - 1,474.76 - 1,657.49 6,005,611.81 506,174.45 18.74 2,135.56 MWD (4) KOP; Top of Billet 7,950.56 91.17 185.25 6,201.20 6,125.20 - 1,494.15 - 1,659.67 6,005,592.41 506,172.30 26.90 2,153.07 MWD (4) 7,980.52 90.52 180.59 6,200.76 6,124.76 - 1,524.06 - 1,661.19 6,005,562.51 506,170.80 15.70 2,179.09 MWD (4) 8,010.26 90.12 174.45 6,200.59 6,124.59 - 1,553.76 - 1,659.91 6,005,532.81 506,172.12 20.69 2,203.41 MWD (4) 8,040.24 91.66 171.41 6,200.13 6,124.13 - 1,583.50 - 1,656.22 6,005,503.08 506,175.84 11.37 2,226.48 MWD (4) 8,070.70 92.09 165.69 6,199.13 6,123.13 - 1,613.33 - 1,650.18 6,005,473.26 506,181.91 18.82 2,248.34 MWD (4) 8,100.33 91.75 162.48 6,198.14 6,122.14 - 1,641.80 - 1,642.06 6,005,444.80 506,190.06 10.89 2,267.95 MWD (4) 8,130.14 92.21 159.49 6,197.11 6,121.11 - 1,669.97 - 1,632.35 6,005,416.65 506,199.79 10.14 2,286.44 MWD (4) 8,160.33 91.66 153.65 6,196.09 6,120.09 - 1,697.64 - 1,620.36 6,005,388.99 506,211.81 19.42 2,303.29 MWD (4) 8,190.47 90.21 158.34 6,195.59 6,119.59 - 1,725.16 - 1,608.11 6,005,361.48 506,224.10 16.29 2,319.87 MWD (4) 8,210.32 90.43 157.69 6,195.48 6,119.48 - 1,743.57 - 1,600.67 6,005,343.09 506,231.55 3.46 2,331.36 MWD (4) 8,240.37 90.71 166.45 6,195.18 6,119.18 - 1,772.13 - 1,591.43 6,005,314.54 506,240.82 29.16 2,350.44 MWD (4) 8,270.47 94.49 170.00 6,193.82 6,117.82 - 1,801.56 - 1,585.30 6,005,285.12 506,246.98 17.22 2,371.92 MWD (4) 8,300.36 95.07 174.02 6,191.33 6,115.33 - 1,831.05 - 1,581.16 6,005,255.64 506,251.15 13.54 2,394.53 MWD (4) 8,330.71 96.30 179.59 6,188.32 6,112.32 - 1,861.19 - 1,579.47 6,005,225.50 506,252.87 18.71 2,419.01 MWD (4) 8,360.43 95.16 181.98 6,185.35 6,109.35 - 1,890.75 - 1,579.88 6,005,195.94 506,252.49 8.87 2,444.13 MWD (4) 8,390.42 93.68 184.98 6,183.04 6,107.04 - 1,920.59 - 1,581.69 6,005,166.10 506,250.71 11.13 2,470.25 MWD (4) 8,420.42 91.87 187.46 6,181.59 6,105.59 - 1,950.38 - 1,584.94 6,005,136.31 506,247.49 10.23 2,497.09 MWD (4) 8,450.31 92.15 191.91 6,180.54 6,104.54 - 1,979.82 - 1,589.97 6,005,106.87 506,242.50 14.91 2,524.59 MWD (4) 8,480.32 91.50 195.69 6,179.58 6,103.58 - 2,008.94 - 1,597.12 6,005,077.74 506,235.38 12.77 2,552.98 MWD (4) 8,510.56 92.49 199.40 6,178.53 6,102.53 - 2,037.75 - 1,606.23 6,005,048.93 506,226.30 12.69 2,582.16 MWD (4) 8,540.26 92.80 200.72 6,177.16 6,101.16 - 2,065.62 - 1,616.40 6,005,021.05 506,216.16 4.56 2,611.11 MWD (4) 8,570.25 91.54 196.25 6,176.02 6,100.02 - 2,094.03 - 1,625.90 6,004,992.63 506,206.69 15.48 2,640.17 MWD (4) 8,600.28 88.28 192.26 6,176.07 6,100.07 - 2,123.13 - 1,633.29 6,004,963.53 506,199.33 17.16 2,668.66 MWD (4) 8,630.40 85.30 189.50 6,177.76 6,101.76 - 2,152.66 - 1,638.97 6,004,934.00 506,193.68 13.47 2,696.59 MWD (4) 8,660.33 84.37 184.56 6,180.45 6,104.45 - 2,182.23 - 1,642.62 6,004,904.43 506,190.07 16.73 2,723.47 MWD (4) 8,690.33 84.15 186.88 6,183.45 6,107.45 - 2,211.93 - 1,645.59 6,004,874.73 506,187.12 7.73 2,750.09 MWD (4) 8,720.57 85.23 191.03 6,186.25 6,110.25 - 2,241.66 - 1,650.28 6,004,844.99 506,182.47 14.12 2,777.66 MWD (4) 8,750.30 85.73 195.72 6,188.60 6,112.60 - 2,270.49 - 1,657.13 6,004,816.16 506,175.64 15.82 2,805.64 MWD (4) 8/11/2010 8:57 :44AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips nau ConocoPhilll s BAKER Definitive Survey Report HUGHES Alaska company , ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Project: Kuparuk River Unit TVD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE Wei!bore: 31 -11 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 Survey Map Map Vertical ;r MD = Inc Azi ND . TVDSS +14/4 +E W Northing Easting D Section " Survevey Tool Name Aiihotolipo 8,783 87 85.54 201.02 6,191.15 6,115.15 - 2,302.25 -1,667.68 6,004,784.40 (1 (1100 5 ,83 4,784.40 506,165.13 15.75 2,838.07 MWD (4) 8,810.11 84.93 204.11 6,193.33 6,117.33 - 2,326.39 - 1,677.71 6,004,760.24 506,155.13 11.96 2,863.81 MWD (4) 8,840.09 84.22 202.01 6,196.17 6,120.17 - 2,353.85 - 1,689.40 6,004,732.77 506,143.47 7.36 2,893.24 MWD (4) 8,870.34 84.35 197.66 6,199.18 6,123.18 - 2,382.16 - 1,699.61 6,004,704.46 506,133.29 14.32 2,922.59 MWD (4) 8,899.95 84.53 194.19 6,202.05 6,126.05 - 2,410.49 - 1,707.70 6,004,676.12 506,125.23 11.68 2,950.81 MWD (4) 8,930.40 84.65 191.41 6,204.92 6,128.92 - 2,440.05 - 1,714.41 6,004,646.56 506,118.55 9.10 2,979.33 MWD (4) 8,960.07 86.16 184.00 6,207.30 6,131.30 - 2,469.34 - 1,718.37 6,004,617.27 506,114.62 25.41 3,006.13 MWD (4) 8,985.08 87.67 182.19 6,208.65 6,132.65 - 2,494.27 - 1,719.72 6,004,592.33 506,113.30 9.42 3,027.86 MWD (4) 9,020.14 88.31 175.70 6,209.88 6,133.88 - 2,529.28 - 1,719.08 6,004,557.33 506,113.98 18.59 3,057.01 MWD (4) 9,050.07 89.97 180.79 6,210.33 6,134.33 - 2,559.19 - 1,718.16 6,004,527.43 506,114.93 17.89 3,081.70 MWD (4) 9,080.20 92.00 183.99 6,209.81 6,133.81 - 2,589.28 - 1,719.42 6,004,497.34 506,113.70 12.58 3,107.73 MWD (4) 9,110.19 91.81 189.58 6,208.81 6,132.81 - 2,619.03 - 1,722.96 6,004,467.58 506,110.20 18.64 3,134.70 MWD (4) 9,140.27 90.89 192.29 6,208.10 6,132.10 - 2,648.55 - 1,728.66 6,004,438.06 506,104.52 9.51 3,162.64 MWD (4) 9,170.38 91.60 196.01 6,207.45 6,131.45 - 2,677.74 - 1,736.02 6,004,408.87 506,097.20 12.57 3,191.19 MWD (4) 9,200.29 91.44 200.47 6,206.66 6,130.66 - 2,706.13 - 1,745.37 6,004,380.47 506,087.87 14.92 3,220.14 MWD (4) 9,230.29 92.36 204.93 6,205.66 6,129.66 - 2,733.78 - 1,756.94 6,004,352.81 506,076.33 15.17 3,249.67 MWD (4) 9,279.00 92.36 204.93 6,203.66 6,127.66 - 2,777.92 - 1,777.45 6,004,308.66 506,055.87 0.00 3,297.90 PROJECTED to TD 8/11/2010 8:57:44AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. • Kuparuk River Unit Kuparuk 31 Pad 31- 11AL2PB1 50- 029 - 21932 -70 Baker Hughes INTEQ Mk. • BAKER Definitive Survey Report HUGHES 17 August, 2010 ConocoPhillips Conoc P 1111ps Definitive Survey Report HUGHES ' Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Protect: Kuparuk River Unit TVD Reference: 31 - 11 @ 76.00ft (31 - 11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 - 11) Well: 31 - 11 North Reference: TRUE Wel!bore: 31 -11 Survey Calculation Method: Minimum Curvature ,Design:: r 31 -11 Database: EDM Alaska Prod v16 Protect Kuparuk River Unit 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 ylell 31 11 • Well Position +NI-S 0.00 ft Northing: 6,007,088.16ft Latitude: 70 25' 50.121 N +E / - 0.00 ft Easting: 507,830.23ft Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Welibore 31- 11AL2PB1 Magnetics Model Name Sample Date Declination Dip Angle. Field Sh ( °) (°) (). t ` BGGM2009 7/15/2010 17.05 79.85 57,388 Design„ 31- 11AL2PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,405.30 Vertical Section: Depth From (TVD) +N /-S +E/-W : Direction x (ft) (ft) (ft) ( 76.00 0.00 0.00 216.49 Survey Program Date From To Survey S rvey (ft) (ft) Survey (Wellbore) Tool Name Description Start,Date End Da 100.00 6,300.00 31 -11 (31 -11) BOSS -GYRO Sperry-Sun BOSS gyro multishot 1/12/2001 6,394.00 7,405.30 31 -11A (31 -11A) MWD MWD - Standard 7/25/2010 7/28/2010 7,423.00 8,450.61 31- 11AL2PB1 (31- 11AL2PB1) MWD MWD - Standard 8/1/2010 8/1/2010 8/17/2010 11 :15.14AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips g Cc nocoPh1IIl 5 Definitive Survey Report HU E; Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference; 31 -11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 © 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE Wellbore;', 31 -11 Survey Calculation Method: Minimum Curvature DeSIgn .'�, ; 31 -11 Database: EDM Alaska Prod v16 Survey Map Map'! VerUcal MD Inc Azi TVD ` TVDSS +NI$ +E/-W Northing Easting DLS Section survey Tool Name Annotation (ft) t °j ( °) (ftj (ft) lftj (n) (n) (ft)' t ° «oo (ft) 7,405.30 92.15 251.77 6,231.59 6,-(17109.26 ) 55.59 1,109.26 - 1,316.47 6,005,977.63 506,515.06 19.50 1,674.65 MWD (2) TIP • 7,423.00 91.74 249.08 6,230.98 6,154.98 - 1,115.19 - 1,333.13 6,005,971.69 506,498.40 15.36 1,689.33 MWD (3) KOP; Top of Billet 7,460.46 97.91 244.69 6,227.83 6,151.83 - 1,129.83 - 1,367.44 6,005,957.01 506,464.11 20.19 1,721.50 MWD (3) 7,490.47 101.65 241.09 6,222.74 6,146.74 - 1,143.29 - 1,393.76 6,005,943.52 506,437.81 17.18 1,747.97 MWD (3) 7,520.55 102.03 237.06 6,216.56 6,140.56 - 1,158.42 - 1,419.01 6,005,928.37 506,412.58 13.17 1,775.15 MWD (3) 7,550.40 101.18 231.66 6,210.55 6,134.55 - 1,175.45 - 1,442.76 6,005,911.31 506,388.85 17.95 1,802.97 MWD (3) 7,580.05 97.73 229.96 6,205.68 6,129.68 - 1,193.93 - 1,465.43 6,005,892.82 506,366.20 12.91 1,831.30 MWD (3) 7,610.12 94.02 229.38 6,202.60 6,126.60 - 1,213.28 - 1,488.23 6,005,873.44 506,343.42 12.50 1,860.42 MWD (3) 7,640.09 89.94 229.01 6,201.57 6,125.57 - 1,232.85 - 1,510.90 6,005,853.85 506,320.78 13.67 1,889.63 MWD (3) 7,670.87 85.72 228.96 6,202.73 6,126.73 - 1,253.03 - 1,534.10 6,005,833.65 506,297.60 13.71 1,919.65 MWD (3) 7,700.48 86.19 226.01 6,204.82 6,128.82 - 1,272.99 - 1,555.87 6,005,813.67 506,275.86 10.06 1,948.64 MWD (3) 7,730.86 89.72 221.91 6,205.91 6,129.91 - 1,294.83 - 1,576.93 6,005,791.80 506,254.81 17.80 1,978.73 MWD (3) 7,760.49 89.45 216.65 6,206.12 6,130.12 - 1,317.76 - 1,595.69 6,005,768.86 506,236.09 17.78 2,008.32 MWD (3) 7,790.69 90.12 210.33 6,206.24 6,130.24 - 1,342.93 - 1,612.34 6,005,743.67 506,219.46 21.04 2,038.46 MWD (3) 7,820.94 89.97 204.41 6,206.21 6,130.21 - 1,369.78 - 1,626.24 6,005,716.81 506,205.59 19.58 2,068.31 MWD (3) 7,850.66 90.71 200.83 6,206.04 6,130.04 - 1,397.21 - 1,637.67 6,005,689.37 506,194.19 12.30 2,097.16 MWD (3) 7,880.33 90.92 196.15 6,205.61 6,129.61 - 1,425.34 - 1,647.08 6,005,661.23 506,184.81 15.79 2,125.37 MWD (3) 7,910.52 94.33 191.10 6,204.23 6,128.23 - 1,454.64 - 1,654.18 6,005,631.93 506,177.74 20.17 2,153.15 MWD (3) 7,940.54 96.61 185.94 6,201.37 6,125.37 - 1,484.18 - 1,658.61 6,005,602.39 506,173.35 18.72 2,179.53 MWD (3) 7,970.51 93.87 181.66 6,198.63 6,122.63 - 1,513.95 - 1,660.58 6,005,572.62 506,171.40 16.91 2,204.64 MWD (3) 8,000.60 93.04 176.50 6,196.81 6,120.81 - 1,543.97 - 1,660.10 6,005,542.61 506,171.92 17.34 2,228.49 MWD (3) 8,030.45 93.57 170.54 6,195.09 6,119.09 - 1,573.56 - 1,656.74 6,005,513.02 506,175.31 20.01 2,250.29 MWD (3) 8,060.60 92.76 165.63 6,193.43 6,117.43 - 1,603.01 - 1,650.52 6,005,483.58 506,181.55 16.48 2,270.27 MWD (3) 8,090.52 92.30 160.74 6,192.10 6,116.10 - 1,631.61 - 1,641.88 6,005,454.99 506,190.23 16.40 2,288.12 MWD (3) 8,120.49 90.95 155.15 6,191.25 6,115.25 - 1,659.37 - 1,630.63 6,005,427.25 506,201.50 19.18 2,303.75 MWD (3) 8,150.54 91.75 150.80 6,190.55 6,114.55 - 1,686.12 - 1,616.99 6,005,400.51 506,215.17 14.71 2,317.15 MWD (3) 8,180.73 94.12 148.13 6,189.00 6,113.00 - 1,712.09 - 1,601.67 6,005,374.56 506,230.51 11.82 2,328.92 MWD (3) 8,210.62 92.76 141.81 6,187.20 6,111.20 - 1,736.51 - 1,584.55 6,005,350.17 506,247.66 21.59 2,338.37 MWD (3) 8,245.31 92.12 144.70 6,185.73 6,109.73 - 1,764.27 - 1,563.82 6,005,322.42 506,268.42 8.53 2,348.37 MWD (3) 8,270.56 92.43 149.29 6,184.72 6,108.72 - 1,785.43 - 1,550.08 6,005,301.29 506,282.18 18.21 2,357.21 MWD (3) 8/17/2010 11:15:14AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Mkt Co ocoPhillips Definitive Survey Report HUGHES Alaska sr ompany: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Project: " Kuparuk River Unit TVD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE Welibore: 31 -11 Survey Calculation Method: Minimum Curvature design: 31 -11 Database: EDM Alaska Prod v16 v . Surrey . M ap Map -- Vertical MD Inc Azi TVD TV DSS +NLS 41"1-/V Noting DLS Section Eason S urve y tool °Name Ann4t o s( (ft) ' ( °)_ ( °) (ft) (ft) 9 ( °f 100') (ft) _•.. , 8,300.35 94.21 154.18 6,183.00 6,107.00 - 1,811.61 - 1,536.00 6,005,275.12 506,296.28 17.44 2,369.89 MWD (3) 8,330.48 94.11 158.16 6,180.81 6,104.81 - 1,839.09 - 1,523.86 6,005,247.65 506,308.45 13.18 2,384.77 MWD (3) 8,360.46 93.90 162.28 6,178.72 6,102.72 - 1,867.23 - 1,513.75 6,005,219.53 506,318.59 13.73 2,401.37 MWD (3) 8,390.40 94.30 166.43 6,176.58 6,100.58 - 1,895.98 - 1,505.69 6,005,190.79 506,326.68 13.89 2,419.70 MWD (3) 8,420.26 90.77 166.79 6,175.26 6,099.26 - 1,925.00 - 1,498.79 6,005,161.78 506,333.61 11.88 2,438.92 MWD (3) 8,450.61 87.30 167.31 6,175.77 6,099.77 - 1,954.57 - 1,491.99 6,005,132.22 506,340.44 11.56 2,458.65 MWD (3) 8,500.00 87.30 167.31 6,178.09 6,102.09 - 2,002.70 - 1,481.15 6,005,084.11 506,351.33 0.00 2,490.90 PROJECTED to TD 6 COMPASS 2003.16 Build 69 8117/2010 11:15:14AM Page 4 • 31 -11 Well Events Summary DATE SUMMARY 6/11/10 LOG GR /CCUPRESS/TEMP FOR PRE SIDETRACK REFERENCE LOG. LOGGED BHPS: 6400'= 3962 PSI, 156 DEGF & 6300'= 3927 PSI, 152 DEGF. 6/14/10 DRIFT TBG W/ 2.78" DMY PLUG (OAL = 46 ") TO 6170' RKB. PULLED GLV @ 5668' RKB, LOST TOOL STRING © —5200' SLM. TAG FISH W/ 2.74" LIB @ 5607' SLM (CLEAN ROPE SOCKET W/ WIRE PRESENT) FISH IN GLM @ 5668' RKB. FISH IN HOLE= 37.5' OAL & —30' OF .108 WIRE. IN PROGRESS. 6/15/10 ATTEMPTED PULL 37.5' TOOLSTRING FROM 5607' SLM. PUMPED 11 BBL DSL, T & IA TRACKED TO 2500 PSI; APPARENT SAND BRIDGE IN TBG. MOVED FISH UPHOLE 28' TO 5579' SLM. IN PROGRESS. 6/16/10 RECOVERED —30' WIRE & TOOLSTRING LOST 6/14/2010. 1.5" GLV PULLED 6/14/2010 MISSING IN WELL. IN PROGRESS. 6/17/10 RECOVERED GLV LOST 6/14/10. BAILED THROUGH SAND BRIDGES @ 6095' & 6122' SLM. TAGGED WITH 2.79" GAUGE @ 6391' SLM. BRUSHED X NIPPLE @ 6123' RKB & SET 2.813" XX PLUG @ SAME. IN PROGRESS. 6/18/10 SET CATCHER ON XX PLUG @ 6123' RKB: PULLED GLVs @ 4760', 3702' & 2511' RKB. SET DVs @ 5667', 4760', 3702' & 2511' RKB. BLED IA TO VERIFY VALVES ARE SET; TBG TRACKING IA. PULLED OV @ 6074' RKB, CHECK OK. IN PROGRESS. 6/19/10 VERIFIED DVs SET WITH HOLEFINDER. CIRCULATED 50 BBL DSL TO LOAD WELL. SET DV @ 6074' RKB. TESTED TBG 2000 PSI, PASSED. DRAW DOWN TEST ON IA, PASSED. MITIA 2500 PSI, PASSED. PULLED CATCHER SUB. IN PROGRESS. 6/20/10 PULLED 2.81" XX PLUG @ 6123' RKB. DRIFTED & TAGGED @ 6395' SLM, EST. 6418' RKB, WITH 2.63" CENT, BLB & 2.77" LIB (OAL =55 "). LIB INDICATES FILL. CLOSURE TESTED TRMAXX -5E SSSV, GOOD. READY FOR E /L. 6/22/10 SET BAKER 3.5" CIBP. TOP OF CIBP SET AT A DEPTH OF 6405.85'. BOTTOM OF CIBP SET AT A DEPTH OF 6407'. CCL TO BOTTOM OF CIBP MEASURED 14.96'. CCL STOP DEPTH RECORDED AT 6392'. 6/28/10 PERFORM POS/ NEG TESTS ON CIBP. DRIFTED TBG WITH DUMMY WHIPSTOCK (2.65" x 18.3') TO TOP OF CIBP @ 6406' RKB. COMPLETE. 7/7/10 T -POT (PASSED), T -PPPOT (PASSED), IC -POT (PASSED), IC -PPPOT (PASSED), MITOA (PASSED), PT & DD TEST ON SV (PASSED), MV (PASSED), SSV (PASSED) 8/9/10 GAUGED TBG WITH 2.80" GAUGERING TO 6180' RKB. PERFORMED 30 MIN SBHPS @ 6180' RKB = 3861 PSI, 143 DEG F. 20 MIN GRADIENT STOP @ 6060' = 3798 PSI.SET CATCHER SUB ON LINER TOP @ 6180' RKB.REPLACED 1.5" DV WITH 1/4" ORFICE @ 6074' RKB.PULLED 1.5" DV @ 5667' RKB.IN PROGRESS 8/10/10 SET GLV @ 5667' RKB. REPLACED DVs WITH GLVs @ 4760', 3702', AND 2511' RKB. DRAWDOWN IA, GOOD. PULLED CATCHER FROM LINER TOP. READY FOR FLOWBACK OPERATIONS. • Time Logs..: Date From, To Dur S. Depth E. Depth Phase Code Subcode T ,Comment 13:42 15:42 2.00 7,910 8,060 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3600 CTP, 1 -2K WOB, 4 -5K CTW, 300 WHP, 4288 BHP, 100 FPH 15:42 17:18 1.60 8,060 6,440 PROD2 DRILL WPRT P TD lateral perform wiper trip chasing low /high sweep to window, 20K 17:18 17:30 0.20 6,440 6,440 PROD2 DRILL DLOG P Tie in depth to RA marker, +2' 17:30 18:42 1.20 6,440 8,071 PROD2 DRILL WPRT P RIH 18:42 19:42 1.00 8,071 6,600 PROD2 DRILL DISP P Lay in liner running pill 19:42 21:00 1.30 6,600 0 PROD2 DRILL TRIP P POOH laying in KWF. Paint flag at 5600 EOP 21:00 21:12 0.20 0 0 PROD2 DRILL SFTY P PJSM for laying down drilling BHA 21:12 21:48 0.60 0 0 PROD2 DRILL PULD P Lay down drilling BHA 21:48 22:48 1.00 0 0 COMPZ CASING PUTB P Rig up floor for liner running 22:48 00:00 1.20 0 0 COMPZ CASING PUTB P Run 20 joints slotted liner 07/31/2010 Ran liner to td at 8071' and left liner top billet at 7423'. Milled off billet and drilled AL2 lateral to 7775'. Mud swap after milling off billet 00:00 01:12 1.20 0 693 COMPZ CASING PUTB P Continue PU liner and make up Inteq tools. 01:12 02:36 1.40 693 6,292 COMPZ CASING RUNL P RIH 02:36 03:18 0.70 6,292 8,071 COMPZ CASING RUNL P Correct at flag, +2.5'. Weight check 18K PUW, 13K RIW. Continue RIH 03:18 05:33 2.25 8,071 0 COMPZ CASING RUNL P Tag at 8071', pump 1.2 BPM and release liner. POOH pumping down backside. At window line up pump down CT and continue POOH 05:33 06:30 0.95 0 0 COMPZ CASING PULD P At surface, PJSM. LD BHA 13, PU BHA 14 06:30 07:33 1.05 0 0 PROD3 STK PULD P PU BHA # 14 07:33 08:48 1.25 0 6,250 PROD3 STK TRIP P RIH 08:48 09:03 0.25 6,250 6,250 PROD3 STK DLOG P Tie in depth, +3'. Closed EDC, 09:03 11:33 2.50 6,250 6,600 PROD3 STK DISP P RIH to 6600' displacing KWF out of well 11:33 14:03 2.50 7,423 7,436 PROD3 STK MILL P Start ST Bring pumps on -line 1.30 bpm, 3546psi, BHP 4266, ECD 13.2, WOB .7K, CT weight 7K. 1 FPH for 1 ' 2 FPH for 1' 3 FPH for 1' 10 FPH for 5' 14:03 14:18 0.25 7,436 7,436 PROD3 STK MILL P Perform dry drift through ST, Good. 14:18 15:48 1.50 7,436 7,580 PROD3 DRILL DRLG P Drill Ahead 1.3BPM, 3600 CTP, 4285 BHP, 1.5 -2K WOB, 300 WHP, 4 -5K CTW Start mud swap 15:48 17:30 1.70 7,580 7,580 PROD3 DRILL WPRT P Wiper trip to window 16K PUW 17:30 21:12 3.70 7,580 7,730 PROD3 DRILL DRLG P Drilling ahead, 3300 CTP, 420 WHP, 4270 BHP 21:12 22:00 0.80 7,730 6,670 PROD3 DRILL WPRT P Wiper to window, 18K PUW Page 10 of 15 • Time,;Logs . Date' From To Dur, S. Depth E. Depth Phase Code Subcode ° . T Comment 22:00 22:54 0.90 6,670 6,430 PROD3 DRILL DLOG P Mad pass build section to verify gamma tool readings. Found that a correction had been put in for the higher potasium. When this correction is removed the logs are correct. 22:54 23:30 0.60 6,430 7,730 PROD3 DRILL WPRT P Wiper trip inhole 23:30 00:00 0.50 7,730 7,775 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 08/01/2010 Drill AL2 lateral to 8500', POOH for sidetrack. 00:00 00:54 0.90 7,775 7,880 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 00:54 02:00 1.10 7,880 6,420 PROD3 DRILL WPRT P Wiper to window, 19K PUW 02:00 02:12 0.20 6,420 6,440 PROD3 DRILL DLOG P Tie in, +2' 02:12 03:00 0.80 6,440 7,880 PROD3 DRILL WPRT P Wiper back in hole, 11K RIW 03:00 04:42 1.70 7,880 8,030 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 04:42 06:57 2.25 8,030 8,030 PROD3 DRILL WPRT P Wiper to window, 18K PUW 06:57 08:27 1.50 8,030 8,180 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 08:27 10:27 2.00 8,180 8,180 PROD3 DRILL WPRT P Wiper to window, 18K PUW 10:27 12:12 1.75 8,180 8,330 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 12:12 14:27 2.25 8,330 8,330 PROD3 DRILL WPRT P Wiper to window, 18K PUW, Tie in depth to RA marker +1'. 14:27 16:57 2.50 8,330 8,500 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3850 CTP, 200 WHP, 4280 BHP, 4K RIW, neg 1 - neg 3K WOB, 200 - 400 PSI motor work. 60 -80 FPH ROP. 16:57 20:12 3.25 8,500 0 PROD3 DRILL TRIP T POOH for sidetrack, drilled into A4 /A5 20:12 21:42 1.50 0 0 PROD3 DRILL PULD T Lay down drilling BHA 21:42 23:48 2.10 0 0 PROD3 STK PULD T MU anchored billet BHA j3j_ 23:48 00:00 0.20 0 200 PROD3 STK TRIP T RIH 08/02/2010 Set anchored billet at 7930', test BOP, mill off billet and drill AL2 00:00 01:12 1.20 200 6,260 PROD3 STK TRIP T Continue RIH with anchored billet 01:12 01:24 0.20 6,260 6,290 PROD3 STK DLOG T Tie into formation, +3' 3I _/(AL- Z 01:24 02:12 0.80 6,290 7,941 PROD3 STK TRIP T Continue to RIH, 11K RIW, window was clean Page 11 of 15 • • Time Logs Date , . From To ..._Dur S. Depth E. Depth; Phase Code ? Subcode T Comment ,. . 02:12 02:24 0.20 7,941 7,930 PROD3 STK WPST T Set anchored billet at 7930 top of billet, 7941.23 bit depth. 02:24 04:48 2.40 7,930 0 PROD3 STK SVRG T POOH, clean through window 04:48 05:48 1.00 0 0 PROD3 STK PULD T Undeploy BHA 05:48 06:18 0.50 0 0 PROD3 STK SFTY T Crew change, PJSM 06:18 07:03 0.75 0 0 PROD3 STK PULD T Continue Undeployment/LD BHA 07:03 07:48 0.75 0 0 PROD3 WHDBO BOPE P Remove check valves, flush lines on rig and stack 07:48 08:48 1.00 0 0 PROD3 WHDBO SVRG P Grease tree 08:48 09:03 0.25 0 0 PROD3 SURFECSVRG P PJSM 09:03 16:33 7.50 0 0 PROD3 WHDBO BOPE P Start BOP testing 16:33 17:30 0.95 0 0 PROD3 WHDBO CIRC P BOP testing complete, displace CT back to Flo -Pro 17:30 18:00 0.50 0 0 PROD3 WHDBO SVRG P Install check valves 18:00 20:30 2.50 0 0 PROD3 STK PULD T Deploy BHA 20:30 21:48 1.30 0 6,260 PROD3 STK TRIP T RIH 21:48 22:00 0.20 6,260 6,290 PROD3 STK DLOG T Tie in, +3,. close EDC 22:00 22:42 0.70 6,290 7,931 PROD3 STK TRIP T Continue RIH, Clean through window and down to tag at 7931', 20K PUW, 7K RIW 22:42 00:00 1.30 7,931 7,932 PROD3 STK KOST T Start time milling off billlet at 1 FPH. 1.4 BPM, 3640 CTP, 4280 BHP, 200 WHP. Increase to 2 FPH after a foot 08/03/2010 Complete drill by billit @ 7931, Swap Mud, Drill Ahead to 8830' 00:00 01:00 1.00 7,932 7,934 PROD3 STK KOST T Continue time milling, 1.4 BPM, 3640 CTP, 4280 BHP, 200 WHP. 2 FPH, increase to 3 FPH for one foot. 01:00 01:30 0.50 7,934 7,965 PROD3 DRILL DRLG T Continue drilling ahead at 15 FPH for 2' then drill ahead. 1.4 BPM, 3640 CTP, 4300 BHP, 200 WHP 01:30 03:00 1.50 7,965 8,080 PROD3 DRILL DRLG T Drift past billet clean, continue drilling. 1.4 BPM, 3640 CTP, 4290 BHP, 200 WHP 03:00 05:15 2.25 8,080 8,080 PROD3 DRILL WPRT T Wiper to window, 18K PUW 05:15 07:00 1.75 8,080 8,240 PROD3 DRILL DRLG T Continue drilling ahead 1.4 BPM, 3640 CTP, 4300 BHP, 200 WHP 07:00 09:00 2.00 8,240 8,240 PROD3 DRILL WPRT T Wiper trip to window 09:00 10:36 1.60 8,240 8,381 PROD3 DRILL DRLG T Continue drilling ahead 1.4 BPM, 3640 CTP, 4300 BHP, 200 WHP 10:36 11:54 1.30 8,381 6,420 PROD3 DRILL WPRT T Wiper to window, 18K PUW _ 11:54 12:06 0.20 6,420 6,460 PROD3 DRILL DLOG T Tie in to RA, +4' correction 12:06 13:00 0.90 6,460 8,383 PROD3 DRILL WPRT T Wiper back in hole, 10K RIW 9 13:00 14:00 1.00 8,383 8,500 PROD3 DRILL DRLG T Continue drilling ahead 1.4 BPM, 3640 CTP, 4310 BHP, 200 WHP. Start new mud down coil Page 12 of 15 • • Time Logs.,: -:; Y ., Date .. . From To . Dur S. Depth E Depth Phase ' Code Subcode T. Comment 14:00 14:30 0.50 8,500 8,530 PROD3 DRILL DRLG P Back on planned time. Continue drilling ahead 1.4 BPM, 3550 CTP, 4310 BHP, 380 WHP 14:30 17:15 2.75 8,530 8,530 PROD3 DRILL WPRT P Wiper to window, 16K PUW 17:15 18:45 1.50 8,530 8,680 PROD3 DRILL DRLG P 8530', Drill ahead 1.4 BPM @ 3400PSI FS BHP =4329 DHWOB =1.8K, RIW = -2K 18:45 20:30 1.75 8,680 8,680 PROD3 DRILL WPRT P Wiper to window 17K PUW 20:30 23:30 3.00 8,680 8,830 PROD3 DRILL DRLG P 8680' Drill Ahead 1.41 BPM @ 3534PSI FS BHP =4220 DHWOB =2.2K RIW = -2K 23:30 00:00 0.50 8,830 8,330 PROD3 DRILL WPRT P Wiper to window with Tie In Midnight Depth 8830 08/04/2010 TD AL2 Lat @ 9279, Condition hole, Lay in Beaded Liner Pill POOH 00:00 01:30 1.50 8,330 6,415 PROD3 DRILL WPRT P On wiper trip with Tie in slight overpull @ 8707 with little motor work 01:30 01:36 0.10 6,415 6,440 PROD3 DRILL DLOG P Log RA marker, +2' correction 01:36 02:54 1.30 6,440 8,830 PROD3 DRILL WPRT P Wiper trip back to bottom. Clean trip with no setdowns saw nothing @ 8707 02:54 06:00 3.10 8,830 8,981 PROD3 DRILL DRLG P 8830' Drill Ahead 1.4 BPM @ 3537PSI FS BHP =4325 06:00 09:00 3.00 8,981 8,981 PROD3 DRILL WPRT P Wiper trip, 18K PUW, pulled 23K at 8886' with now motor work, clean trip uphole. 11K RIW with a steady decrease during trip inhole. Stacked out to -10K at 8860' to 8880', clean PU at 17K. dropped pump rate to .9 BPM and RIH clean. 09:00 12:12 3.20 8,981 9,130 PROD3 DRILL DRLG P Continue drilling, 1.3 BPM, 3600 CTP, 4340 BHP, 300 WHP. 12:12 15:24 3.20 9,130 9,130 PROD3 DRILL WPRT P Wiper trip to window, 17K PUW. Some weight stacking at 8980', dropped pump rate to 1 BPM and continued w /out picking up 15:24 17:54 2.50 9,130 9,279 PROD3 DRILL DRLG P Continue drilling, 1.3 BPM, 3650 CTP, 4380 BHP, 300 WHP. -4K Surface weight while drilling with 1 - 3K WOB TD Well @ 9279 17:54 20:48 2.90 9,279 6,415 PROD3 DRILL WPRT P Pump to -hi sweeps, chase to window for RA tie in 20:48 20:57 0.15 6,415 6,437 PROD3 DRILL DLOG P Log RA marker, +2' correction 20:57 22:57 2.00 6,437 9,279 PROD3 DRILL WPRT P Wipe to bottom to lay in beaded liner running pill Stacking out @8860 with full pump rate to 9010. Back ream 180 degrees out of as drilled 22:57 23:39 0.70 9,279 9,279 PROD3 DRILL REAM P Back ream shales up to 9000, Start Beaded pill PUW =18K RIW -6K Page 13 of 15 • . TimeLogs.: Date From ' To ~ Dui • -, S. Depth E. Depth Phase Code Subcode T Comment 23:39 00:00 0.35 9,279 8,703 PROD3 DRILL TRIP P Trip out of well laying in beaded liner pill / spacer / KWF 08/05/2010 M/U and Run AL2 Liner, Correct to flag -1 ", set liner, PUH tie into formation, TOL =6180, BOL =9079 00:00 02:30 2.50 8,703 0 PROD3 DRILL TRIP P Continue out of well. Overpull at window. Orientation was correct as we entered window area but rolled 45 left as we attempted to run throughl0 FPM @ Min Rate, RBIH oriented to 10R came through @ 18FPM clean pass through. Paint EOP Flags @ 6200 and 3400' 02:30 03:45 1.25 0 0 PROD3 DRILL PULD P At Surface, PJSM, Flow check well, Lay down BHA #16 Prep floor for liner pick up 03:45 04:00 0.25 0 0 COMPZ CASING SFTY P PJSM, Pick Up Liner 04:00 09:48 5.80 0 2,943 COMPZ CASING PUTB P PU liner string 09:48 10:42 0.90 2,943 6,343 COMPZ CASING RUNL P RIH with liner 10:42 17:24 6.70 6,343 8,977 COMPZ CASING RUNL P Corrected depth -1 © EOP flag. wt ck 19k. continue RIH, 12.5k RIW. Started stacking weight at 7979', progressivly worse on the way in until only getting about 1 foot per pick up. 17:24 18:24 1.00 8,977 8,977 COMPZ CASING CIRC P Circulate in KWF with 1% safe -lube at 1 BPM at 3900 psi 18:24 21:54 3.50 8,977 9,079 COMPZ CASING RUNL P Continue to work liner 21:54 22:09 0.25 9,079 9,079 COMPZ CASING CIRC P Circulate lube pill around coil 22:09 23:18 1.15 9,079 9,081 COMPZ CASING RUNL P Work liner, unable to gain any ground, Confer with town set liner here TOL below nipple @ 6156 23:18 23:24 0.10 9,081 8,978 COMPZ CASING RUNL P Release from Liner 1.1 BPM @ 4495 PUW =20K Pull up hole to tie into formation 23:24 23:36 0.20 8,978 6,176 COMPZ CASING DLOG P Log into formation for -2' correction Remove liner lengh left in well BOL =9079 TOL =6180 23:36 00:00 0.40 6,176 6,170 COMPZ CASING CIRC P Pump high vis spacer followed by seawater 08/06/2010 Swap well to seawater, Freeze protect from 2000', Set BPV, RDMO 00:00 01:45 1.75 6,170 6,170 COMPZ CASING CIRC P Swapping well to seawater / recover KWF 01:45 03:21 1.60 6,170 0 COMPZ CASING FRZP T POOH, Pump 25 BBIs Diesel freeze protect on way out @ 2000' 03:21 05:06 1.75 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA# 17 05:06 07:18 2.20 0 0 DEMOB WHDBO NUND T Set BPV, cut orings on firsst attempt, SSV was slightly closed, good set on second attempt 07:18 10:18 3.00 0 0 DEMOB WHDBO CTOP T Blow down CT 10:18 13:18 3.00 0 0 DEMOB WHDBO CTOP T R/U and pull CT back to reel and secure. Page 14 of 15 • • Time Logs Date From To Der S. Depth E. Depth Phases : Code Subcode ...T - Comment '. 08/06/2010 24 hr Summary Swap well to seawater, Freeze protect from 2000', Set BPV, RDMO 13:18 16:00 2.70 0 0 DEMOB WHDBO NUND T PJSM, Rig down MP line, Rig up top drive to lifting cap Vac Mouse Holes, Nipple down stack. Nipple up tree cap flange and PT to 4K * *** * * ** RIG RELEASE @ 16:00** ******* Page 15 of 15 . S [1[F SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3I -11AL2 ConocoPhillips Alaska, Inc. Permit No: 210 -076 Surface Location: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM Bottomhole Location: 2568' FSL, 2367' FWL, Sec. 6, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to drill the above referenced development wellbore. The permit is for a new wellbore segment of existing well KRU 3I -11A, Permit No 210- 074, API 50- 029 - 21932 -01. 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. 'ncerely, Daniel T. Seamount, Jr. Chair DATED this day of June, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/ o end. (via e-mail) • i RECEIVED STATE OF ALASKA N 1 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage la. Type of Work: to lb. Proposed Well Class: Development - Oil 0 , Service - Winj ❑ Single Zone EI . 1 c. Specify if well is proposed for: Drill g�/J/� , 1 Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry 1 Exploratory ❑ Service - WAG ❑ Service - Disp ❑ 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 ° 3I - 11AL2 4 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9180', ND: 6140' . Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM ADL 25523, 25631 , Kuparuk River Oil Pool' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: r I ; 1090' FNL, 1826' FEL, Sec. 6, T12N, R9E, UM 2559, 2564 7/1120T0` Ti Total Depth: 9. Acres in Property: 14. Distance to 2568' FSL, 2367' FWL, Sec. 6, T12N, R9E, UM 2560 Nearest Property: 18560 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: . 76 feet 15. Distance to Nearest Well Open Surface: x - 507830 • y - 6007088 • Zone 4 GL Elevation above MSL: ' 16.5 feet to Same Pool: 31 -13 , 1450 . 16. Deviated wells: Kickoff depth: 7360. ft. 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 100° deg Downhole: 4452 psig • Surface: 3800 psig - 18. Casing Procram: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2.375" 4.7# L - 80 ST - L 2880' 6300' 6042' 9180' 6140' solid / slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) 6772' 6560' 6680' 6473' 6422' Casing Length Size Cement Volume MD TVD Conductor/Structural 116' 16" 250 sx CS II 116' 116' Surface 3348' 9.625" 330 sx Class G, 3383' 3383' Intermediate 544 sx AS III, 175 sx AS I Production 6728' 7" 250 sx Class G, 175 sx AS I 6761' 6550' Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 6437'- 6454', 6457- 6486', 6494' -6503' 6245- 6261', 6264'- 6291', 6298' -6306' 20. Attachments: Property Plat ❑ BOP Sketch Q Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263 - 4093 j 0lQ O Printed Name V. Cawvey Title Alaska Wells Manager Signature , .. pp i Phon 265 -6306 Date 6 '� //40 C (MAN. N �R �T C�a ou Utv l Co fission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: / 7-7 6) (:) 6 50- c' car -��`,2.1-52 / Date: (1)(3 01 J for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedne gas hydrates, or gas contained in shales: 4 i osc 430? /;S r Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No 2' Other: H2S measures: Yes d No ❑ Directional svy req'd: Yes [a No Iii . 2s p sc: Arrn.J0 -A_ es4 - APPROVED BY THE COMMISSION 0 0 DATE: ArAille.....---Higrillil _ , COMMISSIONER 1_r Form 1-401 (Revi -d 7/2009) This permit is valid 5' o Ii Ti o 1 '" ` date o approval (20 AAC 25.005(8)) C • 3 o• !v Submit in Duplicate 6 6, , iS. 7r_ (l/L A • • ✓ RECEIVED ConocoPhillips JUN , 2010 Alaska P.O. BOX 100360 Alaska Oil & Gas Cons, Commission ANCHORAGE, ALASKA 99510 -0360 Anchorage June 11, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three lateral sidetracks out of Kuparuk Well 31 -11 using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 31 -11 as early as July 2010. The CTD objective is to drill three lateral sidetracks (31 -11A, 3I- 11AL1, 31- 11AL2) to access reserves in the Al, A2 and A3 sands south of 31 -11 that are currently unswept. In October 2009, Permit to Drill (PTD) applications were approved for CTD sidetracks 3I-11L1 (PTD# 209 - 1210), 3I- 11L1 -01 (PTD# 209 - 1220), and 3I- 11L1 -02 (PTD# 209 -1230) with the same objectives as the laterals proposed in the attached applications. Work on those sidetracks began in January 2010, however, due to operational issues, only the 3I-11L1 lateral was drilled and completed. The approved permits for the 3I-11L1- 01 and L1 -02 laterals were officially withdrawn on June 3, 2010. Because the first attempt at drilling the CTD sidetracks was unsuccessful, the work proposed in this application packet is essentially the same as previously permitted. The reservoir targets and objectives have not changed, nor have the rig operations. The only difference is that production from the parent wellbore will be isolated prior to drilling the proposed laterals. Plugging the parent wellbore perforations is necessary because of the need to isolate the 3I-11L1 lateral to prevent solids production from the unlined, openhole section. Sundry applications for the plugging of the two wellbores have been submitted separately from these PTD applications. Attached to this application are the following documents: — Permit to Drill Application Forms for 3I -11A, 3I- 11AL1, and 31 -11AL2 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at my office 907 - 263 -4093 or on my cell phone 907 - 230 -7550. Sincerely, Jill Long Coiled Tubing Drilling Engineer • • Permit to Drill Summary of Operations KRU 31 -11A, 31- 11AL1, & 31 -11AL2 Laterals Coiled Tubing Drilling Well History Well 31 -11 was originally drilled and completed as an A -sand producing, single completion well in 1989 with 2- 7/8" tubing. A workover was performed in May 2009 to replace leaking tubing. At that time the well had already been identified as a CTD candidate so the tubing was upsized from 2 -7/8" to 3 -1/2" and a subsurface safety valve (SSSV) was installed in preparation for the sidetracks. The original objective of the CTD sidetracks was to drill three lateral sidetracks out of the 31 -11 parent wellbore targeting the Al, A2 and A3 sands to access reserves from currently undrained areas to the south. The laterals were planned and permitted as 3I-11L1 (PTD# 209 - 1210), 3I-11L1-01 (PTD# 209 - 1220), and 3I-11L1-02 (PTD# 209 -1230) because the perforations in the parent wellbore were going to remain open to production. Nabors CDR2 rigged up on 31 -11 in January 2010 and began drilling operations. Unfortunately, after drilling the 3I-11L1 lateral and partially lining what had been drilled, the window became inaccessible. Drilling operations were suspended on February 13, 2010, to diagnose the problem with the window and acquire additional 13.1 ppg potassium formate completion fluid. Laterals 3I- 11L1 -01 (PTD# 209 -1220) and 3I- 11L1 -02 (PTD# 209 - 1230) were neither drilled or completed prior to rig release. Post -rig diagnostics confirmed the whipstock had released and moved downhole. After completing diagnostics on the window, 3I-11L1 was opened to flow to tanks in an attempt to bring the well pressure down before returning with the rig again. Initial production tests had —850 BLPD at 62.4% WC, 21.5 API, 0.75% solids at 950 WHP. As drawdown on the well was increased, the openhole lateral eventually collapsed and the tubing filled with solids. A fill cleanout was performed in April 2010 and the well has remained shut -in since then. Plan Forward The plan forward for this well is to set a plug in the 3 -1/2" tubing above the previously drilled window prior to attempting the CTD sidetracks again. This will isolate the 31 -11 parent wellbore perforations in addition to the 31- 11 L1 lateral and prevent solids production which could potentially plug the tubing again and prohibit production from the new sidetracked laterals. A whipstock will also be set pre -rig. Once the CTD rig arrives, a dual string window (3 -1/2" x 7 ") will be milled from which the three lateral sidetracks will then be drilled. The laterals will be named and permitted as 3I -11A, 31- 11AL1, and 3I- 11AL2. • Operational Outline Pre -Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Set a cast iron bridge plug in the 3.5" tubing at —6406' 3. Set a 3.5" monobore whipstock at —6397' 4. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 31 -11A Lateral (A2 Sand) a. Mill 2.80" 2- string window with high -side orientation off of the whipstock set at 6397' MD. b. Drill 2.70" x 3" bi- center lateral in the A2 sand to a TD of 9170' MD. Page 1 of 4 f ( I r + p , 6/11/2010 • • PTD Applications KRU 31 -11A, 31- 11AL1, and 31 -11AL2 c. Load well with completion kill weight fluid. Run 2%" slotted liner from TD at 9170' MD up to 7400' MD. An anchored aluminum billet will be set at 7400' MD for kicking off the 31 -11AL1 lateral. 3. 31 -11AL1 Lateral (Al Sand) a. Kick off of the anchored aluminum billet set in the 31 -11A lateral at 7400' MD. b. Drill 2.70" x 3" bi- center lateral in the Al sand to a TD of 9160' MD c. Load well with completion kill weight fluid. Run 2 %" slotted liner from TD up to 7360' MD. An aluminum liner -top billet placed at 7360' MD for kicking off the 31 -11AL2 lateral. 4. 31 -11AL2 Lateral (A3 Sand) • a. Kick off of the aluminum billet set in the 31 -11AL1 lateral at 7360' MD. • ,PT 0 b. Drill 2.70" x 3" bi- center lateral in the A3 sand to a TD of 9180' MD. c. Load well with kill weight fluid. Run 2%" slotted liner from TD up to 6385' MD, inside the 3W tubing. A deployment sleeve will be placed on top of the liner. 5. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Handover to Production group. Post - Rig Work 1. Obtain SBHP 2. Flowback for well cleanup 3. Begin production Operational Details Hazards — The window exit will occur in the top of the C4 sands, very close to the D shale. — The close proximity to the previously drilled 31-11L1 wellbore is an important risk to be aware of when kicking out of 31 -11 and drilling the build section of 3I -11A. The center -to- center separation of the directional plans has been reviewed and the separation is within the range that past wells having similar circumstances have been drilled. — Shale stability is a potential problem, particularly in the build section where the AS sand will be encountered. Potential sloughing problems will be mitigated by drilling this interval at a hole angle less than 60° and by holding a constant 13.2 ppg EMW on the formation throughout drilling operations. - Lost circulation was not a significant issue while drilling 31-110 and thus is not expected to be an issue in . 31 -11A, AL1, or AL2. — Over - pressured zones are a potential hazard in 31 -11. Choke pressure will be maintained while drilling, • both for maintaining well control and borehole stability. — Well 31 -11 has 150 ppm H as measured on 6/22/09. Well 31 -12 is located 25' to the left side and 31 -10 . is 25' to the right side of the 31 -11 surface location. The 31 -12 has no measured H since it is an injector. The H measured in 31 -10 is 120 ppm (1/2/09). The maximum H level on the pad is 160 ppm from wells 31 -04 (12/17/08) and 31 -17 (1/10/09). All H monitoring equipment will be operational. Page O 1 8 M 6/11/2010 Pa e2of4 l U E r • PTD Applications KRU 31 -11A, 31- 11AL1, and 31 -11AL2 Fluids Program - Chloride -based Biozan brine (8.6 ppg) will be used for window milling operations. - Chloride -based Flo -Pro mud (10.0 ppg) for drilling operations. • - The SSSV in 31 -11 is inoperable so completion kill weight fluid will be needed. Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. • 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. New Completion Details _ Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 31 -11A 7400' 9200' 6151' 6158' 2 ", 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 31 -11AL1 7360' 9165' 6152' 6193' 2%' 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 31 -11AL2 6300' 9180' 6042' 6140' 2 ", 4.7 #, L -80, ST -L solid /slotted liner; deployment sleeve on top. • Existing Casing /Liner Information _ Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 0 116 0 116 1640 630 Surface 9%" 36 J -55 BTC 0 3383 0 3383 3520 2020 Casing 7" 26 J -55 BTC 0 6762 0 6550 4980 4320 Tubing 3 1 /2" 9.3 L -80 EUE 0 6438 0 6246 10160 10540 Directional Planning - See attached directional plans for each of the three laterals. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 31 -11A 18560 3I -11AL1 18560 3I -11AL2 18560 • - Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 31 -11A 1500 31 -13 31 -11AL1 1342 31 -13 31 -11AL2 1450 31 -13 • • s .. Page3of4 iUin t� x 6/11/2010 PTD Applications KRU 31 -1 • 31 -11AL1 and 31 -11AL2 PP , Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure — The most recent static BHP survey in well 31 -11 was taken February 16, 2009, after 3I-11L1 was drilled. The reservoir pressure was measured at 4150 psi at 6400 'MD/ 6135' TVDSS, corFesponding to 13.0 ppg EMW. — The highest pressure from surrounding wells is 4250 psi at 6168 TVDSS in offset injector 31 -13. The pressure reading was taken in December 2009. Well 31 -13 had been shut -in since May 2009 to assist in reducing the pressure in the area. Well Control — Two well bore volumes ( -223 bbl) of KWF will be within a short drive to the rig during drilling operations. — 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 4500 psi. Maximum potential surface pressure expected while sidetracking out of 31 -11 is 3800 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest, most recent measured bottomhole pressure in the vicinity, which is from offset injector 31 -13. The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole 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 allows 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. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. 0R Page 4 of 4 1 A L 6/11/2010 • • Conoco Phillips Alaska ConocoPhillips(Alaska) Inc. :- Kuparuk River Unit Kuparuk 31 Pad 31-11 31-1 1AL2 Plan: 31-1 1AL2_wp01 Standard Planning Report 10 June, 2010 Elkill BAKER HUGHES IrsIttA, • ConocoPhillips • Waal ConocoPh11 Itps Planning Report BAKER Alaska HUGHES Database: : " EDM Alaska Prod v16 Local Co-ordinate Reference: - ` Well 31 - 11 :Company:' ConocoPhillips(Alaska) Inc. ND Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: ? 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad North Reference: - _' True Well: 31 - 11 Survey Calculation Method: Minimum Curvature Wel'bore: 31 - 11AL2 Design: 31 -11 AL2_wp01 Project Kuparuk River Unit 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 31 Pad Site Position: Northing: 6,007,285.49ft Latitude: 70° 25' 52.059 N From: Map Easting: 508,056.44ft Longitude: 149° 56' 3.597 W ' Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.06 ° Well 31 - 11 Well Position +N /-S 0.00 ft Northing: 6,007,088.16ft Latitude: 70° 25' 50.121 N +E/ - 0.00 ft Easting: 507,830.23 ft Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellborn 31 -11AL2 Magnetics Model Name Sample Date Declination Dip Angle , Field Strength- ( ( ) (nT) BGGM2009 7/15/2010 17.05 79.85 57,388 Design 31 -11AL2 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,360.00 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (0) 0.00 0.00 0.00 201.00 Plan Sections Measured ND Below Dogleg Build ` Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) - (1 ( °) (ft) (ft) (ft) ( ° 1100ft) ( °HOOft) (° /1OOft) (°) Target 7,360.00 91.60 240.24 6,151.23 - 1,237.47 - 1,250.95 0.00 0.00 0.00 0.00 7,410.00 98.09 236.46 6,147.01 - 1,263.58 - 1,293.34 15.00 12.97 -7.56 330.00 7,450.00 100.10 230.74 6,140.68 - 1,287.00 - 1,325.12 15.00 5.02 -14.31 290.00 7,527.47 90.00 224.96 6,133.87 - 1,338.73 - 1,382.21 15.00 -13.03 -7.46 210.00 7,827.47 90.00 179.96 6,133.87 - 1,608.90 - 1,493.89 15.00 0.00 -15.00 270.00 7,977.47 98.24 158.95 6,122.98 - 1,755.06 - 1,466.82 15.00 5.49 -14.01 292.00 8,177.47 89.78 187.83 6,108.70 - 1,950.98 - 1,444.38 15.00 -4.23 14.44 105.00 8,427.47 89.82 225.33 6,109.62 - 2,170.59 - 1,554.24 15.00 0.02 15.00 90.00 8,737.47 86.25 178.93 6,120.85 - 2,449.70 - 1,667.89 15.00 -1.15 -14.97 265.00 8,987.47 86.42 216.51 6,137.43 - 2,683.07 - 1,742.46 15.00 0.07 15.03 91.00 9,180.00 92.14 188.19 6,139.90 - 2,859.26 - 1,814.85 15.00 2.97 -14.71 281.00 6/10/2010 11 :39 :00AM Page 2 COMPASS 2003.16 Build 69 r , t I ID • v-- Conoco Phillips rsai Conoco Phillips Planning Report BAKER Alaska HUGHES Database: ,,- ,_ EDM Alaska Prod v16 Local Co-ordinate Reference: g: Well 31 ,_. Company: ConocoPhillips(Alaska) Inc. Tv!) Reference: , g g gg Mean Sea Level .. Project g Kuparuk River Unit MD Reference: = - g 31 -11 @ 76 - 00 ft ( 31-11 ) Site: - _ Kuparuk 31 Pad North Reference: True Well: 31 Survey Calculation Method: Minimum Curvature VVellbore: - 31 Design: - 31-11AL2_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map _ Mapgg - - - System eg ue Section Rate Azimuth Northing _ g Easting Depth Inclination Azimuth System +Pil +°,-- . ggft ° (ft) - (ft) (ft) - (.) (.) (ft) ( ft ) (ft) (ft) ( ff ) ( ) 7,360.00 91.60 240.24 6,151.23 -1,237.47 -1,250.95 1,603.58 0.00 0.00 6,005,849.50 506,580.70 TIP / KOP I 7,400.00 96.79 237.23 6,148.30 -1,258.16 -1,285.04 1,635.11 15.00 -30.00 6,005,828.78 506,546.64 7,410.00 98.09 236.46 6,147.01 -1,263.58 -1,293.34 1,643.15 15.00 -30.22 6,005,823.35 506,538.35 2 7,450.00 100.10 230.74 6,140.68 -1,287.00 -1,325.12 1,676.40 15.00 -70.00 6,005,799.90 506,506.60 3 7,500.00 93.59 226.99 6,134.73 -1,319.65 -1,362.47 1,720.26 15.00 -150.00 6,005,767.22 506,469.28' 7,527.47 90.00 224.96 6,133.87 -1,338.73 -1,382.21 1,745.15 15.00 -150.45 6,005,748.12 506,449.56 4 i 7,600.00 90.00 214.08 6,133.87 -1,394.59 -1,428.29 1,813.82 15.00 -90.00 6,005,692.21 506,403.54 7,700.00 90.00 199.08 6,133.87 -1,483.77 -1,472.91 1,913.06 15.00 -90.00 6,005,602.99 506,359.03 7,800.00 90.00 184.08 6,133.87 -1,581.46 -1,492.92 2,011.43 15.00 -90.00 6,005,505.30 506,339.12 7,827.47 90.00 179.96 6,133.87 -1,608.90 -1,493.89 2,037.40 15.00 -90.00 6,005,477.85 506,338.18 5 7,900.00 94.05 169.85 6,131.30 -1,680.99 -1,487.47 2,102.40 15.00 -68.00 6,005,405.78 506,344.67 7,977.47 98.24 158.95 6,122.98 -1,755.06 -1,466.82 2,164.15 15.00 -68.36 6,005,331.74 506,365.40 6 8,000.00 97.35 162.24 6,119.92 -1,776.11 -1,459.41 2,181.14 15.00 105.00 6,005,310.70 506,372.83 8,100.00 93.17 176.71 6,110.70 -1,873.73 -1,441.31 2,265.80 15.00 105.45 6,005,213.10 506,391.03 8,177.47 89.78 187.83 6,108.70 -1,950.98 -1,444.38 2,339.02 15.00 106.78 6,005,135.86 506,388.05 7 8,200.00 89.78 191.21 6,108.79 -1,973.20 -1,448.10 2,361.09 15.00 90.00 6,005,113.64 506,384.34 8,300.00 89.79 206.21 6,109.18 -2,067.65 -1,480.08 2,460.73 15.00 89.99 6,005,019.17 506,352.46 8,400.00 89.81 221.21 6,109.53 -2,150.60 -1,535.42 2,558.00 15.00 89.93 6,004,936.17 506,297.22 8,427.47 89.82 225.33 6,109.62 -2,170.59 -1,554.24 2,583.42 15.00 89.88 6,004,916.15 506,278.42 8 1 8,500.00 88.88 214.49 6,110.44 -2,226.14 -1,600.70 2,651.92 15.00 -95.00 6,004,860.56 506,232.02 8,600.00 87.66 199.53 6,113.47 -2,314.94 -1,645.97 2,751.04 15.00 -94.88 6,004,771.73 506,186.85 8,700.00 86.59 184.55 6,118.51 -2,412.33 -1,666.75 2,849.42 15.00 -94.42 6,004,674.32 506,166.18 8,737.47 86.25 178.93 6,120.85 -2,449.70 -1,667.89 2,884.71 15.00 -93.67 6,004,636.96 506,165.08 9 8,800.00 86.14 188.33 6,125.01 -2,511.89 -1,671.83 2,944.19 15.00 91.00 6,004,574.76 506,161.20 8,900.00 86.17 203.36 6,131.75 -2,607.60 -1,698.99 3,043.27 15.00 90.37 6,004,479.04 506,134.14 1 8,987.47 86.42 216.51 6,137.43 -2,683.07 -1,742.46 3,129.31 15.00 89.36 6,004,403.53 506,090.76 10 9,000.00 86.78 214.66 6,138.17 -2,693.25 -1,749.74 3,141.41 15.00 -79.00 6,004,393.35 506,083.50 9,100.00 89.74 199.95 6,141.22 -2,781.81 -1,795.45 3,240.48 15.00 -78.89 6,004,304.74 506,037.88 9,180.00 ' 92.14 188.19 6,139.90 ' -2,859.26 -1,814.85 3,319.74 15.00 -78.44 6,004,227.28 506,018.56 TD 6/10/2010 11.39:00AM Page 3 COMPASS 2003.16 Build 69 I N. , , i t k:. :•. t ConocoPhillips r?dotio ConocoPhddlips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference :, Well 31 - 11 Company: ConocoPhillips(Alaska) Inc. ND Reference: +`' Mean Sea Level Project:. Kuparuk River Unit. MD Reference: - * 31 -11 © 76.00ff(31 -11) Site: Kuparuk 31 Pad North Reference: True We11 = 31 - 11 Survey Calculation Method:- - . ` Minimum Curvature Wellborn: 31 -11AL2 Design: _ 31 11AL2_wp01 Targets Target Name hitlmiss target Dip Angle . Dip Dir._ , ND +N -S +E/-W Northing : Easting- J_ Shape ( °); (') (ft)- (ft) (ft) (ft) (g) = Latitude Longitude j 31 - 11AL2 t1 0.00 0.00 6,141.00 - 1,287.35 - 1,325.49 6,005,799.55 506,506.22 70° 25' 37.459 N 149° 56' 49.123 W - plan hits target center - Point 31 -11A, AL1, AL1 -01 F 0.00 0.00 0.00 - 790.15 - 523.89 6,006,297.54 507,307.22 70° 25' 42.349 N 149° 56' 25.610 W - plan misses target center by 6210.18ft at 7360.00ft MD (6151.23 ND, - 1237.47 N, - 1250.95 E) - Polygon Point 1 0.00 - 790.15 - 523.89 6,006,297.54 507,307.22 Point 2 0.00 - 1,143.27 - 1,441.33 6,005,943.49 506,390.24 Point 3 0.00 - 1,783.03 - 1,750.00 6,005,303.47 506,082.28 Point 4 0.00 - 2,991.73 - 2,167.25 6,004,094.45 505,666.34 Point 5 0.00 - 3,170.18 - 1,736.39 6,003,916.47 506,097.34 Point 6 0.00 - 1,875.47 - 1,311.05 6,005,211.50 506,521.28 Point 7 0.00 - 1,398.60 - 1,140.56 6,005,688.50 506,691.25 Point 8 0.00 - 1,175.14 - 570.28 6,005,912.54 507,261.24 31-11AL2 t2 0.00 0.00 6,109.00 - 1,973.27 - 1,448.24 6,005,113.56 506,384.21 70° 25' 30.713 N 149° 56' 52.720 W - plan hits target center - Point 31 -11AL2 t3 0.00 0.00 6,140.00 - 2,858.96 - 1,815.22 6,004,227.58 506,018.20 70° 25' 22.001 N 149° 57' 3.478 W - plan hits target center - Point 31 -11A, AL1 fault 5 0.00 0.00 0.00 - 2,306.63 - 2,081.65 6,004,779.58 505,751.21 70° 25' 27.433 N 149° 57' 11.297 W - plan misses target center by 6128.98ft at 8600.00ft MD (6113.47 ND, - 2314.94 N, - 1645.97 E) - Polygon Point 1 0.00 - 2,306.63 - 2,081.65 6,004,779.58 505,751.21 Point 2 0.00 - 2,432.98 - 1,745.74 6,004,653.59 506,087.22 Point 3 0.00 - 2,576.36 - 1,373.85 6,004,510.62 506,459.22 Point 4 0.00 - 2,432.98 - 1,745.74 6,004,653.59 506,087.22 31 -11A, AL1 fault 1 0.00 0.00 0.00 - 912.76 - 902.05 6,006,174.54 506,929.22 70° 25' 41.143 N 149° 56' 36.703 W - plan misses target center by 6165.42ft at 7500.00ft MD (6134.73 ND, - 1319.65 N, - 1362.47 E) - Polygon Point 1 0.00 - 912.76 - 902.05 6,006,174.54 506,929.22 Point 2 0.00 - 1,382.78 - 932.52 6,005,704.54 506,899.25 Point 3 0.00 - 1,197.74 - 948.34 6,005,889.54 506,883.24 Point 4 0.00 - 1,382.78 - 932.52 6,005,704.54 506,899.25 31 -11A, AL1 fault 2 0.00 0.00 0.00 - 2,022.61 - 1,134.26 6,005,064.56 506,698.21 70° 25' 30.228 N 149° 56' 43.510 W - plan misses target center by 6116.99ft at 8177.47ft MD (6108.70 ND, - 1950.98 N, - 1444.38 E) - Polygon Point 1 0.00 - 2,022.61 - 1,134.26 6,005,064.56 506,698.21 Point 2 0.00 - 1,137.61 - 1,040.37 6,005,949.57 506,791.16 Point 3 0.00 512.11 - 599.68 6,007,599.59 507,230.07 Point4 0.00 - 1,137.61 - 1,040.37 6,005,949.57 506,791.16 31 -11A, AL1 fault 3 0.00 0.00 0.00 - 2,059.83 - 1,873.37 6,005,026.57 505,959.21 70° 25' 29.860 N 149° 57' 5.189 W - plan misses target center by 6118.54ft at 8477.90ft MD (6110.06 ND, - 2208.30 N, - 1587.68 E) - Polygon Point 1 0.00 - 2,059.83 - 1,873.37 6,005,026.57 505,959.21 Point 2 0.00 - 2,206.22 - 1,500.48 6,004,880.59 506,332.22 Point 3 0.00 - 2,330.62 - 1,111.56 6,004,756.61 506,721.23 Point 4 0.00 - 2,206.22 - 1,500.48 6,004,880.59 506,332.22 31 -11A, AL1 fault 4 0.00 0.00 0.00 - 2,213.81 - 1,904.53 6,004,872.57 505,928.21 70° 25' 28.346 N 149° 57' 6.102 W - plan misses target center by 6118.00ft at 8500.00ft MD (6110.44 ND, - 2226.14 N, - 1600.70 E) - Polygon Point 1 0.00 - 2,213.81 - 1,904.53 6,004,872.57 505,928.21 Point 2 0.00 - 2,335.11 - 1,618.62 6,004,751.58 506,214.22 Point 3 0.00 - 2,453.49 - 1,249.70 6,004,633.60 506,583.23 6/10/2010 11:39 :00AM Page 4 COMPASS 2003.16 Build 69 • • N.- Conoco Phillips VS tw ConocoPhilli`ps 0 Planning Report BAKER Alaska HUGHES Database: - EDM Alaska Prod v16 ' Local Co Reference: Well 31 Company: ConocoPhillips(Alaska) Inc. 'TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: , _ , s 31-11 © 76.00ft (31-11) • Site: - ' Kuparuk 31 Pad North Reference: - - I -. True Well: 31-11 Survey Calculation Method: Minimum Curvature Wellbore: 3I Design: 3I-11AL2 — wp01 1 Point 4 0.00 -2,335.11 -1,618.62 6,004,751.58 506,214.22 1 Casing Points Measured Vertical Casing - Hole Depth Depth Diameter - Diameter (ft) (ft) Name (") ' (") 9,180.00 6,139.90 2 3/8" 2 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Ni-S +E/-1.01 s _ = ft ft() () (ft) (ft) Comment - , 7,360.00 6,151.23 -1,237.47 -1,250.95 TIP / KOP 1 7,410.00 6,147.01 -1,263.58 -1,293.34 2 7,450.00 6,140.68 -1,287.00 -1,325.12 3 7,527.47 6,133.87 -1,338.73 -1,382.21 4 7,827.47 6,133.87 -1,608.90 -1,493.89 5 7,977.47 6,122.98 -1,755.06 -1,466.82 6 8,177.47 6,108.70 -1,950.98 -1,444.38 7 8,427.47 6,109.62 -2,170.59 -1,554.24 8 8,737.47 6,120.85 -2,449.70 -1,667.89 9 1 8,987.47 6,137.43 -2,683.07 -1,742.46 10 1 9,180.00 6,139.90 -2,859.26 -1,814.85 TD 6/10/2010 11:39.00AM Page 5 COMPASS 2003.16 Build 69 , ,, AzimwsbT tam WELLBORE DETAILS: 31 -11AL2 REFERENCE INFORMATION /^ Project: Kupan k River Unit Meaner Norm 21ST Site: Kuparuk 31 Pad Coordinate (N/E) Reference Well 31 - 11, True North Magnet. Fwd Parent Wellbore: 31 -11A ---- " Well: 31.11 Strength 576/28.3en7 Tie on MD: 7360.00 Vertical (ND) Reference Mean Sea Level BAK� • Cep Angle' 90 a5° Section (VS) Reference: Slot•(0.006,000E) ("' £ Welbore: 31.11A;L2 rw.V� !� OP hill A� � .7 Plan:31- 11AL2_wp01(31- 11131- 11AL2) gl /BG1 Measured Depth Reference: 31 - 11 @ 76.00ft (31 Calculation Method: Minimum Curvature HUGHES ' 0 - 1050_. _ -.. WELL DETAILS: 31 -11 -1200 Ground Level: 0.00 , . , ,,. 0 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 1350- - - - 0.00 0.00 6007088.16 507830.23 70° 25' 50.121 N 149° 56' 10.241 W -1350 3 2 - SECTION DETAILS ANNOTATIONS -1500 � 4 TIP /KOP Sec MD Inc Azi TVDSS +N/ - -S +Ei -W DLeg TFace VSec Target Annotation l6so- - - 5 1 7360.00 91.60 240.24 6151.23 - 1237.47 - 1250.95 0.00 0.00 1603.58 TIP / KOP 2 7410.00 98.09 236.46 6147.01 - 1263.58 - 1293.34 15.00 330.00 1643.15 2 1 - 6 3 7450.00 100.10 230.74 6140.68 - 1287.00 - 1325.12 15.00 290.00 1676.40 3 C ttaoo 4 7527.47 90 °00 224.96 6133.87 - 1338.73 - 1382.21 15.00 210.E 1745.15 4 5 7827.47 90.00 179.96 6133.87 - 1608.90 - 1493.89 15.00 270.00 2037.40 5 a9so 7 6 7977.47 9824 158.95 6122.98 - 1755:06 -1466.82 15.00 292.00 2164.15 6 o , 7 8177.47 89.78 187.83 6108.70 -1950.98 - 1444.38 15.00 105.00 2339.02 7 -- 8 8427.47 89.82 225.33 6109.62 - 2170.59 - 1554.24 15.00 90.00 2583.42 8 ` i 9 III 8737.47 86.25 178.93 6120.85 - 2449.70 - 1667.89 15.00 265.00 2884.71 9 10 8987.47 86.42 216.51 6137.43 - 2683.07 -1742.46 15.00 91.00 3129.31 10 - 2250 - 11 9180.00 92.14 188.19 6139.90 - 2859.26 - 1814.85 15.00 281.00 3319.74 TD c t-i 4. -2400 4 .. .. ..-a- -2550, _. _ i _ rn 1 0 noo- 31- 11/31 -11 AL1 .n...;.._.�:, - 3000 _....... _. ... ..... _..... __ -._ ___... 31- 11/31 -11AL2 ... ,,,_• - 3150 -2700 -2550 -2400 -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 -750 - 600 -450 -300 -150 0 5800 -... West( - )/East( +) (150 ft/in) _ 5850 -. - - -. - - 5900_ 5950_ .. _.. O 6000_ 7 y 6050 10 _ _._. _... ___. ___. __.5_. _..... 6 _..._. __. _.... _.. 8 ___. 9 __ .... rt. _ : : N TIP /KOP J 6100 - g 4 : : 1 ... \.... 2 __.... _... . _..... ___' _ ____. ___. _. 3I.11 /3I- 11AL2 , 671 Si - .. d ..Vi c 6150_ - - -_ . _ - ; > ... _.. - - .... - _ _ _ _ 11 11.3I-DA '., 31- 11 /31 -11AL1 h 6250_ 6300_ -... -. -- -- 6350 -. 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 50 3100 3150 3200 3250 3300 3350 3400 3450 Vertical Section at 201.00° (50 ft/in) ' . Project: KuPanakRiverUntt A... WELLBORE DETAILS: 31-11A REFERENCE INFORMATION ragi Site: Kupar Parent Wellbore 31-11 Coarcinste (N/E) Reference' VVell 31-11, True North M4.91141 : '70V Well: 31-11 S0elg6h:57,2613.3.11 Tie on MD 6300.00 Vertical (WD) Reference' 31-11 © 76.000(31-11) BAKER Corx)coPttillips Plan: Welbore: 31-11A 31-IA wp01 (31-11/31-11A) Dip PNea 8028° Da* 7/152010 Model BCGM20C6 Section (VS) Reference: Slot - (o.00rii, 0.00E) Measured Depth Reference. 31-ft@ 76.0011(31-11) Calculation Method' Minimum Curvature FIUCI.4FILS 1 1-0 ,3 1-05 , 11-03031-03 ' 31410/31-06 1200 1-' ' --*-- ' 1000 •-,. ..-2., 9- 8002 , , / - ,-/ , ..-- 31 12 600 --'' 400 / ---' ' 200 „„> .,,,_... --- /. ,'' ' .- , ' s ,--- ' .---- . , --- / 0 -800 ---- 31- it/ ni ,,,, d . _ ... 31-04/314/4 _i00. , ..---, ,---- . , N -1200 . . , + -1400 1113/31-] , ■ :... - * t 'i, 0 -1600 , ,z,,,//, C/) \ -2400 / , \ -2600 31-11/31-11A 1 -2800 . . . _ - - - - -- r- , s 314 0, / 2 3010 31-11/31-111,1 - 3000 - 0200 - 3200 ' 1 -3400 i . -3600 , -3800 oi-5, , - 3333 , , -4000 6200 31-11 (2 76.00ft (3)-11) ,_._ ------_____ 11.1s/31-15 _ ,42.6 -■----- — -4200 , -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 West(-)/East(+) (200 ft/in) 31 -11A, ALI, & AL2 Proposed CTD Sidetrack Revision Updated; 10-Jun-10 Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) ice, KEY 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface _ Equipment and perforations set in parent ui welfbore ment set a 2512', 3702', 4760', 5668', & 6074' qpnd lateral drilled 16" 62# H -40 shoe 3.1/2" Camco MMG gas lift mandrels (5) @ E during first CTD project @116 MD • ., X' landing nipple @ 6123' MD (2.813" min ID) Equipment set and laterals drilled -.ran ME during second CTD project 9 -5/8" 36# J -55 Baker 3 -1/2" seal assembly 6131' - 6143' MD shoe @ 3383' MD 80 -40 PBR at 6132` - 6145' Baker KBH Anchor Seal Assy at 6145' MD Baker SAB 40 -32 packer @ 6146' MD IIII I Whipstock @ 6397' 'X' landing nipple @ 6156' MD (2.813" min ID) 31.11A L2 l I MD (A3 sand, wp04) Holes shot in 3 - 1/2 " straddle at — 6408' -6413' & 6213' MD Kickoff from 31 - 11 ALt @ 7360' (Baker monobore �. - Full deployment sleeve @ 6300' whipstock) B a k er F 1 permanent packer @ 6422' MD (e -line set) Slotted lr liner from 6450 5 • 80 -40 Sealbore extension (6425'- 6430') TD 3 -1 /2" straddle TD @ 9180 •s, cemented in place , D' landing nipple @ 6433' MD (2.750" min ID) CD I Cast Iron Bri6406 de Flog " +' +I 9 9 v �. WLEG @.6438' MD @ " et+ r= 31 -11A monobore >ssss t .c ;, (A2 sand, wp10) �.. +� whipstock at 6422 sss •s. { . 11 (TOWS) .. _........-'----" .... . . ... .................. Slone to TD G , ... ..- ,.:- � .- 31 1 3 Liner top billet @00001 ' r.,. d liner from 74 ..r.�� nr FISH: 3-1/2" TD @9200' monobore II ................... �� whipstock @ unknown depth A sand oerfs _ .1"__ ...-- \ A3: 6437' - 6454' = 31 -11 u A2: 6457' - 6486' — _ j — A2 sand) 3 sand, w 1 Kickoff from 31 -11 @ 6409' (Al sand, p05) Al: 6494' - 6503' Kickoff from 31-11A @ 7400' .. - — Shorty deployment sleeve @ 7590' Liner top billet 0 7360' Slotted liner from 7590' to TD Slotted liner from 7360' -TD TD @ 9437' TD @ 9165' 7" 26# J -55 shoe @ 6761' MD • • Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing r" Lubricator Riser A I ) T nular Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator _....{<_J L II Choke above BI-IA rams L— --J V' ■44 ir- ■ l r Choke 1 11 2-3/8" Pipe / Slip (BHA) IN Equalize Manifold 2-3/8" Pipe / Slip (BHA) I lip - ,.4, • J L Kill P / ''><. P.- 4 p■ ■ 111 gi 11 M 1 r Blind / Shear II 2" Pipe / Slip (CT) III 11 Swab Valves Choke 2 1111 V ■■■ El Wing Valves 11. 111■416.1.110.,. Tree Flow Cross -411 • PProgriiingri Surface Safety Valve BOPE: Choke Line: 7-1/16", 5M psi, TOT 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union t't 1 A i 1 \ . .1, ' ; 4 — f 1 TRANSMITTAL LETTER CHECKLIST WELL NAME ///1/____ 2 _ -- PTD# 2-7 n' t Development Service Exploratory Stratigraphic Test Non - Conventional Well j POOL: , (,L / 1 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore sepoent of existing well 1—«(( L lr (If last two digits in _ , API number are Permit No. e n f'6, API No. 50- C� - Z/ 9 l . between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 31 -112 _ Program DEV Well bore seg 2 PTD#: 2100760 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type DEV / PEND GeoArea 890 _ Unit 11160 _ On /Off Shore On Annular Disposal ❑ Administration 1 Perrnitfee attached NA 2 Lease number appropriate _ Yes Lateral: kick-offpoint, top prod interval & TD all lie within ADL 25631. 3 Unique well narne and number Yes Kuparuk River Oil Pool, govemed by Conservation Order No. 432C 4 Well located in a defined pool Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 5 Well located proper distance from drilling unit boundary Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 4 miles i6 Well located proper distance from other wells Yes from an external property line where ownership or_ landownership changes. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, iswellbore plat included Yes 9 Operator only affected party _ Yes 10 Operator has_appropriate_ bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 1 12 Permit can be issued without administrative approval Yes SFD 6/15/2010 13 Can permit be approved before 15 -day- wait Yes 1 14 Well located within area and strata authorized by_Injection Order # (put 10# in comments) (For NA • 115 All wells within 1/4 mite 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 Nonconv_en, gas conforms to AS31.05.030(f.1.A),(j,2.A -D) NA 18 Conductor string provided NA _ Conductor set in 31 -11 Engineering '19 Surface casing protects all known USDWs NA Surface casing set in 3I -11 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 31 -11 21 CMT vol adequate to tie-in long string to surf csg NA _ _ Production casing set in 31 -11 22 CMT will coverall known productive horizons No. OH slotted liner is planned. _ 23 Casing designs adequate for C, T, B & permafrost Yes 1 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. 25 Ifare -drill, has a 10-403 for abandonment been approved Yes 310 -177 and 310-178 _ • 26 Adequate wellbore separation proposed Yes Proximity analysis perfromed. No issues. - :27 If diverter required, does it meet regulations NA _ Wellhead in place... BOP to be placed on production tree. Appr Date 28 Drilling fluid program schematic h_& equip list adequate Yes Max formation press =4452 psi ( 13,9 ppg) Will drill with 10 ppg FloPro mud and use MPD technique. GLS 6/30/2010 129 BOPEs,_do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments)_ . _ - Yes . _ _ MASP = 3800 psi Will. test BOP to 4500 psi • 31 Choke manifold complies w/API RP -53 (May 84) Yes !32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on 31 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 31 -11 measured 150 ppm H28 in June 2009; measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is between_ 13.0 and 13.2 to as high as 13.9 ppg EMW. Appr Date 1 37 Seismic analysis of shallow gas zones NA Wellbore will be drilled using coiled tubing,10.0ppg mud, and Managed Pressure SFD 6/15/2010 38 Seabed condition survey (if off - shore) . NA Drilling technique to maintain well control and wellbore stability. 39 Contact name /phone for weekly_progress reports [exploratory only] _ NA Geologic Engineering P c Date: ate: Date ate Com issi Date e f4-lam ` e"..0-/e .
