The URL can be used to link to this page

Home My WebLink About210-125New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 By Samantha Carlisle at 9:28 am, Jan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ñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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¶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¶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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð (II 4)ORZ/PLQ 'DLO\%XON 6XSSO\,WHP'HVFULSWLRQ(TXLSPHQW)XHO 8QLW/DEHOJDOXV 8QLW6L]H 1RWH 'DWH &RQVXPHG 5HFHLYHG 5HWXUQHG &XP&RQVXPHG &XP5HFHLYHG &XP5HWXUQHG &XP2Q/RF 1RWH 6XSSO\,WHP'HVFULSWLRQ5LJ)XHO 8QLW/DEHOJDOXV 8QLW6L]H 1RWH 'DWH &RQVXPHG 5HFHLYHG 5HWXUQHG &XP&RQVXPHG &XP5HFHLYHG &XP5HWXUQHG &XP2Q/RF 1RWH 6XSSO\,WHP'HVFULSWLRQ5LJ:DWHU 8QLW/DEHOEEO 8QLW6L]H 1RWH 'DWH &RQVXPHG 5HFHLYHG 5HWXUQHG &XP&RQVXPHG &XP5HFHLYHG &XP5HWXUQHG &XP2Q/RF 1RWH /DVW$XWKRULW\9LVLW 'DWH 7RWLQVS1EU 7RWDO,1&QXPEHU &RPPHQW 6723&DUGV6XEPLWWHG &RPSDQ\ 5SWV &RP 125',&&$/,67$6(59,&(6 3-60 *HQHUDO1RWHV &RPPHQW :HOO1DPH2325 :HOOERUH1DPH23 :HOO&RGH -RE:25.29(5 :&(,/HYHO 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI :HOO+HDGHU 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH '(9(/230(17:(// 5RWDU\7DEOH(OHYDWLRQP *URXQG/HYHOP )LUVW)ODQJHP 5.%%DVH)ODQJHP 5.%7XELQJ6SRROP 5LJV 5LJ1DPH 5,* &RQWUDFWRU 125',&&$/,67$ 5LJ7\SH /$1'5,* 5LJ1XP 5LJ6WDUW'DWH 5LJ5HOHDVH'DWH 'DLO\,QIRUPDWLRQ :HDWKHU 2YHUFDVW:& 7HPSHUDWXUH& :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% 6DIHW\,QFLGHQWV1HDU0LVV 'DWH &DWHJRU\ 7\SH 6XEW\SH 6HYHULW\ &DXVH /RVWWLPH" 1R &RPPHQW 5HYLHZDQGGLVFXVVHGRQHRIWKH&V&RQWURORIZRUN'LVFXVVHGRQHRIWKH(QL*ROGHQ5XOHV3HUPLWWRZRUN 6DIHW\'ULOOV 7\SH 2FFXU /DVW'DWH 1H[W'DWH 'D\V8QWLO1H[W&KHFN GD\V %233UHVVXUH7HVW .LFN:KLOH'ULOOLQJ'ULOO 6DIHW\0HHWLQJ &DVLQJVVHDW &DV7\SH 2'LQ ,'LQ *UDGH 7RSP.% %RWWRPP.% 79'%RWP.%/DQGLQJ'DWH &21'8&725 ; &$6,1* / &$6,1* / /,1(5 / /DVW&HPHQWLQJ &HPHQWLQJ6WDUW'DWH6WULQJ&$6,1*P.%&RPPHQW6FKOXPEHUJHUSXPSEEOV+2 WHVWOLQHVWRSVL2.?3XPSEEOVRISSJ0XGSXVK,,?'URSERWWRP SOXJ?%DWFKPL[ SXPSEEOVRISSJ'HHS&UHWHFHPHQWVNVIWVN\LHOGZLWKPL[IOXLG# JDOVN?'URSWRSSOXJ?6FKOXPEHUJHUSXPSEEOV+2IRUZDVKXS?5LJSXPSGLVSODFHFHPHQWZLWKEEOVRI SSJPXG#ESP,&3SVLVORZSXPSUDWHWRESP#SVL#EEOV?%XPSSOXJWRSVLSVL RYHU)&3#SVL?+ROGIRUPLQXWHVEOHHGRII FKHFNIORDWVKROGLQJ?*RRGUHWXUQWKURXJKZLWKVRPHVOLJKW ORVV?&,3#KUV?/DQGKDQJHUDQGGLGQ WUHFLSURFDWHGGXHWR+LJK)ULFWLRQ)DFWRUV. 08SZW .'Q ZW .(VWLPDWHGWRSRIFHPHQW 6WJ 7RSP.% 7RS0HDV0HWK %WPP.% &RP 9ROXPH&DOFXODWLRQV 3XPSFHPHQW DERYHWKH1VDQG IRU]RQDOLVRODWLRQRIIRUPDWLRQ -RE,QIRUPDWLRQ -RE3KDVH :25.29(5 3ODQQHG6WDUW'DWH 6WDUW'DWH (QG'DWH 3'XUDWLRQGD\V 'DLO\6XPPDU\2SHUDWLRQV K)RUHFDVW 5XQLQKROHZLWK(63FRPSOHWLRQ K6XPPDU\ 5,+Z;7GULOOSLSHDQG5HWULHYDPDWLFWHVWSDFNHU6HWWKHUHWULHYDPDWLFDW PG)LOOWKHKROHDQGSUHVVXUHWHVWWKHFDVLQJWRSVL*RRGWHVW322+WRVXUIDFHZKLOHOD\LQJGRZQGULOOSLSHLQ VLQJOHVOD\GRZQWHVWSDFNHU2IIORDGGULOOSLSHDVZHDUHSXOOLQJRXWRIWKHKROH/RDGWKHSLSHVKHGZLWKWXELQJDQGVWUDSIRUDWXELQJWDOO\ 2SHUDWLRQDW 0DNLQJXS(63DVVHPEO\ 7LPH/RJ 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 0 3 5,+ZWHVWSDFNHURQ;7GULOOSLSHIURP PGWR PG/RZHUFODPSKRVHOHDNLQJRQWKHLURQURXJKQHFN &KDQJHRXWWKHKRVH :2 0 3 5,+ZWHVWSDFNHURQ;7GULOOSLSHIURP PGWR 6HWWKHWHVWSDFNHU38:N'1:7. 6HWWKHWHVWSDFNHUDW PGDQGVWDFN.GRZQRQWKHSDFNHU :2 0 3 )LOOWKHZHOOZLWKSSJEULQHWRWHVWWKHSDFNHW7RRNEEOVWRILOOWKHKROH3UHSWR37WRSVL :2 0 3 0,7SUHVVXUHWHVWWKH$QQXOXV$WRSVLZKLOHPRQLWRULQJWKH$QQXOXV%'XHWRILOOLQJWKHKROHZLWKEEOVLWLQGLFDWHV WKHIOXLGOHYHOZKLOHUXQQLQJSLSHZDVDW PG3UHVVXUHXSWKH$QQXOXV$WRSVLZLWKEEOV,QLWLDO3UHVVXUHV DP$QQXOXV$SVL$QQXOXV%SVL7%*SVL $IWHUPLQDP$QQXOXV$SVL$QQXOXV%SVL7%*SVL/RVWSVL $IWHUPLQDP$QQXOXV$SVL$QQXOXV%SVL7%*SVL/RVWSVL :2 0 3 8QVHDWWKHSDFNHUDQGOHWWKHZHOOVWDELOL]H3LFNXS DQGOHWSDFNHUUHOD[IRUPLQ :2 0 3 3XOOLQJRXWRIKROHOD\GRZQ;7IURP PGWR PG6WRSSXOOLQJRSHUDWLRQVWRSHUIRUPWKHOLIWSODQPHHWLQJDQG SXWWKH(63DQG&$3OLQHVSRROVRQWKHULJIORRU :2 0 3 3HUIRUPWKHOLIWSODQPHHWLQJZLWKWKH(QLOLIWDGYLVRU+6(236OHDG:RUOH\FUDQHFUHZDQG1RUGLFFUHZ3HUIRUPWKHOLIWVWR LQVWDOOWKH(63VSRROHUDQG&$3OLQHVSRROHU :2 0 3 /D\GRZQ;7SLSHFRPLQJRXWRIKROHIURP WRVXUIDFH/D\GRZQ7HVWSDFNHU%+$ :2 & 3 3XOOZHDUULQJ3UHSDUHSLSHVKHGIRUORDGLQJWXELQJDQG%DNHUHTXLSPHQW :2 0 3 /RDGFRDWHG+<'WXELQJLQWRSLSHVKHGGULIWDQGVWUDS 2SHUDWLRQIURPWR 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 0 3 &RQWLQXHWRORDGLQWHUQDOFRDWHG+<'WXELQJLQSLSHVKHGGULIWDQGVWUDS8QORDG6FUDSHUPDJQHWVWHVW SDFNHUDQG;2 VIURPSLSHVKHG/RDG(63FRPSOHWLRQDQGVOLSVLQWRSLSHVKHG *DV5HDGLQJV $YJ%DFNJURXQG*DV 0D[%DFNJURXQG*DV $YJ&RQQHFWLRQ*DV 0D[&RQQHFWLRQ*DV $YJ'ULOO*DV 0D['ULOO*DV $YJ7ULS*DV 0D[7ULS*DV 'DLO\0XG9ROXPHV 7DQN$GGLWLRQ/RVV 7\SH 'HV 9ROXPHPñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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ñ /RVV 7DQN +ROH &XPXODWLYH0XG9ROXPHV $FWLYH9ROXPHPñ +ROH9ROXPHPñ $GGLWLRQVPñ &XP$GGLWLRQVPñ /RVVHVPñ &XP/RVVHVPñ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ð 'DWH 'HSWKP.% 6ORZ6SG 6WURNHVVSP 3NJIFPð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urf. Casing13-3/8", 68 # +/- 2,249' MD, 2,170' TVD31º Inc. Interm. Casing 9-5/8", 47 #8,506' MD, 3,557' TVD87º Inc.4-½” 12.6 ppf WH563 L80 Production Tubing – TK15-XT Internal CoatedSlotted Liner,5-½” 17 ppf18,040 MD, 3,522' TVDHAL Zonal Isolation Swell Packers4-½” cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj LineConfidentialOP17-02Oil Producer withESP LiftNikaitchuq Field – Oliktok Point Pad7,816' MD, 3,513' TVD, 86º inc.– Bottom of Motor Centralizer, 75 stages 538PMSSD Flex80 pump, 5.13 GSB3DB seals, Gassep, 400 HP MTR562XP Motor, Zenith E7 series sensor, Baker SureTREAT Chem. Inj. Valve8,265' MD, Baker SLXP Liner Hanger/Packer5-½” Silver Bullet Ecc. Nose Guide ShoeAs completed12-11-2020Resman Prod Tracer Carrier7,735' MD, 3,507' TVD, 86º inc. – Discharge Gauge Sub13-3/8" x 4-½” 5kpsi Tubing Hanger with 4" nom. Type “H” BPV Profile 30' MD/TVD 4-½” Swivel Joint By Samantha Carlisle at 10:35 am, Nov 16, 2020 320-488 10-404 X X BOP test to 3500 psig DSR-11/17/2020DLB11/16/2020 X VTL 11/24/20 11/24/2020 dts 11/24/2020 JLC 11/24/2020 RBDMS HEW 11/25/2020 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com November 13th, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP17-02. OP17-02 was originally completed on Oliktok Point on December 18th, 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set a depth of 7,888’ MD. The ESP failed due to electrical fault on August 13th, 2011 after facilities shut-down and the well was recompleted on September 5th, 2011. The ESP failed again in July 8th, 2013: the well was recompleted on July 21st, 2013 and put back on production. A workover was performed in April 2018 and the TTC-ESP was replaced by a new conventional ESP system to increase production. A suspected ESP failure has occurred in April 2019 and a workover was performed in May 2019 for an ESP swap. A workover was performed in April 2020 due to tubing leak detected thru Caliper and ACX logs. The well was recompleted with internal coated 4 ½” 12.6 ppf W563 production tubing. In November 2020, the well was shut-down due to suspected tubing leak. A rigless job to verify tubing integrity by means of pressure test (thru an Evo Trieve plug) was performed on November 7th, 2020: test was unsuccessful, tubing leak was confirmed. The Evo Trieve was pull out of the hole and the well handed over back to Production. Scope of this workover is to pull the current ESP tubing completion and recomplete with a new conventional ESP system and coated tubing. The estimated date for beginning this work is December 1st, 2020. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Alessio Medea at 907- 865-3347. Sincerely, Stefano Pierfelici Well Operations Project Manager OP17-02 Workover – Proposal Summary and Wellbore Schematic PTD#: 210-125 Current Status Well OP17-02 is currently shut down due to tubing leak detected after pressure test performed on November 7th, 2020 thru Evo Trieve plug set at 7,700’ MD above discharge gauge sub. Scope of Work Scope of this workover is to pull the current ESP tubing completion and recomplete with a new conventional ESP system and coated tubing. Repair has to be completed with no HSE accidents or incidents, to comply with state AOGCC and company requirements. General Well Info Reservoir Pressure/TVD: The well is expected to have a static max bottom hole pressure of approximately 1,450 psi (3,557 ft TVD) during the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/Blind/VBR/Pipe Well type: Producer TIFL/MIT-IA/MIT-OA: Intermediate 9-5/8” casing was tested to 1500 psi during workover on April 21st, 2020. Estimated start date: December 1st, 2020 Drilling Rig: Nordic Calista Rig 4 Drilling Engineer: Alessio Medea Alessio.medea@eni.com Work: 907-865-3347 Well Operations Project Manager: Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure Summary 1. MURU Nordic Calista Rig 4; 2. Kill the well; 3. Set BPV; 4. N/D X-tree; 5. Set Blanking Plug; 6. N/U BOP and test to 250/3500 psi; 24 hour notice to AOGCC to witness; 7. Pull out of hole Blanking Plug and BPV; 8. POOH tubing and lay down ESP assembly; 9. Perform a contingent clean-out run; 10. MU new ESP assembly and RIH new coated tubing to setting depth; 11. Land hanger and test it; 12. Install BPV; 13. N/D BOP; 14. N/U tubing adapter and X-tree; 15. Pull BPV; 16. Install Two Way Check Valve and test X-tree; 17. Circulate Freeze protect through X-tree down IA; 18. RDMO. Below the current schematic of the well: Vetco Gray, MB-247/5000 psi 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: _ESP Change-out____ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18,200 feet N/A feet true vertical 3,523 feet N/A feet Effective Depth measured 18,040 feet N/A feet true vertical 3,522 feet N/A feet Perforation depth Measured depth 8,505-18,040 feet True Vertical depth 3,557-3,519 feet Tubing (size, grade, measured and true vertical depth)4.5"L-80 7,732' 3,507' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 5/6/2020 Contact Phone: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 -649 8,505' Eni US Operating Co. Inc. OP17-02 measuredPlugs Junk WINJ WAG 73 Water-Bbl MD 160' 18,040' Tubing Pressure ADL 0355024, 0373301, 0391283 2448 Oil-Bbl measured true vertical Packer 212 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-125 50-029-23431-00-00 5. Permit to Drill Number:2. Operator Name N 3. Address: 4. Well Class Before Work: measured 2,249' Size Authorized Signature with date: Authorized Name: Liner 8,505' 3,519' Caliper/ACX Submitted by Halliburton to AOGCC on 4/ 23/2020 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 450 Gas-Mcf 970 2,249' 5.5"9,795' Casing Structural 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-139 230 Representative Daily Average Production or Injection Data 2122079 Casing Pressure Stefano Pierfelici Nikaitchuq Schrader Bluff Oil Pool Conductor Surface Intermediate Production Length 160'20" 13.375" 9.625" TVD 160' 2,170' 3,557' Slotted Burst 5,210 6,890 Slotted Collapse amjad.chaudhry@eni.com 907-865-3379 Senior Engineer: Senior Res. Engineer: 2,480 4,790 Well Operations Project Manager Amjad Chaudhry t Fra O 6. A G L PG , R _ Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:54 pm, May 06, 2020 DSR-5/6/2020MGR10MAY20 SFD 5/7/2020 Surf. Casing 13-3/8", 68 # +/- 2,249' MD, 2,170' TVD 31º Inc. Interm. Casing 9-5/8", 47 # 8,506' MD, 3,557' TVD 87º Inc. 4-½” 12.6 ppf WH563 L80 Production Tubing –TK15-XT Internal Coated Slotted Liner, 5-½” 17 ppf 18,040 MD, 3,522' TVD HAL Zonal Isolation Swell Packers 4-½” cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line Confidential OP17-02 Oil Producer with ESP Lift Nikaitchuq Field – Oliktok Point Pad 7,815' MD, 3,513' TVD, 86º inc.–Bottom of Motor Centralizer, 93 stages 538PSXD Flex47 pump, 513 GSB3DB seals, Gassep, 350 HP MTR562XP Motor, Zenith E7 series sensor, Baker SureTREAT Chem. Inj. Valve 8,265' MD, Baker SLXP Liner Hanger/Packer 5-½” Silver Bullet Ecc. Nose Guide Shoe Completed 23-Apr-2020 Tracer April 2011 Resman Prod Tracer Carrier 7,732' MD, 3,507' TVD, 86º inc.–Discharge Gauge Sub 13-3/8" x 4-½” 5kpsi Tubing Hanger with 4" nom.Type “H” BPV Profile 29' MD/TVD 4-½” Swivel Joint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´FDVLQJVFUDSHUDQGWHVWSDFNHUIURP6,'LQYHQWRU\KDQGOLQJWRROVDQG;2¶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¶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´DQG´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´GULOOSLSHDQGSURFHVV0DNHXSFDVLQJVFUDSHUPDJQHWVDQGVLQJOHLQKROH3XOORXWRIKROHDQGUDFNEDFNSLSHDQGLQVWDOO%DNHU SDFNHUWRUXQLQKROHDQGWHVW´FDVLQJ K6XPPDU\ &RPSOHWH%23WHVWLQJVWDJHGHFRPSOHWLRQHTXLSPHQWRQULJIORRUSXOO%39LQVWDOOODQGLQJMRLQWDQGSXOOWXELQJKDQJHUIUHH3XOORXWRIKROHDQGOD\GRZQ(63FRPSOHWLRQIURP¶WR¶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¶WRµDGGLQJ%3+WR$DQQXOXVDORQJZLWKSLSHGLVSODFHPHQW127( $W¶¶RXWRIKROHLQQHUSLSHVKRZHGODUJHDPRXQWRISLWWLQJ$W¶RXWRIKROHZDVVHHQ%RWKMRLQWVZLOOEHFXW DQGVHQWIRUDQDO\]LQJ :2 / 3 3XPSWXELQJYROXPH#%3036,%ORZGRZQWRSGULYH :2 / 3 3XOORXWRIKROHZLWK(63FRPSOHWLRQIURP¶WR¶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´GULOOSLSHDQGZRUNRQ%23(%OLQGUDPV7HVWUDPVDQGUHWULHYHSOXJ0DNHXS%DNHUFDVLQJVFUDSHUDVVHPEO\DQGUXQLQKROH K6XPPDU\ 3XOORXWRIKROHZLWK(63FRPSOHWLRQDQGOD\GRZQVDPHORDGGULOOSLSHLQSLSHVKHGDQGVWUDSVDPHZKLOHFKDQJLQJUROOHUVRQLURQURXJKQHFNVSLQQHU5LJXSDQGVWDUWWRPDNHXS%DNHUFDVLQJVFUDSHUDVVHPEO\ 7ULHGWRRSHQEOLQGUDPVWRUXQLQKROHDQGRQHVLGHZRXOGQRWRSHQ,QYHVWLJDWHGSUREOHPDQGFDOOHGWRZQIRUFRQVXOWDWLRQ/RDGLQJ´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´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´WHVWSDFNHUDQGUXQLQKROHDQGVHWDW¶7HVW´FDVLQJWRSVLIRUPLQ3XOORXWRIKROHOD\LQJGRZQGULOOSLSH DQGWHVWSDFNHU K6XPPDU\ 3LFNXSGULOOSLSHVHW%DNHU*SOXJDQGUHSDLUHG%23WHVWEOLQGUDPVSXOO*SOXJPDNHXSVFUDSHUDQG5,+WR¶:RUNVFUDSHUXSDQGGRZQQRURWDWLRQWKHQZLWKUSPIURP¶WR¶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¶UHOHDVHGSOXJDQGSXOOHGRXWRIKROHZLWKVDPH :2 0 3 3-600DNHXS%DNHU´FDVLQJVFUDSHU%+$WULSLQKROHWR¶IURPSLSHLQGHUULFNFRQWLQXHWRVLQJOHLQKROHWR¶ :2 0 3 :RUNFDVLQJVFUDSHUXSDQGGRZQIURP¶WR¶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´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´WXELQJZLWK7.LQWHUQDOFRDWLQJ7HVWFDSLOODU\OLQH DQGPDLQWDLQSVLZKLOHUXQQLQJ/RJVDPHRQ%DNHU'DWD5HFRUGHU :2 . 3 5XQLQKROHZLWK(63FRPSOHWLRQRQ´7.LQWHUQDOO\FRDWHGWXELQJIURP¶WR¶0DNHHOHFWULFDOFKHFNVHYHU\ ¶DGGLQJ%3+RI33*EULQHGRZQ´FDVLQJDQGSXPSLQJWXELQJYROXPH%%/6DW¶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´+\GULO,QWHUQDOO\FRDWHGWXELQJDQGODQGRQ9HWFRKDQJHU K6XPPDU\ 0DNHXS(63FRPSOHWLRQDQGUXQLQKROHWR¶ 2SHUDWLRQDW 7HUPLQDWLQJOLQHVDWWXELQJKDQJHU 7LPH/RJ 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 . 3 0DNHXS%DNHU(63FRPSRQHQWVDQGHQVXUHIUHHURWDWLRQRIDOOHTXLSPHQW3XOOFDEOHDQGFDSOLQHWKURXJKVKHDYHVSUHS KDQGOLQJHTXLSPHQWDQGVWDJHFODPSVRQULJIORRU :2 . 3 3HUIRUPHOHFWULFDOFKHFNVRQPRWRU3-60PDNHXSILUVWMRLQWRI´WXELQJZLWK7.LQWHUQDOFRDWLQJ7HVWFDSLOODU\OLQH DQGPDLQWDLQSVLZKLOHUXQQLQJ/RJVDPHRQ%DNHU'DWD5HFRUGHU :2 . 3 5XQLQKROHZLWK(63FRPSOHWLRQRQ´7.LQWHUQDOO\FRDWHGWXELQJIURP¶WR¶0DNHHOHFWULFDOFKHFNVHYHU\ ¶DGGLQJ%3+RI33*EULQHGRZQ´FDVLQJDQGSXPSLQJWXELQJYROXPH%%/6DW¶ :2 . 3 5XQLQKROHZLWK(63FRPSOHWLRQIURP¶WR¶WHVWLQJHOHFWULFDOLQWHJULW\HYHU\¶ILOOLQJ%3+DQGSXPS%%/6 RIEULQHGRZQWXELQJDW%3036, :2 . 3 &RQWLQXHWRUXQLQKROHIURP¶WR¶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o: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log with ACX and Multi Finger Caliper Records: OP 17-02 Run Date: 4/10/2020 210125 32795 April 23, 2020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 OP17-02 Digital Data in LAS format, Digital Log File®C 1 CD Rom RECEIVED GENE APR 2 3 2020 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and Amjad.Chaudhry@eni.com NN/= Date: Signed: 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change out 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18,200 N/A Casing Collapse Structural Conductor Surface 2,270 Intermediate 4,760 Production Liner slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: COMMISSION USE ONLY Authorized Name: slotted Perforation Depth TVD (ft): Tubing Size: 18,040 3,522 N/A913 2,249 154 2,170 Size 154 154 Tubing Grade: Tubing MD (ft): 3,557-3,519 Amjad Chaudhry L-80 7,839 907-865-3379 Stefano Pierfelici Well Operations Project Manager amjad.chaudhry@eni.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 355024, 373301, 391283 OP17-02 210-125 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23431-00 Eni US Operating Co. Inc. N/A Nikaitchuq Schrader Bluff Pool 3,523 PRESENT WELL CONDITION SUMMARY TVD BurstMDLength 6,870 5,020 20" 13-3/8" 9-5/8" 5-1/2" 8,505 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 3,5578,505 2,249 Authorized Signature: April 10th, 2020 18,0409,795 4-1/2" 3,519 Perforation Depth MD (ft): 8,505-18,040 Perforate Repair Wepair Well Exploratory StratigraphicDevelopment Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval.Submit Form and Attachments in Duplicate On behalf of PT02627 03/26/2020 By Samantha Carlisle at 8:53 am, Mar 27, 2020 320-139 10-404 DSR-3/31/2020 ADL- -00 BOPE test to 3500 psi. SFD 3/27/2020MGR02APR20GWV ion Required? Yes N V 4/2/2020 JLC 4/2/2020 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.Pierfelici@eni.com March 26th, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RRE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP17-02. OP17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888’ MD. The ESP failed again due to electrical fault on 8/13/11 after facilities shut-down and was recompleted on September 5, 2011. The ESP failed again in July 8, 2013 recompleted on July 21st, 2013 and put back on production, WO was performed in April 2018 and TTC-ESP was swapped upgrade with a new conventional ESP system to increase production. A suspected ESP failure has occurred in April 2019 and WO was performed in May 2019 for an ESP swap. Currently well is down because of a suspected tubing leak. Plan is to pull tubing and ESP and run a new ESP completion. The estimated date for beginning this work is April 10th, 2020. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager OP17-02 Workover –Summary Page OP17-02 Rig Workover PTD#: 210-125 Current Status Well OP17-02 is currently shut down because of suspected tubing leak. Scope of Work Scope of this workover is to pull the current ESP tubing completion and swap with a new tubing and conventional ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 3,519’TVD. This well is expected to have a static maximum bottom hole pressure of approximately 1,300 psi during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/Blind Shear/2-7/8” x 5” VBR/4-1/2” Pipe TIFL/MIT-IA/MIT-OA:Intermediate csg 9 5/8” was tested to 2000 psi for 30 minutes on April 11, 2018. Well type: Producer Estimated start date: April 10 th 2020 Drilling rig: Nordic 4 Completion Engineer: Carlos Monteiro carlos.monteiro@eni.com Work: 907-865-3345 Sr. Drilling Engineer: Amjad Chaudhry amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Stefano Pierfelici: Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure: 1. MIRU Nordic 4. 2. R/U on x-tree to pump down tubing. 3. Perform well killing by pumping down tubing and annulus with 8.8 ppg 3% KCl/NaCl brine. 4. Ensure well is killed. 5. Set BPV. Nipple down X-mas tree and Nipple up BOP and test to 3500 psi. 6. POOH and lay down ESP assembly. 7. RIH scrapper & magnets for well conditioning (CONTINGENCY). 8. MU new ESP assembly and RIH to depth. 9. Land hanger, and test it. 10. Install BPV and nipple down BOP. 11. Nipple up tubing adapter and tree. 12. Pull BPV, install test plug and test tree (5000 psi test) 13. Circulate Freeze protect through tree down annulus A. 14. Shut in well. 15. RDMO. Below the current schematic of the well: 24 hour notice for AOGCC to witness BOPE test. Updated: 2/28/18Revision: 7Updated By: BWRig #4 Flowpath DiagramPIPE RAMS BLIND/SHEAR RAMS VBR RAMS BUFFER TANK MM 7 MM 8 MM 9 MM 6 MM 5 MM 2 MM 4 MUD GAS SEPERATOR SHAKER #2 SHAKER #1 ANNULAR MM 1 MM 10 MM 3 MM 14 PLUG VALVE CUTTINGS BOX MM 11 MM 12 SPARE CIRC LINE MM 13 FILL UP LINE FV -1 2" STAND PIPE 2" BLEEDER TO PITS TOP DRIVE GAUGE TREE CAPPED AT END 3" 5,000 PSI WP KILL LINE CM1 CM2 CM3 CM4 CM5 CM6 CM7 CM8 CM9 CM10 CM11 CM12 CM13 CM14 CM15 MANUAL CHOKE CM16 REMOTE ACTUATED MP 2 MM 15 MANUAL CHOKE MM GA 1 MM GA 2 MM SN 1 MM SN 2 SN 1 SN 2 CM GA 1 FLOW BACK TANK UKC (ACTUATED) LKC (MANUAL) TO MGS TO SHAKER MP 1 OPEN PORT CAPPED 3-1/8" 5,000 PSI WP CHOKE MANIFOLD Drilling Riser: 13-5M Flange x Hub KILL HCR INSIDE KILL CHOKE HCR MANUAL CHOKE 3" 5,000 PSI WP CHOKE LINE DV -1 SP -1 CV -1 FB -1 12" Flow line 8" vent line 20' long PRV 1 Pit 4 PRV 2 Pit 4 Spacer Spool: 13-5M Flange x Flange Rig Nordic #4 Well OP-18 Stack measurements Note: To be confirmed when rigged up Top Flange Upper Lock Down Screws Rotary Table 8’ 5” 13’ 2” 14’ 3” 34’ to GL (Nordic Rig 4 RKB 33.5’ + 6” mats) 24’ 9” 25’ 3” 29.5” 85” RISER 16’ 4” Projected KILL LINE CHOKE LINE TOP OF WELL HOUSE 13’ 10” to GL Draft 09-28-18 4-1/2” pipe rams 2-7/8” x 5” VBR rams STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !'lAl 11 9p19 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Li Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: _ESP Change -out ❑✓ 2. Operator Eni US Operating Co. Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic ❑ Service ❑ 210-125 3. Address: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 6. API Number: 99503 50-029-23431-00.00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0355024, 0373301, 0391283, OP17-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Caliper and ACX (submitted by HES and received by AOGCC on 06/03/2019) Nikaitchug Schrader Bluff Oil Pool 11. Present Well Condition Summary: Total Depth measured 19146 feet Plugs measured N/A feet true vertical 3559 feel Junk measured N/A feet Effective Depth measured 19136 feet Packer measured N/A feet true vertical 3560 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 160 Surface 2,249 13.375" 2,249 2,170 5,210 2,480 Intermediate 8,505 9.625" 8,505 3,557 6,890 4,790 Production Liner 9,795 5.5' 18,040 3,519 Slotted Slotted Perforation depth Measured depth 8,505-18,040 feet True Vertical depth 3,557-3,519 feet Tubing (size, grade, measured and true vertical depth) 4.5 L80 7,839 3,513 Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 972 87 11998 1199 1203 Subsequent to operation: 1431 61 12345 123 1200 14. Attachments (required per 20 Anc 25.070,25.o71, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ✓ Gas LJ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ Sundry N 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.umber or N/A if C.O. Exe l"1-230 Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Project Ma a er Contact Email: anad.chaudhrvrom..rn Authorized Signature: Date: Contact Phone: Form 10-404 Revised 4/2017—/- /2017[% RgDMSC' JUN 13 2019 Submit Original Only �f /d/� Surf. Casing 13-3/8", 68 # +/- 2,249' MD, 2,170' TVD 31° Inc. Item MD (ft) Tracer Sub #1 16,601 Tracer Sub #2 15,330 Tracer Sub #3 13,911 Tracer Sub #4 12,793 Tracer Sub #5 11,826 Tracer Sub #6 11,018 Tracer Sub #7 9,500 Tracer Sub #8 8,501 Nikaitchuq Field — Oliktok Point Pad Tubing hanger with 4" nom. Type "H" BPV Profile. Pup joint 4.5" WH563 pin x IBT pin #12.6 4-'/z' 12.6 ppf, L-80 Hydril-563 Production Tubing 4-'/2" cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line e n o us opera t�rnng OP17-02 Oil Producer with ESP Lift 7839' MD, 3513' TVD, 85.6° inc. - Discharge Gauge Sub As Completed 5/22/2019 Tracer April 2011 7925' MD, 3521' TVD, 860 inc.— Bottom of Motor Centralizer 93 -stage 538PSXD Flex47 pump, 513 GSB3DB seals, Gassep, 350 HP MTR562XP Motor, Zenith E7 series sensor 8,265' MD, Baker SLXP Liner Hanger/Packer Interm. Casing 9-5/8", 47 # 8,506' MD, 3,557' TVD 87° Inc. Confidential HAL Zonal Isolation Swell Packers Resman Prod Tracer Carrier 5 '/2' Silver Bullet Ecc. Nose Guide Shoe Slotted Liner, 5-'/2" 17 ppf 18,040 MD, 3,522' TVD Well Name: OR Wellbore Name: me: OPI OP17A2 Well Code: 25097 Job: WORKOVER ani WCERLevel: Daily Report Date: 5/16/2019 Report #: 1 Page: 1 of 2 Well Header P..WConcessi= N' operator SubsMiary Inldal /afros Code ADL -3911503 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation (d7 Level (N) First Flange (ft) RKB -Base Flange un RKS-TUMng Spam (in Johnson 53.28 12.20 21.48 31.70 32.36 Rigs inName COMuCtar Rig Tyke Rig Num Rig Start Data Rig Release Date RIG 4 NORDIC CALISTA LAND RIG 0981 5/1412019 Daily Information weamer Temperature(•F) Wind oaya LTlldaysi Days Rl(days) Poe .outly 284 NE ®36 MPH 50.0 Safety Incidents - Near Miss Date Category Subtype Severity Cause Lost time? Comment Safety Drills Days Undl Next Check Type Aoccur Lail Data Next Date (days) Rig Inspection 1 511612019 5/1712019 1 Safely Meeting 1 511612019 5/1]/2019 1 Casings seat Cas. Type Do (in) ID (in) Grade Top (ftl i Bottom (ftKB) TVD BOL fftKBI I Run Date CONDUCTOR 20 18.25 %65 3].1 ifi1.0 1610 101312010 CASING 13318 1242 L80 -2,1]5.2 2,249.5 2.1699 11/12010 CASING 9 A 868 L-80 36.0 6,5058 3.55)0 11/122010 LINER 51/2 LSO -11,093.9 18,030.0 3,483.8 12/14/2010 Last Cementing Lemmdng Start Oale: 11/12/2010 S[drq: CASING, 8,505.6flKB Comment SCgu pumps psi.-ce \ Pump 70 DI10.5 MudWs6Ii\Drop linestoDeep ks)bix p30H2O8test kyi 5,17 plug Birch mix 8 pump 300 Crate cement (1095 aks) 1.54 ft3hk mu fluid ®, Batch 0112.5 p5 iDeep nt 812 Mils, of 91 cement of 9 Dray top plug 1 Schlumberger pump 5 bras. H2O for wes650 1 Rig Dump displace cement par Bump plug to 1150 psi. (500 pea. mud @ 85 bpm, ICP 142 psi. -slow pump tele to 3 bpm fl psi. in 600 to 1 pollgaVA.%mu flows realmihmug6p withsomealight war check Home-ighlF \ Tact p over FCA®6500her\ Untar5mingles-bleedoftr nFa losa.l 1810 firs \ Land manger and didn't redpromtetl due b High Frk1bn Factors (K&M)- Up x1=290K Do 5K s w1.= 85K. Estimated lop IN mmeM 5400'. Stgn Top(ftKB)Top Meas Meth elm (ftKB) Cord 1 35.0 Volume CalculationsI 505.6 1vurrip cement 1000'+ alcove me N -sand 15400'1 for zonal caldron affirmation. Job Information Jab Phase Plannetl start Date Shit Dale End Data P50 Duration (days) WORKOVER 5115201912:00 5/16201912.00 800 _ Daily Summary Operations 24h Forecast Complete the leak detect program with Hallibcton E Am by puling the 4.5 Evo-Tdeve from 7800'. Move Nomic 4 over OP17-02 and prep to perform the RWO. Idh Summary Norl 4 released from Opt 0-09 at 12:00. Preparations for rig move to OP17-02. of aradon At 9"90 Prep for Rig Move to OP17-02 Time Log Start End Cum our Time Time Dur(hr) MI Phase Dor. Act. Plan Doer. Deacr. 1200 Do Do 12.00 12.00I.. 1 P Nordic 4 was released from 1`100.09 at 12:00. Begin instructions fes rig move to OPV-02Conduct a PJSM with ENI Safely, ENI Operations. Noo is 4 case, Jacobs Crane operates and rgger. Perform 5 picks to re-aneitge the spools on the ng JA floor to pull IM1e 4S' ESP Completion on OP17-02.Clean and dear dg poor, shaker roam, and pipe shed in preparation for ng Gas Readings Avg Background Gas l%) Max Background Gas l°/) Avg Connection Gas Max Connection Gas l%1 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Mae Trip Gas (°41 Cumulative Mud Volumes Active Volume(bM) Hole Volume (but Addifimu(bbl) Cum Addition(John) Losses (boll Cum Losses lbbll Daily Contacts Position Contac], Name Company I Tide I Email mice Mobile Ent representative Russ Wimmer En -6650]15 9W-320-0058 Ent representative Chad Guem Ent Ddling Sup. star OPPdnIMg@eni.com Eni representalNe Wade Thomas Ent Rig Clerk 907485.0122 Eni representative Mike Delp Em HSE Tool Push Richard! Teredt Nomic Taal Pusher Tool Push Al Hensen Nordic Tour Pusher ngmanagerng4@noNbmnsta.com 907-670-8804 Tod Push Mark Herod Nomic Nordic 4 HSE Personnel Log (P( B) Company Sam. Type Wars H(hr) Stand4ry H fin Count Note BHGE (Netto) Wellhead 1250 1 12.5 Hours Mi Swam Mud .,inner 12.50 1 12.5 Hours ASRO Company Men 12.50 2 25 Hours Wali. Tredor 12.50 2 25 Hours BHGE (CaMnlifl) ESP 12.50 3 75 Hou. GBR Tubular ironing 12.50 3 37.5 Hours Halllbuno l Slick Line 12.50 4 506mrs LRS Pumping 12.50 5 62.6 Hours Jamba Equipment Operators 12.50 8 100 Hours Nordic Nordic Personnel 12.50 21 262.5 Hours BOP Stack B Components Description start Data Last C.mw.tion Data Pressure Ratio, (cal) Type Make Model ID Nom (in) PRango(psi) Last Cart Ddto Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5/16/2019 Report #: 1 Page: 2 of 2 Slow Circulation Rates Pump Number: Make: Mali Start Date Entl Dale Llner Sire (in) Volume Per Stroke Override(bbllak) Max Pressure (psi) Date DeDIM1 IKKRI $low Spd Strauss (am) P (Psi) EM (%i O Flow /ppm) Daffy Bulk Supply Item Descripdon: Equipment Fuel Unit Label: gal us Unit Sire: Note: Dote Consumetl Received Returned Cum Consumed I Cum Received Cum Returned Co. On Loc Note Supply Item Dascriptlon: Rig FuelUnit Label: gal us Unit Size: Nom: ate Consumed ReceWeE Returned Cum Consumetl Cum ReceNetl Cum Returned Cum On Loc Note Supply Item 11me rlplem: Rlg Water Unit Label: bbl Unit Sire: Note: DaK Consumed Rscelvetl Returned Cum Consumetl Cum Recelved Cum Returned Cum On Loc Note Last AUtbonty Visit Data Tar /rep. Nbr Total I.N.C. number Comment STOP Cards Submitted gomaany Y Rale Com NORDIC-CFLISTN SERVICES 3 1 PJSM General Notes Comment:- Well Name: OP17-02 OR I�iE Wellbore Name: OP17-02 PMTS Well Code: 25097 II Job: WORKOVER er�II11 WCER Level: Daily Report Date: 5/17/2019 Report #: 2 Page: 1 of 2 Well Header ParmltlCon,east.. N° Operator Subsidiary Inmel LaM1ee Code ADL -388583 ENIPETROLEUM ENIPelmleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation(R) Ground Level (of First Flange (R) .5 -Base Flange(Rl KKB Tubing "Pam (m) 5326 1220 2108 31.]8 32.36 Rigs Rio Name Contractor Rig Type Rig Num RIg Sbrt Dam Rig Release Doh RIG4 NORDIC CAUSTA LAND RIG 0981 5/14'2019 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 302 E 11141 MPH 50.0 Safety Incidents - Near Miss Dale category Type Subtype Severity Cause Lost bmel Comment Safety Drills Days UntilNext Check Type 0Occur Last Date Next Date (days) Rgaton 2 511 P2019 5/18/2018 t Safen,MMeeasating 2 SIRI2019 5/1812019 1 Casings seat Cas. Type OD(in) 1 to (in) Grade Top (111148) Bottom (Most TVD But(RKB) Run Data CONDUCTOR 20 18.25 Xfi5 3].1 1610 1610 101312010 CASING 13318 1242 I. -2,1]5.2 2,248.5 21699 11112010 CASING 9518 868 L40 3fi.0 8,505.8 3.55].0 11/12J2010 LINER 512 LBO -11,093.9 18,030.0 3,4fi3.912J142010 Last Cementing Cementing StartDab: 11/122010 String: CASING, 8,505.6RKB Comment: Schlumbeger pump 5 bbls. H2 & lest lines to 3000 poi. - OK %Pump 70 bbl.. of LOS p,Wdpu.h II Qnop bottom plug \ Balch mix & pump 300 tibia. of 12.5 ppg Deep Crete cement (1095 aka)1.54 R3hk yield with mix fluid ® 5.177 ga#.k.\ Drop top plug \ Schlumberger pump 5 bbl. H2O ler washap %Rig pump displace cement will 612Idea. of 9.1 arg Mud Q 6.5 bpm. ICP 142 psi. - slow pump rete to 3 bpm It 650 psi. @ 600 bbls I Bump plug to 1150 psi. (9)(101. weir FCP ® 650 psi.) k Hol for 5 minutes - bleed off & check goal - hoom; k Good Ilium through with sane slight loss.\ CIP ® 1810 hrs.1 Land hanger and dldn3 reciprocated due to High Friction FrA as ("M)- Up w1= 290K- Dn w1= 85K. Estimated top of cement 5400'. Stg# Top(Rol) Top Meas Meth B1m (fucB) Can 1 3fi0 Voiume Calculations 8,505.8 Pump cement 1069', above the N-sand(5400)forzonal isolation offormalion. Job Information Job Phase Plenmtl Start Date Start Date End Date P50Duretion(do") WORKOVER 5116201912:00 SI16201912:00 0.00 Daily Summary Operations 24h Forecast Complete Ne leak detect program with He imp on E line by pulling the 4.V Evo-Tmwe from 7WIT, Move Nods, 4 oar OP17-02 and prep to perform Me RWO. fall wind speed t0 ensure Me a ufly to perform came operatscm, 24h Summary Hailibumm E tine h unable to dg up due to high winds ranging from 3"6 mph, monitor the wind speeds coach. A 4.5- Ev Tm ve Is set In the robing at 7800. Nordic 4 is prepping the rig to move onto OP1T-02 once Elms has pulled the Evo-Triave Plug. Pull Nordic 4 away from OP10-02 and stage Me d9 on single rig mats. Clean Me dg and complete the welding on the pits and all monthly inspections. Install the annulus A piping spool and verify that 09 well is wmphbd on surface to perform the wallp own with production CPS Operation .1 07.00 Prep for Rig Move to OP1 7-02, perform rig maintenance, general housekeeping. Time Log Sure End Co. Dur Time Time Dur Mr) on Phase opo Act. Plan Opal. Deacr. 00:00 1000 1000 1000 MOB A 1 P Commus housekeeping on the rig. service the pipe skate, lube the chains, and perform a safety walk down in Ile pita for confined space entry. Complete the asking on pd t & 2 equalization valves and verify all is in working order. 1000 1430 4.50 14.50 MOB A 2 P Conduct a PJSM with all of the Ni 4 crew and prep the rig to walk out awry from OPI0.02 ant remove the double stacked rip mats. Rig dawn the wrongs box and begin movinglbe 49 in the southern direction away from the OPt0G2. Moved Nordic 4 swth of the wellbays 34 bet and prep W remove all the double stacked mats enca away ham me ENI -and 1430 2000 5.50 2000 MOB A 1 P Remove all the double moved rig mats and adty ail is Gear of all stmclures. Nordic 4 is now an 1 layer of dg mats ready to move west to OP17I . Clean up the area of all wcetl splinters from rul the dg and verify all Is ready to move the rig to OP17-02. 2000 2200 200 22.00 MOB C 5 P Conduct a PJSM with ENI Production, Nartlic 4 crew, ENI safety and ENI comp in, man to instill the annulus A flange an OP10-02 to return the well to normal operating parameters. Pressure test the annulus A spool to 115 psi of a8 pressure and -stwD the connections. Good test. 2200'. 00:00 2.00 24.00 MOB A 1 P Continue all M1ousekeeping and monthly inspections on all wugment mr Non is 4. Smm lost b hole - Last 24 hwrs (midnight) 0 BBL Brine lost to hole - Total (midnight) 0 BSL Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Comecdon Gas (%) Avg Drill Gas (%) Max ONII Gas (%) An Trip Gas (%) Max Trop as (%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bli Additions (but Cum Additions( bbl) Lasses(bbl) Cum Losses(bbl) Daily Contacts Posltbn Contact Name Company TNI. Email office Mobile Ere representative Russ Wimmer Eni Dnlling Sup, OPPtlrilingen com 90]E85-0115 907-3200058 Ent repasenbtrre Chad Gueco Ent Drilling Supervisor OPPdrilling(eni.win Ent representative Wade Thomas Em Rig CIeIX WIN0110722 Ent mpresental MIX. Gap Ent HSE Tool Push Richard Tanut North. Tool Pusher Ted Push At Hen... Nokk Tpur Pusher Ogmmm,etrig4®nohic-caliata.com 90]46]0-8604 Tod Push Mark Honest Nordic Notoc 4 HSE Personnel Log (POB) company Sam. Type work H (Irl Stand-by H (brl I count Nota al (Vance) heatl 12.50 1 12.5 Nours NO Sam. T-d engineer 12.50 1 12.5 Hours ASRC o._Men 1256 2 25 Hours We 0 1250 2 25 Hours Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5117/2019 ReportN: 2 Page: 2 of 2 Personnel Log (POB) Company I Sam. Type Warn H (hr) Stand-by H (hr) Count Note S G ( eft//') GBR Halliburton LRS Jacobs Nordic ..12M Tubular running Sndc Line P.myirg Equipment ope ekes Nord. Personnel 12.50 12.50 12 50 1250 12.50 3 3 4 5 6 21 75 Hours 37.5 Houm SO hours 62.5 Hours 100 Hours 262.5 Hours BOP Stack & Components Description Stan Date Last certification Date press... Rating(pal) TyPe Make Model ID Nom lin)1 PRange Joel) Last Cert Date STOW Circulation Rates Pump Number: Make: Model: ten Date End Date Liner Size (in) Volume Per Stmne Ovenide (bbllatld Mae PressIme Ual) Data DepIM1 (NK.) Slow Spd Stakes(apm) P(psi) OFlow (gpml Daily Bulk Saintly item oesctlptlon: Equipment Fuel Unit Labal: gal us Unit Size: Note: Date ConsumedRCcelVed 511712019 ]99.0 399.0 Returned Cum Caneumetl Cum Received ]990 399.0 Cum ReWmetl cum On Loc Note 0.0 00 Sopply Item DescdpenFuel ti: Rlg Unit Lotsl: gal us Unit Size: Note: Date Consumetl Recefvetl 511712019 fi000 0.0 Returned Cum canaume0 Cum Received fi00.0 0.0 Cum assumed Cum On Loc Note OO -000.0 8upp1 Item D...dption: Rig Water Unit Label: bbl Unit Size: Note: Date Consumed NCc.lved 511 N2019 5D 0.0 Returned Cum Consumed Cum R...iV.d n.i 0.0 Cum Returned Cum On Loc Note c 5.11 Last Aurbonry Visit Date Tot map. Nb. Total LN.C. number Comment STOP Cards Submitted ComWny a Ras Com NORDIC-ChLI TA SERVICES 3 PJSM Gwent Notes Comment Well Name:OR Wellbore Name: me: OP1 OP17-0-02 Well Code: 25097 nn Job: WORKOVER s- n 0 WCER Level: Daily Report Date: 5/1812019 Reportft: 3 Page: 1 of 2 Well Header PenmttlCodcember, N° Operator Sehsldlary Initial Lahee code ADL -388583 ENI PETROLEUM ENI Pdrokum Go. Inc. DEVELOPMENT WELL Rotary Table Elevated. JM Ground Level (n) Fort Frange 1-1 RNB-Base Flange,r) B -Tubing Spool(k) ion 53.26 12.20 21.48 3178 32.36 Rigs Poe Name Conitacbr Rig Type Rig Num Rig Skirt Data Rig Release Date RIGS NORDIC CALIBTA LAND RIG 0981 51142018 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 28.4 HE @ 25 MPH 50.0 Safety Incidents - Near Miss Date Category Type Subtype Saystity cause Lost fire] Comment Safety Drills Days UPS1 Next Check Type aOccur "at Date Next Date (days) Rig Inspection 3 5/1812019 5)1912019 1 Safely Meeting 3 511812019 511912019 1 Casings seat Cas.Type OD(ia) ID (in) Grade Top(ftKB) Bottom(eKB) Too Bot(ftKB) Run Data CONDUCTOR 20 1825 Xfi5 3].1 161.0 161.0 ID(JV2010 CASING 13318 1242 L80 -2,1]5.2 2,249.5 2,1fi9.9 i1/120ID CASING 9518 868 L-80 38.0 0,505.6 3.55].0 11/122010 LINER 512 180 -11,093.9 18.030.0 3,463.8121142010 Last Cementing Cumepteng StartDate: 11112/2010 Stripe CASING. 006AMS Comment ScIfiflumber,er pump 5 bbk. H2O 8 test lines k 3000 psi. - OK t Pump 70 bbis. d 10.5 ppg Mutlpush II \temp bottom plug 1 Balch mix S pump 300 bbis. d 12.5 ppg Deep Crete cement (1095 sks) l.541131sk yield with mix fluid ®5.lP gaVsk \ Drop top plug t Sch umberger pump 5 bbis. H2O krwash-up %Rg pump displace cement with 612 bbis. of 8.1 ppg mud @ 6.5 bpm, ICP 142 on. - slow pump mk to 3 bpm ® 650 psi. @ 600 We t Bump plug to 1150 psi. (500 psi. ver FOP ® 650 psi.) t Held for 5 minutes - hiked oft 0 check floats - holding \ Good relwd through with some slight less.\ CIP @ 1810 hrst Land hanger and didn't mipeocated due to High Frklkn Factors (KSM) - Up cal = 290- Da wt.- 85K. Estimated top of cement 5400'. Big E. Top(NKBI Top Meas Mark Ban IN(BI Com 1 .0 Volume Calculations B505.6 Pumpcement 1000'+aboveme N -sand 15400'Iforzonal lsolationolmmmumn. Job Information Job Phase Planned Start Data Shirt Dale Ead Dale P50 Duradon (days) WORKOVER Sn8201912 on 5116201912:00 000 Daily Summary Operations 241a Forecast Move Nordic 4 on OP17-02 and dg up b perform Me well IMI operations.1411 Me waft with 9.3 post brine by Pumping a volume of 150 bar down Me tubing and 600 the down Me annulus A. Instal a SW in Me Ndng hanger via SHOE Veldt Gay and nipple down the X Vee. Install a blade ng plug in the ba rg hanger add nipple up the Nom, SOPEa, Begin the DOPE teal with the 4 W alb S testjoins, are per pahcy and procedure 24h Summary Prep the rig and location to move Me ng an 0917-02. The empty ESP sydd was lifted via Jacobs crane and set In on the rig Mm spotter to ensure all is Prepped as pull Me ESP completion in OP17-02. The Energy Isolation Procedure was completed with iha Nordic 4 To /pusher, ENI Operafimvs, ENI Safety and ENO Company Mon. The pad was prepped for Nordic 4 to move and Me companion and blank flanges were installed on Ne annulus A after the piping spool was removed along with the re -spotting of the cuffings box and Neer lank. OperaBon at 07.00 Rig Move Openvons to OP17-02 Time Log start End Cum Dar Time Time Dur Mr) (br) Phase Opt. Act Plan Open. Defier. 0000 1200 12.00 12.00 NAB A 1 P Nordic 4crew continued W prep Ma dg to move onto OP17- 2 and all monthly meatuma x:e checks were completed The C- 15 diesel fuel lank was Med and Me welding in the pts was continued on Me equalization valves. Load the pipe shed with the landing joint and clean area to begin loading Me pipe shed. 1200 2000 800 20.00 MOB A 1 P NeNic 4 crew continuing to prep to move the ng an OPt7-02. meele all modern, maintenance. 2000 21:00 1 00 21 00 MOB A 1 P Take dawn all berms on Me cuffings tank and Me tiger lank in preparation to move the tanks. Communicate with Me Spy Island Drill Site company man and tack pusher to mobilize 2 stand roll trucks to OPP to move Me Links. 2100 22:30 1.50 22.50 MOB A 2 P Conduct a PJSM with Nordic 4 dew, Ent Sa ty. ENI Operations, Flat bad tack drivers. Jacobs crane crew and ENI company and identify all hazard. to move Me cubing lank and tiger tank with the flat bed butte, along with Me reviewing of Me IM Men and permhling to complete the &pool Oft to enable Nordic 4 to be prepped for the polMg of Me ESP completion. Move the curing lank and stage the tiger tank SO' farm the OP17-02 wellhead amt build herrn for both tanks. Confirm Me wend speeds are 2236 mph with ENI safety and conduct Me final e,0 to eel the empty ESP spool in Me spooling taken h rig floor. 22:30 00:00 1.50 24 00 MOB A 1 P Conduct a PJSM to lay out the herculde antl ne mets in font of OP17-02 to begin the Nordic 4 be move. Lay dawn the hemulits finer In front of OP17-02 and begin laying the 14 rig mats needed to deverthe herouMe fast. Brine Inst to hole - Lest 24 hours (midnight)0 BBL Bane lost b hole - Total (mmnlghp 0 BBL Gas Readings Avg Background Gas I%) Mex Background Gas (%) Avg Connection Gas I%) Mea ...."No Gas i%) Avg Drill Gas (%) Max Drill use l%) Avg Trip Gas (%) Max Trip Gas l%I Cumulative Mud Volumes Active Volume (ball Hole Volume (bbl) Atttendans (bM) Co. Additions (bM) Losses Ibbl) Cum Losses (bbl) Daily Contacts Position Contact Name Company Title Enall Deice Mobile Em depresenlredve Russ Wimmer Eni Onllifig Supv. OPPdrilling®eni.com 807485.OTi5 900 -Rte -0058 Ed representative Chad Go. Ent Drilling Supervisor OPPdnlling@enscom Enl repreaentaiive Wade Thomas End Rig Clerk 907485-0722 Eni rep entafive Mike Dab Edi HSE Tool Push Richard Tweot Nordic Tool Pusher Tod Push At Hansen Nordic Tour Pusher rgmanageedg46donic-deistecam 907470-8604 Tod Push Mark Herbst Needle Nordic 4 HSE Personnel Log (POB) Company Be,. Type I Week IN Mr) I S1and4ry H(hrl 1 Crud Note BNGE (Vdco) WeIlM1eatl 125 1 12.5 Hours Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5118/2019 Report #: 3 Page: 2 of 2 Personnel Log (POB) Company Sew. Type Work H Ibn Standby H (IR) Count Note MI Sweet, ASRC Walden BHGE(Certfill) GBR Halllnurtut LRS Jamba Nordic Mudenginear Company Men Tractor ESP Tu alar running Slick Line Pumping Equipment Opeabra Nordic Personnel 12.50 1250 12.50 1250 12.50 12.50 12.50 12.50 12.50 1 2 2 3 3 4 5 B 21 125 Houm 25 Hours 25 Home 75 Houn 37.5 Hours 50 boure 62.5 Noun 100 Hours 262.5 Home BOP Stack & Components Description Sart Data "at Certification Data Pressure Rating (psi) Type Make Model ID No. (in) P Range (pa0 Last CeH Daa Slow Circulation Rates Pump Number: Make: Model Start Date End Date Liner Sim (in) Volume Per Stmkc Override (bbllstk) Max Pressure (Pei) Date Depth (INKS) Slow Spit Spoke.(apm) P(Pit I Ee(%) OFt. (gpm) Daily Bulk Supply lam Description: Equipment Fuel Unit Label: gal us Unit St.: Note: Date Consumetl Received 51182019 3259 32fi.o Remrnetl Cum Consumetl 125.0 Cum It .n ISE Cum Returned Cum On Loc Note 0.0 0.0 Supply Item Desatlptlon: Rig Fuel ----Cumed Unit Label: gal us unit Size: Note: DTW Receivetl SI'to.'s SItS.0 0.0 Reametl Cum Consumetl 1.00.0 Cum Receded 0.0 Cum Returnetl Cum On Loc Note 00 -1,400.0 Supply lam Descdp5on: Rig Wear Unit Label: bbl unit Size: Note: Case Consumetl Receivetl 611&2018 5.0 0.0 Returned Cum C.m.to ed 10.0 Cum Received 0.0 Cum Retumetl Cum On Loc Note 00 -10.0 Last Authority Visit Dare Tptaap. Nor Total I.N.C. number Comment STOP Cardsu miffed Company NRpa Com NORDIGCALI TA SERVICES 3 PJSM General Notes Comment Well Name:OR Wellbore Name: me: OP1 OP17-0-02 Well Code: 25097 �a ee Job: WORKOVER e 11II WCER Level: Daily Report Date: 5/19/2019 Reportp: 4 Page: 1 of 2 Well Header PermuConcession N. Operates subsidiary Initial Lahas Code AOL -308583 ENI PETROLEUM ENI PeUoleum Co. Inc. DEVELOPMENT WELL Rotary Tables Elevation (ft) Gourd Level (ft) First Flange (h) RKB-Base flango to) RKB - Tubing Spool in) 53 28 12.20 2148 31 ]8 32.36 Rigs Rle Name Contractor Wg Type 9Num Rig Start Data Rig Release Date I.S. RIG 0 NORDIC CAUSTA LAND RIG 51142019 Daily Information Weather Txnperature(-F) Wind Days LTI(do") Days RI (days) 1,06 Cloudy 30.2 NE ® 17 MPH 50.0 Safety Incidents - Near Miss Gate Category Type Subtype Severtly cause Lost time? Comment Safety Drills Days Until Neat Check Type NOccur Last Date Next Date (days) Rig Inspection 4 5/192019 520201 1 Se"Meefing 4 5/1912019 520/2019 i Casings seat Cos. Type OD (in) to (in) Grade To, HtKB) Bottom(ftKB) TVD Bot(ftKB) Run Data CONDUCTOR 18.25 X65 3].1 161.0 161.0 10812O,u CASING 18 1338 12.42 L80 -2,1]5.2 2,249.5 2,169.9 11112010 CASING 9518 B.fiB L-00 36.0 0,50Sfi 3,55].0 11/122010 LINER 5112 180 -11.0939 16,030.0 3,483.912/142010 Last Cementing Cementing Slort Date: 11/122010 String; CASING, 8,5G5BftKB Comment Sehiumberger pump 5 bbis. H2O 0 test lines to 3000 psi. - OK \ Pump 70 able. of 10.5 DD9 MuOPueh II \pop boftom plug \ Batch mix 8 pump 300 bbls. of 12.5 ppg Deep Cress Gement (1095 sail 1.54 ft3ftk yieM with mix fluid @ 5.177 gaVsk\ Drop top plug \ Schlumbeger Pump 5 bbis. H2O forwashruD \ Rig pump displace cement with 612 bass. of 9.1 M mud ® 6.5 bpm, ICP 142 pal. - slow pump late to 3 bon ® 650 psi. @600 hots \ Bump plug la 1150 psi. (500 pill. over FCP @ 650 psi.) \ Hold for 5 minutes- bleed off 8 check Both - holding 1 Goad realm though with some slight bas.\ CIP @ 1810 hrs.\ Land hanger and da,10 reop axased due to High Friction Factors PJAI)- Up M= 290K- on va= 6SK. Estimated tap of cement 54001 Bigg Top O KB) Top Meas Meth Bhn (MB) I Cam 1 36.0 VOIume Calculations 6, Pump cement 1000'+ above Me N-eand(MOO') for zonal isolation of famencen. Job InfOrmadOn Job Phase Planned Slort Date StuartDate te End Date PSO Duration(days) M. WORKOVER 5/16201912: Be 511620191200 Daily Summary Operations 24n Forecast Complete Me BOPS test We per poiiry and provcadure to 3500 psi wdb the 45- test pint. Install Me landing /Cunt back out the lock down screws and unseat the tubing hanger on the 4.5- ESP completion. Begin pulling Me ESP completion while monitoring the damaged tubing taming Out of the hole. Acetate Me damaged joint with the known hole at 672 +1- and ward, Me damaged area is col into 3 pieces and seat 0 the reluastetl Imsom. hom Me ENI management. 24h Summery Move Nordic 4 onto OP17A and set up all the plywWe at the walkway base to ensure sufficient coverage. Begin bleeding aft all the gas Rom Me tubing and annulus A prior to performing the MII Tracodum, Build Me berms around Me tiger aims! oft kink and the causes fox and have ACS inspect Me berms. Lead the pile with 9.3 pD9 thine and prep to IW OP17-02.1411 Me wall with 150 ods of 9.3 ppg brine down Me tubing followed by a 16 bet m -vis pill and 600 bbis of 9,3 ppg pone down the annulus A. Confirm the well Is h31M with a 1 hour no flow test and sat a BW in the hblig hanger. Nipple down the X Use and begin nippling up the ROPE stack. Begin waking back Me 9.3 Poe arms to 80 ppg tonne. Operation at 07.00 Testing ROPE Time Log start Endcum our Time Time our Mr) (hn Phase oar. Act wan open. Coact. 00:00 IMOD 4 00 4.00 PREP A 1 P ley out all 14 rig mets on top of Me terrain liner. Bleed of Me Annulus A free spool and Instal a blind flange an Me facility side and a companion 1502 flange on the wellhead side to enable Nordic 4 to tie into the well ead dung well kill comforts INIMI Preres: ssu1uNng-270 psi, Anulus A-237 psi. Annulus B -120 asi. Begin bleeding oft Me gas oft of the Annulus A and Tubing to reduce Me possibflity of gas migneflon after the well kill operation and the off work begins. 0400 OZ00 3.00 TOD PREP A 2 P Candud a PJSM with the entire Nordic Rig sew, ENI Safety and ENI Cohpmry Man to Whole the 1' rig have on top o OPi7-0 . Move Me rig with all Temporal in place to monitor the rig move. Center NoWip 4 on top of Me well. 07'.00 10'.00 3.00 10.00 PREP A 2 P Conduct a PJSM to spot the earnings box in place on the Behr b ensure a I is in working order. Secure Me BOP end0sure, spot Me cuffings box and remove Me re mats and heicuMe ft. b hent of opt 049, Chan the had and area 10 sumng-95 Tai, Anulus A.- 34 psi, Annulus B-120 psi. Shut M Me bland begin Me TWO on Opt 7-0 . Well perasurea linea b begin rigging up all kill line house. 1000 12:00 200 1200. W.0 A 1 P Conduct a PJSM Is prep the flab for loading the 9.3 ppg brine and rig up all the kill fine hopes W the tumrg and annulus A Have ACS Inspect Me earnings bar and 69er look berm, all Is approved. Rig up the 2- Kelley base from Nordic 4 to Me tiger Gleed off fork arias a1I Incorporated hoses for Mil oVemOone. 12.00 1500 3.00 15,00 W O A 12 P Conduct a PJSM 1. pressure test all Ibis MII line hoses with air to 120 psi and kill operations.. Test all linea with air to 120 pal and see no leaks. Loud fast Continue to lead 700 bbis of 9.3 ppg bine into the pits ler kill Operations. 15:00 15:30 0.50 15.50 W O. 12 P Pressure lest all the all ins with 9.3 ppg flans orcof test. Pump 15D bbis down Me tubing at 6 bpm with a starting pressure of 8 psi and a finishing pressure Of 0 psi. 7-3-0 1830 3.00 18.50 W.O. M 9 P Pump a 16 tom hivis pid followed by 600 looks of 9.3 ppg bdne dove the annulus A at 7 term Win a staining pressure of 1 psi and a finishing pressure of 0 psi. Monitored pressures during failing: maximum S annulus pressure 240 psi WM 5 psi on A annulus and Ipsi on lulds, Shut down Me pumpers amforen 1 hour static flow check no pressure build up. 1830 00:00 5 50 24.00 W.O. C 5 P Conduct a PJSM with BHGE Video Gray, ENI lafiom, Nordic 9 crew and ENI company man to nipple down Me X bee. Install Me back possum valve ties BHGE Vetco grey followed by nippling down the X Vee. /ladesil the blanking plug in the tubing hanger and verify RKB length of 25.42'. Begin to nipple up the ROPE slack vie HardIC 4 am Install the HCR choke, Manual and 3 way block Brine lost to brie - test 24 hours (midnight) 750 BBL Brine lost to hole - Total (mgnghl) 750 BBL Gas Readings Avg Background Use (%f Mex Background Gas 1%) Avg Connection Gas I% Max Connection Ws l%) Avg Drill Gas Pit) Moa Drill Gas (%) Avg Trip Gas (%1 Max Trip Gas (%) Cumulative Mud Volumes Active Volume(IMI) Hole Volume total) Addition. (bbl) Cum Act Itone(bbl) Losses (WHO Oum Losses (take Daily Contacts PoSIll00 Contact Name Company Titles Email Once Mobile Ent reprasentalive Ruses Wlmmer Eni Orllling Supv. PPoHllingWeni.cpm 9m105-0]15 HO? -320.0058 Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5119/2019 Report #: 4 Page: 2 of 2 Daily Contacts Position Contact Name Company Thin Email Office Mobile Eni representative Em representative Eni representative Tool Push Tool Push Tool Push Chad Gueed, Wed. Thames Mike Dep Richard Twang Al Hansen Mar, Hemel Eni eal Eni Nordic Nordic heath, Odllin, upervisor Rig Clark HSE Tool Pusher Tour Pusher Nordic4 HSE OPPddlling@ani.mm rigmenager.dg4ditnordluasura.com 90]$85-0]22 9W -611L8604 Personnel Log (POB) Company Sil Type Work H(hr) Standby H(hr) Count Note SHOE (Velco) Mi Swbi ASRC Weldec SHGE(Cenlrilih) GSR Halbbudon LR5 Jacobs Nordic Weimead Mud engineer Company Man Treater ESP Tubular running Slick biro Pumping Equipment Opeadare Non is Personnel 12.50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 1 1 2 2 3 3 4 6 8 21 125 Hours 12.5 Hours 25 Hours 25 Hours TS Hours 37.5 Hours 50 noure US Hours 100 Hours 262.5 Hours BOP Stack & Components Description Sort Data Last Certification Date Pressure Rating (psg TYpe Make Model 1 ID been (in) PRanga /pail Last Cert Dale Slow Circulation Rates Pump Number: Make: Model: Start Date End Dale Liner Size lin) Volume Per Stroke Oserdtle hubli Max Pressure (nail Date Depth (WB) Slow Spot Stakes (spm) P(WI) Eff TOFlow(gpm) Daily Bulk Supply Item Deecdpdon: Equipment Fuel Unit Label: gel us Unit Siae: Note: Oate Consumetl Recelvetl 811913019 353.p 3530 Returned Cum Consumetl Cum Recelvetl 1,0]8.0 1,0]8.0 Cum Returned cum on Loc Nola 00 0.0 Supply Item Deaerip0on: Rig Fuei Unh Label: gal us Unig Size: Note: Date Consumed Recelvetl 812019 6s00 0.0 Retumed Cum Consumetl Cum Recelvetl 2,0500 0.0 Cum RaNrnetl Curb On Loc Note 0.0 -2.o50.0 Supp%Item Rig Water Unit Label: bbl Unit Slxe: Note: Dale Consumed Recelvetl 5/1912010 50 iD0.0 Pb Returned Concomitants! Oum Recelvetl 65.0 We Gum fteturrretl Com On Loc Note 0.0 35.0 Last Authority visit DaM1 Tot int, Net. I Total I.N.C. number I Comment STOP Cards Submitted Ldmwrn 9 Rots Com NOR01 LISTASERVICES 3 PJSM eneral Notes Comment. Well Name: O0R Wellbore Name: e: OP1OP17-02 Well Code: 25097 rhe' Job: WORKOVER ani II WCER Level: Daily Report Date: 5/20/2019 Report 0: 5 Page: 1 of 2 Well Header Permlteon, 1.N' Operator Subsstary Initial Lease Code ADL388593ENI PETROLEUM ENI Pntmpum Co. Ina DEVELOPMENT WELL Rotary Table Elevation th Often.. Level Do First Flange to) RKB -Base Flange IRI RKB - Tubing Spool,., 5336 12.20 21 48 31.78 32.36 Rigs Rig Name ConRacWr Rig Type Rig No. fee Start Date Rig Release Data I RIG NORDIC CMJSTA LAND RIG 0901 51142019 Daily Information Weather Temperature (-F) Wind Days Ln (days) Days RI(days) POB Cloudy 32.0 E@5 MPH 45.0 Safety Incidents - Near Miss Data Gtagory Type Subtype Severity Cause Lost mei Comment Safety Drills Days Until Next Check Type is Occur Last Date Next Date (days) Rig lnspeptlon 5 W20I2019 52112019 1 SafetyMeeting 5 5/201201If 521/2019 1 Casings seat Cas. Type Do (in) to (in) I Crude I TOpfftKB) Bottom(RKB) I TVD Bot. IRKS) I Run Date CONDUCTOR 20 18.25 X65 ]7.1 181.0 ifi1.0 1 1/2010 CASING 13318 1242 L00 -2,175.2 2,2495 2.ifi9.9 11/112010 CASING 9518 &68 L -d0 36.0 8,505.8 3.557.0 1111MO10 LINER 512 L80 -11,093.9 18,030.0 3.4639 12/14x2010 Last Cementing Cementing StartDap: 11/1212010 String: CASING, 8.505 Offlog Comment: Schlumberger pump 5 bible. H2O & test linea to 3000 psi. - OK I Pump 70 bels. of 10.5 Mg Mudpush II Vmop treasurer r Batch mix & pump 300 bbls. of 12.5 ppg Deep Crete cement (1095 said 1.54 ft3 xk yield with me fluid @ 5.177 gapsk \ Drop top plug \ Schlumberger pump 5 phis. H2O forwashup \ Rig pump displace cement with 612 bbh. a 9.1 Mg mud it 6.5 bpm, ICP 142 psi. -slow pump rate to 3 bpm 111650 psi. Q 800 Max \ Bump plug to 1150 psi. (500 psi. over FOP ® 650 Pill,) i Hold for 5 minutes- bleed off & check (luau - hakling \ Good relum through with some sight lora.\ CIP Q 1810 hal Land hanger and dldg1 reciprocated due to High Friction Factors OUIND- Up st, 290K- On wt = 85K. Etureated top of cement 5400'. BID # Top IRKS) Top Meas gi Bgm (RKB) end 1 36.0 Volume Calculations 8,505 8 Pump cement 1009* above the N -sand some) for aonnl isentem el he matlon. Job Information Job Phase Planned Short Data Spit Date End Date Pyo Drmild.(days) WORKOVER 5016201912:00 5/18/201912:00 000 Daily Summary Operations 24h Forecast Complap Me dr.ingelian of the 4.5' ESP compkfon. Lead 50 joint of F Bins pipe in the pipe had, and Pick up the 5'testjoint. Test the BOPE's with Me 5'tast joint prior to picking up any dell ppe. Run a 9 WW Retrievamatic packer to fail the casing van 20joints of Mi pipe bedew and 29joinb of drill pipe above to put Me packer M 900' /-. Test the 9 59' 47# ma g to 800 psi an 15 min while charting Me test. Sens the test to the Anchorage team for approval, Pick up the new 4.W ESP motor and prep W run Me emw 4.5' ESP completion. 24b Summary Complete Me nippling up of the ROPE slack book up Me koomey lines, bull the lest pint and function test the rams and VBR u Set Me fest joint and comphta the ROPE test that was wimese waived by Me AOGCC rep Malt Herrera. Rg down all of the lesdng equipment; remove the back pressure valve and prep to pull Me tubing hanger Pull the tubing hanger at 180K (40K of blocks and 140K of pipe). Pull the 4.5' ESP completion from 7815 to 2337' QSintl95 to joint 56). Pump 15 buts of Be ppg brine every hour to ensure the well kill procedure expectations are met IS boa displacement and 10 bels to 411). Operation at 07.00 POOH W/ESP ASSY Time Log Stan End Cum oar Time Time Our ph,) film Phase Gen. Act Plan Oce.Oesc, 0090 0230 2.50 2ba W.O C 1 P Conducts PJSM whh the new Nogdfi14 Crew com#g Pin town m completie, the Nippy up of Me BOPE's, installing the Imomey lines, and fraction testing Me rams and VBR's. Complete Me function test of all blind rams and installation of all equipment t0 perform the ROPE fest 0230 0430 200 4.50 W.O. C 12 17- Set Me 4.5'test faint and fill the stock W pedonn a shell test to 250 psi Sol 3500 on high to Seems the stack hes good W1egldy. 0430 1000 550 10 00 W.O. C 12 P Conduct a PJSM to perform the BODE test at 250 psi dew / 3500 psi high. COntad Me AOGCC rep MSR Herrera at 05:10 am and confirm that we have Me witness waiver to move forxarl on the SORE test. Complete a passing BOPE test; upload as treasure chads antl ROPE test tome on the N: Drive. 1000 13.00 300 13.00 W -0 6 P Rig duan all of Me testing equipment ant We the test dad from Me wellhead remove BPV. 13:00 14:00 1 DO 14,00 W.O. L 1 P Conduct a PJSM to unseat the tubing hanger aePulling Me 4.5 ESP completion. Ensure all haws. are Identified and miDgated. Conduct a well tack Bull with Me NorQc 4 aver and review a tubing pan respond due to pipe waft thlckn ishe hurt. Vanfy',he. to phase' and 'Ph... to Ground' mndudifity Pin the ESP poor to pulling to tubing hanger Unseat the tubing hanger at 180K (40K block weight and 141% tubing weight) pup Me tubing hanger W through Ser rig Kelley bushing at a weight of t00K. NOTE' Upon unseating Me hanger and Value, the ESP line 0 was documented that after the unseating Me'Phase Is Greater failed to show conductiviy while the 'Phase to Phase' was still showing conduct". Mdniler the ESP cable closely "go pulling to very any cable damage. 1400 15:30 1.50 15.50 W.O. L 5 IsRemove Me BHI GenMIM yerstretor and rig up Me GSR tangs to begin pulling Me 45 -ESP completion Break out the luting hengm end prop Me ng floor to b Jin pule, Me completion. 1530 1800 2.50 1000 W.O. L 4 P Begin pulling Me 45' Monsanto and montbnng the pipe and ESP table for any damagelHales. Upon pulling Me pipe it was found that joint 181 has 2 holes on the pin and Me box antl of joint 100 does not have any significant damage. This damaged area was 635' from the rig Kelley bushing. Another huge was found just babe Me box afloat 179 at a depth d 678Rom Me ng Kelley bushing. On Ore hole W jdnt 179 thv ESP cable was over Me hob and it was verified Mat the ESP had a hale In Me sheath most likely due to fluid jaMe, through Me hole. Pictures, dapples and descnpfiens of the damaged equipment were sant W Me Anchorage team vis E may. 1600 00:00 6 OD 24.00 W.O. L 4 P Continua b pull the 45 ESP completion as --per Pump 15 bible of 9.0 ppg bnne every hour W endure Met to hit Mocedum plus pipe displacement expo on are met No visible damage on any equipment has been Drugs after Me damage on pint 179. At NMI pint 56 ie In Me slips with Me ESP at a depth of 2337'. Complete Me change-Sut WM Me new Nordle 4 crew coming on tower. Ename a PJSM k conducted to ensure a sae everyone amironment. Canton Me selling depth and weigh( needed to set the ad 9 W Rebbvamatic with the ENI tldlling supennWndent. Mobil fire 9 SIB- BHI Reulevama8c from Spy Island DMI Sib to DiMok Point Coordinate the antval of Me Baker Hughes pecker Mol mp on 5-21- 19 to Inspect the 9 SIB' Rel vamaGc on location and prep to min ft to 900' H- with 20 jotn(s of S drill pipe bebx (12A5 bid ant 29 joints of 5- ddl pipe above (913.5' of pipe) W test the Boiling W 800 psi for 15 min. erne feat W hole - last 241roufa (midnight) 112 BBL anon fast W hole - Tolyl (midnight) 851 8131, Gas Readings Avg Background Gas (%) Max Background Gas I%) Avg Connection Gas 16) Max Connec0on Gas (%) Avg DMI/ Gas (%) Max Drgl was Via) Avg top Gas (%) Max Trip Gas (%1 Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5/20/2019 Report #: 5 Page: 2 of 2 Cumulative Mud Volumes Acture Volume (bbB Hole Volume (bell Additions (bbp Cum Additions (beB Losses (bel) um Losses (bbp Daily Contacts Position Contact Name Company Title I Email ONkeI Mobile Em representative Eni repreaenlalive Eni representative Eni representative Tool Push Tool Push Tool Push Russ Wimma Chad Gueco Wade Thomas Me Delp Plot Twedt Al Hannan Mark Hill Eni Eni Eni Eni song. Nomlc NONIc Drilling Supv. Drilling Supervisor Rig Ck11 HSE Tool Pusher Tour Pusher NoMk 4 HSE OPPdrilling@eni.com CPPdn10ng@enicom rigmanager. dg4linordiocalisla.cum 9076850715 907685-0722 8076708604 901-320D058 Personnel Log (P( B) Company Sure Type work H (M) Split H (hr) Count We Halilbunon BHGE (V.(.) MI Sweco ASRC Welgec GBR LRS Jacobs BHGE(CentrilR) Nmdio Slick Line Wellhead Mud engineer Company Men Tredor Tubular running Pumping Equipment OpemMrs ESP Nordic Personnel 12.50 12.50 12.50 12.50 12.5) 12.50 12.50 12.50 12.50 12.50 0 1 1 2 2 3 3 6 7 20 50 hours 12.5 Houre 12.5 Hours 25 Hours 25 Hours 37.5 Hours 62.5 Hours IN Hours 75 Hours 2625 Hours BOP Stack Components Oesaiptlon tart blue Lasl Certification Dah Pressure Rating (psi) Type Make Model IO Nan (in) P Range (pol) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Simons End Date Liner St. (I.) Volume Per Stroke Overrlda p;llstk) Mm Preaaure(pai) Data DeptM1(fMB) Slow and 5lroleas(spm) Pfitt I SIT (%) OFlow(gpm) Daily Bulk Supply Qem Descdpaon: Equipment Fuel Unit Label: plus Unit Size: Note: DaeConsumatl Racelved 512012019 327.0 3210 Returned Cum Conumed Cum Received 1.405.0 1,4050 Cum Returned Cum On Lac Nate 00 OD Supply Item Description: Rig Fuel Unit Label: gat us Unit Site: Note: Data Consumatl Received 54012019 6030 D.0 Relurnotl Cum Cansumetl Cum Received 2.653.D 0.0 Gum Returned Cum On Loc No[e 0.0 -2.653.0 Supptyltem Reached.: Rig Wants Unit label: bbl Unit Size: Note: Date Consumatl Racelved 5404019 90 0.0 ReNmed Cum Deneumetl Cum ReceNetl 740 100.0 Cum Returned Dvm On Loc Note 00 26.0 Last Authority Visit Date Tot rasp Nbr Total I.N.C. number Comment STOP Cards Submitted Company Is RM Co. NORDIC-CAUSTA SERVICES 3 PJSM General Notes Cwnmem: Well Name: 0R Wellbore Name: me: OP1OP17-02 Well Code: 25097 ��ff �i1 a' Job: WORKOVER em II II II WCER Level: Daily Report Date: 51212019 Report #: 6 Page: 1 of 2 Well Header PeoratiConcession N° Operates Satellite, Inwal Lahee Made ADL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation (Rl Ground Levd fR) Flnt Flange to) RKB-Bae Flange U.) RKB-Tusing Spool 1R1 53.26 12,20 21 d8 31.78 3236 Rigs Mg Name Commdor we Typa Rig Not Rig Start Data Rig Release Date RIG NORDIC CAUSTA LAND RIG 0981 511d2019 Daily Information We at Temperature(°F) Wind Days LTI(days) Days Rl fill Poe Clear 30.2 Sat MPH 430 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost fine Comment Safety Drills Days Until Nex[Check Type at Occur last Date Next Dale Nays) AuthorityViso 1 5I20/20iB Sl2]I2018 -359 wg Inspedipn 6 512112019 522/2019 1 Safety Mwi 6 512112019 522/2019 1 Casings seat Cas. Type OD (in) ID of Grade Top(RKB) I Bottom(ftal TVD Bot@KB) Run Data CONDUCTOR 20 18.25 X85 ].1 t6L0 161.0 10n12010 CASING 13318 1242 LBO -2,141E.2 2,2695 2,169.9 11/1/2010 CASING 9518 0.68 L-80 960 8.5056 3.557.0 11/12/2010 LINER 512 L00 -11,0939 18,030.0 3.453.9 12/142010 Last Cementing Cementing Start Date: 11/122010 SMrg: CASING, 8.505 BIDS Comment: Bphlume sinter pump 5 bills. H2O S lest lines to 3000 psi, -OK \ Pump 70 bible of 10.5 pati Mudpush II \Drop bottom plug 1 Batch mix 8 pump 300 fills. of 12.5 app Deep Creep cement (1095 ske) 154 ft3lsk yiem with rob NO ® 5.177 gagsk.l Drop lop plug 1 Schlumberges pump 5 bills. H2O fir washup \ Rig pump ebplace cement with 612 bills. of el pDg mud a SS baro, ICP 142 psi. - shear Pump rete to 3 bpm ® 650 psi. a 800 bble \ Sump plug to 1150 psi. (sola psi. over FCP ® 650 psi.) \ Head far 5 minutes -bleed oft S check New- holding \ Good return MmWh with soma s119M loss.\ CUP @ 1810 hmA Land hanger and call reopmcatetl due b High Frie im Factors fKdbt)- Up M= 2WK- Da m, 85K. Es9meted top of expert 540x. Big Top(RKB) Top Meas MeM Ban IKKBI Com 1 36.0 Volume Calculations 8,505.8 Pump cement 1000'4 above the N -sand 15400) for conal isolation of formation. Job Information Jab PM1ase Planned Start Gate Start Date End Dant P50 Duration (days) WORKOVER 5/18201912:00 5116201912:00 0.00 Daily Summary Operations 24h Forecast Pick up the 4.5- ESP motor and completion as per procedure. Run The 4.S ESP completion and set the bottom Of the ESP motor camralizer at Me planned 7916MD. Ensure 10 bible of 9.0 peg brine is pumped every hour as per kit procatlum, 24h Summary Complete the de<ompletion of OP17-02 as per procedure, Lay down the ESP pump and empty the pipe shed of all equype rt in geparalion of running Me new 4.5- ESP_ TM final 7 joirds that were laid down babre Me ESP reached surface were pulled wet due to the ESP and not kiting the NO drain. Pull Me 7 pinta wet and rasped the ESP pump once it is on surges. lay dawn the ESP Dump and prep M con the 9 "' Ratrevamagc packer. Test the BOPE's with Me 5- hinjoim le 250 psi Tow and 3500 psi high. Set tha wear nng and con 25 jdMs of 5' dril pipe in Me hole. Ppk up Me 9 WO- RetreivemaW and mn in w 30 ms. Test the 9 SM- sing to 000 psi and confirm a good test win Me Anchorage team. Put Me 9 518' Rebiearmal to joints of F OR pipe, set Me 9 5/8' Rearvamatic at award bait the annulus A with 9.0 firca surtace and prep to sock up the 4.5- ESP completion. Conduct a PJSM and review Me IM plan to perform the 8 picks for the loading of all the ESP cable and capillary line. Operation at 07.00 MLE Splice, pre, for RI -1 Areas Time Log Start Endcpm Dur Time Time Our fir) im) phase Our. Act Plan Oper. Dever. 00: 0 W:30 4.50 450 1NG L 4 P Continue pulling to surface with fl 4.5- ESP completion while pumping 15 bbl every hour. OR load d0jomts out of the pipe Mi stations to ensure there is 1 rowM inspect tubing Mille pulling to surtace. NOTE: Upon pulling joint #7 Me pipe began pulling wet hoes the ESP not felling Oust Man through. Attempt to pump though the ESP unlock or clear passible debris. Pump 5 fids and the TBG pressures up to 1400 psi. Bleed or Me Mang and begin pulling the final Fare and 0430 0530 1.00 5.50 W.O. L 5 P lay down Me final pints and begin breaking down the ESP. Total joints and clamps: Joints -195, Full Clamps -195, Pump Clamps -3. Protect Clamps -4, Seal Clamps 4, Motor Clamps -3, Flat SO clamps -4. 0530 08:00 250 0.00 W.O. L 5 P Lay down the ESP as par procedure via Still Carroll Confirm the Intake pont have no sand in them and have BHI mad tie ESP in boxes M diagnose Me issue. Continue to lay down all the completion equipment in peperetipn to Moda e 9 518- ingtest. 0800 09:30 1.50 9.50 W.O. C 12 P Pick up Me 5- testpinl and test Me BOPE's M 250 psi loss 13500 psi high. Good test. 09'.30 10:00 0.50 1000 W.O. C 5 P Rig down all Me lana( equipment and set Me wear ring in preparation to fast Me 95/8' casing with Me Retrwemalic fast packer from goo, to i uraw. 10:00 1530 5,50 15.50 WO M 4 Run more holeMih 25 pints off? fishpipe wIM a u ose on the bottom of the pipe. Makeup the 9 B ehevamabc Mat Decker as per SHI parker rep. SIM OPS: Load the pipe shed arch 60 joints of T and pipe strap and tally Me unit pipe, 15 30 1700 1.50 17 00 W.O. M 4 P Run in the note wNM1 29 jo nil M set Me Rebievamadc at 900' 41-. Set the 9 518 Retrlevamatic at 900' and load the backside of the S dnO pipe with 9.0 peg. 17.00 1900 2.00 19.00 W.O. M 12 P Bleed de annulus B fines 135 psi to 10 pei, Close the annular and pressure up Me annulus A to NO pill r the 800 psi casing test Hold pressure for 20 min and gal a flet line test at 810 psi Or 15 minutes Good fest. 1900 2030 1.50 20.50 WO M 4 P lay down all 29 joints of drill pipe, Me 9 51W ReMevamalic packer. and Me 25 jdnts of 5' call pipe that was Maw Me lest packer. 20:30 22:00 1.50 22 to O C 5 P Pull Me wear ung from Me wellhead and routine prepping the rig Nor tit son e P completion. SIM OPS: Unload all 60 joints of call pipe off of the rig. 22:00 0000 2.00 24.00 W.O K 2 P Spot ilia naw ESP cable antl capillary line to perform Me picks via Jacobs crane. Conduct a PJSM wind Jambs gene opa2toG ENI safety. ENI Operations, Nordic 4 crew and ENI company man. Review Me lift plan famished by Me ENI IM adviser and prep to perform Me lifts. BMs lost M hole - Last 24 hours (midnight) 310 BBL Bane lost M hole - Total firou M) 1161 BBL Gas Readings Avg Background Gas I%) Max Background Gas (%I Avg Connection Gas I%) Max Connection Gas f%) Avg Dail Gas (%) Max Drla Gas 1%l I Avg Trip Gas fall Max Trip Gas 1%1 Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5121/2019 Report #: 6 Page: 2 of 2 Cumulative Mud Volumes Active Volume last) Hole Volume bull Additions (bell Cum Additions (bbl) Losses bl) Cum Lasses (bbl) Daily Contacts Position Contact Name Company Title Small OMGe Mobile Em represerd,., Eniremitim uni. Em hop, eaentaeve Err i repreaentalWe Tool Push Tool Push Tool Push Rme Wimmer Chad Cusco Wade Thomas Mike Delp Richami Twedt Al Hansen Merle Hemet Enl Ed Em EnI Nordic Nordic Nordic Drilling Supv. Drilling Supervisor Rig Clerk HSE Tool Pusher Tour Pusher Nordic 4 USE OPPdnlling@eni.wm 0PPdn11ing@mdcom rgmanager.ng4®nGN'm-calista.com 90]-6050]15 90]$85-0]22 0]4i]0-BBD4 90]-320-0058 Personnel Log (P( B) Company Sew. Type Work H an) Stand-by H (hr) Court Note Welker Halliburton aHGE (Vetao) Mi Swec. ASRC GSR LRS Jacobs SHGE (CenInIM) Nordic Tractor Slick Litre Wellhead Mud engineer Company Men Tubular running Pumping E,ub menl Operates ESP Nordic Personnel 12,50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 0 1 1 2 3 3 6 ] 20 25 Hours 50 hours 12.5 Hours 12s Hours 25 Hours 37.5 Hours 625 Hours 100 Hours 75 Hours 2625 Hours BOP Stack B ComponenFs OescrlpNon tart Date Last Certification Data Pressure Rating (psi) Type Make Model ID Nom (in) P Range Usi Last Cert Data Slow Circulation Rates Pump Number: Make: Nei Start Data End Date Liner Sim, (in) Volume Per Strgke Ovaidde(bbl/Stk) Max Pressure(psi) Data I Drum dUa) I Slow Sptl I Stroke, blood I PI'd) EH (%) OFlow(gpm) Daily Bulk Supply land Description: Equipment Fuel Unit Label: gal us Unit Size: Note: Date Consumed Recehmd 52012019 32> 0 32].0 Reamed Gum Consumetl cur -Re ceived 1,%14.0 ]190 Lum ReturnedCum On Loc Note 0.0 0.0 Supply item Description: RI Fuel Unit Label: pal us Unit SI-: Note: Date Consumed Receivetl 5201W19 603.0 0.0 Returned Cu. Consumed Cum Receivetl 3.281.0 0.0 Lum Returned Cum On Loc No[e 00 -3,261.0 Supply Iran Description: Rig Water Unit Label: bbl Unit Slze: Note: Date Consumed Received 52012019 9.0 0.0 Returned Cum Consumed Cum Receivetl 80.0 10.0 Cum Reainetl Cum on Lac Note 0.0 20 0 Last Authority Visit Date T01 map. Nbr S2o2010 I Total I.N.C. number OommeM BOP test whines waived by AOGCC Inspector Mail Hemers, next teat due 527119 STOP Cards Submitted Company MRRta Can NORDIC-CALISTA SERVICES 3 PJSM General Notes Canmenr Well Name: OOR Wellbore Name: e: OP1 OP17-0-02 Well Code: 25097 Job: WORKOVER Q n i WCER Level: Daily Report Date: 512212019 Report p: 7 Page: 1 of 2 Well Header PermitiConcessiati N° Operator Subsidiary Initial Lahee Code AOL388583EM PETROLEUM ENI Petroleum W. Inc. DEVELOPMENT WELL Rotary Table Ossetian(R) Ground Level in) First range in) RKS-Base Flange(R) RKB-Tubing Spool DO 53 26 12.20 2148 31.78 32 36 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Data RIG NORDICCMUSTA LAND RIG 0981 5/ta2019 Daily Information Weather Tit ",abre PF) Wind Days LTI(days) Days RI(days) Poe Clear 294 Ngg 6 MPH 4d.0 Safety Incidents - Near Miss Dale Cabgasy, Type Subtype Beverly cause Leer time? Comment Salety Drills Days UntilNext Check Type %Occur Last Date Next Date (days) Aumanty Visit 1 512012018 52]12010 -360 Ng manicure 7 5222018 52312019 1 S."Meeting 7 5IM2019 5!1312019 1 Casings seat Cas. Type Do (in) to (in) I Grade I Top (liked I Bottom fil TVD Bot(RNB) I Run Date CONDUCTOR 20 1825 X65 3).1 161.0 1610 10/312010 CASING 133/6 1242 180 -2.1]52 2,209.5 2.1699 11fl2010 CASING 9 u 8.68 L-80 36.0 8.505.6 3,557.0 11/122010 LINER 512 US -11,0939 10,030.0 3,463.912/142010 Last Cementing Cementing SkirtDate: 111122010 Sting: CASING 8.505.BN( Comment: ScMumbelger pump 5 bbis. H2O &lest lines to 3000 psi - OK k Pump 70 hes. of 105 ppg Madinah II 1Dmp bottom plug 1 Batch mix 8 pump 300 bbis. of 12.5 ppg Deep Cock cement (1085 sks)1.5103hk yi with mu fluid @ 5.177 gatisk \ Drop lap plug k Schlumberger Pump 5 bbis. H2O he wash-up 1 Rig Pump displace cement with 612 this. 019.1 ppg mud @ 6.5 bpm, ICP 142 psi. -slow pump rete to 3 bpm ® 650 psi. @ 600 bbis k Bump ph, to 1150 pal. (500 pan. over PCP @ 650 psi.) t Hold for 5 minutes - timed off A check floats- holding 1 Good return mmugh with same seem kiss .\ CIP ® 1810 hm.1 Land hanger and dil reciprocated due to High Friction Factors (MM)- Up wL= 290K- On cel = 85K. Esdmafed lap of cement 5400'. SIR Top(ftKB) Tap Meas Meth- Ban(ftKB) Com 1 38.0 Volume Calculations 5,505.6 Pump cement 10MY1 above the N-sand(54o Mr a.mishadid. of formation. Job Information Job Phase Planned Sun DabBien Data End Deb PW Wu .(days) WORKOVER 51162o1912A0 5116201912:00 000 Daily Summary Operations 24h Forecast Complete the running of Me 49- ESP completion setting Me bmrom of the ESP at 7927' with 209 pima of 4.5- 12,60 LA0 pipe. Tenninab all lines after making up the tubing hanger and kind the completioninstill a tiro way check and ni,la down in. BOPE's and apple up in. X tree. 24h Summary Complete all lifting operations by spotting all of the ESP and Capillary spools along win, spoolea m place to ton the LV ESP connotation. Lead Me she shed win 255 pints of 4.5' 563 L-80 range 2 pipe (31.7' ere,e). Drift me dS" here vnth a 3.833- mishit "its acquiring Me tally measurements. Build Me as ton tall, and ensure all pentnent personnel has a copy. Complete the ESP splice to Me ESP motor connector with Me ENt eRdmtian widening all electrical work. Lead Me pipe shed with all Me clamps needed to ton the new ESP completion. Pick up the ESP molar assembly and assemble as per polity and procedure. Begin running 4.5- ESP compiedon while pumping 10 blue every hour, testing Me ESP cable every hour and monitoring the capillary line cable pressure. Bottom of pipe is at 3437' as of 24:00. Operation at 07.00 RIH WIESP ASSY Time Log stare End Cam Our Time Time Dur(hr) (kin Phase DID, act. Plan Dan, Deers. 0090 9309 399 300 W D. M 1 P Remove Me put etl ESP cable and apooler ft.. Me it, along with the ml capillary line vu Jacobs cone. Metall Me new capillary line and ESP cable in new slanders. All is prepped for the BHI to begin the cable splice to me ESP motor. 0300 0930 6.50 9.50 W . M i P Conduct a PJSM to prep all equipment for the running of Me 45' ESP completion Load all 255 pints of 4.5' 12.60 LA0 pipe In Me pipe shed Ensure all pipe drifted win Me 2.033- rabbit and the pipe length is dwum xuted In Me tally. Load ell ESP damps and pipe camps in the pipe had, Complete the ESP cable splice via Baker Hughes CentnM with the ENI Electrician solution, .4 eleci l won. 0930 1200 2.50 12.00 W.O. M 1 P Conduct a PJSM for Me running of the 4.5 ESP completion. Begin picking up Me new 4,5ESP and Makin, up all the sections to build Me maxi It was found upon picking up the ESP Gaswp (Gas Generator) that it had a broken fin The Baker Hughes Centnlift contacted Meir field management and moblik ed another Gassep potion of the ESP assembly to OPP to replace the damaged pad. 1200. 14.00 2.00 14.00 W . K 5 P Conduct a PJSM with the new Nordic 4 crew coming on tower to pick up the ESP wmple8on. Pick up the ESP lower portion tithe aasemby and connect the CapMe, line and ESP cable. Test the Capillary line and the ESP cable, good test. 14:00 1600 2,00 1600 W.O. K 5 P Pick up me GER power tongs and tercel equipment. VerKy all is in working order. Begin picking up 4.5- pipe wile lamenting every contwction and Installing a fug collar mention damp on every collar. Ensure 10 blas are pumped every hour as per Wit procedure, me ESP cable is tested every 100' of pipe ran and a tubing vdume Is pumped every 3000'to flush Me tubing and Wit me well as per procedure. SIM OPS: New Gassep (gas separator) on location. Moblgae Me unit to the rig floor. Complete the assembly dthe 4.S ESP motor and vmdy Me ESP cable has conductivity and the Papillary line has inbgmy, 160o 19:00 3 o0 19.00 WO K 4 P Continue b ton Me 4.5- completion as per Pracetlu s. Test the ESP cable due to Me bottom of the ESP motor being at 1050'. Continue pumping 10 bbls every hour. Good test on me capillary line and ESP cable. 19:00 21:00 2.00 2100 W.O. K 4 P uthentomn e,IE-completim as per procedure. Test the ESPcabledue b thebottom ofthe ESPmotarbeingat 215T. Continue pumping 10 bbls every hour. Good test on Me capillary line and ESP cable. 21:00 22:30 1.50 2250 WO K 4 P Continue to ton Me 4.5 completion as per procedure. Test the ESP cable due to Me Whom of the ESP moire being at 3000'. Continue pumping 10 bbls every hour. Good lest on Me capillary One and ESP cable. 22:30 2330 1.00 23.50 W.O. lK 10 IP Pump 45 bbis of Se pp0 Mil ax i brine down Ore TBG at 1]5 bpm to flush Me TBG and kin the well as per procedure. 2330 00:00 0.50 20.00 W.O. K 0 P Continue 10 ton in. 4.5 completion as per procedure. Continue Pumping 10 bbki svary hour. Bottom of Me ESP completion at3437"7.124:00. Gas Readings Avg Background Gas I%) Max Background Gas (y) As' Connection Ws l%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%I Avg Trip Gas (%7 Max Trip Gas (%) Cumulative Mud Volumes Active Volume but Hole Volume(bbl) AddlBons(bbIH Oam Additions (110) Losses fbbl) Cum Lossesfld) Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 512212019 Report #: 7 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email office MOMIe ni re'resionfirstare Eni repres.abuse Eni representative Sal representative Tool Push Tool Push Tool Push Russ Wiarmar Chad Gusto Wade Thomas Mika Delp Richard Twine Al Hansen Mark Herbst Eni Enl Em Eni Nordic Nordic Nordic Drilling Sup, Drilling Supervisor Rig Clerk NSE Tod Pusher Tour Pusher Nordic 4 HSE 0 Pdrilling@eni rem OPPdrblling@am.rpm rgmanagerrig4@nordkwcalisla.com 907-685-0715 907-685-0722 9W -670-860e 90732400 Personnel Log (POB) Company Serv. Type Work N(hr) Stand-by H(hn Count Nob Welaec Hallibudon BHGE (Velcro) AM Swaco ASRC LRS GBR BHGE(Cenlnlifl) Jacobs Nordic Traveler Slick Line Wellhead Mud em neer Company Man Pumping Tubular running ESP Equipment Operators Nordic Personnel 12.50 12.5) 12.50 12.50 12.50 1250 12.50 12.50 12.50 12.50 0 1 1 2 3 4 6 6 21 25 Hours 50 hours 12.5 Hours 12.5 Hours 25 Hours 625 Hours 37.5 Hours 75 Hoar 100 Hours 262.5 Hours BOP Stack 8 Components Description Start Dab Last Certification Date Pressure RMeg(psq Type Make it Modal 10 Mo. (m) PRange (psi) Last Cert Daft Slow Circulation Rates Pump Number: Make: Model: Sen Deb End Data Liner Sizella) Volume Per Stroke Override lubblstk) Max Pressure tal) Date I output twos I Slow Spd Smakes(spm) P(psi) Effl%) 0Floor (gpm) Daily Bulk Supply Item Cantaloupe: Equipment Fuel Unit Label: gal us Unit Size: Note: Dale Consumetl Retelvetl 612L2018 306.0 306.0 Returnetl Cum Consumed Lum Received 2329.0 2,3290 Cum Returned Cum On Loc Note 0.0 0.0 Supply bear Description: Rig Fuel Unit Label: gal us Unit Size: New Dae Consumed Received 52211019 618.0 00 Returned Cu. Consumed Cum Receivetl 4,4870 Co Cum Returned Cum on Loc Note 00 4,4870 Supply Item Description: Rig Walsr Unit Label: bbl Unit Size: Note: Data Consumed Fareload 5222019 2.0 DO Returned Cum Consumetl Cum Recurred 880 100.0 Cum Returned Cum On Loc Nate 00 12.0 Last Authority Visit Date Tot roan. Nur 5202018 I I Total I.N.C. number comment HOP test witness waived by AOGCC Inspector Matt Herrera, need test due 5@7119 STOP Cards Submitted Company aRpm Co. NORDIC-CALISTA SERVIULS J PJSM General Notes Comment: Well Name: 011 Wellbore Name: me: OPI OP17-02 Well Code: 25097 Job: WORKOVER nn to n i WCER Level: Daily Report Date: 5123/2019 Report #: 8 Page: 1 of 2 Well Header PermlUCommesal. N' pmalr Suosllflary Initial ICode ADL -388583 ENI PETROLEUM ENI Prominent Co. Inc. DEVELOPMENT WELL Rotary Table Woman. Do Gsool Lo'eift) First Flange(ft) meas - Base Flang. IN RKB-Tubing spool(it) 53.26 12.20 21 48 31.70 32.36 Rigs Rig Nem. Contractor Big Type Rig Num RIg alit Dal Rig Rebaase Date RIG NORDIC CAUSTA LANDRIG 0981 51142019 Daily Information Weather Temperature(°F) Wind Days LT! (days) Days Rl (days) POS Cloudy 32.0 SW a 12 MPH 49.0 Sall Incidents - Near Miss Oats Category TyPe aubype Severity Cause Lost tummy Comment Safety Drills Days Until Nazi Check Type pOccur I Last Date Next Date (days) Authority Usil 1 52012018 52712018 -36 Rig Inspection a 5222019 5123!2019 0 SafetyMeeting 8 51VI2019 52312019 0 Casings seat Cas. Type OD (in) ID (in) Grade To,(ftl I Bottoon NKB) TVD Set Ril Run Data CONDUCTOR 20 18.25 X65 3].1 161.0 161.0 10131! 1 CASING 13310 11.42 L80 -$1]51 2,249.5 2.169.9 11/1"2010 CASING 9518 a.68 L-811 35.0 8,505.8 3,55],0 11/112010 LINER 512 L80 -11,093.9 18,030.0 3,983.9 1VIV2010 Last Cementing Cementing Start Dal: 1111 10 Stafty, CkSING. Rome SMUS Comment: Schlumberger pump 5 mos. H2O B lest lines to 3000 psi. - OK f Pump 70 bbl.. of 10.5 ppg Mudpfeh II 10mp bottom plug 1 Balch mix 8 pump 300 bbl,. of 12 5 ppg Oeep Crete cement (1095 sks)1.5I ft3lak yieB with mix find @ 5.177 gal Drop top plug 1 Schlumbeger pump 5 bins. H2O for wash-up 1 Rig pump displace cement with 612 bole. of 9.1 ppg mud @ &5 all ICP 142 psi. - show pump rate to 3 bpm Q 650 psi. ® 600 Ms 1 Bump Plug to 1150 psi. (500 psi. over FCP @ 050 psi ,)1 Hold for 5 minutes - bleed oR a check floats - holding 1 Good return through with some sight loss \ CIP @ 1810 hon \ Land hanger and didn't ream ocaltl due to High Fill Fal (KAM)- Up Me 29011 On art, 85K. Estimated top of ...out MOKY Stg# Top(ftl(B)Top Meas Meth Bon HKBl Can 1 38.0 Volume Calculations 8,505.6 Pump cement 19p9'+ above me N-sand(5400') for zonal isolation of fomlation. Job Information Job Ph..Banned Start net. Seen Dal End Dal P50 Duration (days) WORKOVER 5118201812:00 511620191200 0.50 Daily Summary operations 24h Forecast Complete Me nippling down hof Om RUDE'c with the Nordic 4 crew. Nipple up the 4 1118- SK Veto Gey X free. Test the ESP cable penetrator via BHI cardnliR. Test the tubing hanger pack off and to 5000 psi and perform le passport lest on Me X tree as per procedure. Release Nordic 4 of of OP17-02. 2011 Summary Complete Me mnning of Me 45- ESP compbation wIM 249 jams of 4.S 12.88 L-80 pipe, 249 Cross "at Cannon Chomps. 5 Motor Clamps, and 1 Splice Champ- Land the tubing "nor and run in the hock down moa positioning Oa ESP motor cemral¢m boMh at fail M0. Ve ay the Cal line sM1... burst of. ie sheared and Me ESP penetalr has mntluctivity after landing. Perform bath of Me tubing hanger seal bases to Sam mai, good reefs. Begin nippling down the BOPE's and prep 0 nape up Me 41116. 5K BHGE Vetco Gray X bee. Operation at 07.00 HAD BOPE NIU Tree Time Log Sart End Cum Dur Time Time Our Mr) (ban phase OF, Act Pon Open. Enter. 00:00 0530 MO 5.50 or 0 K 4 P Continue town the 4.S completion as per procedure F13,437' T18,039' Testotl the E8P moble at 400 '. 5040'. 3039' (gootl testa). Continue pumping 10 bole every hour. Good lest on Me capglary line and ESP cable. 0530 06'.00 0.50 6.00 W.O. K 9 P Pump 75 bible (tubing unions) dein Me tubing as per procedure. Catch pressure on the tubing with 32 M. easy. Continue pumping at 1.75 bpm pushing fluid through the ESP. 0600 1000 400 1000 W.O. K 4 P Continue to run the 4.5- completion as per procedure F16039'TT009 Tested the ESP cable at 7009 (good lest. Conlinue pumping to the every hour Good test on the capillary line and ESP came. SIM OPS: Repair GSR Tongs (Pin Replacement) 1000 1200 2.00 12.00 W.0 K 5 P Conduct a PJsM with the Handle 4 crew, Jacobs Cane Opemtco ENI safety, ENI Production OPS and ENI Company Man W random the 2 picks to replace Me empty ESP spool with the new ESP cable spool In complain the ESP centralion mnning procedure. Review Me IBI plan and identify all hasams and mitigate the risk. Perform the 2 picks with Jacobs sane to replace Me empty ESP spool with Me full spool to continue mnning Me ESP completion. 1200 1530 3.50 1550 IN 0 K 5 P Conduct a Pull to perform Me ESP cable splice as per procedure. Ensure the ENI safety rep is on site to witness all electrical work. Complete the ESP splice and confirm conductivity Rom Phase - Phase and Phase - Ground. 15 TM 1330 1 00 1650 W.0 K 4 P Continue to run the 4.5' completion as per procedure F2009Tn900' Tested Me ESP at 7MMY (good test). Continue pumping 10 bole every hour. Good test on the captllary line and ESP cable. 10:30 1700 0.50 1700 WO, K 5 P Make up Me Hydro 563 x her crossover pups and tubing hanger: anent Me tubing hanger to ensure all is lined up with me expom hole native ho b onll hole in the wellhead X tree. Verify a Iwo wry check is insta11M in Me tubing M1angmr to handed. the wellbore mea Me tubing hanger Is limited 1700 21:00 400 2100 W O K 5 P Terminer. the Oapillryline through the tubing banger and ensure Mere are 4 ways of capi9ary line around Me tubing hanger pup. Install Me ESP cable penetalor through Me Nbing hanger rays perform the ESP wok splice to the connector for the penetrator. Test to ESP cable after Me splice is wmplaled and connected to the penetrator, good fast. Install in. umbilical Pool to moral the ESP cable coreduct", Dominion the pressure test sequence on Me Capillary line at 250,Uf am PSV 2000 PBI antl shear the buret disc at 41W psi after Me confirmed pressure festa. Pump through the tanglary line for 5 min as per procedure at a consistent pressure d 2000 pal. Capital line duedauitl packed 21.00 2300 2.00 2300 W.O. K 5 P Land the tubing hanger via BHGE Veto. Gray rep. Vel all is M line for Me ho o mal caped mi Me Wbmg M1anger. Run in the to ung larger tock down wawa as per procedure. Show, dawn Me oll One and choke sled prior to landing Me tubing hanger. Ensure all permits are In place with the ENI Preelection OPS max to operate within compliance_ Total surge: 249. Total Clamp: 249 tensa collar cannon clops, 5 Motor Clamps, and 1 splice clamp. NOTE: 45- ESP completion (myself wash Me befmm of Me Manor Centralizer at ]927.4]' MO Both tubing hanger.eals have been basted to NO psi and vnlnessed by ENI company man. 2300 00:00 1.00 24.00 W.O. C 6 P Conduct a PJSM wiM all of the Npmic 4 crew and begin nipping down Me BOPE's as pm Momentum. Release me worm the bents and remove the upper BOPE mor Bane lost to Isle - fast 24 hours (mgngM) M8 BSL Brine lost to bole - Total (midnight) 1030 BBL Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 812312019 Report #: 8 Page: 2 of 2 Gas Readings Avg Background Gas (%) Mo. Seek, ... al Ga.� A) Avg Connection Gas (%) Mex Connection Gas � 4l Avg Drill Gas(%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (°/) Cumulative Mud Volumes Active Volume (bbl) Hole Volume (660 Additons (bull Cum Additions (bbl) Losses (bbl) Cum Losses (bull Daily Contacts Position Contact Name Company Title Email Dolce mobile t representative En, represennelive Em repreaentalive Eni represenWtive Tool Push Tool Push Tool Push Russ Wimmer Chad Gen. Wed. Thome. Mike Delp Richard Tweet Al Hansen Mark Hamad E Em Eni Eni Nordic Nordic Nordic Orillm, Supv. Drilling Supervisor Rig Clerk HSE Teel Prober Tour Pusher Nordic 4 HSE OPPdrillin,@.u, am OPPddllingtienicom Ullman ... r.m4@.Wdircaliata.Som 907-685A715 907A6s-0I`M 907-670.860, 907-320-0056 Personnel Log (POB) Company guru Type Work H(hr) Stand-by Hgal Count NOW Welpec Halliburton BHGE (Voice) Mi SWecO ASR, LRS GBR SHGE(Cenldlift) Jacobs Nordic Tractor Suck One Wellhead Mud engineer Company Men Pumping Tubular mnnitg ESP Equipment Operators Nordic Personnel 12.50 1250 12.50 1250 12.50 12.50 12.50 12.50 12.50 1250 0 0 1 1 2 3 4 6 6 21 25 Hours 60 hours 12.5 Hours 12.5 Hours 25 Hours 62.5 Hours 37.5 Hours 75 Hours 100 Hours 2625 Hours BOP Stack 8 Components Uescrksk o start Data Last CUlfte ion Date Pressure Raring (pail Type Make Model to Nom (in) P Range (pap Last Cert Date Slow Circulation Rates Pump Number: Make: Model! Start Data End Date Liner Size pnl Volume Per Stroke Ove"Idd (bbllstp Maa Pressure (pap Dale I Dai JMB) Slows" Stroke. h,m) I P(Rsl) Effj%) 0Ficus (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: gal us Unt Size: NOW: Date Consumed Received SI23I2018 3820 367.0 Redrnetl Cum Consumed Cum Re"Sead Cum Returned Cum Go LOU Note 2,716.0 2,7160 00 0.0 Supply Ilam Description: Rig Fuel Unit Label: gal us Unit Size: Note: Mt. Cum ad Received 52312019 83]0 '0.0 Redrnetl Cum Consumed Cum Received Cum Returned Cum On Lac Note 5,120.0 0.0 D.0 -5,1200 Supply Ilam Description: RIB Water Unit Label: bbl Unit Size: NOW Dad Consumed ReceWar! 52312019 0.0 0.0 Returned Cum consumed Cum R ... ivetl Cum Returned Cum COL. Note 880 100.0 00 12A Last Authority visit Dant Tot insp. Nbr S202o16 ToWI11i number Comment BOP test witness waived by ACGCC Inspector Man Herrera, next lest due 527119 S P Cards Submitted Co.", NRnts Com NORDIC-CALISTA SERV ICES ; pJSM General Notes comment: Well Name: '1POR Wellbore Name: OP17-02 Well Code: 25097 na� a'a Job: WORKOVER en 0 WCER Level: Daily Report Date: 5/24/2019 Report #: 9 Page: 1 of 2 Well Header Permitl0oncession N° Gwator. Sobsldlary Initial Lahee Code ADL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL RW., Table Elevation 1.1 G1Ountl L.1hir and First Flange( -1 RKB-Base Flange (ft) RKB-Tubing Spool (ft) 53.26 12 20 21 48 31.]8 3236 Rigs Rig NameContrectw RIg Type Rig NO. Rig Start Data Rig Release Date RIGq NORDICCALISTA LAND RIG 0981 51142019 Daily Information WeatherTemperature(°F) Wind Days LTI(days) Days NO(dayn) POB Cloudy 32.0 SW@12 MPH 44.0 Sa efy Incidents - Near Miss Data category Type Subtype Severity Cause Lost timet Comment Safety Drills Days Undl Next Check Type #Occur Last Dale Next Dale (days) AuthoOy nll 15/2020(8 52812018 -361 Rig lnspect0n 8 5232018 5252019 1 Safety MeeBng 8 52312019 5252019 1 Casings seat Can. Type 00 On) to (in) Grade Top(RKB) 1 Bud..itrs) TVD SOL(RKB) Run Data CONDU TOR 20 18.25 X65 3Z1 1fi1.0 161.0 101312010 CASING 13318 12.42 L80 -2.1]5.2 2,249.5 2.1699 11112010 CASING 9518 8.68 L.0o 36,0 8,5056 3,55].0 112122010 1 LINER 512 -1 10,0300 3,463.9 12/142010 Last Cementing Cemenbry tartDate: 111122010 Spring: CAGING, 8SGSARKB Comment: 5chlumbeger pump 5 bbls. H2O & test lines to 3000 psi. - OK\ Pump TO bus. of 10.5 ppg Mudifluffh 11%Dmp bottom plug \ Batch one S pump 300 late. of 12.5 ppg Deep Gate cement (1095 .1m) 1541 ftW.k yield with mk 0uld @ 5177 ,r/sk \ Drop tap plug \ SCblumberger pump 5 bible. H2O for wash-up \ Rig pump displace cement with 612 bible. d 9.1 ppg mud @ 6.6 tpm, ICP 142 psi. - slaw pump rete t0 3 bpm @ 6%psi. @ 800 bbls k Bump plug to 1150 psl. (500 psi. over FCP @ 650 psi.) %HOW Im-5 minutes - bleed! off 8 check Roals- Inlding l Gaud return through in some akght lose \ CUP @ 1810 hmA Land hanger and didn't mciproaded due to high Friction Factors (KBMI- Up w1= 290K - On wt= 85K. Estimated top of cement 5400'. Stg p Top (RKB) Top Meas Mem Bush (RKB) Com 1 36.0 Volume Calcula0dns B.50s.6 Pump Cement 100e+above the N-sand(540e) for zonal isolation of formation. Job Information Job PM1ase Planned Start o,ta Start Date End Data PH boom. (days) WORKOVER 511820191200 5/18201912:00 52420191200 0.00 Daily Summary Operations 241, Forecast Prep for dg move ta OPo305 241, Summary WD DOPE, NN X -Tree, perform Passport Testing hidden test) Rig Released @ 12.00Hm Operation at 07.00 OP17-02 Workdver operations complete. Time Log Start EM Cum Our Time Time Durmr) fie) Phase Opr. ACL Plan 0", past, 00:00 03:30 1 3.501 350 W.O. C 5 P PJGM. Nipple down stack. ENI Unit work named for putting tree and riser. 03,30 0430 100 450 W.O. C 5 P Nipple up tree and set test plug. Grease choke mane 04:30 0500 0.50 5,00 W.O. C 12 P Test tom. mad to 5000 psi for to min. Witnessed. 05 00 11:00 6 00 11 00 W G. C 12 P Perform Pass Pod testng on X -Tree. SIM OPSPJSM and Und work permit. Remove and ESP compla0on equipment and GBR tongs off floor via Crane. 11:00 1200 1 00 12.00 W O. C 5 P Install p..l heroperations and test. Rig Released @ 12:OOHrs Opt 7-02 Wo aver owmtion compete. NOTE: This will be the final report for OP17-02 W01kown Gas Readings Avg Background Gas (%) Max Background Gas 1%) Avg Correction Gas Ch) Max Connection Gas 1%) Avg Drill Gas I%) Max G111I as M Avg Tip Gas I%) Max Ind Gas (%) Cumulative Mud Volumes Active VOlume(bb11 Hale Valume(bbl) Addftlons(hbl) Cum Additions(bb0 Losses(bb0 CUM Losses (but Daily Contacts Position Contact Name Company TMe Email Office Mobile Ent represenratoo Russ WMmer Eni Dnlling Supv. OPPdrillmg@are com 90A685 -W15 907)20 -CCSB Eni repmsanWBve Chas Guam Em Drilling Supervisor OPPddlltng@entcam En representagve Wade Thaws Em Rig Clark 907-685-0722 Ent mpresedetiva He. Delp Ent HSE Tool Push Richard Tvmdt Nordic Tool Pusher Tod Push AI Hansen Nordic Tour Pusher Ogmana r,4g4@noNipc isM.com 907-670.8604 Tool Push Me*Harbst Nordic Nordic 4 HSE Personnel Log (POB) Company Sam. Type Work N (1,r) S h ndLy H the) Count Note Welllec Troc10f 12.50 0 25 Hours H Iltpurtdn Shok Line 12.50 0 5o hours BHGE (Vetm) Wellhead 12.50 1 12.5 Fours M Swam Mud cheaper 12.50 1 12.5 Fours ASRC Conim, Men 12.50 2 25 Hours IRS Pumping 1250 3 62.5 Hours GBR TubUtarrunndg 12.60 4 37,5 Hours BHGE (CentdlR) ESP 12.50 6 75 Hours Jacobs Equipment Operators 12.50 6 100 Hours NOMk Nordic Personnel 12.50 21 2625 Hours Well Name: OP17-02 OR Wellbore Name: OP17-02 Well Code: 25097 Job: WORKOVER WCER Level: Daily Report Date: 5/24/2019 Report #: 9 Page: 2 of 2 BOP Stack & Components Descriptmn announce Last Certification Date Pressure Rating (psi) Type Make Motlel ID Nam (int PRange(psll Lasl Cett Doh Slow Circulation Rates Pump Number: Make: Madel: End Start DateLi ner Size Iinl Volume Per Stroke Override Vienna) Max Pressure (psi) Data D.;(ditKeDate) Slow Spot Smoked(spml P(psi) ERI%) OFlow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: gal us Unit Size: Note: Data Consumed Received 543/2019 36]0 38]0Unit Returned Lum Conaumetl Gum Receivetl Cum Returned tum On Loc Note 00 0.0 Supply Item Desctlption: Rip Fuel Unit Label gal us Unit Size: Note: Ooh Consumed Received 543/2019 6330 00 Returnetl Cum Consumed 5,120.0 Cum Received 0.0 Cum Returned Cum On Loc Note 0.0 -5,120.0 Supply Item 0eacdpaan: Rq We%r Ung Label: bbl Unit size: Note: OMe Consumed Received 5123I20t9 0.0 00 Returned um Continued 88.0 Cum Received 1000 Cum Returned Cum On Loc Note De 12.0 Last Authority Visit Data Tot Imp. Nbr Total I.N.C. number Gammen 540/2018 SOP last wdness waived by AOGCC Inspector Man Hear am, next test due 5127/19 STOP Cards Submitted Company It aper Com NORDIC-CALISTA SERVICES 3 P M General Notes Comment 21 0125 30873 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. May 30, 2019 Ann.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper and Leak Detect Log with ACX: OP17-02 Run Date: 5/14/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 OP17-02 Digital Data in LAS format, Digital Log File 1 CD Rom 50-029-23439-00 RECEIVED JUN 0 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and Amjad.Chaudhry@eni.com Date:O U�iV" Signed: WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper and Leak Detect Log with ACX: OP 17-02 Run Date: 5/14/2019 21 -125 30 87 3 May 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 OP17-02 Digital Data in LAS format, Digital Log File 1 CD Rom 50-029-23439-00 RECEIVED JUN 0 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and Amjad.Chaudhry@eni.com Date: �V( I Signed: THE STATE "'ALASKA GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Operations Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP 17-02 Permit to Drill Number: 210-125 Sundry Number: 319-230 Dear Mr. Pierfelici: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.a laska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 10/2:5� Daniel T. Seamount, Jr. Commissioner 7� DATED this Q day of May, 2019. RBDMSdif MAY 0 9 2019 DECEIVED, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 2619 APPLICATION FOR SUNDRY APPROVALS �n n nn nr nen A P4 /"` lPo ,3`4 .r 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change out❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Eni US Operating Co. Inc. Exploratory ❑ Development ❑✓ 210-125 . 3. Address: Stratigraphic El 6. API Number: ❑ Service 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23431-00,6v 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 OP17-02 9. Property Designation (Lease Number): 10. Field/Pool(s): ff1yL 355024, 373301, 391283 Nikaitchuq Schrader Bluff Pool - 11. lip 5. 7_- /7 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18200 3523 18,040 3,522 1028 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 154 20" 154 154 Surface 2249 13-3/8" 2249 2170 5,020 2,270 Intermediate 8505 9-5/8" 8505 3557 6,870 4,760 Production Liner 97955-1/2" 18040 3519 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8505-18040 3557-3519 4-1/2" L-80 7909 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary ✓ Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch✓ ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for May 16th, 2019 • 15. Well Status after proposed work: Commencing Operations: OIL Q ' WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Proje anager Contact Email:amad.ChaUdh eni.CDm Contact Phone: 907-865-3379 Authorized Signature: �1 Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r30 510 230 — Plug Integrity L1 SOP Test Mechanical Integrity Test ElLocationClearance Other: -Y,31500 nS li �S y j / RBDMS (MAY 0 9 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Q Subsequent Form Required: APPROVEDBY Approved b COMMISSIONER THE COMMISSION Date: i / `/ 1Fl �7 0 �( �©-R (1 JN A Submit Form and Form 1 03 Revised 4720rovatl epplic ti i r nrgl om the date of approval. Attachments t Duplicate App 571,y s 7. r9 gni Cin�ii f� trollo�uiinn� 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.Pierfelici@eni.com May 6'h, 2019 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP 17-02. OP 17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through -Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888' MD. The ESP failed again due to electrical fault on 8/13/11 after facilities shut -down and was recompleted on September 5, 2011. The ESP failed again in July 8, 2013 recompleted on July 21", 2013 and put back on production, WO was performed in April 2018 and TTC-ESP was swapped upgrade with a new conventional ESP system to increase production. A suspected ESP failure has occurred in April 2019. Plan is to pull ESP and run a new ESP completion. The estimated date for beginning this work is May 161, 2019. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, V� \ Stefano Pierfelici Well Operations Project Manager OP17-02 Workover— Summary Page OP17-02 Rig Workover PTD#: 210-125 Current Status Well OP 17-02 is currently shut down. Scope of Work Scope of this workover is to pull the current ESP tubing completion and swap with a new tubing and conventional ESP system. General Well info Reservoir Pressure/TVD: The ESP downhole gauges are not functioning due to the electrical failure of the system. Estimated BHP is expected to be approximately 1,420 psi at reservoir depth of 3557' TVD. Wellhead type/pressure rating: BOP configuration: TIFL/MIT-IA/MIT-OA: Well type: Estimated start date: Drilling rig: Completion Engineer: Sr. Drilling Engineer: Well Operations Project Manager: Vetco Gray, MB -247/5000 psi Annular/blind rams/VBR/pipe Intermediate csg 9 5/8" was tested to 2000 psi for 30 minutes on April 11, 2018. Producer May 16" 2019 Nordic 4 Tommaso Mallano tommaso.mallano tni.eni.com Work: 907-865-3345 Amjad Chaudhry amiad.chaudhrvnn eni.com Work: 907-865-3379 Stefano Pierfelici: Stefano.nierfelicigeni. com Work: 907-865-3320 G f/ Procedure: 1. MIRU Nordic 4. 2. Circulate 9.3 ppg NaCl/KCI brine through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. POOH and lay down ESP assembly. 5. MU new ESP assembly and RIH to setting depth. 6. Land hanger, and test it. 7. Install BPV and nipple down BOP. 8. NU tubing adapter and tree. 9. Pull BPV, install test plug and test tree.( 5000 psi test) 10. Circulate Freeze protect through tree down IA. 11. Shut in well. 12. RDMO. Below the current schematic of the well: Surf. Casing 13-3/8", 68 9 +/- 2,249' MD, 2,170' TVD 31- Inc. Item MD (fl) Tracer Sub #1 16,601 Tracer Sub #2 15,330 Tracer Sub #3 13,911 Tracer Sub #4 12,793 Tracer Sub #5 11,826 Tracer Sub 96 11,018 Tracer Sub 07 9,500 Tracer Sub Me 81501 Nikaltchuq Field - 010,10k Point Pad Tubing hangar with 4' nom. Type 'H' WA BPV Profile, 4.5" Hydri6563 12.6ppf ani pup and HES Swivel joint Ifl�i"a➢1fr31P1116�q 4-%' 12.8 ppf, L-80 Hydril-563 OP17-02 Production Tubing Oil Producer with ESP Lift As Completed 4/15/2018 4 -'/.'cable clamps, for ESP Power Tracer April 2011 Cable, (1) 3/8" Chem Inj Line 7839' MD, 3513' TVD. 85.6° inc. - Discharge Gauge Sub 7916 MD. 3521' TVD, 88° inc.- Bottom of Motor Centralizer r BHGE (ALS) ESP, 93 -stage 538PSXD Flex47 pump, 513 GSB30B seals, 400 HP MTR562XP Motor 8,265' MD, Baker SLXP Liner Hanger/Packer HAL Zonal Isolation 5-'h' Silver Bullet Ea. Swell Packers Nose Guide Shoe Interim Casing I Slotted Liner, 9-5/8", 47 # Rosman Prod 5-%' 17 ppf 8,506' MD, 3,557' TVD - Tracer Carrier 18,040 MD. , 87° Inc. 3,522' TVD Confidential VetcoGray MB -247 SURFACE COMPLETION SYSTEM PRP 10161. NC i0 OF iU 29 JANUARY 2,009 '��^1 6� II'1pC�l00I W'0 P. a✓Jf4 rs/Iq_ 1 ��T71l111 ��f ► _ NIS -,�o- o��! II I�fli i F �znY��'l�hii PRP 10161. NC i0 OF iU 29 JANUARY 2,009 '��^1 6� II'1pC�l00I W'0 P. a✓Jf4 KILL LINE TOP OF WELL HOUSE 13'10"to GL Rig Nordic #4 PROJECTED RKB STACK UP ARRSR INSIDE KILL KILL RAMS MaHuaL W CHS CHOKE HCR 81,511 1312/1 CHOKE LINE Top Flange Upper Lock Down Screws 14' 3" 29.5" 77 85" RISER 16' 4" Projected 241911 34' to GL (Nordic Rig 4 251311 RKB 33.5' + 6" mats) k (Vet( Guc. OPI?—o • • t Z50 • Regg, James B (DOA) From: Wimmer Russ <Russ.Wimmer@enipetroleum.com> n Sent: Wednesday, April 11, 2018 6:24 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA);Wallace, Chris D (DOA) Subject: MIT 9 5/8" casing Attachments: MIT 4-11-18 Chart.pdf; MIT OP17-02 4-11-18.xlsx I included test chart.Thanks This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. SCANNED 1 • i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reocialaska.gow AOGCC.Insoectors@alaska.gov' phoebe.brooks@aleskaaov chris.wal/lace2Ttalaska.nov OPERATOR: Eni US Operating Co.Inc. 11 C/ I,T)y FIELD/UNIT/PAD: Nikaitchuq/Oliktok Point Pad '1 Lt it ii"' DATE: 04/11/18 OPERATOR REP: Dr.Supervisor(Wimmer Russ)/Steve Lawrence AOGCC REP: Waived Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 210-125 Type Inj W Tubing 0 0 0 0 Type Test P Packer ND 8210 r BBL Pump 4.2 ' IA 0 2250' 2250' 2240' Interval V / Test psi 2000 .BBL Return OA 160 220 ' 220 - 220 - Result P Y Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type IN Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result of s: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 80 Min. PTD Type In) Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Non: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval • Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result NNS: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W•Water P•Pressure Test I•Initial Test P•Pass G•Gas 0•Other(describe in Notes) 9•Four Year Cycle F•Fell S•Slurry V•Required by Variance I•Inconclusive I•Industrial Wastewater 0•Other(describe in notes) N•Not Infecting Form 10-426(Revised 012017) 2018-04r1MITP NIkaitdmq_OP17-02 • Z40(2)3?) 4149 S r ' d , f �F 1 1,1 � t I7 �1 • • 04N.a --;- , w 0 o I 0. 0. 0. 0. 0. 0. O. 0. 0. '0. 0. a 0. 0. 0.: 0. a 0. 0. 4 m CD co M 0 a E I- J 0 cn o Z >, U. Us L Q Z a) U � a) a 0 in' ) > cv m C < „ o z C o > O L � fn N � � _c N N •O > U a) E N E Li.' U 0 6. OJ = cnE ') cnv`o)icco v0W a3 C Y � o A o v � �' og> CL RI — 7:: Ea Lu I F2aiE 0. V 0as > co •y= C C Q. C Q o C) >_, 2 H c 13- co co N a) .� Q > a) o m0. 0. , c .. o a Y � 3 5a � oo �o � Q � (1) 0- 13 L 43 70N •- ` L a) co c > E > EP coL Q. M N a) U •- O O .� 0 -0N O co a) O N a ��LL� co) > OLL fn QmUULLN z > c4LLI- m W Z Z C) O k, N N _ Co 30 _ a N Q NI ° = E <- ,i. 0-aaaaaaaaaa O Z L , o z U a) E r- — d 0 Z � _ 5 "' w O L L us I•- a 2 O O � Lv N 2 iT Co Ire :_, U U 0 ,c N Z LLI ,, C C C U L C cn O C cn N N C LL 3 a) - O COL C O O v N O U ? a o D LO cyto vii 0 0 O—a. > > m IX w o c Q Z E) UJ co N y c a) = p „ C a. — L. ca c >co > O O Y CO c - OC o_ QZ rnuoiW p` -) a) co co a-1 '= pz, o u0. TU0 a) L L a) . a m 0 G 0 �.0 ° ° c"o CO N ° a�Oi Y co c L wit/ U 9 Z = w co E U 5 0. O O as co0 - a) Z I_ o LC,n cl ca s �o Q 0. .. a li 3 "0 0) 0. " 0 co Q >' o N. Cl) N J O .a, O a) cn ++ O 7 a) a) (B N _c a) •- a) o C CO ›., Qp 0 0 0. E _au 20cn (DQ0c - _Y LLD UIY Y cn Q co W CO co Q a 0. 0. CL CL CL CL O. CL CL CL 0- CL CL as aao. o N O . r4 co o a) D 0 rn0 v W CV . a0 zoLLJ 1.- o o O � cn Qv Loz'. 4 ° y = 0 E o Gw ZZLu 'z5 aim m �' W 73 F- co m N N Ncc c �_ c C o _ cn N C N C cn I-- 0. U LO cNn cn a) c) E E y N U a CO ~ c 0. W Z ZtU7 m ms- L C Q. CLN Co aa)) t a) m > Q O a) a) o •Q o cc W O C O O Q) ,a E N 0 C J a c0 > ` a C•J O Y O J 2 2cn a a) Q U m coo C C co 0. 0. C Y a) c > CD a)) c Z o U a) U Q 0 o) g) o. m Q o o c a C o .UO. cJ U co cCv o o nw. a) o m 0 EEo � O � � Q0. mJcn0YH22LLOu. 0 Et i: yOF Ty • • e.,9%II/7• THE STATE Alaska Oil and Gas Of�LASJKIA. Conservation Commission 333 West Seventh Avenue M ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF r Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck D&C Engineering Manager Eni US Operating Co. Inc. SCAN 3800 Centerpoint Drive, Suite 300 Anchorage,AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP 17-02 Permit to Drill Number: 210-125 Sundry Number: 318-096 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 2-°-day of March, 2018. FIBDMS11 MAR 2 12018 • • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 7 2013 APPLICATION FOR SUNDRY APPROVALS CO 7/2o/ !V 20 AAC 25.280 q 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 ' p ..,,,...r—on..shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change out0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co. Inc. Exploratory ❑ Development ❑✓ 210-125 . 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23431-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / OP17-02 • 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024, 373301, 391283 Nikaitchuq Schrader Bluff Pool 01 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): / Plugs(MD): Junk(MD): • 18200 3523 . 18,040 3,522 1028 t/ N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2249 13-3/8" 2249 2170 5,020 2,270 Intermediate 8505 9-5/8" 8505 3557 6,870 4,760 Production Liner 9795 5-1/2" 18040 3519 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8505-18040 • 3557-3519 4-1/2" L-80 7909 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for April 1st,2018 15.Well Status after proposed work: Commencing Operations: OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Marc Kuck Contact Name: Amjad Chaudhry Authorized Title: D&C Engineering Manager Contact Email:_amiad.chaudhryc enipetroleum.com Contact Phone: 907-865-3379 Authorized SignatureZ.-- ---.._. Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 _4_, ti V ILL Plug Integrity ❑ `_ t p BOP Test cr. A Mechanical Integrity Test ❑ Location Clearance ❑ Other: I,�,j e.. 1c.! DIS v,6%—feecr. Zd 4�'!n'G 2..5'. Z�s ) -A-0 poops i ' oP 'rest" Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Zr Subsequent Form Required: jt -. 'dpy Teff Niru APPROVED BY ) Approved by: LOCI-- COMMISSIONER THE COMMISSION Date: 1Z'�l tte, C. 4, „„) j' Form 10-403 Revised 4/2017 Approved application is I' 1 I t`SRrOhl�th L of applta�BDM��'�"A M^ ± Fend t[achments m Duplicate • .007" • Enil PetiroIkum enn RECEIVED 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 MAR 0 7 202 Marc Kuck Phone (907) 865-3322r`o nn Email: Marc.kuck@enipetroleum.com 4� March 6th,2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies fora Workover Sundry for well OP17-02. OP17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888' MD. The ESP failed again due to electrical fault on 8/13/11 after facilities shut-down and was recompleted on September 5, 2011. The ESP failed again in July 8, 2013 recompleted on July 21st, 2013 and put back on production, currently well is on production. Scope of this workover is to pull the current TTC-ESP tubing completion and upgrade with a new conventional ESP system to increase production / The estimated date for beginning this work is April 1" , 2018. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Marc D. Kuck Drilling & Completions Engineering Manager • • OP17-02 Workover— Summary Page OP17-02 Rig Workover PTD#: 210-125 Current Status Well OP 17-02 is currently producing. Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and upgrade with a new conventional ESP system to increase production. General Well info Reservoir Pressure/TVD: The ESP downhole gauges are not functioning due to the electrical failure of the system. Estimated BHP is expected to be approximately 1,420 psi at reservoir depth of 3557' TVD on February 1st Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out. 4 � t 7—_ Sq Well type: Producer Estimated start date: March 15th, 2018 Drilling rig: Nordic 4 Drilling & Completion Engineer: Amjad Chaudhry: amjad.chaudhry a,enipetroleum.com Work: 907-865-3379 Drilling & Completion Engineering Manager: Marc Kuck: Marc.Kuck(a,enipetroleum.com Work: 907-865-3322 Well Operations Project Manager: Stefano Pierfelici: Stefano.pierfelici@enipetroleum.com Work: 907-865-3320 • • Procedure: 1. MIRU Nordic 4. 2. Shear lower GLM valve and circulate 8.6 ppg hot water with 3 % KCl kill fluid through tree-('u..1C-? 3. Set BPV!ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 5. Circulate out remaining production fluid. 6. Continue POOH and lay down ESP assembly. 7. Perform a CO run 8. RIH and set a plug +/- 8200' 9. Perform casing pressure test to 2000 psi. record it on chart 10. POOH and LD plug. 11. MU new ESP assembly and RIH to setting depth. 12. Land hanger, and test it. 13. Install BPV and nipple down BOP. 14. NU tubing adapter and tree. 15. Pull BPV, install test plug and test tree. 16. Circulate Freeze protect through tree down IA. 17. Shut in well. 18. RDMO. Below the current schematic of the well: lVacuum Insulated Tubing(VIT).4-W x 5-16", eni us operating 79'length.two joints """ OP17-02 fit 1111 4-W 12.6 ppf Production Tubing Oil Producer with 2399'MD,2,295'TVD,36.5°inc.-GLM,KBMG, 4-W x 1", ESP Lift with 2,000 psi STS-1 SOV installed As Completed 7121/201 3 fla4-W cable clamps,for ESP Power Tracer April 2011 Cable,(1)3/8"Chem In)Line fir. 7,754'MD,3,509'ND.85.6°inc.-GLM,KBMG. 4-W x 1",with 3,100 psi STS-1 SOV installed 7813'MD,3513'ND.85.6°inc.-Discharge Gauge Sub 7915'MD.3521'ND,88°inc.-Bottom of Motor Centralizer Surf.Casing TTC-ESP,198-stage(80+116)380P18SXD pump, 13-318",68# 1n 513 GSB3DB tandem seals.210 HP MSP motor +1-2,249'MD, 7.930'MD 23#Shroud Assembly with cable and 2.370'ND 31°Inc chemical injection line feed-thrus 8.285'MD,Baker SLXP HAL Zonal Isolation 5-W Silver Bullet Ecc. Liner Hanger/Packer Swell Packers Nose Guide Shoe Item MD(ft) Tracer Sub#1 18,801 '10111111111111, * 1At 7�e +r. 1,4012.Tracer Sub#2 15,330 Tracer Sub#3 13,911 Tracer Sub#4 12,793 Tracer sub#5 11.826 = M IMI% um +i, MIA Tracer Sub#6 11,018 Tracer Sub#7 9.500 Interni.Casing Slotted Liner. Tracer Sub#8 8,501 9-5/8",47# Resman Prod 5-Y,"17 ppf 8.508'MD.3,557'ND Tracer Carrier 18.040 MD, 87°Inc. 3,522'TVD Nlkellchuq held- Okktok Peril Pao Confidential , • • VetcoGray MB-247 SURFACE COMPLETION SYSTEM AL s• 7.1- ,Io. iiiiiiiii 4,-*iiiiniiiii;', tiiiv, 1 : r1 ' is imewo 7:•Fill .002 OFFSET C/L I BA.S, EL 78'7-1/47 EL 78'2-1/4' OI O �� D1 ��/. PBEORIR{I 2/A, 13-0/51 5000 PSI %4 •P1 : VC 5177 CLOMP /��'.. 1 ._..01li n N pho erili - III- acjI3liii '411711.1r1111IIl��, 0477 0Fs5Ei ,00.0 , .......•, 4.50111 P!MI 2-1 IV 7-1/161"P. N. t , /FI ligi 5000 P51 .e.r, ` �� artoF roSmoN ,�•500o P.1 52.W ` iI III V0,04 000. m 1 , , , 1. aur 0� 7a.2 Oil � �f..rasmo0 .� I Il i .aa911 . 1. TOP OF ORAO4Na.._.__..____1 , I F I EL 16TO I/4• f Lao 1 N 20"OD 134 K-88 • 13-3/0"00 8B/L-B0 — EN'ALASKA 00 53.5 L-BO �-~ HORIZONTAL MULTI-BOWL SYSTEM ♦-l/z•00 wRN.-!/B VII -_._ 2x a 13z/IBTNX 8-5/85/8M _51• ---•-- ANO ESP FLAT CABLE II MN ON fajfignnTairr N17J370-I PRP 10161. NC 10 OF 10 23 JANUARY 2009 ( _ )GE irlag,,,Uor,u:work 0i • • 'U N o � + �• Owi- m `n E \ z 10 m W cC m 1 rn m zn ' 1. N N N to mommo CO 73 j� 4 4.t CU 4 .4--- 0-,.— * cc c-I CN \ u I -V �y co O m CC ► r-Ig to 3 ... i. N V CC '� r..I CCto o G1 Q L.LJ c t Cl. z ct LU V a D 13 O N U O Z Y I_ bl° CC CC Q vi IP , ;W I i • ii ►4ii I' 11fl: 14.i I _ 11111 III III ... I mIn a e 5 I ►*+ In in 4 w D sZ o (13 E— ILII J w � > o c LL ++ o 0 COC w Orn Z Hr"-I 7.1 J J • S O 3 I. 8 w g' �iE f g ..:S nN 02LL 8 s, — ►�� 1�1 I �i 1 i t III b iig 1 '"I E. o m .. : o —----- a 4 w w E F NSW " ° 1 I r F f u W :_,,s,,, 11 ii es .. 1,25 y j 2 F 2a f .•• S9W 01 V V w *` o E F' r :. m II L. , f f Z i �` h '' U � 1's 1 - f I.....� a 0 m m Ilea t3830 3 1 i 3 a o 4rc� • • • Eno Petirolleum eno 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 . Marc Kuck Phone (907) 865-3322 Email: Marc.kuck@a enipetroleum.com March 6th, 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP17-02. OP17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888' MD. The ESP failed again due to electrical fault on 8/13/11 after facilities shut-down and was recompleted on September 5, 2011. The ESP failed again in July 8, 2013 recompleted on July 21st, 2013 and put back on production, currently well is on production. Scope of this workover is to pull the current TTC-ESP tubing completion and upgrade with a new conventional ESP system to increase production The estimated date for beginning this work is April 1St , 2018. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Marc D. Kuck Drilling & Completions Engineering Manager 0 i 1.11 C I0 CC CO C W N C k'-: It �- .p m .- W W r M N r W m umi n m N nn-- OQi W m W o co OU ' - C7 0 /� LL C`.../�,J rl CO M C N 0 M W CO CO n m n 'a T N n N n W O m Q M O O U) p / U) Q CO N M m CO CO d N a N N N M M N Q N N M d N V M W i 0- C7 LU CED TA e O �� ''� L� 'CC 0' IR CI M NnNNNU NWO CO Co N W W CO N 0 n CO N CO 4'iin .f N 0 N Q XN n d 10 N Q CO SO N N 2 aN 2 0 M v v 0 o vC y �9 2 C a O _5' m 0) co co 0) 0) O W co C co ^ W n ^ CO CO 0) ' ' ® m ^ N 0) N C) n Q 0) e> LV ' C O N O w 8 N N G r D' m O u m N 17 A O) N A N N O) - N N lvl ° 2 0 W N dN 10 St SD n N r If01 1� 9 O O "0pp v 1,2 ? Q M N /7 M N N N N Q )` M CO N Q N z D 2 > a m 0 65 LL C m 0 nn N m N N m 0 N 0) CO C N CO 0 W 0) CO N N m N N m W 0 0) n E N a E n n co n n n n co n n N N n CO C n SO C n C P n n n CO n N n co 2 CD W 00 r4 P. 0,coZQ O fh aC _ Q NNNN .- NNNNN 0 M 7 COM 0 N N n CO � N N N N N yQ ' Wa grewN LL J N ..ti C7 ii.; m Z UaQ N N O 0) CD N M d d 0 CO 0 N N O NPNN NNNWOJW p W W W W C W W W n C W n srNM NM d N co N N N N N N N N N N N C) N N N N N J N Co x 0 y NC OM WO Wn N N n O OO Q Cd n C v O O N ON anSCO N N n n nZ Z N N NM N N N d N N N C1N N CQ O 0 O J E FeO cCO Mm N to N0 m o o CD 2 NNM NOO C(n F COCN N N N ' N NC) NN NNNNNNM 5 5 L Q N LO N C mV.0 _ CO CO �,{ COm m C m m m CO m m C C C C aa} E 0 N N Q N r r r r r N r r r N M r r r Q V N N N m S. N W L N r r W 0 o y U E m a H 2 x' WLLF. CO 10 0 In In tO in N N N N CO N N N N N N N N U) N N N N N N N N N d 2 2 IL z - O N to. m a c F m CD CO m CO CD CO CO CD C m C to to CO CO CO m m CO CO m C CO Amy, m m m m rv. y C o Q f6o a fd {6 , a {cps (6 ab o) (o 6 {<�d (J)) Jm'. p m '1 o NJ, (A '� u5 A m' o '/1G co O �+ O O O O O O O O O O O S a a C� S O O O N L pt H ,7(cQ 0 0 0 8 o g$ o 0 0 0 o cg o o8 o Q oa g 3 0 0 00 8 8 p o 0 E 5 o 0 a $ a 0 0 0 9 oa `b) 0 o `mY' 0 0 o d o $ A $ 2 2 0 0 0 0 0 0 o c d rb a n d m W n' N z M m s '� m c7-, ; a N „ co M N d N C Q N N N N SV N N N N N N N N N N N N N N CO CV N 0 C SA N N N N N N N N N N N N N N N N N N N N N N N N N N N N N ti e N h0 1 0 1 0 0 ,p1, 0 0 0 (Q� o m t�Qj pm m m m m m o m CO m m 1v m CO 1 m 3 0 try 1S j N An CC) 0 )O N U) 1O U) N SS) 1f) N N 10 Ya) 1O N Vd) LU') 0 IO 1(5 p0) Y1 N 10 E E g L 9 E. E ¢ W U Q A 0 0 0 °i N 2 n N n N M M _ C 2 d d 8 d 8a. 1 [Mi) a.8 C O H W W 2 n z W 2 N 3 2 M W N c� - m nom. z .- 4 u65 coo o N (6 m z N 2 4 z 2 3 .1 A 3 y a ?? to E o 0 0 0 o N ti °� W m .{ ,J, c z w 3 a a a a LL a a a a a a a o p p N N lS N N N N M N 0 m :7- z 0 0 0 0 0 0 0 0 0 0 0 tan co v) N N CO dap y co tail U) U) ) CO °) co cocco Q L '� Alaska Oil and Gas (CrOF ��j,�s� THE STATE�� of Conservation Commission ____ ALAs A `. 4 ,E 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OF ALAS Fax: 907.276 7542 www.aogcc.alaska.gov Marc Kuck Drilling and Completion Engineering Manager 5 Eni US Operating Co. Inc. °"- 3800 Centerpoint Dr., Ste. 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP 17-02 Sundry Number: 315-070 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P- 1( 4'iLr __ Cathy P. oerster Chair DATED this I day of February, 2015. Encl. SCANNED 1'LL 2 6 ::iii `.s . STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 0 2015 APPLICATION FOR SUNDRY APPROVALS Ori et/ e(5 A 20 AAC 25.280 OGCC 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑., Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing Q Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: _ESP Change Out_ Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Exploratory ❑ Development Q• 1210-125 • 3.Address: Stratigraphic ID Service El6.API Number. 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23431-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? ✓ ?K/2N Will planned perforations require a spacing exception? Yes El No ❑ OO . OP I T –D). 9.Property Designation(Lease Number): 10.Field/Pool(s): 0373301,0355024,0391283 • Nikaitchuq Schrader Bluff Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): •18,200 - 3,523 -18,040 - 3,522 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 154 154 Surface 2,249 13.375 2,249 2,170 5,210 2,480 Intermediate 8,506 9.625 8,506 3,557 6,890 4,790 Production Liner 9,775 5.5 18,040 3,522 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,506-18,040 ‘ 3,557-3,522 41/2 L80 7,930 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A Nff[ ' E'reN. 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program O BOP Sketch ❑' Exploratory ❑ Stratigraphic❑ Development ❑r • Service ❑ 14.Estimated Date for 21-Mar-15 15.Well Status after proposed work: Commencing Operations: Oil E• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature,,„......... . Phone Contac 907-865-3328 Date 2/9/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\S — 6`1 4/ Plug Integrity ❑ BOP Test 121Mechanical Integrity Test ❑ Location Clearance ❑ Other: -� 3500 /5, /30.( /Q,4- ( /2&4sf ., 0 Pry Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: /6 -Y(.1 / 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:2_,45, _, ,-- ,4,<-,-- —/ _J 1 �3 RideitiAaLl ' If �`� Su is nForm ane F 10-403 evised 2012) for 12 months from the date of appro al. i � Attachments in Duplicate RBDM� FEB 2 3 202015 i�l��'i8�i� EnO iiiiiiis RECEIVED FEB 10 2015 _Mt ACGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: Marc.Kuck@enipetroleum.com February 9`h, 2015 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage,Alaska 99501 / RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Workover Sundry for well OP17-02. OP17-02 was originally completed by ENI Petroleum at Oliktok Point on December 19th,2010. In July 2013 a work over was performed and the well was completed with a Thru Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at 7,930' MD. Currently the well run at 65.6 Hz, so in order to improve production rate a new ESP system will be installed. The estimated date for beginning this work is March 21t', 2015. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information,please contact Giuseppe Maugeri at 907-865-3328. Sincerely.ra Marc Kuck Drilling&Completions Engineering Manager OP17-02 Workover— Summary Page OP17-02 Rig Workover PTD#:210-125 / Current Status Well OP 17-02 is currently in production. k Scope of Work AAA( Scope of this workover is to pull the current TTC-ESP tubing completion and run in with a new conventional ESP system. i General Well info Reservoir Pressure/TVD: The ESP downhole gauge are still functioning and reading 671 psi at 7,915'MD/3,521'TVD on February 9`'' (well in production). Reservoir depth is 8,506'MD/3,557'TVD. This well is expected to have a static max bottom hole pressure of approximately 1,300 psi during the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out on November 17th 2010.✓ Well type: Producer Estimated start date: March 21th 2015 Drilling rig: Nabors 245 RWO Engineer: Giuseppe Maugeri: Giuseppe.Maugeri@enipetroleum.com Work: 907-865-3328 Drilling&Completion Engineering Manager: Marc Kuck: Marc.Kuck@enipetroleum.com Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. Shear upper GLM valve and pump 9.1 ppg 3% KC1 brine inside tubing through tree and circulate to surface. 3. Ensure well is dead. 4. Set BPV. N/D tree and N/U BOP and test to 3500 psi. 5. Pulling tubing to upper GLM. 6. Pressure up and shear lower GLM,pump 9.1 ppg 3% KC1 brine inside tubing and circulate to surface. 7. Pull tubing to ESP and lay down ESP assembly. 8. MU new ESP assembly and RIH to setting depth. 9. Land tubing hanger and test it. 10. Install BPV and nipple down BOP. 11. NU tubing adapter and tree. 12. Pull BPV, install test plug and test tree. 13. Circulate Freeze protect through tree down IA. 14. Shut in well. 15. RDMO. Below the current schematic of the well: 1 — —_.—Vacuum Insulated Tubing(VIT),4-%,x 5-%=. PAI ��operating79'length,two pints NIB ____�--4-W 12.6 ppf Production Tubing Oil Producer with ESP Lift lk ItION 2399'MD,2,295'TVD,36.5°inc_-GLM,KBMG, 4-W x 1", with 2,000 psi STS-1 SOV installed As Completed I! 4-CI %:'cable damps,JroESP Power 7/21/2013 Cable,(1)3f8'Chem In)Line 7,754'MD,3,509'TVD,85.6°inc.-GLM,KBMG, 4-W x 1",with 3,100 psi STS-1 SOV installed 7813'MD,3513'TVD,85.6°Mc.-Discharge Gauge Sub 7915'MD,3521'TVD,86°Mc.-Bottom of Motor Centralizer S� Centrilift TTC-ESP,196-stage(80+116)380P18SXD pump, 13-3/8",68# 513 GSB3DB tandem seals,210 HP MSP motor +1-2,249'MD, 7410 2,170'TVD 7,930'MD 23#Shroud Assembly with cable and 31°Inc. chemical injection line feed-thrus , 8,265'MD,Baker SLXP Liner Hanger/Packer HAL Zonal Isolation 5-W Silver Bullet Ecc. Swell Packers Nose Guide Shoe Item MD(ft) Tracer Sub#1 16,601 „ ___ Tracer Sub#2 15.330 lIIIIMW Mir - .rvim- , Tracer Sub#3 12.793 I I " I ,I I Tracer Sub#t4 12,793 Tracer Sub#5 11.826 A J Tracer Sub#6 11.018 ---' `— - - Tracer Sub#7 9.500 Interni.Casing Slotted Liner, Tracer Sub#8 0.501 9-5/8",47# = 5-W 17 ppf 8,506'MD,3,557'TVD 18,040 MD, 87°Inc. 3,522'ND Nth Field- ktok Point Pad Confidential R J irr4 N $ sa W tt g U � Q11 frIIIUII_I5-4' wF lk � � a W 3 � i _. W d 11 m L21 1 , 1 :1: ;lei g r 1 Iw `' I au.�n n Ela. I Z IiFi:IUiJ Lt Ct R P I. I I [IL■�i1,111= 011 _`__ a 6'@ II ® M_o „ _ ' iii - oQ' Zw I. a o 0 0" �� o k v8 -t>y 2K iaMO - n~p := '%.::, 4 " Bio$ %i@E 0 • Off" • 2 cJ 11-'yr I 1 IW ,:;`s1= i' I,� N V O s �� ■ ■ ■A ■ ea Z IA_ WIIIII ii 11111 --- R �� III IQ I1.11161 w ;; a Y m w Lu TT ■�, LI _ o cc 14111to _ g .r/I r-s k N VetcoGray MB-247 SURFACE COMPLETION SYSTEM _,_ -YNN/CL r-------x.3.50 J "IS 37.19 - u !. o. -,.; itiF....iit1.11 am!! f..,."11,11.L.4.., elfi50 T i,,Awm-lizgit .•i� /'Moir T.O.S. EL 26 5-3/4" "-- so 1.062 OFFSET CIL ! B.O.S. EL 25' 7-1/4" F.LTOP OF WELLHEAD 5.00" EL 25' 2-1/4" 1 / J l b ' FL CI ELECTRICAL or, FEEDTNRU 2,.8, i !,1— 13-5/8"5000 PSI r�w�w VG S137 CLAMP . 4-1/16' �� 5000 PSI maikila hello.1_ _. ..G LJ_. —_ -1'rigi:Jill 3.437 OFFSET 108.0 g VISE II. 13.50" 2-1 16" il 5000 PSI —;��:7:;.. __..I� 5000 PSI E ': 66.71 OUT OF _MR- ,:. �� POSmON __i, "" 4199! 130 134 537 PSI vMOO. 52.96" .Wirt J 181 20.5. is {'j r . ..'cam I 34.00" 2.1/16" •.•Atili "' � 50017 P51 OUT OF 24.2 r- , 15.25" POSRION ■=i� j=• 1l ' TOP OF GRADING III ., - I 1 EL 16'TOG 1-1/4" L1.00 .PROPRIETARY.NoncE at M.�. vetcogFBy- 20` OD 133# K-55j�li` R•r•.r+. 13-3/8" OD 68# L-BO VO0 HORIZONTAL MUL ENI SKAWL SYSTEM KA 9-5/8" OD 53.5# L-B0 �.ee Pa 4-1/2" OD WITH 6-5/B VR UU ( _ 20 X 13-3/8 X 9-5/8 X E.AN X 4-1/2 WITH 6-5/8 VIT MINN NM AND ESP FLAT CABLE 23 AM•L ro e•E Iff is r H173370-1 )� OP PPRU INS PAM R RIX XXXI•IR ILLI x I, R• PRP 10161. NC 10 OF 10 23 JANUARY 2009 ( ND )GE Inoginaticn o:work 0 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. cQ La - I as- Well History File Identifier Organizing(done) ❑ Two-sided III 111111111111111 ❑ Rescan Needed III IllillU 111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) for Items: ❑ Diskettes, No. ❑ Ma s: ov/ Greyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner Cbfl R i/O N ❑ Poor Quality Originals: r 1,0 &S OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: /� El Other:: BY: Maria Date: p/0 I /s/ rvif Project"ect ProofingII I II111111111 11111 BY: Date: 3 a Q i 7 /s/ rvtf (7\lana Scanning Preparation 9 x 30 = vC70 + c.7 = TOTAL PAGES 7 (Count does not include cover sheet) a BY: Date: 3 , 0 Is! u Production Scanning II 1111111111 Mil 3 Stage 1 Page Count from Scanned File: aCi. (Count does include cover heet) Page Count Matches Number in Scanning Preparation: ES NO BY: WE. Date: 3 ita Q `q is111413 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 1111II 111N 11 III ReScanned III 11111111111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111III IIII III o C = o C U c 2 -• . w m O E m O 0 of C) 30 0 3p 3JLL O) o f U C E o ' 0 a) r I m o 0 o p > a) o a) U N Z D U € a ~UEa a J J �° c 0 0 °) m .2> Z > .2 N O iti °� Y3 mxf�o� aaias��= c o 0 0 2 a E 0@ = m co,-) cn .>2 in 9 p d __•5 n _a .5) _Tti g . is 0 0 L m u_ 3 0 0 , 0 0 o H E a) vE m a5 Q2 Fs LL 0 E o 0 N C a a a a o o •N o •y T a) E >W d 0 wa0 • ) 0 LL > J 00 5 2 2 2 ti N w z o V comm al o m m0 a p a p a a m m m m 0 p p p j 6:c)pp iLUppd rn 2 I- 2 2 2 a a 0_ d o 2 F- 2 H 0 0 _ `'> CL O O O O O O _ O O O O NNN J 0 •V O O NQ m 0 N N N N N N N N N N N N _ _ _ _N N OOOOO 0 X M M M M M M M M CO M M co J f- '•' I E O 7 2 •- C C C C C C C C C C C C C C C C C ? 'Cr) C = = a a) a a a a a a a a a) a s Cl). a) s I— ° Y 000°- O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N 0a LI. O a o 0 0 0 0 0 0 0 o O o o 0) 0) rn C) 0) O o 0 0 0 0 0 0 o v rn 0) rn rn rn Z j N O N N N N N N N N O 0 r O 'p CO W CO CO CO Co Co CO CO Co Co CO CO CO CO CO co CL g w w ce d C t O co 0 O co M M M W 0 O 00) 00) m 0) Co CO CO CO O V w O Z o 8 0 < R i ce z° J a o o o'y 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 G co N 'j ZI J a I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 �j a� ! y a) O a Cl, C1 l0 E a0 0 N N N N N N N N N N LO N N LO LO UO 0 E ...1 CO J r I en LQL I�' Ali 1."' N p I 9 - O N 1 a Cr) m a = z CD w QQca a Y p Q 00 w z 0 z Q c -CF). zI 1 � - - w w w Q z o CC a' •a'a� > '> '> > a) U 0 0 > > N N N v) E J X m m ai ai a) a) Z 3 O C 2 fX X Ce Ir-. LL 77-3 I E0 oJ JJ J J J J J J J •y U U U U IM C to N Cil fa 10 Z y a) 7 7 7 7 7 7 7 7 3 7 c 10 17 73 73 C) N > O J /... 0 'O 0 15 E 0 e- a a) 0 0 0 j 0 N 2 O 0 W 0 Z :i, Q 0 E w 0 a 0 u c 5 0 a $ w LL m Z w °' 2 \.) ,N� \ \ , ) 1 \ \ N \ 1 0 E 0 a 0 J dp 1 w 1 F- a 0o 2 ai. 3 0 OOOOOOOOOOOO O O O a- re , 0 H J 0 H W J J J J J J J J J J J J J J J O I 1 O UO >. N N U 0 Li- j I 9 UUd0 I 1 i ZC 0 m .c a , r co Z cOi a) c/ (/) cn c 3 N 'E c C O C 0 cK d I � I T UN •o .9. y O w O 'I O _ OC > w . ,i I OO 1:9 Q 0 > O N j I to o > aa , aam .Lm a a. CO CO a co HO t O L ✓ J N N N N NN N - .N U 0) 0) 0) 0) Q) 0) 0) i 0 ..0 .r.- Cx0 C.) c cc c cc c c d CO y Z roa a a a a a s o. a E - x I— U v) 0 0 0 0 0 0 0 0 U�\m� co Ce Z °' �i rn rn rn rn (-4. °) O 7 y, 00 00 d U m - - COCO — — ao n m a N N CL cam ; _ W w (0 Z Et p cn Nr 0 0 0 0co •ctco co 0 o cs- W m y 0 0 (1) _ J N N > U Z O N a) W V .... N N Z 1 �I CL a o I Q O co wo c a) 7 N o Om 0 mc U U U U U U o O i° 1C N ca) I O to a E N N N to 10 I 1 1 UO 0 0 Ql0 0 v o 0 0 2 co c 5� N .N f0 c W a N C +. 0 O I a) a O co Cn I- _ Q rn Q Y E o a) Q ICCa Z O > > > > > > > Oil 1 Z O N N N N 7 1N N V) Ce IYCCQ C y O >, O O O O O O 1 Z � • N C I 7 c 7 7 7 7 7 7 M C 0 C C C C C c Ir Z o N O In o O H EZ) m N j cc. n c Q Qd/! T3 O d Q d N a aC) c c CI. 0.. II d q) W ,. R G 7 7 N .- •� O ' IU U > yN Z Q p.J ` Jy C 2 co \ O 6 J\\ ‘, .iiU OU Uo �y.�OEda C 0 JJJ a > a 2 J J J W W —_ _I < > 0 Q C I U , 0 OAP* 1%%i THE STATE Adizska Gil and Gas 44) ASKA CLLL`VICLLLmuk GOVERNOR SEAN PARNELL 333 West Seventh Avenue gP Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Marc D. Kuck Production Optimization Coordinator Eni US Operating Co. Inc. � ' 3800 Centerpoint Drive, Suite 300 0 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Pool, OP 17-02 Sundry Number: 313-366 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, , /a90/44,4*--' Cathy :. Foerster Chair DATED this /7 day of July, 2013. Encl. RECEIVED i STATE OF ALASKA t`� JUL 1 1 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑., Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing Q Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: is f'tou•4,1,:bor ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc.. Development DI Exploratory ❑ 210-1254 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23431-00-00* 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ OP17-02• 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024, 373301, 391283. Nikaitchuq Schrader Bluff Pool* 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): g18200 +3523 .18040 . 3522 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2249 13-3/8" 2249 2170 5,020 2,270 Intermediate 8505 9-5/8" 8505 3557 6,870 4,760 Production 9795 5-1/2" 18040 3519 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8505-18040 . 3557-3519 4-1/2" L-80 7909 Packers and SSSV Type: Packers and SSSV MD(ft)and:ND(ft): N/A IJ AIJT' IA 13 N/A g t),IoS i4.6 It t}IID 12.Attachments: Description Summary of Proposal 0' 13.Well Class after proposed work: Detailed Operations Program D. BOP Sketch Q- Exploratory ❑ Development Q- Service ❑ 14.Estimated Date for July 15 2013 15.Well Status after proposed work: Commencing Operations: Oil 2. Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 7•/G•/3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: C S 4..k24 ie GSTOR 111 SPLUG 11117.I hereby certify that the foregoing if true and correct to he best ef,ftif knowledge. Contact Marc D.Kuck Printed Name Marc D.Kuck Title Production Optimization Coordinator 7 Signature j Phone 907 865-3322 Date j/d /i.? COMMISSION USE ONLY �j Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓13 '3(610 Plug Integrity ❑ BOP Test Lid Mechanical IntegrityTest ❑ Location Clearance ❑ Other: 41 S S /05C- L�°J"nSt- lx„.(1,15 tsAd_*aq Atri-ki ' 0 YLs diGO Subsequent Form Required: /p—Yd L1 RBDMS JUL 2 3 20 \lt APPROVED BY Approved by:ICP71Q;1€414 — COMMISSIONER THE COMMISSION Date: 7_17„/3 7413 Form 10-403 Revised 1/2010 • Submit in Duplica ORIGINAL ..„-= �� 1al13 RECEIVED JUL 1 1 2013 Enii Pet Mu AOGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907)865-3322 Email: Marc.kuck®enipetroleum.com July 10th,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc.hereby applies fora Workover Sundry for well OP17-02. OP17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888' MD. The well was started up for production on February 8, 2011. It was operated for approximately 45 days when the ESP failed on March 25, 2011 due to an electrical fault, repaired on 4/17/11, and put back into production. The ESP failed again due to electrical fault on 8/13/11 after facilities shut-down and was recompleted on September 5, 2011. The ESP recently failed on re-start attempt after an unplanned facilities shut down on July 8, 2013. The estimated date for beginning this work is July 15th,2013. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information,please contact Michele Cesari at 907-865- 3338 or me at (907)865-3322. Sincerely, i 79/ Marc D. Kuck Production Optimization Coordinator OP17-02 Workover— Summary Page OP17-02 Capital Rig Workover PTD#: 210-125 Current Status Well OP 17-02 is currently shut in waiting for rig workover. Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and run in with a new TTC-ESP system. General Well info Reservoir Pressure/TVD: The ESP downhole gauges are not functioning due to the electrical failure of the system. Estimated BHP is expected to be approximately 1,300 psi at reservoir depth of 3557' TVD on July 15`t'. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out. Well type: Producer Estimated start date: July 15th, 2013 Drilling rig: Nabors 245 RWO Engineer: Marc Kuck: Marc.Kuck@enipetroleum.com Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. Shear lower GLM valve and circulate 8.6 ppg hot water with 3 %KCl kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 5. Circulate out remaining production fluid. 6. Continue POOH and lay down ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, and test it. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree. 12. Circulate Freeze protect through tree down IA. 13. Shut in well. 14. RDMO. Below the current schematic of the well: iflifiS I Vacuum Insulated Tubing(VIT),4-%,"x 5-W, eni us operating 79'length,two joints I OP17-02 4-W12.6 ppf Production Tubing Oil Producer with 2399'MD.2,295'TVD,36.5°inc -GLM,KBMG. 4-W x 1", ESP Lift with 2,000 psi STS-1 SOV installed As Completed 4-W cable clamps,for ESP Power 9/5/2011 Cable,(1)3/8"Chem Inj Line x40 %. Nte 7814'MD,3513'TVD.85.6°inc.—Discharge Gauge Sub Surf.Casing \ 13-3/8",68# s 7909'MD,3520'ND.85.7°inc.—Bottom of Motor Centralizer +/-2,249'MD. Centrilift TTC-ESP.142-stage(80+62)380P18SXD pump, 2,170'TVD 513 GSB3DB tandem seals.126 HP MSP motor 31°Inc. ‘/- / 8,265 MD.Baker SLXP • o' Liner Hanger/Packer HAL Zonal Isolation 5-W Silver Bullet Ecc Swell Packers Nose Guide Shoe I Item MD(tt) - Tracer Sub#1 16,601 Tracer Sub#2 15,330 7. weal, rimb• Tracer Sub#3 13,911 i 1 f 0 1 i I M I I Tracer Sub#4 12.793 R 1 IR all Tracer Sub#5 j 11,826 hu am=_ J Tracer Sub#6 11,018 Tracer Sub#7 9,500 Intern,.Casing Slotted Liner, Tracer Sub#8 ! 8,501 9-5/8",47# Resman Prod 5-%;17 ppf 8.506'MD.3.557'ND Tracer Carrier 18,040 MD. 87°Inc 3,522'ND Nikadctwq Field-- OIIktUk Point Pad Confidential io,2e',l kick VetcoGray MB-247 SURFACE COMPLETION SYSTEM --,Is 44/CL .93 I F-7... 37.19 41'. Iiii TiàøA.. h; !1 •' * TOS EL 26'5-3/4' •�Ui • h I1r .:..\ 062 0 T5E1 C/L 8.0.5. EL 25' 7-1/4• n TOp OF WELLHEAD 5.1°• EL 25'2-1/4' -) . l 0 b 1` Psi ci/ 13 1 2181 4 4ll 13-5/6.5000 PSI 4. i VO 5137 CU,IP 1♦,w H. llilgt -- 11 4_1/16• —1• 59.9 P51 erIII , ....,_ fr-iri. �.,, 3.437 0fP5ET /06A — _el 1,, � ;,II 6.30= II, 111 2-1 ,6• i1 5000 PS I WOO PSI :i► SMP( rI POSm0N II rr 13.6000 PS 52.96• wl. r W:136 �'r 26. 1�1�'' `Ii:� 2_t t '16. _ l�il�' 1: 24.2 .-i .1 I 61� IS . •I-' 100 TOP OF GRADING •'`+ ��'1 1 EL 18' 1-1/4• `1.00 440.440.4 Kw. eat 20.OD 133/6-55 ry 13-3/8.OD 88/L-80 i•1.44. ENI ALASKA 9-5/B'00 53.5/L-80 15m4I4HORIZONTAL 0ULT1-BOWL SYSTEM 4-1/2'OD WITH 6-5/8 on 20 x13-3/8 X 9-5/8 K X 4-1/2 WITH 6-5/8 NT AND ESP FLAT CABLE YMLML13,1 I• @ o IMIr17337MI R-1 I IMO '1 PRP 10161. NC 10 OF 10 23 JANUARY 2009 G_Irac lot on m work • Schwartz, Guy L (DOA) From: Wright James <James.Wright@enipetroleum.com> Sent: Tuesday,July 16, 2013 4:38 PM To: Schwartz, Guy L(DOA) Cc: Kuck Marc Subject: RE:OP17-02 (PTD 210-125) Guy—Please withdraw sundry request 313-370. Thank you, James From: Schwartz, Guy L(DOA) [maul_o:guy.schwartz q:aiaska.gov] Sent: Tuesday,July 16, 2013 4:20 PM To: Wright James Cc: Kuck Marc Subject: OP17-02 (PTD 210-125) ENI has sent two separate sundries to pull and rerun the ESP for OP17-02.AOGCC will approve the first received sundry from Marc Kuck and is numbered 313-366 Can you request to withdraw the duplicate sundry which is number 313-370. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake,we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. RECEIVED ♦ STATE OF ALASKA JUL 15 2O ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOG.CC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0 Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ IESP Swab Q 2.Operator Name: 4.Current Well Class: Permit to Drill Number: Eni Us Operating Co.Inc. Exploratory ❑ Development Q 210-125 3.Address: Stratigraphic ❑ Service El 6.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 50-029-23431-00-00 7.If perforating: 8.Well, ame and Number: What Regulation or Conservation Order governs well spacing in this pool? / OP17-02 Will planned perforations require a spacing exception? Yes ❑ No ❑ V 9.Property Designation(Lease Number): 10.Field/Pool(s): , ADL 355024,373301,391283 Nikaitchuq _ 11. PRESENT WELL CONDITION SUMMARY A ' / Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD( : Plugs(measured): Junk(measured): 17992 3482 18029 3519 Casing Length Size MD / ND Burst Collapse Structural Conductor 160 20" 1.4'/ 160 Surface 2249 13 3/8" `% �, 2133 Intermediate 8505 9 5/8" 8 3521' Production 2982.5 1/2" /992 3482 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: V ubing Grade: Tubing MD(ft): Packers and SSSV Type: / Packer<nd SSSV MD(ft)and TVD(ft): / 12.Attachments: Description Summary of Proposal Q 113.W: Class after proposed work: 111 40Detailed Operations Program ❑ BOP Sketch � : xp,e to ❑ Stratigraphic❑ Developt Service ❑ 14.Estimated Date for July,16th ....*i / ( ell Sta s after proposed work: Commencing Operations: �/ 1%, 0.1 El Gas ❑ WDSPL ❑ Suspended Ill 16.Verbal Approval: Date: �/ , I J El GINJ ❑ WAG III Abandoned III Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the be- of my kn. , :.ge. Contact 907-865-3321 /907 306 6244 Email james.wright@enipetroleum.com Printed Name James Wright Title Drilling Engineering Manager Signature /---ThPhon, Date '----____77L----Ac) �'/A / /3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a rep sentative may witness Sundry Number: i 31b Plug Integrity ❑ BOP Test ❑ echanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ o ❑ Subsequent Form Required: APPROVED BY RBDMS JUL 2 3 26)1/4 Approved by: COMMISSIONER THE COMMISSION Date: f1 L aJ Submit Form and Form 10-403(Revised 10/2012) Approved application is li fONr 2 h f t e of approval. Attachments in Duplicate • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,July 16, 2013 4:04 PM To: 'Wright James' Cc: 'Regg,James B (DOA) (jim.regg@alaska.gov)' Subject: RE:210-125 Well OP17-02 Sundry Number Sundry is 313-366 for ESP workover.. You have verbal approval to proceed with the RWO as proposed. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Wright James [m TitoJames.Wright( enipetraleum.com] Sent:Tuesday, July 16, 2013 2:53 PM To: Schwartz, Guy L(DOA) Subject: 210-125 Well OP17-02 Sundry Number Guy, The AOGCC representative on the slope is asking for a Sundry#for the OP17-02 start-up BOP Test. Can you send to me and I pass on to wellsite supervisor? Thank you, James Wright eni petroleum Drilling&Completion Engineering Manager 3800 Centerpointe Drive Suite 300 Anchorage Alaska 99516 Direct:907 865 3321 Mobile 907 306 6224 vos ens peti°leuml This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Sunday,July 14, 2013 10:42 AM To: Wright James Cc: Bettis, Patricia K(DOA); Carballo Nelson;Simeone Davide; Regg,James B (DOA) Subject: RE:OP22-WW3 Sundry Request James, Operational shutdown (not suspend)may require a verbal depending on your status. Call first thing Monday morning... I'm out of town till,tuesday but Jim Regg can help you. From:Wright James [James.Wright@enipetroleum.com] Sent: Sunday,July 14,2013 9:54 AM To:Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA);Carballo Nelson; Simeone Davide Subject: RE:OP22-WW3 Sundry Request Guy! Please see attached notification of Eni's intent to move off Well OP22-WW3 to Well OP17-02 to perform an ESP swap. Once the OP17-02 Workover is complete, eni will move the rig back to well OP22-WW3 and complete planned works. It is estimated that the OP17-02 workover will take 15 days. The current status of well OP22-WW3: - 13 3/8"casing run and cemented to a depth of 3,940 md. (Cement has not been drilled out) - The 13 3/8"casing is set in the top of the Canning.The HRZ, Kuparuk,or Sag have not been penetrated. Thank you, James Wright Eni Drilling Engineering Manager 907 306 6224-Cell This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient,you are prohibited from utilizing,copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake,we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network,the Company is not responsible for any statements made or opinions expressed,that are not strictly related to the Company's operations. 1 • • • Cn�� Petirolleuim eau 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907) 865-3321 Email: James.Wright@enipetroleum.com July 15th , 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP17-02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP17-02. OP 17-02 was originally completed on December 19th 2010 with a Through Tubing Conveyed ESP pump. The well was put on production on February 9`h 2011 and it was operated until August 11th 2011 when the ESP system failed mechanically and stopped producing fluid. A workover was performed in order to retrieve the pump and run in hole a new one. Well was put back on production on September 5th 2013 and it failed mechanically again on July 7th 2013 . The estimated date for beginning this work is July 16`h, 2013. Please find attached the Commission form 10-403 and supporting documentation. If you have any questions or require further information, please contact Lara Occhionero -865- 3323. i"Sincerely, J es Wright Drilling Engineering Manager Enli D PPtlr011kLUIlnn eno Sundry Application for Well OP17-02 WO OP17-02 ESP SWAB Prognosis Objective Move rig from well OP22-WW3 to OP17-02 and perform (workover) ESP swap. Once the OP17-02 workover is complete, move rig back to well OP22-WW3 and complete planned works. The workover of well OP17-02 is estimated to take 15 days. Current Status Well OP17-02 is currently shut in waiting for rig workover. Proposed Works 1. MIRU Nabors 245. 2. Set BPV. ND tree and NU BOP and test to 3500 psi. 3. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 4. Circulate out remaining production fluid. 5. Continue POOH and lay down ESP assembly. 6. MU new ESP assembly and RIH to setting depth. 7. Land hanger, and test it. 8. Install BPV and nipple down BOP. 9. NU tubing adapter and tree. 10. Pull BPV, install test plug and test tree.( 5000 psi test) 11. Circulate Freeze protect through tree down IA. 12. Shut in well. 13. Move Rig from Well OP17-02 to Well Op22-WW3 OP17 Sundry Prognosis 15July13 (3).doc Page 1 of 2 Printed: 15-Jul-13 E [F ALASEA 9 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 Marc D. Kuck Sr. Completion Engineer ENI US Operating, Co. Inc. 10 3800 Centerpoint Drive, Suite 300 a Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP17-02 Sundry Number: 311-263 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of August, 2011. Encl. RC fw AUG 2 6 2011 Vois, AaS til G • )eni AUG 2 6 20kimono, canmss on 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc D.Kuck Phone(907)865-3322 Email: Marc.Kuck@enipetroleum.com August 23,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP17-02 ESP Replacement Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP17-02. The well was last completed on April 17,2001 with an ESP completion. The ESP failed due to downhole electrical issues on August 13, 2011. This sundry is for replacement of the ESP system to place the well back in operating condition. The estimated date for beginning this work is August 27,2011 . Please find attached for the review of the Commission forms 10-403 and supporting documentation If you have any questions or require further information,please contact me at 907-865-3322. Sincerely, 0/1 Marc D.Kuck Sr. Completion Engineer cti3Liiiitti RECEIVED' /7, STATE OF ALASKA �,� ..ti AUG 2 6 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION Q APPLICATION FOR SUNDRY APPROVALS Alaska Oil&Gas Coat. Gomrnission 20 AAC 25.280 Itnct!$ra o 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well' 0 Change Approved'Program ❑ Suspend 0 Plug Perforations❑ Perforate❑ Pull Tubing 1 ?Q•zt Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: FSP et/Ac amo.,Or K. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Development Q. Exploratory ❑ 210-125 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23431-00-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ OP17-02 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024:373301, 391283' Nikaitchuq o_5"4- c..(1-41ic',, 5/,.,-r4( .)t'/ ..( S. L / 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): - Total Depth TVD(ft): _ Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 18200 3523 18040 3522 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2249 13-3/8" 2249 2170 5,020 2,270 Intermediate 8505 9-5/8" 8505 3557 6,870 4,760 Production 9795'5-1/2" 18040 3519 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8505-18040 3557-3519 4-1/2" L-80 7924 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development Q ' Service ❑ 14.Estimated Date for 27-Aug-11 15.Well Status after proposed work: Commencing Operations: Oil Q - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc D.Kuck Printed Name Marc D.Kuck Title Sr.Completion Engineer Signature �� Phone 907 865-3322 )Date v� Z3 / COMMISSION USE ONLY ''^^ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r3i l-a col Plug Integrity ❑ BOP Test El Mechanical-�- Integrity Test ❑ Location Clearance ❑ Other: 3500 fIL rsd I�[� / S f- >F ZS-60v 1,51. AKn4...1a.✓ SI-- 61'14-0", Subsequent Form Required: /0 -clog APPROVED BY 4811 Approved by.�: COMMISSIONER THE COMMISSION Date: —_ - 613MS AUG R G! t V/��, $� 'n Form 10-403 Revised 1/2010 '27.00 �„e !� Submit in Duplicates= to-V OP17-02 Workover-Additional Data Sheet 8/27/11 Workover Objectives: • Objective of this workover is to pull the failed TTC-ESP tubing completion and run in with a new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. Well History: OP17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888' MD. The well was started up for production on February 8, 2011. The well was operated for approximately 45 days when the ESP failed on March 25, 2011 due to an electrical fault with causes currently unknown. The well was repaired on 4/17/11 and put back into production. The ./ ESP failed again due to electrical fault on 8/13/11 after facilities shut-down. Pressure Data: 7.14 'rcl- This well is expected to have a static pressure of approximately 1300 psi. 8.8 ppg hot seawater with 3% KCI is planned as kill wt fluid for this workover. 3500 Ti/D A A. T "-• % _ �4 ei`'r sr, Operational Plan Summary: 1. MIRU Nabors 245E. 2. Shear GLM valve and circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to GLM. Rig up wireline and pull tubing stop check valve.- 5. Circulate out remaining production fluid. 6. Continue POOH and LD ESP assembly. 7. MU new ESP assembly and RIH to setting depth. - 8. Land hanger, RILDS and test hanger. 9. Install BPV and nipple down BOP. • 10. NU tubing adapter and tree. • 11. Pull BPV, install test plug and test tree. 12. Circulate Freeze protect through tree down IA taking returns up tubing. 13. Shut in well. 14. RDMO. 1 IP Y U o 0 1 n W O C }, , I 1 a� a o 0 .3cD m � . Q2 � !V L c=' G) r L 5a) 0 i. - O N CP R C C) J Q C v) a) o � ao `n G r Cl. \ Z N �, r- Cr; Cl. � ' U IA O T- V' W m .= eL Zr) oill � www Q -752 CO . O V O C O M += N r V � 0 a) x O Q co L) mimr _ - 4 2 Q C a "" • w u O O O(� � X _J �m ooho =Y an d OCO OL Y -CU I� (0 d J NiiiiitCO . Li In (n U r w x • a0 Y (Q c s L U - c •S p ,-- d H ' u 0) aa) CO0 aN o r ~ C d (-NI 2 ca . y 1 0 O > m 0 co _ > .- � = U rn °° > LU .-E- i- ch rS � c�'a (0aa)) I I C O oco cn o E O u) 0 ~ N N C I a co-Lff) J QU M Qmom a) . O a) H E - O N C D *k � '� L a) 0) cu in � O O a) C (0 - � N O N . -C-.) M 2r N- a U -4- c 5 3 Q N Q a) v CSO CO N M o C QO c0 � +• � � a0 E• _Oo° N Zoo 0 cp ~ 3 E' 6 - • x — ;:r C4 \ - �\ � OD \ U Ci CN ao> 4 01,11. ,. + `\ \4 , N- CO r M CO CO O r O co r O N r 0 0 am 1 IIIIIIi 1 1 millir , I, co 4:t : c0 M CA N. 00 O u'i in co M N r r Cn CO T". N M if)U tO it N COOO U E 7 = = = = = = = o 0 c0 .. O C w N CO N V) N V) CO CO 0000000o CD CD a'5 = M e4 <4 f4 l9 RS !4 <4 <4 7 d N L + (n F- F- F- F- H F- F- E- 0 o N Y 2O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑✓ . Gas❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory❑ GINJ❑ W INJ❑ W DSPL❑ WAG❑ Other❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co Inc Aband.: 12/19/2010 • 210-125 ' 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 ;191.261g17) IC,.Y)./ 50-029-23431-00-00 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: ,�„;•J.• 14.Well Name and Number: Surface: 3156.3 FSL 1653.9 FEL S5 T13N R9E UM 12/8/2010 . OP17-02 Top of Productive Horizon: 8.KB(ft above MSL): 53.2 15.Field/Pool(s): / 642 FSL 2021 FEL 31 T14N R9E UM Ground(ft MSL): 12 Nikaitchuq _ie l ef4 le-Y Total Depth: 9.Plug Back Depth(MD+TVD): Ci/ �-,-%'/ ,Iii 1376 FSL 4169 FEL 25 T14N R8EUM , 18200 MD/3523 TVD . c'F I, 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.PropertyDesignation: Surface: x- 516626.28 ' y-6036509.37 . Zone- 4 18200 MD/3523 TVD 355024,373301,391283 TPI: x- 510965.06 y-6039263.86 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 503668.68 y-6045270.7 Zone- 4 none ADL 417493 18.Directional Survey: Yes 0 No Li 19.Water Depth,if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 1816 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES/NEU/Den 22. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 20" 178.89 X-65 SURFACE 154 SURFACE 154 30 Cement to Surface 13-3/8" 68 L-80 SURFACE 2249 SURFACE 2170 16 • 470 bbls 10.7#ASL,80 bbls 12.5#Crete 9-5/8" 47 i L-80 SURFACE 8505 v SURFACE 3557 12.25 300 bbls 12.5#Deeperete 5.5" 17 L-80 8245 18040 3604 3519 8.5 slotted liner 23.Open to production or injection? Yes No❑ If Yes,list each 24. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) Slotted Liner with ESP completion 4.5 7888 NA _ 25. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ) cu'9=I-=ii0fi ; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED t,- :A.,..11 i <j !,.i 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 27. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ . Sidewall Cores Acquired? Yes ❑ No❑✓ • 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. RECEIVED: r 6- et, .. RBDIIAS FEB 412011 liasitm 1/11 &Gas Cons.CET, �`ssion Form 10-407 Revised 2/2007 CONTINUED ON REVERSE / - S 'Z 1( '')) I.! 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 18161779 OA sand top 9455 • 3554 Formation at total depth: OA sand 182003522 30. List of Attachments: Summary of Daily ops,Directional survey,wellbore schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907-865-3321 Printed Name: Maurizio Grandi Title: Well Operation Project Manager Signature: ii2,4;`''e- F., fAa'-'I~'d Phone: 9e 7 $g,S 33 xi Date: / — a---7- // Cs-ra...4% INSTRUCTIONS IITIA to 2500 PSI. 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 Item la: 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 prod 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 in 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 listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Eni E&P Division ., (Well Name:0P17-02 EN/Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • Date:10/26/2010 - Report#: 1 API/UW:50-029-23431-00-00 21 " page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 -3.19 Daily Information End Depth(ttKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 72.0 21.2 Cloudy,light snow, 355'N @ 7.7 mph WC 12.2' Daily summary operation 24h Summary N/U flowline and de-gasser line. RID CMT,water and raw mud innerconnect lines. Finished cleaning mud pits. Jack rig up and install crib blocks. Lay new herculite and rig mats. Spot rig over OP17-02 wellbore. Berm ng and remove old herculite. Jack rig down and hook up innerconnects. Begin installation of ECD equipment. Operation at 07.00 Installing starting head 24h Forecast Install starting head and test. N/U to conductor. Continue installation of ECD equipment. Load pipe shed with drill pipe. Lithology Shows MAASP Pressure(psi) •Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 MOB A 2 P RIG DOWN FLOWLINE AND DE-GASSER LINE.TIE UP CELLAR CURTAINS. RIG DOWN CMT,WATER AND RAWMUD INNERCONNECT LINES. TIE UP LAMPSON CURTAINS. RIG DOWN BERMING AROUND RIG. FINISH CLEANING MUD PITS. 06:00 08:30 2.50 8.50 MOB A 2 P JACK UP RIG INSTALL CRIB BLOCKS. LAY HERCULITE AND SET RIG MATS FOR DRILL MODULE. ELECT RIG DOWN WIRES FOR RIG SEPARATION. 08:30 12:00 3.50 12.00 MOB A 2 P MOVE DRILL MODULE AND SPOT OVER HOLE. CLEAN UP OLD HERCULITE AND LAY NEW HERCULITE. SET RIG MATS FOR UTILITY MODULE AND MOVE/MATE UP SAME. ACCEPT RIG AT 0001 HOURS 10-26-2010. 12:00 13:00 1.00 13.00 MOB A 2 P SPOT PIT MOD\JACK RIG DOWN 13:00 16:00 3.00 16.00 MOB A 2 P HOOK UP INTERCONNECTS\SET BERM AROUND RIG AND SECURE HERCULITE\JACK BACK PIPE SHED SHUTE 1600 18:00 2.00 18.00 MOB A 2 P BRING ECD MANIFOLD TO RIG FLOOR AND SET IN PLACE 18.00 00:00 6.00 24.00 MOB A 2 P SKID PIPE SHED SHUTE BACK INTO PLACE\PREPARE WELL BAY COVER\GET STEAM AROUND RIG\SET DRILLING HEAD\SET RISER DOWN,FLOW LINE NEEDS TO BE CUT. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Eni representative Eni representative Eni representative Eni representative Eni representative Tool Push Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ttKB) Bottom(ttKB) Run Date Last Leakoff Test Depth(ttKB) TVD(ttKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) If* Eni E&P Division I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2^ Date:10/27/2010 - Report#: 2 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.68 125.3 -2.19 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 96.0 16.7 Overcast,WC 13.5° 77°ENE @ 2.4 mph Daily summary operation 24h Summary Loaded 274 joints of 5"DP in pipeshed,strapped and tallied same. Serviced rig dravwvorks and inspected derrick. N/U surface riser to well head and test to 500 psi. Removed extension.adjusted clamps and raised up standpipe. Placed Tee's and valve in standpipe. Worked as directed by MEI for installation of EC manifold. Operation at 07.00 Finishing standpipe and loading DP in pipeshed. 24h Forecast Finish loading 5"DP in pipeshed and S/B 30 stands. Load 13-3/8"csg in pipeshed. Load BHA in pipeshed. Continue installation of EC manifold. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 MOB A 5 P PULL SURFACE RISER OFF WELL HEAD AND LID IN PIPESHED\FLOWLINE NEEDS TO BE CUT SHORTER. 01 30 03:00 1.50 3.00 MOB A 5 P FINISH BERMING AROUND RIG\P/U SCAFFOLDING FROM PIPESHED AND CONSTRUCT ON DRILL FLOOR AS PER CH2 SCAFFOLDING CREW. 03.00 07:00 4.00 7.00 MOB A 5 'P GREASE DRAWVVORKS\INSPECT DERRICK\LOAD 5"DP IN PIPESHED\STRAP AND TALLY SAME 07:00 11:00 4.00 11.00 MOB A 5 -P WELDER CUT 1-1/2'OFF BOTTOM OF TOPDRIVE RAIL\REMOVE FLOWLINE AND CUT 6"OFF FOR N/U\WELD SQUARE STOCK ON ECD UNIT AND JACK UP 1 FOOT OFF FLOOR\CONTINUE LOADING PIPE IN SHED\STRAP AND TALLY SAME. 11.00 12:00 1.00 12.00 MOB A 5 •P N/U FLOWLINE AND RISER TO WELLHEAD 12.00 14:00 2.00 14.00 MOB A 5 P N\U SURFACE RISER\SECURE CELLAR AND WELL BAY\TEST CONNECTIONS TO 500 PSI AS PER VETCO GRAY 14:00 00:00 10.00 24.00 MOB A 5 P WORKING AS DIRECTED BY OPERATOR FOR INSTALLATION OF EC MANIFOLD\REMOVE EXTENSION FROM STAND PIPE\ADJUST CLAMPS\RAISE STAND PIPE\PLACE TEE'S AND VALVE IN STAND PIPE\MOVE EC MANIFOLD OVER ON FLOOR\CONTINUE LOADING 5"DP IN SHED\STRAP AND TALLY SAME\274 JTS IN PIPESHED AS OF MIDNIGHT. Deily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Eni representative Eni representative Eni representative Eni representative Eni representative Tool Push Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:OP17-02 EN!Petroleum Co.Inc. Daily ReportWell Code:25097 Field Name:Nikaitchuq VI* • API/UWI:50-029-23431-00-00 2^ Date:10/28/2010 • Report#: 3 II II page 1 of 1 Wellbore name: OP17-02 Well Header PermitlConcession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.68 125.3 -1.19 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 102.0 25.2 Mostly Cloudy,WC 13°NNE @ 4.4 mph 19.4` Daily summary operation 24h Summary Serviced rig. Added oil and greased pipe skate. Repositioned tugger line in derrick. Picked up drill pipe and stand back 25 stands in derrick. Continued work on installation of EC manifold. Completed stand pipe work. Operation at 07.00 Simultaneous operations:Mixing spud mud. Setting scaffolding for stand pipe inspection. Setting drip pan around riser. 24h Forecast Finish rig up operations in preparation to spud well. Mix drilling mud. Dress up bottom of top drive rail. Install catch can/drip pan on surface riser and set drip pan around riser. Set scaffolding for Tuboscope to inspect stand pipe welds. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(Br) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 MOB A 2 P ADD OIL AND GREASE PIPE SKATE\ REPOSITION TUGGER LINE IN DERRICK AND CLEAR\CLEAN UP 12:00 14:00 2.00' 14.00 MOB A 2 P PICK UP 27 JOINTS OF DRILL PIPE AND RACK BACK IN DERRICK\25 TOTAL STANDS IN DERRICK 14:05 00:00 10.00 24.00 MOB A 2 P WORKING AS DIRECTED BY MEI ON EC MANIFOLD\WELDERS WORKING ON PIPING FOR SAME\DUMMY RUN WITH EC MANIFOLD VALVE\PLUMB IN EC MANIFOLD PUMP\DRESS UP TORQUE TUBE\PUT CLAMPS BACK ONTO STAND PIPE\LEFT VALVES LOOSE UNTIL PIPING TO MANIFOLD IS IN PLACE. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Eni representative Eni representative Eni representative Eni representative Eni representative Tool Push Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division (Well Name:0P17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUW:50-029-23431-00-00 en � Date:1012912010 - Report#: 4 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 -0.19 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 108.0 26.2 Mostly Cloudy,WC 329`NNW @ 12.2 15.3` mph Daily summary operation 24h Summary Dressed up topdrive rails. Installed catch can/drippan around surface riser and set same. Mixed 600 bbls spud mud and tested mud line to 1500 psi. P/U scaffolding for work on standpipe. Continued work on installation of EC manifold and pump. Operation at 07.00 Picking up HWDP @ 0400 hours. 24h Forecast Presure test standpipe to 1500 psi. Cut and slip drill line. Replace hydraulic motor on skate. P/U 12 Joints HWDP. Clean out-200'of hole. P/U BHA and RIH. Spud well. Drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00-.00 06:00 - 6.00 6.00'MOB 'A 5 P DRESS UP BOTTOM OF TOPDRIVE RAILS WITH GRINDER I INSTALL CATCH CAN/DRIP PAN AROUND SURFACE RISER AND SET SAME AROUND RISER. MIX 600 BBLS SPUD MUD IN ACTIVE SYSTEM AS PER MI-SWACO. P/U AND CONSTRUCT SCAFFOLDING TO WORK ON STAND PIPE ON DRILL FLOOR. 06.00 12:00 6.00 12.00 MOB "A 5 P ROUTE 2"HOSE FROM EC MANIFOLD UNIT TO CHARGE PUMP. P/U AND M/U 4"LINES FROM CD UNIT TO STAND PIPE. PRIME AND PAINT LINES. WELDER FABRICATING FRONT LEGS FOR EC MANIFOLD UNIT AND CUT HOLES THROUGH DRILL FLOOR FOR PLUMBING. 12.00 17.00 5.00 17.00 MOB 'A '5 •P CONTINUED INSTALLATION OF EC MANIFOLD AND PUMP. 17.00 23.00 6.00 23.00 MOB "A 5 'P TUBOSCOPE X-RAY WELDS ON EC MANIFOLD. WELD#7 FAILED X-RAY ON LOWER SECTION OF PIPE. TAKE DOWN SCAFFOLD\REMOVE SECTION OF PIPE. 23.00 00.00 1.00 24.00 MOB A '5 'P CALIBRATE CANRIG/SLB BLOCK HEIGHT. FILL HOLE AND CHECK FOR LEAKS\NO LEAKS. TEST MUD LINE TO 1500 PSI\NO LEAKS Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 111#1 Eni E&P Division I Well Name:0P17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2�, Date:10/30/2010 - Report#: 5 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 1220 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2510 27,680.00 220.88 125.3 0.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather •Wind 747.0 747.00 9.82 76.1 107.0 23.0 Cloudy,Snow.WC 344°NNW @ 13.4 10.9` mph Daily summary operation 24h Summary P/U BHA#1 and cleaned out conductor to 160'. POOH. PJSM,P/U BHA#2 drilled ahead f/160'5/246'MD. POOH 2 stands and racked back in derrick. P/U remaining BHA and RIH. Drilled ahead f/246' t 747'MD. Operation at 07.00 Dnlling ahead,depth @ 0400 hours 990'MD 24h Forecast Drill ahead as per directional plan Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL I A 2 P CUT AND SLIP DRILLING LINE 02:00 03:00 1.00 3.00 DRILL 'E 1 P P/U HWDP AND RACK BACK IN DERRICK 03:00 04:30 1.50 4.50 DRILL E 1 P P/U BHA 04:30 05:30 1.00 5.50 DRILL 'E 3 P CLEAN OUT CONDUCTOR TO 160'\450 GPM\35 RPM\400 PSI\2-10 WOB 05:30 06:00 0.50 6.00 DRILL •E 4 P POOH 06:00 06:30 0.50 6.50 DRILL E 1 P PJSM WITH ALL HANDS\P/U M/U BHA 06:30 09:30 3.00 9.50 DRILL E 1 P P/U BHA TOGS FROM PIPESHED AND M/U BHA#2 PER DRILLING PROGRAM AND SLB 09:30 12:00 2.50 12.00 DRILL 'E 3 P DRILL SURFACE ROTATING 8 SLIDING F/160'1/246'\460 GPM/2K TORQUE 1110$11bU.IO43SI-ON\_4t9.PSI-OFE_._ 740 RPM 12-15 WOB 1 AST.75 HRS\ART.19 HRS 12:00 13:00 1.00 13.00 DRILL E 3 P DRILL ROTATING/SLIDING F/246'T/342' 13:00 14:30 1.50 14.50 DRILL 'E 4 P POOH 2 STDS AND RACK BACK IN DERRICK. P/U REMAINING BHA 14:30 00:00 9.50 24.00 DRILL •E 3 P DRILL AHEAD ROTATING/SLIDING F/342'T/747'MD\745'TVD\UP WT 90\OWN WT 90\ROT WT 90\40 RPM\ TORQUE 3/1\WOB 15-25\500 GPM\850 PSI\MUD WT 9.0 PPG\ECD 9.11 PPG\AST 6.02\ADT 8.13 Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile En presentative Frank Cormier 'Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 - Drilling@enipetroleum.com Ern representative Eni representative En:representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 37.1 161.0 10/31/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) - ft* Eni E&P Division I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2^„ Date:10/31/2010 - Report#: 6 _ '� 'I II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(Er) Avg ROP(ftlhr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 1.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,240.0 1.493.00 13.76 108.5 108.0 16.9 Cloudy,WC 8.6' 342°NNW @ 5.8 mph Daily summary operation 24h Summary Drilled ahead from 747'to 2240'MD back reaming 90'up and washing down. Operation at 07.00 Back Reaming to HWDP 24h Forecast TD Surface section©-2265'MD and CBU 3X. Back Ream to HWDP and CBU until clean.RIH to bottom on elevators and circulate mud.POOH and lay down BHA,Dummy run with hanger. Run and cement 13-3/8"casing. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06'00 6.00 6.00 DRILL E 3 P _DRILL AHEAD ROTATING/SLIDING F/747'T/1100'MD,-560 GPM\130 SPM\1080 PSI-ON\950 PSI-OFF\3500 TO- ON\2000 TO-OFF\92 UP-WT\90 DWN-WT\90 ROT-WT\6-25K WOE\40 RPM\9.35 ECD\9.0 PPG. BACK REAM 90'UP AND WASH GOING DOWN. 06.00 1200 6.00 12.00 DRILL E 3 P DRILL AHEAD ROTATING/SLIDING F/1100'T/1544'MD. 600 GPM\140 SPM\1200 PSI-ON 11000 PSI-OFF 13600 TO- ON 12500 Ta-OFF 1105 UP-WT 198 DWN-WT 195 ROT-WT 16-25K WOB 140 RPM 19.60 ECD\9.0 PPG. BACK REAM 90'UP AND WASH GOING DOWN.ADT 2.5 HRS AST 3.65 HRS. 12.00 00:00 12.00 24.00 DRILL E 3 P DRILL AHEAD ROTATING/SLIDING F/1544'T/2240'MD,2162 TVD. 650 GPM\1200 PSI-ON\1000 PSI-OFF\4000 TO- ON 13000 TO-OFF 1128 UP-WT 1105 DWN-WT\117 ROT-WT 120-25K WOB 142 RPM 19.72 ECD 19.2 PPG. BACK REAM 90'UP AND WASH GOING DOWN. ADT 7.6 HRS AST 4.17 HRS.ART 3.43. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Frank Cormier Eni Petroleum Drlg Spw. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 37.1 161.0 10/31/2010 Last Leakoff Test Depth(11KB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P DivisionWell Name:0P17-02 rill* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • Date:11/1/2010 - Report#: 7 APIIUWI:50-029-23431-00-00 eh o page 1 of 1 Wellbore name: OP17-02 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27680.00 220.88 125.3 2.81 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,265.0 25.00 0.62 40.3 103.0 14.2 Cloudy,Snow.WC- 5'N @ 15.1 mph 1.7" Daily summary operation 24h Summary Dulled ahead as per directional plan to TD @ 2265'MD. CBU 3 times and BROOH reciprocating pipe. RIH on elevators. CBU+Hi-Vis sweep. POOH on elevators and rack back DP. Lay down BHA. R/U and run 13 3/8"csg to 2209'MD verify landing depth 2249'MD. Operation at 07.00 Cementing 13 3/8"surface casing 24h Forecast Cement 13 3/8"surface casing.N/D N/U BOPS and test. P/U drill pipe Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL E 3 P DRILL ROTATING/SLI IING F/2240'T/2265'MD.TD.\700 GPM\162 SPM\1400 PSI-ON\1350 PSI-OFF\128 UP-WT\ �' 110 DWN-WT\20K WOB\9.52 ECD\9.2 PPG 00:30 02:00 1.50' 2.00 DRILL E 7 P CBU 3 TIMES\800 GPM\185 SPM\50 RPM\1600 PSI\3500 TORQUE\RECIPROCATING PIPE SLOWLY. „Sa ( 02:00 0430 2.50 4.50 DRILL E 6 P BACK REAM F/2265'T/630'MD\800 GPM\185 SPM\50 RPM\1600 PSI\3500-2300 TORQUE\NO TIGHT SPOTS\ LOTS OF CUTTINGS BACK. 04:30 05:00 0.50 5.00'DRILL E 7 P CIRC AND COND UNTIL SHAKERS CLEANED UP. 750 GPM\175 SPM\50 RPM\1170 PSI\1350 TORQUE\ RECIPROCATING PIPE. 05:00 -06:00 1.00 6.00 DRILL E 4 P TIH TO BOTTOM.TOOK NO WEIGHT, 06:00 07:30 1.50 7.50 DRILL E 7 P CIRC AND COND+HI-VIS SWEEP. 700 GPM\1400 PSI\30 RPM\2500 TQ\RECIPROCATING PIPE. 07,30 08:30 1.00 8.50'DRILL E 11 P ACTIVATE GWD V4(GYRO PULSE TOOL)INTO BATTERY-OUT RUN MODE AS PER GYRODATA TECH. 08:30 10:00 1.50 10.00 DRILL E 4 P POOH ON ELEVATORS AND RACK BACK DP F/2260'T/680'MD. NO DRAG OR TIGHT SPOTS\NO SWAB. 10:00 12:00 2.00 12.00 DRILL E 4 P RACK BACK HWDP,JARS AND COLLARS. 12:00 14:30 2.50 14.50 DRILL E 4 P LAY DOWN BHA 14:30 15:30 1.00 15.50 DRILL G 1 P CLEAN AND CLEAR FLOOR\PERFORM DUMMY RUN WITH 13 3/8"HANGER AS PER VETCO GRAY 15:30 16:30 1.00 16.50 DRILL G 1 P RIG UP GBR 13 3/8"CSG EQUIPMENT AND FRANKS TOOL. PJSM ON RUNNING CSG, 16:30 20:00 3.50 20.00 DRILL G 4 P RUN 13 3/8"-68#-L80 SURFACE CASING.CIRCULATE THROUGH FLOAT COLLAR AND CHECK FOR HOLDING. INSTALL CENTRILIZERS AS PER RUNNING ORDER. MAKE UP PIPE T/OVAL,\AVG TORQUE 3750 FT LBS. TIH T/1B36'MD 1 160 UP-WT 1140 DWN-WT. FILL PIPE ON THE FLY\TOP OFF EVERY 10 JOINTS 20.00 20.30 0.50 20.50 DRILL G 7 P CIRC AND COND 5 1/5 BPM @ 250 PSI 20.30 2200 1.50 22.00 DRILL G 4 P RUN 13 3/8"SURFACE CSG T/2209'MD.\200 UP-WT\145 DWN-WT. P/U HANGER AND LANDING JOINT\VERIFY LANDING DEPTH @ 2249'MD. 22.00 00:00 2.00 24.00 DRILL G 7 P CIRC AND COND @ 6 BPM\270 PSI. UNABLE TO RECIPROCATE PIPE DUE TO HANG UP IN WELL HEAD Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum 'Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Dulling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division [Well Name:0P17-02 fill* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2^ Date:11/2/2010 - Report#: 8 'i II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 3.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 2,265.0 0.00 92.0 11.1 Pty Cloudy,WC-6.2' 5'N @ 17.1 mph Daily summary operation 24h Summary Schlumberger pumped Mud Push 105.6 bbls#10.1-Lead slurry 470 bbls @ 10.7 ppg-Tail Slury 80 bbls @ 12.5 ppg. Retumed 186 bbls to surface. Rig pumps displace with 318 bbls&bump plug.. check floats-holding. R/D and wash out stack. N/D flow nser&starting head. N/U well head.BOP stack.flovdine,bell nipple.ketch can. Installed hatch cover. Cleaned out hole fill line and flow line. Set wear nng. Began picking up DP. Operation at 07.00 Picking up DP and installing ECD subs. 24h Forecast Finish picking up DP and install ECD subs. Test BOP,witness waived by AOGCC rep. P/U BHA and RIH. Test casing. Drill out shoe and perform LOT. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -01:00 1.00 1.00 DRILL H 1 P RIG UP CEMENT HEAD AND HOSE TO LANDING JOINT. 01:00 01:30 0.50 1.50 DRILL H 1 P PJSM WITH ALL HANDS FOR CEMENT JOB 1 01:30 03:30 2.00 3.50 DRILL H 7 P SLB PUMP 5 BBLS H2O AND PRESSURE TEST LINES TO 3000 PSI\PUMP 1005.6 BBLS 10.1 PPG MUD PUSH/RED C M DYE.\DROP BOTTOM PLUG\SLB MIX AND PUMP 470 10.7 PPG LEAD SLURRY CEMENT AND 80 BBLS 12.5 PPG f • TAIL SLURRY CEMENT I RETURNED 186 BBLS TO SURFACE\DROP TOP PLUG\SLB PUMP 5 BBLS H2O FOR S WASH UP. 03:30 05.30 2.00 5.50 DRILL H 7 P SWAP TO RIG PUMPS AND DISPLACE WITH 318 BBLS 9.2 PPG MUD©8 BPM\450 PSI TO BUMP\PRESSURE UP TO 986 PSI I CHECK FLOATS\OK\CIP @ 0530 HOURS -186 bbl Cement to surface 05:30 08:00 2.50 8.00 DRILL H 1 P R/D CEMENT HEAD AND LINES\ATTEMPT TO 13/0 LANDING JOINT AS PER VETCO GRAY. R/U GBR CSG TONGS AND B/O\UD LANDING JOINT 08:00 09:30 1,50 9.50 DRILL 'H 1 P CLEAR DRILL FLOOR OF CSG HANDLING EQUIPMENT.TONGS.ELEVATORS,SLIPS AND XO. 7:30 12:00 2.50 12.00 DRILL E 1 P CLEAN AND R/D KATCH-CAN\R/D FLOWLINE AND SURFACE RISER. 112:00 12.30 0.50 12.50 DRILL E 1 P REMOVE STARTING HEAD FROM CONDUCTOR 12:30 15:00 2.50 15.00 DRILL E 12 P TEST 13 3/8"HANGER TO 5000 PSI FOR 10 MIN AS PER VETCO GRAY 15:00 22:00 7.00 22.00 DRILL E 1 P N/U BOP STACK\FLOWLINE\BELL NIPPLE\KATCH CAN\INSTALL TURNBUCKLES I BLEEDER LINE FROM STANDPIPE AND CD MANIFOLD. INSTALL HATCH COVER ON WELL HOUSE. CLEAN OUT HOLE FILL LINE AND FLOWLINE. 22:00 22.30 0.50 22.50 DRILL E 1 P INSTALL WEAR RING BUSHING AS PER VETCO GRAY 22:30 23.30 1.00 23.50 DRILL 'E 1 P STAGE CD MANIFOLD VALVES ON RIG FLOOR 23:30 00.00 0.50 24.00 DRILL E 1 P P/U DRILL PIPE Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum 'Ddg Spvr. 'Enipetroleum.AK 907-670-8623 DnIfing@empetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 37.2 2.249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) r Eni E&P Division (Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • API/UW:50-029-23431-00-00 2^n Date:11/3/2010 - Report#: 9 II II II page 1 of 1 Wellbore name: OP17-02 Well Header PermiVConcession N° Operator ENI Share(%) 'Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 4.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,265.0 0.00 92.0 21.6 Cloudy,Blowing 22'NNE @ 38.8 Snow,WC 1.9` mph Daily summary operation 24h Summary -- M/U mule shoe and P/U 1 stand of HWDP and 30 joints of 5"DP. RIH. M/U side entry subs on top of every stand torquing twice and racked back. Installed CD valves on stands 38 through 92,picked up and racked back 12 stands without CD valves. Tested choke manifold. Tested CD manifold,recording on chart,250/5000 psi,10 minutes each. Pulled wear ring and made up test joint. Set test plug. Operation at 07.00 Testing BOPs 24h Forecast Test BOPS,P/U BHA and RIH to shoe and test casing. Drill out cement and 20'of new hole. Perform LOT. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02.00 2.00 2.00 DRILL E 1 P M/U MULE SHOE AND P/U 1 STAND HWDP AND 30 JOINTS OF 5"DP\RIH 02:00 05:30 3.50 5.50 DRILL E 1 P M/U AND TORQUE PIN AND BOX END OF SIDE ENTRY SUBS TWICE ON TOP OF EVERY STAND AND RACK BACK. 05:30 07:00 1.50 7.00 DRILL E 1 P CONTINUE P/U DP FROM SHED 07:00 09:30 2.50 9.50 DRILL E 1 P M/U SIDE ENTRY SUBS ON EVERY STANDS AND TORQUE TWICE\RACK BACK. 09:30 11:30 2.00 11.50 DRILL E 1 P CONTINUE P/U DP FROM SHED 11:30 12:00 0.50 12.00 DRILL E 1 P M/U SIDE ENTRY SUBS ON EVERY STAND AND TORQUE TWICE\RACK BACK. 12:00 22:00 10.00 22.00 DRILL E 1 P INSTALL CD VALVES ON STANDS 36 THROUGH 92(55 STANDS),P/U 12 STANDS AND RACK BACK 22:00 23:00 1.00 23.00 DRILL E 1 P TEST CD MANIFOLD,RECORD ON CHART\250/5000 PSI 10 MINUTES EACH 23:00 00:00 1.00 24.00 DRILL E 1 P PULL WEAR RING\M/U TEST JOINT AND INSTALL TEST PLUG Daily Contacts Position _ _ Contact Name Company __ Title E-mail Office Mobile Eni representative Frank Cormier 'Eni Petroleum Ddg Spur. ..Enipetroleum.AK 907-670-8623 Drilling@enipetroleu m.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Eni representative Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 $111* Eni E&P Division 'Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • Date:11/4/2010 - Report#: 10 APIIUWI:50-029-23431-00-00 ei page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N" Operator ENI Share(%( Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 5.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 2,379.0 114.00 0.63 181.0 86.0 23.7 Cloudy,Blowing 355"N @ 22.3 mph Snow,WC 8.2" Daily summary operation 24h Summary Installed test plug and fluid packed testing equipment. Tested BOPS 250 psi-low,3500 psi-high. Pulled test plug and installed wear bushing as per Vetco. B/D choke kill line and manifold. P/U BHA#3 and performed shallow hole test. RIH to 2153'MD a tested casing. Drilled out test plug,float shoe and-20'new hole,evened out mud weight @-9.2 ppg and performed FIT. Displaced well to 8.8+ppg LNSD mud. Cleaned out mud system. Drilled ahead 5/2379;MD Operation at 07.00 Drilling ahead. Depth @ 0400 hours 2592'MD 24h Forecast Drill ahead as per Eni&SLB directional plan Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 12 P P/U TEST TOOLS AND INSTALL TEST PLUG/FILL BOP STACK WITH H2O 00:30 03:30 3.00 3.50'DRILL E 12 P TEST BOP EQUIPMENT 250 PSI LOW/3500 PSI HIGH FOR 5 MIN CHARTED. KOOMEY ACCUMULATOR TEST 40 SEC-AIR 164 SEC OVER ALL TIME. WITNESS WAIVED BY BOB NOBLE,AOGCC REP. 03:30 04:00 0.50 4.00 DRILL E 12 P R/D TEST EQUIPMENT&PULL TEST PLUG AND INSTALL WEAR BUSHING AS PER VETCO GRAY. 04:00 05:30 1.50 5.50 DRILL E 12 P BLOW DOWN EQUIPMENT-CHOKE/KILL LINES AND CHOKE MANIFOLD. CLEAN UP DRILL FLOOR. 64 05.30 06:00 0.50 6.00 DRILL E 1 P PJSM WITH ALL HANDS FOR P/U OF BHA#3. 06.00 09.30 3.50 9.50 DRILL E 4 P P/U BHA#3 ROTARY STEERABLE ASSEMBLY AS PER WELL PROGRAM AND SLB DIRECTIONAL PLAN. RIH T/656' MD,TOP OF HWDP. 09.30 10.00 0.50 10.00 DRILL E 7 P CIRCULATE TO PERFORM SHALLOW HOLE TEST OF SLB MWD TOOL @ 650 GPM/770 PSI/TEST OK. 10.00 12.00 2.00 12.00 DRILL E 4 P TIH F/656'T/2153'MD FILLING PIPE EVERY 10 STANDS 12.00 13:30 1.50 13.50 DRILL E 7 P _Rill TO TEST CASINQ.0.1KIL ATE SURFACE TO SURFACE @ 8 8PM,500 PSI TO EVEN MUD WT AROUND 9.1+ PPG. 13:30 15:00 1.50 15.00 DRILL E 12 P TEST 13 3/8"CSG TO 2500 PSI FOR 30 MIN/RECORD ON CHART. R/D TEST EQUIPMENT AND BLOW DOWN LINES. 15:00 16:30 1.50 16.50'DRILL E 3 P ROTARY DRILL OUT CEMENT PLUG AND FLOAT COLLAR/659 GPM/1000 PSI/40 RPM/3.5K TORQUE/WOB 12K. 16:30 18:00 1.50 18.00 DRILL E 3 P ROTARY DRILL F/2265'T/2284'MD. DRILL OUT SHOE AND-20'NEW HOLE/700 GPM/1150 PSI/70 RPM/4200K TORQUE/WOB 5-7K. 18:00 18:30 0.50 18.50 DRILL E 7 P POOH TO SHOE AND CBU TO EVEN MUD WEIGHT TP-9.2 PPG/700 GPM 11150 PSI. 18:30 19:30 1.00 19.50 DRILL E 19 P PERFORM FORMATION INTEGRITY TEST(FIT)12 PPG EMW. 19:30 21:00 1.50 21.00 DRILL E 7 P CIRCULATE AND CONDITION/RIG DOWN TEST EQUIPMENT,BLOW DOWN LINES. 21:00 21:30 0.50 21.50 DRILL E 7 P DISPLACE WELL TO 8.8+PPG LNSD MUD 21:30 23:00 1.50 23.00 DRILL E 20 P CLEAN OUT SHAKER,POSSUM BELLY AND PIT#7. 23:00 00:00 1.00 24.00 DRILL E 3 P ROTARY DRILL F/2284'T 2379'MD/UP-WT 130/DOWN-WT 105/ROT-WT 115/700 GPM/800 PSI/70 RPM 15/3 TORQUE/WOB 2-12 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Drlg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Eni representative Last Casing seat Cas.Type OD(in) ID(in) Grade Top(f1KB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2.249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division 'Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq � API/UWI:50-029-23431-00-00 2^ Date:11/5/2010 - Report#: 11 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 6.81 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4,410.0 2.031.00 16.26 124.9 87.0 21.0 Cloudy,Patchy Fog. 177°S @ 15 mph WC 7.3" Daily summary operation 24h Summary Drilling Rotary Steerable 1/2379'-54410'(TVD 2986')per ENI well plan 8 Schlumberger DD\Maintaining mud properties as per Mud Engineer\Mud weight 9.0 ppg with an ECD @ 9.6 ppg @ 4410'.\ Continues circulating while making connection @ 650 gpm with 1050 psi.as per WEI Operator,started @ 3715' Operation at 07.00 Drill ahead Rotary Steerable as per well plan\Use CD system while making connection with 650 gpm. 24h Forecast Drilling ahead as Well Plan 8 Schlumberger DD\Maintain mud properties as per Mud Engineer/Finish loading pipe shed with 9 5/8"csg. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 12.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/2379'-83239'(TVD 2246')as per Schlumberger DD with 800 gpm @ 1150 psi.\130 rpm @ 5-6K torque\WOB=4-25K\Up wt.=133K-Dn wt.=105K-Rot wt.=110K.\8.8 ppg mud wt.\ECD=9.50 ppg.\Back ream stand before connection 8 reduce pump when reaming down.\ADT=8.32 hrs.\Jars=99.36 hrs. 12.00 00:00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable(/3239' t_/44441100' N.D 2986')as per Schlumberger DD with pump rate of 908 gpm @ 1730 psi.\120 rpm-@-13-9K forque(.WOt93 10k\Up wt.=135K-Dn wt.=80K-Rot wt.=108K.\9.0 ppg mud wl.\ECD=9.67 ppg.\Back ream @ connection-Continued circulated while making connection with CD system @ 3718'. ADT=7.94 hrs.\Jars= 107.3 hrs. Total ADT=16.89 hrs. Total Jar=107.30 hrs. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum 'Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division I Well Name:0P17-02 0111* EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2 Date:1116/2010 - Report#: 12 I"' page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 7.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5.355.0 945.00 13.95 67.7 87.0 21.6 Cloudy,WC 15.6° 244'WSW @ 4.9 mph Daily summary operation 24h Summary Drilling Rotary Steerable f/4410'-1/5355'(TVD 3136')per ENI well plan&Schlumberger DD\Mud weight 9.1 ppg with an ECD @ 9.47 ppg @ 5355'.\Connection circulated with 780 gpm @ 1530 psi.-As per WEI Operator.\ROP slowed down f/5330'-/15355'with increase in shock levels to ARC tool\Consult with town to POOH\CBU 1.5X(clean)\POOH on elevators(/5355'-51326'\Pumped dry job @ 4894'\Monitor well @ 2188'(static). Operation at 07.00 Working BHA#4. 24h Forecast Finished POOH&work BHA#3\Down load&reprogram SLB tools\P/U new MWD with MVC&MN Stab\Continue to work BHA#4\Surface test tools\RIH\Drill ahead with 12-1/4"hole. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12.00 12.00 12.00 DRILL E 3 P Drill Rotary Steerable(/4410'-85255'(TVD 3120')as per Schlumberger DD with 900 gpm @ 1980 psi.\120 rpm @ 9-10K torque\WOB=3-15K\Up wt.=140K-Dn wt.=80K-Rot wt.=110K.\9.1 ppg mud wt.\ECD=9.72 ppg.\Back ream before connection-used CD system during connection as per WEI Operator./ADT=8.22 hrs.\Jars=115.52 hrs. 12:00 19.00 7.00 19.00 DRILL E 3 P Drill Rotary Steerable 1/5255'-t/5355'(TVD 3136')as per Schlumberger DD\ROP slowed down 1/5330'-V 5355'(sand& cemented sand stone).\Pump rate 900 gpm @ 1980 psi.\60-80 rpm @ 8-12K torque\WOB=20-25K\Up wt.=140K- Dn wt.=78K-Rot wt.=110K.\9.1 ppg mud wt./ECD=9.47 ppg./ADT=5.73 hrs.\Jars=121.25 hrs.Schlumberger recorded shock levels 011 while drilling this interval and increased to 2-3 on ARC tool within last 1/2 hour of drilling. Total ADT=30.84 hrs. Total Jar=121.25 hrs. 1900 20:00 1.00 20.00 DRILL 'E 7 P Circulate bottoms-up 1.5X(clean)-Reciprocate and rotate drill string pumping @ 900 gpm with 1980 psi./120 RPM @ 7- 8K torque.\Monitor well for 10 mins. 20.00 00:00 4.00 24.00 DRILL E 4 P POOH f/5355'on elevators\Pumped dry job @ 4894'\Continue POOH 1/1326'\Flow check @ 2168'-static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Frank Cormier Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 r.* Eni E&P Division (Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • API/UWI:50-029-23431-00-00 2^„ Date:11/7/2010 - Report#: 13 II II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-52 DRILLING 10/30/2010 27.680.00 220.88 125.3 8.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature)°F) Weather Wind 5,800.0 445.00 5.68 78.3 86.0 22.3 Cloudy,WC 10.4' 355°N @ 9.4 mph Daily summary operation 24h Summary POOH on elevators(/1326'-1/650'\Work BHA#3 as per Schlumberger-L/D SLB NM Stab&Drill collar(due to bad box&galled threads)\P/U BHA#4 RIH 1/654'(safety inspection to remove ice in derrick)\RIH 1/654'-1/2186'(test MWD @ 1037'-P/U Ghost reamer)\Service Rig&replace Elmago brake control level©drillers console\Continue RIH f/2186'-1/5355'-wash down last 60'\Drill Rotary Steerable f/5355'-1/5800'. Operation at 07.00 Drilling ahead at 5,988'as per Well Plan&Schlumberger DD. 24h Forecast Drilling ahead to 9 5/8"csg.TD @ 8542' Lithology Shows -MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 4 P POOH f/1326'-1/650'to BHA 3#-LID ghost reamer 01:00 04:00 3.00 4.00 DRILL E 4 'P Work BHA#3-L/D Schlumberger tools-Down load of data from tools-Clear floor of BHA stabilizers(bad box on stab). - 04:00 06:30 2.50 6.50 DRILL E 4 P L/D Schlumberger bottom NM drill collar,due to thread damage(galled)-P/U&M/U SLB spare drill collar-Load floor with new NM stabilizers-Held PJSM to P/U BHA#4. 06:30 07.30 1.00 7.50 DRILL E 4 P P/U BHA#4 as per Schlumberger DD/MWD(Bit-Exceed,NM Stab&MWD tool). 07:30 08.00 0.50 8.00 DRILL E 20 P Safety inspection to clear ice from derrick. 08:00 09.30 1.50 9.50 DRILL E 4 P Continue P/U BHA#4 as per Schlumberger 1/654' 09:30 11:00 1.50 11.00 DRILL E 4 P RIH 1/654'-1/2186'\Test MWD @ 1037'pumping 700 gpm @ 810 psi.\P/U ghost reamer.Up wt.=105K-On wt.95K. 11:00 1300 2.00 13.00 DRILL E 25 P Service ng-Top Drive,Draw works.Cown&Blocks-Replace Elmago brake control level @ driller's console-change out pop-off on#3 mud pump. 13:00 15.30 2.50 15.50 DRILL E 4 P RIH(/2186'-1/5355'-fill every 10 stands.Up wt.=140K-Dn wt.80K.\Wash down last 60'. 15:30 00.00 8.50 24.00 DRILL E 3 'P Drill Rotary Steerable f/5355'-1/5800'(TVD 3207')as per Schlumberger DD\Pump rate 908 gpm @ 2120 psi.180-115 rpm @ 9112K torque\WOB=2-15K\Up wt.=150K-Dn wt.=70K-Rot wt.=115K./9.0+ppg mud wt.\ECD=9.81 ppg.\ ADT=5.68 hrs.\Jars=126.93 hrs. Total ADT=5.68 hrs. Total Jar=126.93 hrs. Daily Contacts Position Contact Name Company Title • E-mail Office Mobile Eni representative Frank Cormier 'Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.250.0 Spud Mud WBM 9.20 222.0 cf* Eni E&P Division (Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • API/UWI.50-029-23431-00-00 en Date:11/8/2010 - Report#: 14 page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 9.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) •Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,290.0 1.490.00 15.46 96.4 86.0 12.0 Cloudy.Blowing 182'S @ 10.5 mph Snow.WC-1.3° Daily summary operation 24h Summary Drill Rotary Steerable(/5800'-1/7290'.\Continued circulating @ drilling rate when making connection with CD system.Mud engineer dumped and diluted system and added total 500 bbls.new mud to maintain mud weight.All surface mud cleaning equipment operating. Operation at 07.00 Operation at 0400 Hours. Drilling ahead at 7,466'as per Well Plan&Schlumberger DD. 24h Forecast Drill ahead to 9 5/8"csg point @ 8542'. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P Drill Rotary Steerable f/5800'-1/6490'(TVD 3332')as per Schlumberger DD\Pump rate 900 gpm @ 2210 psi./105-120 rpm @ 10-11K torque\WOB=5-20K\Up wf.=160K-Dn wt.=70K-Rot wt.=120K.\9.1+ppg mud wt.\ECD=9.70 ppg.\ ADT=7.14 hrs.\Jars=134.07 hrs.Dump and dilute mud system-add 100 bbls.to maintain mud weight-all surface mud cleaning equipment operating. 12.00 0000 12.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/6490'-07290'(TVD 3464')as per Schlumberger DD\pump rate 900 gpm©2420 psi./120 rpm @ 11-12K torque\WOB=10-20K\Up wt.=155K-Dn wt=75K-Rot wt.=118K./9.1 ppg mud wt.\ECD=9.80 ppg.\ADT= 8.32 hrs.\Jars=142.39 hrs.Continue to dump&dilute mud-add 400 bbls.to maintain mud weight. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative -Frank Cormier Eni Petroleum Ddg Spar. Enipetroleum.AK '907-670-8623 Drilling@enipetroleum.com Eni representative Eni representative Eni representative Eni representative Tool Push Drilling Engineer • Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division I Well Name:OP17-02 fill* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUWI:50-029-23431-00-00 2^ Date:11/9/2010 - Report#: 15 '� "'I page 1 of 1 Wellbore name: OP17-02 Well Header PermitlConcession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 10.81 Daily Information End Depth(ftKB) End Depth(TVD)(f..r Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,520.0 1.230.00 12.93 95.1 88.0 10.2 Cloudy,WC-4.5' 196'S @ 11.7 mph Daily summary operation 24h Summary Drill Rotary Steerable(/7290'-1/7467.1 Problems with MWD surveys quality(FAC),performed check shot surveys as required-consult with Schlumberger OSC&Drilling Superintendent\Short top f/7310'-57068'-back-reaming and using WEI CD system,while waiting for Schlumberger to reply(MWD in spec(FAC)with check shot survey 1 RIH(/7168'-57467'survey&down link to SLB tools\Drill Rotary Steerable(/7467'-58520'-TD for 9 5/8"casing. Operation at 07.00 POOH-back-reaming and using WEI CD system for continues circulation. 24h Forecast Circulate bottoms-up 3-5X until clean-condition mud for 9 5/8"csg job.\POOH back-reaming to 13 3/8"csg.shoe using the WEI CD system for continues circulating while tripping\Circulate bosoms-up @ 13 3/8'csg.shoe\POOH to BHA and L/D as per Schlumberger\Pull wear bushing and install test plug Vetco Gray Rep(screw-in out downs)\Change rams to 9 5/8"(top)and 10"(bottom)\P/U test joints and test to AOGCC requirements-Pull test plug\Perform dump run with 9 5/8'csg.hanger\R/U GBR equipment&run 9 5/8"csg. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 '02:30 2.50 2.50 DRILL E 3 P Drill Rotary Steerable ff7290'-1/7467'(TVD 3484')as per Schlumberger DD\Pump rate 900 gpm @ 2430 psi./120 rpm @ 11.3-12.5K torque\WOB=10-20K\Up wt.=160K-Dn wt.=75K-Rot wt.=120K.\9.2 ppg mud wt.\ECD=9.84 ppg.\ ADT=1.45 hrs.\Jars=143.84 hrs. 02.30 05.00 2.50 5.00 DRILL E 12 U Directional surveys due to results of drastic changes in azimuth(dogleg)1 Check shot MWD surveys @ f/7461',7390', 7363'.7310'-MWD roll test @ 7258'to check quality(FAC)\Consult with town&Schlumberger OSC on problem.Held PJSM for short trip&reviewed WEI procedure for tripping with CD system. 0500 06.30 1.50 6.50 DRILL E 4 U POOH-Short trip(17310'-57068'\Used WEI CD system while braking out stands./pumping @ 900gpm @ 2460 psi\ i120rpm @ 11K torque./Survey @ 7161'\Waiting on reply from Schlumberger OSC-MWD was in specification(FAC)- could go back to drilling. 06:30 08:00 1.50 8.00 DRILL E 4 U RIH ff7068'-5 7467'-survey @ 7467'and send down link to Schlumberger tools. 08:00 12:00 4.00. 12.00 DRILL E 3 P Drill Rotary Steerable 57467'-57675'(TVD 3500')as per Schlumberger DD\Pump rate 900 gpm @ 2480 psi.\120 rpm @ 10.3-12.5K torque\WOB=10-15K\Up wt.=160K-Dn wt.=75K-Rot wt.=120K.\9.1 ppg mud wt.\ECD=9.79 ppg.\ /,`` ADT=2.31 hrs.\Jars=146.15 hrs. ` 12:00 00:00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable(/7675'-1/8520'(TVD 3556')as per Schlumberger DD\TD for 9 5/8"csg_\Pump rate 908 gpm @ 2815 psi.\120 rpm @ 8-15K torque\WOB=10-15K\Up wt.=150K-Dn wt.=70K-Rot wt.=115K.\9.2+ppg mud wt.\ t,j�° ECD=9.98 ppg.\ADT=9.17 hrs.\Jars=155.32 hrs. Total ADT=34.07 hrs. Total Jar=155.32 hrs Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Drilling Engineer Joe Longo Eni Petroleum Ddg Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division I Well Name:0P17-02 fli* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUWI:50-029-23431-00-00 2^n II Date:11/10/2010 - Report#: 16 If II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) •Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 11.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 8,520.0 0.00 88.0 9.3 Cloudy.WC-4.9' 180°S @ 10.9 mph Daily summary operation 24h Summary Circulate bottoms-up 5X&condition mud for 9 5/8"cement job.-rack one stand every bottom-up 1/8520'-68051'\POOH f/8051'-6 5843'-Back-reaming&using WEI CD system\WEI system#2 valve on manifold washed out-blow down&isolated system.\Continue to POOH(/5843'-V2249'-Back-reaming conventional with out use of WEI CD system./Circulate bottoms-up 2.5X until clean in 13 3/8"csg.\ POOH f/2249'-V 283'to BHA#4\Held PJSM-L/D BHA#4 as per Schlumberger-down load data. Operation at 07.00 Testing casing rams in BOPE-9.625"(top)&10.75"(bottom). 24h Forecast Finish UD BHA#4 as per Schlumberger DD/MWD.\Pull wear bushing and install test plug Vetco Gray Rep(screw-in out downs)\Change rams to 9.625"(top)and 10.75"(bottom)\P/U test joints and test to AOGCC requirements-BOPE test witnessing waived by Jeff Jones AOGCC/Pull test plug\Perform dump run with 9 5/8'csg.hanger\R/U GBR equipment&run 9 5/8"csg.as per tally. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log r Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '0430 4.50 4.50 DRILL 'E 7 P Circulate and condition mud for 9 5/8"cement job\Bottoms-up 5X as per K&M model f/8520'-8051'-Rack back one stand each bottoms-up.\Pump rate 900 gpm @ 2700 psi.\140 rpm©14.5K torque./9.1 ppg mud wt.\ECD=9.65 ppg.\Up wt.= 170K-Dn wt.=60K-Rot wt.=120K.\Monitor well-static 04.30 12.30 8.00 12.50 DRILL E 4 P POOH f/8051'-65843'\Back-reaming and using the WEI CD system for continues circulating\Pump rate 900 gpm @ 2200 psi.\130 rpm @ 8k torque\Up wt.=145K-Dn wt.=70K-Rot wt.=110K\Schlumberger check surveys©6674'.6477'. 6280'.\9.1+ppg mud wt.\ECD=9.61 ppg.\SLM. 12.30 20:00 7.50 20.00 DRILL E 4 P POOH(/5843'-62249'\Back-reaming-Note:Stopped using WEI CD system @ 5843'found valve#2 in WEI circulating manifold washed out.Isolated manifold and continued back reaming out of hole in conventional method.\Pump rate 900 qpm @ 1325 psi./120rpm @ 3-4K torque.\Up wt.=130K-On wt.=105K-Rot wt.=118K Schlumberger check surveys @ 4040',3260',2876'\9.1+ppg mud w4\ECD=9.45 ppg.SLM\Contacted AOGCC @ 1645 Hrs.for up-coming test on 9 5/8"&10 3/4"casing rams.-Jeff Jones wavied witness of test. 20:00 21 00 1.00 21.00 DRILL 'E 7 P Circulate bottoms-up 2.5X until clean 1900 gpm @ 1325 psi.\Monitor well-static\pump dry job. 21:00 22.30 1.50 22.50 DRILL 'E 4 P POOH(/2231'-6283'\with correct pipe displacement.Ghost reamer cut down 3"(grooved)off bottom of blades. 22:30 00.00 1.50 24.00 DRILL .E 4 P Held PJSM-L/D BHA#4 as per Schlumberger DD/MWD Rep.Top SLB NM stab missing 50-85%tiles off blades.1/8"out- Bottom NM stab grooved on bottom of blades-1/16"out. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Frank Cormier Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.cow 907-980-7545 907-980-7545 Drilling Engineer Joe Longo Eni Petroleum Ddg Eng. Joe.Longo@enipetroleum.cow 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 37.2 2,249.5 11/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division I Well Name:0P17-02 J Vil* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq Date:11/11/2010 - Report#: 17• APIIUWI:50-029-23431-00-00 2" "g page 1 of 1 Wellbore name: OP1 7-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30,/2010 27,680.00 220.88 125.3 12.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F( Weather Wind 6,520.0 0.00 89.0 10.2 Cloudy,Light Snow. 348'NNW @ 16 WC-6.5' mph Daily summary operation 24h Summary L/D BHA#4&clear floor\Pull wear bushing and install test plug&verified by Vetco Gray Rep(lock-downs in)\Change rams to 9 5/8"(top)and 10"(bottom)/P/U 10 3/4"test joints-unable to get Low/250 psi.,but tested high @ 3500 psi.f/5 mins.\Change out 10 3/4"to 9 5/8"test jt. Test 9 5/8"to Low/250 psi.\High/3500 psi.for 5 mins.-chart recorded\Change back 9 5/8"to 10 3/4"test jt.\ Attempt to retest-unsuccessful\Open lower ram doors&found broken sealing element,remove rams&dose BOP's\Pull 10 3/4"test joint and test plug-fill hole with 10 bbls.of mud\P/U 9 5/8"csg. hanger and make dummy run,verified by Vetco Gray Rep.-L/D same\Dress rams with new elements and install in BOP's\Install 10 3/4"test joint\Test Low/250 psi\High/3500 psi.for 5 mins.&chart recorded.\Pull test joint&plug-L/D\Held PJSM-R/U GBR equipment&Frank's tool\P/U 9 5/8"csg.479,L-80 as per tally to 2241'\Circulate 9 5/8"csg.capacity-Check#1&#2 mud pump efficiency. Operation at 07.00 P/U 9 5/8",479,L-80\Fill while RIH&break circulation every 10 joints\K&M record parameters./Circulate bottoms-up every 2000'after surface csg. 24h Forecast P/U 9 5/8,479,L-80 casing to 8505'\Circulate&condition mud\Hold PJSM-R/U Schlumberger-Batch mix cement&pump\Displace with LSND mud using rig mud pumps-bump plug&check floats\ R/D Schlumberger\Little Red to freeze protect annulus with diesel./Clean pits for OBM\Change rams. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02.00 2.00 2.00 DRILL E 4 P L/D BHA#4 as per Schlumberger and clear floor of components. 0200 0400 2.00 4.00 DRILL G 5 P Pull wear bushing-M/U one stand HWDP w/mule shoe under test plug-land in well head,Vetco Gray screw-in lock downs 0400 06:00 2.00 6.00 DRILL G 20 P Change rams-To2-1q_LtLB'gild.Bottom to 10 3/4". 06.00 08:30 2.50 8.50 DRILL G 12 P Install 10 3/4"test joint&fill stack with water-test to 250 psi.(Could not get low pressure test),tested to 3500 psi.- function rams several times-no low test.-Pull 10 3/4"test joint. 08.30 09:30 1.00 9.50 DRILL G 12 P P/U 9 5/8"test joint and install-test to 250/3500 psi for 5 mins.each&chart record.UD 9 5/8"test joint.P/U 10 3/4"test joint and install same. 09:30 10:00 0.50 10.00 DRILL G 12 XR05 Attempt several times to get low pressure test(250 psi.)-would not test 10:00 11:30 1.50 11.50 DRILL G 20 XR05 Open lower rams and found damaged sealing elements,remove rams and close doors-made calls for replacement element or rams.\located a set at Doyon. 11:30 12:00 0.50 12.00 DRILL G 20 XPO5 Pull 10 3/4"test joint and UD-Pull test plug,took 10 bbls.mud to fill hole. 12:00 13:00 1.00 13.00 DRILL G 5 P Performed dummy run with 9 5/8'csg.hanger-Venfied by Vetco Gray.1 UD landing joint&hanger. 13:00 15:00 2.00 15.00 DRILL G 5 P Install test plug-verified by Vetco Gray(lock-downs in).P/U 10 3/4"test joint-Redress 10 3/4"rams-install in BOP.\ New seal elements amved on rig#1330 hrs.) 15:00 15:30 0.50 15.50 DRILL G 12 P Test 10 3/4"low 250 psi/high 3500 psi.for 5 mins.-chart record. 15:30 16:30 1.00 16.50 DRILL G 20 P L/D 10 3/4"test joint and pull test plug. - 16:30 18:00 1.50 18.00 DRILL G 20 P Held PJSM-R/U GBR equipment&Franks tool to run 9 5/8"csg.-load floor with components. 18.00 22:30 4.50 22.50 DRILL G 4 P P/U and run 9 5/8"csg.47#,L-80 as per la((y,to 2240'-,break circulation&check float equipment-record parameters.\Fill with Franks tools&break circulation every 10 joints-Up wt.=140K-Dn wt.=130K. 22.30 00:00 1.50 24.00 DRILL G 7 P Circulate 9 5/8"volume @ 13 3/8"shoe-210 gpm @ 150 psi.\Up wt.=134K-Dn wt.=122K.Check pumps efficiency#1 @ 93%and#2 @ 90%. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Dolling Engineer Joe Longo Eni Petroleum DrIg Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(f1KB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.250.0 Spud Mud WBM 9.20 222.0 1"1* Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • API/UWI:50-029-23431-00-00 2^ Date:11/12/2010 - Report#: 18 II II page 1 of 1 Wellbore name: OP17-02 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 13.81 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,520.0 0.00 88.0 8.2 Cloudy,Light Snow. 355 N @ 20.9 mph WC-11.6" Daily summary operation 24h Summary P/U 9 5/8"L-80,47#casing(/2241'-U 8505'-P/U landing joint&hanger-circulate bottoms-up @ 4321'.6027',7063'stage rate to 360 gpm @ 550 psi.\R/D Frank's fill-up tool&P/U Schlumberger cement head-Held PJSM\Schlumberger test lines to 3000 psi.-batch mix 300 bbls of Deep Crete 12.5 ppg cement I Displace with rig pumps 612 bbls.9.1 LSND mud-bump plug-pressure up to 1150 psi\Breed off to check floats-holding\R/D Schlumberger&GBR equipment\Install 9 5/8"pack-off&test V 5000psi for 10 minutes./R/U Little Red Hot Oil to freeze protect 9 5/8"x 13 5/8"annulus-test lines to 3000 psi-displace with 150 bbls dirty diesel pumping FCP @ 2 bpm with 1375 psi.-shut 900 psi.\Change bottom rams to 3"x 6". Operation at 07.00 RIH with 5"pipe to UD. 24h Forecast Change top rams to 4"x 7"and shell test-Install wear bushing\RIH 5"HWDP&5"drill pipe with bad hard band\POOH L/D same\Continue cleaning pits for OBM\P/U 5"drill pipe and install WEI CD sub(make&break connection). Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9,10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03.00 3.00 3.00 DRILL G 4 P P/U and run 9 5/8"csg./L-80/47#as per tally 1/2241'-04321'\Fill with Franks tools&break circulation every 10 joints- K&M recording parameters for friction factor./Up wt.=182K-Dn wt.=126K. 03:00 04.30 1.50 4.50 DRILL G 7 P Circulated bottoms-up @ 4321'\Stage pump rate up 1\200 gpm @ 230 psi.-final rate of 348 gpm @ 450 psi.Reciprocated 9 5/8"csg.\Up wt.=180K-Dn wt.=129K. 04.30 07.00 2.50 7.00 DRILL G 4 P Continue P/U 9 5/8"csg./L-80/47#per tally f/4321'-96027\Up wt.=225K-Dn wt.=92K. 07.00 08.00 1.00 8.00 DRILL G 7 P Circulated bottoms-up @ 6027'\Stage pump rate up f/206 gpm @ 245 psi.-final rate of 347 gpm @ 460 psi.Reciprocated 9 5/8"csg.\Up wt.=235K-Dn w1.=90K. 08.00 09.00 1.00 9.00 DRILL G 4 P P/U 9 5/8"csg./L-80/47#per tally f/6027'-97063'\Up wt.=272K-Dn wt.=77K. 09.00 10.00 1.00 10.00 DRILL G 7 P Circulated bottoms-up @ 7063'\Stage pump rate up f/206 gpm @ 230 psi.-final rate of 347 gpm @ 430 psi.Reciprocated 9 5/8"csg./Up wt.=235K-Dn wt.=90K 10.00 12.00 2.00 12.00 DRILL G 4 P P/U 9 5/8"_csg./L-80(47#per tally 1/7063'-98456'\Up wt=295K-Dn wt.=80K 12.00 12:30 0.50 12.50 DRILL G 4 P P/U Landing joint&9 5/8"csg.hanger-RIH(/8456'-08505'and land casing in well head./Pumping 360 gpm @ 550 psi./ Up wt.=290K-Dn w1.=85K. xii 12.30 14:00 1.50 14.00 DRILL G 7 P Circulate&condition mud\bottoms-up 1.5X(clean)\360gpm @ 550 psi. �sl tr 14:00 14:30 0.50 14.50 DRILL G 20 P Shut down circulating\UD frank's fill-up tool&P/U Schlumberger cementing head. 4 14:30 15:00 0.50 15.00 DRILL H 7 P Continue circulating-checking pump efficiency\Held PJSM with Schlumberger and rig personnel. till' 15:00 18:30 3.50 18.50 DRILL H 7 P Cement Job-Pump 5 bbls of H2O\Pressure test lines to 3000 psi./Pump 70 bbls.of 10.50 ppg Mud push\Drop bottom v t plug\Batch mix and pump 300 bbls.(1095 sacks)of Deep Crete 12.5 ppg cement\Drop top plug&pump 5 bbls.H2O\ i Iv \ Switch to rig pumps&displace with 9.1 ppg LSND mud pump rate @ 330 ggpm @ 650 psi./slowed rate to 3 bpm 650 psi. ,Y @ 600 bbls.\612 bbls.away bump plug to 1150 psi(500 psi of FCP 650 psi.)Cement in place @ 1810 hrs.Hold for 5 mins. -bleed off&check floats-holding.Good returns through the job with a small amount of loss. 18:30 19:30 1.00 19.50 DRILL G 20 P R/D Schlumberger cement head&lines I GBR casing equipment-clear floor. 19:30 21:00 1.50 21.00 DRILL G 20 P P/U and install 9 5/8"csg.pack-off with Vetco Gray\screw-in lock downs and pressure test to 5000 psi for 10 minutes. 21:00 22:30 1.50 22.50 DRILL G 20 P R/U Little Red Hot Oil\Test lines 9 3000psi.-displace 9 5/8"x 13 5/8"annulus with 150 bbls.dirty diesel @ 75\ICP 600 psi @ 2 bpm-FCP 2 bpm @ 1375 psi.-shut in pressure @ 900 psi. 22:30 00:00 1.50 24.00 DRILL G 20 P ,SI anae rjrrl@_-_Bpttom rams from 10 3/4"to 3"06". . Daily Contacts Position 1 Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com En:representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com En:representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 En:representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.250.0 Spud Mud WBM 9.20 222.0 fill* Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • API/UWI:50-029-23431-00-00 2^ Date:11/1312010 - Report#: 19 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 14.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,520.0 0.00 85.0 5.2 Cloudy,Light Snow 34T NNW @ 11.7 WC-10.8" mph Daily summary operation 24h Summary Change top rams to 4 1/2"x 7".Shell test BOP with top rams.Low 250/High 3500 psi./RIH 5"HWDP&DP with worn/bad hard band 03334'./POOH LID same\RIH 6 stands from derrick 8590'-installing WEI/CD sub(make&break connection)\Continue P/U 5"DP singles f/590'-U 4018'-installing WEI/CD sub(make&break connection).Gave AOGCC 24 hrs.notification of early BOP test(due date 11- 18-2010)-AOGCC replied and will witness test. Operation at 07.00 POOH w/5"drill pipe with WEI CD-sub installed. 24h Forecast Finish P/U 5"drill pipe singles and install WEI CD sub./POOH-rack in derrick./P/U 5"HWDP&jars\Change saver sub\Test BOP w/AOGCC to witness\Cut drilling line/P/U BHA#5/RIH P/U 5"DP to float collar with no CD sub./Test 9 5/8"csg to 3000 psi./Displace casing with new OBM\Drill out float collar&shoe. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01.30 1.50 1.50 DRILL E 20 P Change rams-Top rams from 9 5/8"to 4 1/2"x 7" 01 30 03:00 1.50 3.00 DRILL E 20 P P/U test joint&test equipment-fill stack with H2O 03.00 03:30 0.50 3.50 DRILL E 12 P Shell test BOP with 5"test joint(4 1/2"x 7"rams)-Low 250/High 3500 psi.for 5 mins.each-chart record. 03.30 04:30 1.00 4.50 DRILL E 20 P L/D test tool equipment&blow down-pull test plug&install wear ring(ID 9.125)with Vetco Gray Rep. 04.30 07.00 2.50 7.00 DRILL E 4 P RIH with 4 stands HWDP(with mule shoe)&31 Stands DP-513334' 07.00 14.00 7.00 14.00 DRILL E 4 P POOH LJD 5"DP and HWDP with won/bad hard band-3334'-vac out fluids.Gave AOGCC 24 hrs.notification of early BOP test-AOGCC replied and will witness the test. 14:00 15.00 1.00 15.00 DRILL E 20 P Clear short pipe shed of 5"HWDP,WEI-CD subs to ng floor&load with Schlumberger BHA#5. 15:00 16.00 1.00 16.00 DRILL E 4 P RIH with 5"doll pipe from derrick(6 stands)installing WEI/CD sub(make-up&break-out&make-up each sub connection).\ 0590'. 16:00 00'00 8.00 24.00 DRILL E 4 P Continue RIH P/U 5"doll pipe singles installing WEI/CD subs(make-up&break-out&make-up each sub connection). f/590'-84018'Up wt.=90K-Dn wt.=80K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Em Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Drlg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division [well Name:opn-oz Of* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • Date:11/14/2010 - Report 20 API/UW:50-029-23431-00-00 2l "ii page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator EM Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 15.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,520.0 0.00 85.0 -0.2 Cloudy,WC-18.8" 229 SW @ 12.4 mph Daily summary operation 24h Summary P/U 5"DP singles(/4018'-5/4923'-installing WEI-CD sub(make&break connection).\POOH 1/4923'-1/1279'(wash out CD subs)\P/U 5"HWDP&Jars 1/1556'\POOH 1556'-1/679'-(wash out CD subs)/Cut drilling line I Service rig I POOH 1/679'-U surface.(wash out CD subs)./Pull wear bushing&install test plug./Change Top Drive saver sub&new gripper dies.\Test BOPE with 4 1/2"&5" tubular-Annular Low 250/High 2500 psi.-Remaining to Low 250/High 3500 psi.-5 mins.chart record./Pull test plug&install wear ring./RIH-P/U 5'DP singles 5/959'. Operation at 07.00 P/U 5"drill pipe for production interval. 24h Forecast P/U 5"DP\POOH with 5"DP\P/U BHA#4\RIH to above float collar&circulate bottorn-up./Test 9 5/8"csg.to 3000 psi.f/30 mins./Displace hole with new OBM\Drill out shoe track&20'0 new hole\ Perform LOT with a minimum of 12 ppg.EMW or FIT @ 14 ppg EMW.\Drill ahead as per Schlumberger&Well Plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03.00 3.00 3.00 DRILL E 4 P Continue RIH P/U 5"drill pipe singles installing WEI/CD subs(make-up&break-out&make-up each sub connection). //4018'-5/4923'\Up wt.=90K-Dn wt.=80K. 0300 06:00 3.00 6.00 DRILL E 4 P POOH with 5"DP dress with WEI-CD subs f/4923'-1/1279'rack in derrick,SLM\WEI wash out all CD sub. 06.00 06:30 0.50 6.50 DRILL E 4 P P/U 5"HWDP(8joints)&jars-stand back in derrick.///1279'-//1556' 06:30 08:00 1.50 8.00 DRILL E 4 P POOH 1/1556'-5/679'-SLM\WEI wash out all CD sub.\Up wt.=65-Dn wt.=60K. 08.00 09:00 1.00 9.00 DRILL E 4 P Cut drilling line&slip 85'of line. 09:00 09:30 0.50 9.50 DRILL E 20 P Service rig-Top Drive,Draw-works.Blocks&Crown. 09:30 10:00 0.50 10.00 DRILL E 4 P POOH 1/679'to surface./SLM 10:00 11'00 ' 1.00 11.00 DRILL E 20 P Pull wear bushing and install test plug. 11:00 13:00 2.00 13.00 DRILL E 25 P Change out saver sub&install new dies in gripper for Top Drive. 13:00 14.00 1.00 14.00 DRILL E 12 P P/U 4 1/2"test joint&R/U test equipment./fill choke&stack with water. 14.00 21'.00 7.00 21.00 DRILL E 12 P TeSt BOPS-4_,V2:'Sest joint-Annular Low 250/High 2500 psi.&Variables(Upper/Lower)rams Low250/High 3500 psi./ Change to 5"DP test joint-tested Variables(Upper/Lower)rams,choke&kill line valves-HCRS-choke manifold-top drive-floor valves and Blind rams to Low 250/High 3500 psi.for 5 mins.each-chart record all test.Performed accumulator , dram-down test(total recover time 151 seconds).AOGCC(Chuck Schieve)waived witnessed test. 21:00 22-.00 1.00 22.00 DRILL E 20 P R/D test equipment\Pull test plug-drain stack&blow down lines\Install wear bushing-Vetco Gray. 22.00 00-.00 2.00 24.00 DRILL E 4 P P/U 5"drill pipe singles with mule shoe f/surface-U 959'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Cnswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0' 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 11* Eni E&P Division 'Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • Date:1111512010 - Report#: 21 APIIUWI:50-029-23431-00-00 2'r i ii page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27680.00 220.88 125.3 16.81 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,520.0 0.00 85.0 7.0 Blowing Snow,WC- 163"SSE @ 19.7 12.5" mph Daily summary operation 24h Summary RIH-P/U 5'DP singles 1/959'-t/8041'\POOH f/8041'-V surface\Down Time-Elmagco brake was not working properly-trouble shoot,possible bad bearings.\Disconnect from draw-works&remove from rig\Replacement Elmagco brake unit on location @ 2130 hrs. Operation at 07.00 Rig Down Time-in process of putting replacement Elmagco electric brake on draw-works. 24h Forecast Rig Down Time-Install Elmagco electric brake on draw-work./P/U BHA#5/RIH above float collar&CBU./Test 9 5/8"csg.to 3000 psi.f/30 mins./Displace hole with new OBM\Drill out shoe track& 20'0 new hole\Perform LOT with a minimum 0112 ppg.EMW or FIT @ 14 ppg EMW.\ Drill ahead as per Schlumberger&Eni Well Plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.05 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 08:00 8.00 8.00 DRILL E 4 P RIH P/U 5"drill pipe singles f/959'-680413 Up w1.=160K-Dn w1.=55K 08:00 12:00 4.00 12.00 DRILL E 4 P POOH with 5"DP f/8041'-6surface-rack in derrick,SLM. 1200 00:00 12.00 24.00 DRILL E 25 XR01 Rig Down Time-Elmagco electric brake on draw-works failed due to possible bad bearing./Disconnect from draw-works and remove from ng floor down V-door beaver slide-remove from pipe shed.\Replacement unit on location @ 2130 hrs. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 D ril l i n g@ e n i pe t ro le u m.co m Drilling Supt. David Smith Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 907-632-3058 D rill in g@ en ipetrole u m.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Caswell Eni Petroleum Expediter eniexpeditor@gmail.cow 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505.6 11/12/2010 Last Leakoff Test Depth(RKB) TVD(11KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.250.0 Spud Mud WBM 9.20 222.0 f iff* Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2 Date:11/16/2010 - Report#: 22 I' li II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 17.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8.520.0 0.00 85.0 19.4 Blowing Snow,WC 175`S @ 15.9 mph 5.2 Daily summary operation 24h Summary Rig Down Time-Removal&installation Elmago brake on draw-works-make modification as required to dial-in and make operational. Started P/U BHA#5 at 0200 hours. Operation at 07.00 P/U BHA#5 and RIH 24h Forecast Check glycol system for leaks and function test Elmagco electric brake(good)-Install guards(modified).\P/U BHA#5 1 RIH above float collar&CBU./Test 9 5/8"csg.to 3000 psi.f/30 mins./Displace hole with new OBM I Drill out shoe track&20+new hole\Perform LOT with a minimum of 12 ppg.EMW or FIT @ 14 ppg EMW./Drill ahead as per Schlumberger&Well Plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '06.00 6.00' 6.00 DRILL E 25 TRO1 Rig Down Time-Remove feet off old Elmago electric brake unit and remove shipping pedestal from new unit-prep to P/U./ Remove pipe skate alignment yoke by beaver slide./Remove electrical conduct from side of brake./Pull new unit to rig floor up beaver slide. 06:00 '13:00 7.00- 13.00 DRILL E 25 TRO1 Rig Down Time-Install feet on Elmagco brake and spot in place\Modified hole alignment in floor structure beam.\Remove alignment key stock from floor./Weld-down push guides to move Elmagco brake for dial-in place.Install bolts in beams. 13.00 '20.00 7.00' 20.00 DRILL E 25 Rig Down Time-Mechanics dial-in and shim Elmagco brake spline coupling to draw-works coupling./Re-weld skate yoke alignment brace back in place @ beaver slide./Torque down Elmagco brake and hook-up electrical. 2000 0000 4.00- 24.00 DRILL E 25 TRO1 Rig Down Time-Plumb glycol lines back to unit./Install water spear through Elmagco to draw-works(modified bolt caps for clearance).\Put coupling back together and weld handle on with lock,re-install grease hoses./Hook-up transducers for Epoch/Canag&Schlumberger/Electrician check gap on magnets prior to power-up unit. • Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spvr. Enipetroleum.AK °907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Dig Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Caswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.250.0 Spud Mud WBM 9.20, 222.0 lifi* Eni E&P Division I Well Name:0P17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq Date:11/17/2010 - Report#: 23 APIIUWI:50-029-23431-00-00 en II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53,26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680,00 220.88 125.3 18.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8.520.0 0.00 85.0 29.3 Cloudy,Light Blowing 204'SSW @ 22.7 Snow.WC 15.8' mph Daily summary operation 24h Summary Rig Down Time until 0200 hrs.-Check Glycol system&test Elmagco-Calibrated block with Epoch/Canrig&Schlumberger.\Held PJSM&P/U BHA#5-(load radioactive sources)-t/471'.\Continue RIH 1/471'-6950'.1 Surface test MWD tool and WEI manifold V3000 psi.\RIH 1/95V-1/8321'/Circulate Bottoms-up(clabbered up mud)./R/U to test w/head pin-circulate&condition LSND mud 9.1 ppg./Test 9 5/8"to 3000 psi f/30 mins./Waiting on weather(Phase 3 condition)&held PJSM to displace well bore./Displace to OBM as per Mud Engineer. Operation at 07.00 Cleaning shakers&pits./Waiting on weather-Phase 3. 24h Forecast Clean shakers&pits 1 Displace well to VersaPro mud./Drill shoe track&204 new hole I CBU for equal mud weights-P/U into 9 5/8"csg./Perform LOT/FIT.\Drill production interval as per Schlumberger &Well Plan to TD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 25 XR01 Rig Down Time-Check glycol system for leaks and install guards./Function tested Elmagco brake(operational)./ Calibrated block with Epoch/Canrig&Schlumberger.Clean up area of tools. 02:00 05:30 3.50 5.50 DRILL E 4 P Held PJSM with Schlumberger-P/U BHA#5 as per DD/MWD Reps(Load radioactive sources in tools)./RIH HWDP&Jars 1/471'. 05.30 06.00 0.50 6.00 DRILL E 4 P RIH with BHg15-f/475J/850'to surface test MWD tools 06.00 08.00 2.00 8.00 DRILL E 7 P Circulate-Test Schlumberger MWD pumping 560 gpm @ 780 psi./Pressure test WEI manifold to 3000 psi. 08.00 13.00 5,00 13.00 DRILL E 4 P RIH f/950'-t/8321'.\Up wt.=170K-Dn wt=55K. 13:00 14.30 1.50 14.50 DRILL E 7 P Circulate Bottoms-up with 300 gpm @ 600 psi.LSND mud wt.=9.1 ppg. 14:30 15:00 0.50 15.00 DRILL E 1 P R/U head pin,valve&hose to test 9 5/8'csg. 15:00 16:30 1.50 16.50 DRILL E 7 P Circulate&condition mud pumping 300 gpm @ 770 psi.-LSND mud wt.=9.1 ppg. 16:30 18:00 1.50 18.00 DRILL E 12 P Test 9 5/8"csg to 3000 psi for 30 minutes.-chart record./9.1 ppg LSND mud./Total of 6 bbls.pumped-bleed back 6 bbls. 18:00 23:00 5.00 23.00 DRILL E 22 XWO1 Waiting on weather-Phase 3 condition-Service Top Dnve-mechanic,clean floor\Held PJSM for displacing OBM. 23:00 0000 1.00 24.00 DRILL E 7 P RIH f/8321'-1/8417'Tag w/4K.-Displace to OBM\Pumped 22 bbls.LVT spacer 8.4 ppg.-pump rate 84 gpm @ 180 psi.- followed with 8.4 ppg of VersaPro LS mud./252 gpm @ 620 psi.Up wt.=175K-Dn w[=.60K, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener 'Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bemie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505,6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,250.0 Spud Mud WBM 9.20 222.0 Eni E&P Division (Well Name:0P17-02 Pi* EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2^ifl Date:12/2/2010 - Report#: 38 ii page 1 of 1 wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 33.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(H) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,940.0 0.00 86.0 -5.1 Overcast,Calm,WC 24`NNE @.5 mph Daily summary operation 24h Summary Continued single joint TIH to-8000'MD.Circ and cond mud to 9.2 ppg in/out. POOH T/2300'and racked back 4-1/2"DP,L/D mule shoe and XO.C/O elevators. PU BHA#6 and TIH T/8467'MD.Cut and slip drill line. Operation at 07.00 Troughing S/T. Depth @ 0400 hours 9,458'MD 24h Forecast Service top drive brake,calibrate depth for MWD and set crown-o-matic.Begin low side SIT @ 9440'MD. Rotary drill ahead as per plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03.00 3.00 3.00 DRILL E 4 U P/U and single in 135 joints 4-1/2"DP and RIH to 8,000'MD,UP-WT 12K,DOWN-WT 90K. 03:00 07.30 4.50 7.50'DRILL E 4 U Circ and Cond @ 160 SPM/2000 PSI/560 GPM/to 9.2 PPG IN/OUT 07:30 12.00 ' 4.50 12.00 DRILL E 4 U POOH F/8,000'T/2.300'no swab,proper hole fill. 12:00 '13:30 1.50 13.50 DRILL E 4 U POOH F/2300'standing back 4-1/2". L/D mule shoe and XO. C/O elevators T/5". 13:30 1700 3.50 17.00 DRILL E 4 U PJSM.P/U BHA#6 and load nuke source. BHA WT @ Jars 60K,BHA WT @ top of HWDP 65K / 17:00 22:00 5.00 22.00 DRILL E 4 U TIH w/4-1/2"DP T/8467'MD/UP-WT 135K\DN-WT 85K. Fill pipe every 20 stands Ir/ 22:00 00.00 2.00 24.00 DRILL E 4 U Cut/Slip 60'drilling line Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Gary Goerlich Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mall Coord. 907-670-8581 907-240-2712 Drilling Engineer Joe Longo Eni Petroleum Ddg Eng. Joe.Longo@enipetroleum.cow 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550,0 OBM Versapro 8.40 814.0 Eni E&P Division I Well Name:0P17-02 PI* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2^H„ Date:12/3/2010 - Report#: 39 " " page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(15) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 34.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 9,502.0 3,554.8 42.00 11.07 3.8 87.0 2.8 Blowing Snow,WC- 17°NNE @ 35 mph 23.4` Daily summary operation 24h Summary Serviced top drive brake.calibrated depth for MWD and set crown-o-uratic.Besan low side S/T Ai 9460'-t/9502'MTpp Drive problems with torque(double valves)&reduced RPM @ 2000 hrs.- Trouble shoot,check torque booster&back brake-OK,change out encoder still had problems.POOH U9448,119348'. Operation at 07.00 Trouble shooting Top Drive problems with torque&RPM reduction. 24h Forecast POOH to shoe\Trouble shoot Top Drive problems and fix\RIH to 9502'and continue to side track\Drill ahead as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 25 P Service Top Drive-Fix back brake,(calibrated brake pads as per mechanic)-Schlumberger&Epoch block calibration. 02:00 02:30 0.50 2.50 DRILL E 4 P RIH 1/8647'-119448' 02:30 05:30 3.00 5.50 DRILL F 3 P Open hole side track as per Schlumberger-Trenched 1/9440'-89460'-Reciprocated pipe\Pump rate 600 gpm @ 3500 psi.\120 rpm @ 5K torque\Condition mud 8 9.2 ppg as per Mud Engineer. 05:30 09:30 4.00 9.50 DRILL F 3 P Time drill as per Schlumberger 1/9460'-89475'with 2 FPH and increased to 5 FPH\Pump rate 600 gpm @ 3500 psi.\120 rpm @ 5K torque. 09:30 10:00 0.50 10.00 DRILL F 3 P Attempt to kick-off @ 1/9475'-89477'\Pump rate 600 gpm @ 3500 psi./120 rpm @ 6K torque\2K WOB\went back into old hole. 10:00 20:00 10.00 20.00 DRILL F 3 P Time doll back @ f/9475'-89502'as per Schlumberger with 3 FPH increased to 5 FPH @ 9485'-10FPH @ 9495'14K WOB @ 9500'\600 gpm @ 3350 psi.\120-140 rpm @ 5-6K torque\Up wt=130K-Dn wl.=80K-Rot 105K.\9.2 ppg mud wl.\ECD=10.44 ppg. Total ADT=11.07 hrs. Total Jar=11.07 hrs. 20:00 23.30 3.50 23.50 DRILL E 25 XR04 Down Time-Trouble shoot Top drive(torque valves 12-14K&RPM erratic)POOH 89484'.\Check torque booster&back brake if they were engaging-OK\Electrician replaced encoder on motor-tested with same results.by-pass encoder and could get to 140 rpm but with 2K torque over dolling parameters.Consulted with CanRig on problems. 23:30 00.00 0.50 24.00 DRILL F 4 XR04 POOH f/9484'-119349'1Up w1.=140K-Dnwl.=70K Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum 'Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ng Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilfing@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mall Coord. 907-670-8581 907-240-2712 Drilling Engineer Joe Longo Eni Petroleum Ddg Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 f� Eni E&P Division I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UW:50-029-23431-00-00 2^n Date:12/4/2010 - Report#: 40 II lI II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 35.61 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POE Temperature(°F) Weather Wind 10,137.0 3,556.7 635.00 6.58 96.5 89.0 -2.9 Overcast,WC-22° 37°NE @ 12.8 mph Daily summary operation 24h Summary POOH to 8463'in 9 5/8"csg.\Trouble shoot Top Drive-final replacement of encoder(second time)-function test-good.\RIH 09502'continue to control drill(/9502'-09511'(concretion)\Slowly pick-up drilling rate to parameters and drill ahead f/9511'-1/10137'as per Schlumberger DD&well plan. Operation at 07.00 Operation at 0400 Hours: Drilling rotary steerable as per Schlumberger DD at 10,498'MD. 24h Forecast Drill ahead Rotary Steerable as per Schlumberger DD and well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.20 Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL F 4 TRO4 POOH(/9349'-08467'in 9 5/8"CSG.\4 mins.per stand\Up w1=135K-Dn w1.=80K.\Monitor well static. 02:00 14:30 12.50 14.50 DRILL F -25 TRO4 Down Time-Trouble shoot Top drive(torque valves&RPM erratic)\Consult with Can Rig in Houston.\Wire bumed into @ encoder(repair)-found two Ores not connected in TD J-box(hooked-up)-checked all Ores from TD J-box to J-box on rig floor\Remove wash pipe and check tolerances of TD bearings(in spec.),reinstall wash pipe\Encoder failure and replaced ,/ for the second time-fixed the problem-function test system-good. f////// 14:30 15:30 1.00 15.50 DRILL -F -4 TRO4 RIH 68467'-09502'\Up wt.=135K-Dn wa.=75K 15:30 19:00 3.50 19.00 DRILL F 3 P 'Ooen hole side track-Control drill 119509'-09511'two 35.55'1 as ner Srhlumheager with 2-4K WOB'\609 gpm @ 3450 psi.\120 rpm @ 6.8K torque\Up wt=130K-On wt.=70K-Rot 102K.\9.3 ppg mud wt.\ECD=10.66 ppg.\ADT=3.0 hrs.\ Jars=3..0 hrs. 19:00 00:00 5.00 24.00 DRILL E °3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan(/9511'-010137'(TVD 3556')\Pump rate 605 gpm @ 3430 psi.\120 rpm @ 6-8K torque\WOB=4-15K\Up wt.=140K-Dn wt.=65K-Rot wt.=100K.\9.2 ppg mud wt.\ECD= 10.72 ppg.\ADT=3.58 hrs.\Jars=3.63 hrs. Total ADT=17.65 hrs. Total Jar=17.7 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Frank Cormier Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spar. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.6om Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mat'I Coord. 907-670-8581 907-240-2712 Drilling Engineer Joe Longo Eni Petroleum Ddg Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(f1KB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 IP* Eni E&P Division (Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • API/UWI:50-029-23431-00-00 2 Date:12/512010 - Report#: 41 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 36.81 Daily Information End Depth(ftKB) . End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,401.0 3,541.8 2,264.00 13.43 168.6 88.0 -8.0 Overcast,WC-23.4° 30°NE @ 7.8 mph Daily summary operation 24h Summary Drilling Rotary Steerable(/10137'-5/12,401 as per Well plan\Maintain 9.2 ppg mud weight.\Change out sensor on stand pipe manifold\Layed down WEI CD sub due to bad threads in the box.WEI CD sub L/D(SN#120-06)-P/U(SN#664.07) Operation at 07.00 Drilling ahead @ 12750'. 24h Forecast Continue to drill ahead with Schlumberger Rotary Steerable as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.20 TimeLog SItart End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 1200 - 12.00' 12.00 DRILL E '3 P Drill Rotary Steerable as per Well Plan(/10137'-5/11,219'(TVD 3523')\Pump rate 600 gpm @ 3580 psi.\120 rpm @ 7-8K torque\WOB=2-15K 1 Up wt.=155K-On wt.=80K-Rot wt.=102K./9.2 ppg mud wt./ECD=11.05 ppg.\Changed out mud pump sensor on stand pipe manifold-(pumps down 12 minutes)/Lay down CD sub with bad threads in box(SN#120- 06)P/U new CD sub(SN#664.07)-(pumps down 19 mins)/ADT=5.76 hrs.\Jars=5.76 hrs. 12:00 00.00 12.00 24.00 DRILL E 3 •P Drill Rotary Steerable as per Well Plan 911219'-5/12401'(TVD 3541')\Pump rate 584 gpm @ 3650 psi./120 rpm @ 9-10K torque\WOB=2-15K 1 Up wt.=178K-Dn wt.=No Data-Rot wt.=110K.19.2 ppg mud wt.\ECD=11.31 ppg.1 ADT=7.67 hrs.\Jars=7.67 hrs.\Total loss for 24 hrs.=44 bbls. Total ADT=31.08 hrs. Total Jar=31.08 hrs. Daily Contacts Position Contact Name Company Title • E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bemie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Caswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mad Coord. 907-670-8581 907-240-2712 Drilling Engineer Joe Longo Eni Petroleum Ddg Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2^„ Date:12/6/2010 - Report#: 42 iI II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N" Operator ENI Share(55) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP((tRrr) DFS(days) 0P17-02 DRILLING 10/30/2010 27680,00 220.88 125.3 37.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress((t) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 14,595.0 3,544.5 2.194.00 12.66 173.3 89.0 -19.5 Overcast,WC-31.4` 9&E @ 4 mph Daily summary operation 24h Summary Drilling Rotary Steerable(112401'-1112929'as per Well plan\Down Time:Lost communication link at top drive console rack-trouble shoot,check out plug @ J-box on top drive of communication cable, tighten&secured same,function test-OK.\Drilling Rotary Steerable 8/12929'-014595'I MWD tool alarm for low oil in reservoir,system is leaking oil and may fail(estimated 4-30 hrs),consult with town to continue to drill ahead until failure.\Maintain 9.2 ppg mud weight. Operation at 07.00 Drilling Rotary Steerable @ 14,595'. 24h Forecast Continue to drill with Schlumberger Rotary Steerable as per Well Plan until T/D of well or MWD tool failure. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.30 6.50 6.50 DRILL E 3 P Drill Rotary Steerable as per Well Plan f/12401'-V12929'(TVD 3535')\Pump rate 570 gpm @ 3630 psi.\120 rpm©8-10K torque\WOB=6-15K\Up wt.=175K-Dn wt=No data-Rot wt.=110K.\9.2 ppg mud wt.\ECD=11.2 ppg.\ADT=3.27 hrs.\Jars=34.35 hrs. 06:30 07.30 1.00 7.50 DRILL E 25 TRO4 Down Time:Lost communication link with top drive console rack and shut down entire system,trouble shoot-reboot system and set back stand.Check out J-box on top drive and one wire seemed loose @ connection plug.Unplug and re- plug.secured and support wire to plug.Test function top drive and all seems to be working correctly.P/U stand and go back to drilling. 07:30 12.00 4.50 12.00 DRILL E 3 P Drill Rotary Steerable as per Well Plan 012929'-1/13102'(TVD 3535')\Pump rate 570 gpm @ 3620 psi.\120 rpm @ 9-10K torque I WOB=5-15K\Up wt.=175K-Dn wt.=No data-Rot wt.=110K.\9.2 ppg mud wt.\ECD=11.27 ppg.\ADT=222 hrs.\Jars=36.57 hrs. 12.00 00-.00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable as per Well Plan(/13102'-V14595'(TVD 3541')\Pump rate 556 gpm @ 3720 psi.\120 rpm @ 11- 13K torque\WOB=6-15K\Up wt.=170K-Dn wt.=No data-Rot wt.=10510 9.2 ppg mud wt.\ECD=11.63 ppg.\ADT= 7.17 hrs\Jars=43.74 hrs.\MWD tool oil reservoir alarm for low level(50 cc).system is leaking oil while pumping and may fail(estimated 4-30 hrs).Consult with town to continue to drill ahead until failure. Total ADT=43.74 hrs. Total Jar=43.74 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Ong Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ong Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mat'l Coord. 907-670-8581 907-240-2712 Drilling Engineer Jason Bnnk Eni Petroleum Dng Eng. 907-865-3321 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(f1KB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 filf* Eni E&P Division . I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUW1:50-029-23431-00-00 2^rl II Date:12/7/2010 - Report#: 43 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 38.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 16,892.0 3,509.8 2,297.00 15.33 149.8 88.0 -9.8 Overcast,Light Fog 95°E @ 5.3 mph WC-22.4` Daily summary operation 24h Summary Drilling Rotary Steerable 614595.-5/16,892'as per Well plan\Maintain 9.2 ppg mud weight. Note TeleScope status word flagged low oil in its turbine assembly. This indicates possibility of tool failure. Operation at 07.00 Drilling Rotary Steerable @ 16,988'. 24h Forecast Drill rotary steerable to T/D as per well plan or MWD tool failure\Circulate bottoms-up+I-5x and back ream to the 9 5/8"csg.shoe. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00-DRILL E '3 P Drill Rotary Steerable as per Well Plan 614595'-1/15352'(ND 3521')\Pump rate 560 gpm @ 3660 psi./80-120 rpm @ 11- 14K torque\WOB=8-15K\Up wt.=180K-Dn wt.=No data-Rot wt.=108K\9.2 ppg mud wt.\ECD=11.71 ppg.\ADT= 8.02 hrs.\Jars=51.76 hrs. 12:00 00:00 12.00 24.00'DRILL E '3 P Drill Rotary Steerable as per Well Plan(/15352'-1/16892'(TVD 3509')\Pump rate 524 gpm @ 3740 psi./80-120 rpm @ 14- 16K torque\WOB=8-15K/Up wt.=190K-Dn wt.=No data-Rot wt.=11 OK.\9.2-n ppg mud wt./ECD=12.1 ppg.\ADT= 7.31 hrs.\Jars=59.07 hrs. Total ADT=59.07 hrs. Total Jar=59.07 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Frank Cormier Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mat'I Coord. 907-670-8581 907-240-2712 Drilling Engineer Jason Brink Eni Petroleum Ddg Eng. 907-865-3321 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division 'Well Name:0P17-02 rilliiil ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UW1:50-029-23431-00-00 2^ Date:12/8/2010 - Report#: 44 " I' page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name - Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore - Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27.680.00 220.88 125.3 39.81 Daily Information End Depth(RKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,200.0 3,522.8 1,308.00 13.59 96.2 88.0 -6.3 Overcast,WC-9.6" 80"E @ 1.6 mph Daily summary operation 24h Summary Drilling Rotary Steerable(/16892'-1118200'TD as per Well Plan\Maintain 9.2 ppg mud weight.\Circulate bosoms-up-rotate&reciprocate pipe-pull one stand every bottoms-up. Operation at 07.00 Continue circulating bottoms-up\pull one stand every bottoms-up/117715'-pump rate 531 gpm @ 3877 psi.\121 rpm @ 14k torque. 24h Forecast Circulate bottoms-up+5x or until clean(Pull one stand each bottoms-up)\Back ream to the 9 5/8"csg.shoe.\CBU\Displace well to VersaPro(OBM)solids free 9.2 ppg.\Continue POOH&L/D BHA. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 12.00' 12.00 DRILL 'E 3 P Drill Rotary Steerable as per Well Plan 1/16892'-1117190'(TVD 3509')\Pump rate 549 gpm @ 3920 psi./120 rpm @ 16- 18K torque\WOB=10-16K\Up wt.=195K-Dn wt.=No data-Rot wt.=105K./9.2 ppg mud wt.\ECD=11.64 ppg.\ADT= 7.8 hrs.\Jars=66.87 hrs. 12:00 21:30 9.50' 21.50 DRILL E 3 P Drill Rotary Steerable as per Well Plan(/17190'-5/18200'(TVD 3523')/Pump rate 521 gpm @ 3850 psi.\120 rpm @ 15-20K torque\WOB=8-10K\Up wt.=230K-Dn wt.=No data-Rot wt.=108K./9.2+ppg mud wt.\ECD=12.06 ppg./ADT=5.79 hrs./Jars=72.66 hrs.TD well @ 18.200' Total ADT=72.66 hrs. Total Jar=72.66 hrs 21 30 00:00 2.50' 24.00 DRILL •E 7 'P 'Circulate and condition mud\Reciprocate&rotate(/18200'-/1181091 Back reaming slovAy @ 500 gpm @ 3550 psi./120 rpm @ 13-14K torque/Reaming down,reduce to 200 gpm @ 1000 psi.\100 rpm @ 13-14K torque.Rack back one stand every bosoms-up\WEI CD system utilized on connection.ECD=11.79 ppg Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum 'Ddg Spvr. Enipetroleum.AK 907-670-8623 Dnlling @e n ipetro le u m.co m Dnlling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 D d tl i n g@ s n i p et ro le u m.c o m Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Caswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mat'I Coord. 907-670-8581 907-240-2712 Drilling Engineer Jason Brink Eni Petroleum DrIg Eng. 907-865-3321 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8.505.6 11/12/2010 Last Leakoff Test Depth(RKB) TVD(f1KB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 ffilli* Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • Date:12/9/2010 - Report#: 45 APIIUWI:50-029-23431-00-00 ti i II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 40.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,200.0 3,522.8 0.00 85.0 -6.3 Overcast,WC-9.6° 80°E @ 1.6 mph Daily summary operation 24h Summary Circulate bottoms-up-rotate&reciprocate pipe-pull one stand every bottoms-up(/18109-1/17420'.5 POOH back reaming 1/17420'-1/11121'\@ 4-8 minutes per stand.600 gpm @ 3500 psi.\120 rpm @ 9K torque.ECD @ 10.71 @ 11121' Operation at 07.00 POOH Back reaming @ 11010' 24h Forecast Back ream to 10985'increase in torque,ECD&sight pump pressure-RIH 1 11308'circulate clean and continue to back through shale section @ 11035'to 10930'S Continue Back reaming to 9 5/8"csg. shoe.\CBU/Displace well to VersaPro(OBM)solids free 9.2 ppg.\Cut drill line\Continue POOH&UD half of the 4.5"drill pipe and BHA. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase i Opr. Act. Plan Oper.Descr. 00-.00 08.30 8.50 8.50 DRILL E 7 P Circulate and condition mud-total of 8X\Reciprocate&rotate 1/18109'-1/17420'\Back reaming slowly pumping rate 535 gpm @ 3850 psi./120 rpm @ 14K torque\Rot Wt.=110K\Reaming down,reduce to 200 gpm @ 1000 psi.\100 rpm @ 12K torque.Rack back one stand every bottoms-up\WEI CD system utilized on connection.ECD=11.82 ppg.Monitor well f/10 mins.-static. 08.30 1200 3.50 12.00 DRILL E 4 P POOH-back reaming @ 4 min/std 1/17420-t/1643&/pumping 560 gym @ 3850 psi.\120 rpm @ 12K torque./Rot Wt.= 110K\WEI CD sub used on connection,sub(SN#235.09/STD#174)had trap pressure could not bleed off.ECD=11.54 ppg 12-00 00.00 12.00 24.00 DRILL .0 4 P Continue POOH-back reaming @ 4 min/std.1/16435-V11350'-decrease speed to 6-8 min/std(/11350'-V11121'pumping 600 gpm @ 3500 psi./120 rpm @ 7-8K torque./WEI CD sub(SN#165-07/STD#156&SN#99-06/STD#129)trap pressure couldn't bleed off.ECD=10.71 ppg. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Frank Cormier Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Caswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling •Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum •Mall Coord. 907-670-8581 907-240-2712 Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 1111* Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.lnc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2^„ Date:12/10/2010 - Report#: 46 II II II page 1 of 1 Wellbore name: OP17-02 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 41.81 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 18.200.0 3.522.8 0.00 89.0 -17.0 Overcast.WC-30.3° 196`SSW @ 5.2 mph Daily summary operation 24h Summary POOH back reaming f/11121'-1/8500'\Clean-up shale section f/11035'-1/10930'and dog leg @ 9778'\WEI CD sub while back reaming\Highest ECD=12.12 ppg.\Circulate clean @ 8467'\Cut dulling line while cleaning active pits\Bring on new solid free VersaPro(OBM)9.4 ppg-consult with town to lower weight to 9.2 ppg. Notified AOGCC(48 hrs.)of up coming BOP test on 12-11-2010 @ 1700 hrs.\Mr.Bob Noble returned call @ 2005 hrs.and waived witness of test.\will update Mr.Noble tomorrow. Operation at 07.00 Clean shakers&prep to UD 4.5"drill pipe. 24h Forecast Lower new solid free VersaPro(OBM)1/9.4-1/9.2 ppg in active system&Vac trucks. Displace well to VersaPro(OBM)@ 9.2 ppg.\Clean shakers\Continue POOH&L/D one half of the 4.5"drill pipe- rack the rest back in derrick\L/D BHA#6. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 30 1.50 1.50 DRILL E 4 P POOH-back reaming f/11121'-/10956'/600 gpm @ 3470 psi./120 rpm @ 7.5K torque.\Schlumberger logged 1/11.117'- 1/10990'@ 5'/min:ECD @ 10.7 ppg\Continue to back ream 1/10985'increase in parameters-torque @ 14K,ECD @ 11.8 ppg and 100+pump pressure.RIH 1/11211'with no problems./Work up 1/10977'&10956'Max.(ECD 12.12 ppg)\WEI CD sub while back reaming.\Consult with town.\RIH V11308'on elevators. 01:30 03.00 1.50 3.00 DRILL E 7 P Circulate bottoms-up 3X(clean)1 Rotate&reciprocate sting(/11308-V11210'pumping 600 gpm @ 3470 psi.\120 rpm @ 7.2K torque./slow pump 5/200 gpm on down stroke.1 Rot Wt.=115K/ECD=10.54 ppg.1 Check sample of cutting @ bottoms-up,80%sihstone&20%sand. 03:00 05.30 2.50 5.50 DRILL E 4 P POOH-back reaming @ 4-5 min/std.f/11318-5/10924'pumping 450 gpm @ 2100 psi./120 rpm @ 7.2K torque-with no problems.RIH f/10924'-V11121'on elevators with no problems-Dn w4=75k.\WEI CD system. 05.30 09:30 4.00 9.50 DRILL E -4 P POOH-back reaming(/11121'-V10000'1600 gym @ 3280 psi.\120 rpm @ 6.3K torque./Slow pump rate down to 450 gpm @ 2100 psi f/10000'-5/9740'@ dog leg section.\RIH U 10039'1 Dn wt.80K with no problems.\WEI CD system. 09.30 16:00 6.50 16.00 DRILL E 4 P Back ream f/10039'-V9700'pumping 550 gpm @ 2730 psi./120rpm @ 6.2K torque.\Continue back reaming 1/9700'- 58500'increased to 600 gpm©3000 psi./120 rpm @ 5-6k torque\Rot wt.=98K\Mud w4.=9.2 ppg\ECD @ 10.08 ppg.\ WEI CD system. 16.00 16:30 0.50 16.50 DRILL E 4 P L/D 3 jts.4"drill pipe 1/8467'\Up wt.=130K\Dn wt.=85K 16.30 18:30 2.00 18.50 DRILL E 7 P Circulate bottoms-up until clean/Reciprocate&rotate 1600 gpm @ 2900 psi.\75 rpm @ 4k torque. 48 hrs.Notice to AOGCC of up-coming BOP test due on 12-12-2010 18.30 20:00 1.50 20.00 DRILL E 25 P Cut drilling line.\Service rig\Cleaning active pits./Bob Noble with AOOGC returned call @ 2005 hrs.and waived witness of BOPE test. 2000 21:30 1.50 21.50 DRILL E 1 P Finish cleaning active pits for solids free VersaPro OBM mud 21 30 00:00 2.50 24.00 DRILL E 1 P Bring on solid free VersaPro OBM into pits,found weight to be 9.4 ppg\Consult with town to reduce to 9.2 ppg\Add LVT to system,move Vac trucks to add LVT to same. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Such Bowe Eni Petroleum Mall Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 614.0 1111* Eni E&P Division .. I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2�, Date:12/11/2010 - Report#: 47 I' II page 1 of 1 Wellbore name: OP17-02 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase •Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 42.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18.200.0 3,522.8 0.00 91.0 -18.4 Overcast,WC-24.3' 161°SSE @ 2 mph Daily summary operation 24h Summary Finished lowering new VersaPro OEM 1/9.4-1/9.2 ppg in active pits&Vac-spot Vac trucks back in place to displace well.\Displace well to VersaPro OBM.\Clean possum belly&shaker of old mud.\ POOH UD 126 jts.of 4 1/2"drill pipe\Rack back 42 stands of 4 1/2"DP\UD BHA#6\Test BOPE. Operation at 07.00 Finish testing 4 1/2"tbg.in BOP. 24h Forecast Finish testing ROPE to AOGCC specification of Sundry\Replace off driller's side draw-works brake band while testing BOPE 1 PJSM-R/U GBR equipment to run 5 1/2"liner.\P/U and run 5 1/2"liner- record data points as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 1 U Lower new VersaPro OBM solid free mud f/9.4-t19.2 ppg in active with LVT-move Vac trucks with the remaining 9.4 gpm to take on LVT to lower weight to 9.2 ppg\Re-spot Vac trucks to bring.\Held PJSM to displace. 0230 03:30 1.00 3.50 DRILL E 7 P Displace well to VersaPro OBM(solid free)@ 9.2 ppg pumping 436 gpm @ 1790 psi.\Rotate and reciprocate 80 rpm @ 4- 6K torque Rot wt.=103K\Record parameters before 8 after increase in torque(2K)&weight(3K). 03.30 05:00 1.50 5.00 DRILL E 1 'P Clean troughs,shakers,return fowls pits&trip tank of old OBM. 05.00 12:00 7.00 12.00 DRILL E 4 P POOH UD 4 1/2"drill pipe f/8467'-04470'. 12.00 16:00 4.00 16.00 DRILL E '4 'P POOH with 4 1/2"DP f/4470'-0473'to HWDP. 16.00 19.00 3.00 19.00 DRILL E 4 P L/D 8 joints of HWDP&jars\Held PJSM&UD Schlumberger tool sting-remove radioactive source\Down load data from tools\Load out on truck. 19.00 20.00 1.00 20.00 DRILL E 12 P P/U 5 1/2"csg test joint-pull wear bushing,drain stack./Install test plug and flood stack w/water 20.00 21:00 1.00 21.00 DRILL E 25 U Downtime time:Test pump would not work correctly-mechanic found obstruction in the fluid end. 21 00 0000 3.00 24.00 DRILL E 12 'P Test BOP equipment to AOGCC requirements\5 1/2"test joint on annular low 250/high 2500 psi.\Rams,choke manifold, floor&TD valves to low 250/high 3500 psi.\Bob Noble waived witness of test 2005 hrs.on 11-11-2010.\Prep to replace off driller's side brake band. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener En:Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 DnIling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 DnIling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enlpetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.corn 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Sach Bowe Eni Petroleum .Mall Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 • I, Eni E&P Division I Well Name:OP17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUWI:50-029-23431-00-00 2 Date:12/12/2010 - Report#: 48 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27.680.00 220.88 125.3 43.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB _ - Temperature(°F) Weather Wind 18,200.0 3,522.8 0.00 92.0 4.8 Overcast,Light 339`NNW@ 20.4 Snow,WC-15.9' mph Daily summary operation 24h Summary Test BOP with 5 1/2"&4 1/2"tubular to AOGCC Sundry specification.)R/D test equipment and set wear ring.)RIU GBR equipment&P/U 5 1/2"liner f/surface-541721 Torque to 10K(problems reaching desire torque with out damage tubular-Nabors coming out with different dies and two set of tongs)\Install different heads/dies&stage torque up 512.5-13K.)Service pipe skate. Operation at 07.00 P/U 5 1/2",179,L-80 Liner(Hydril 521)55921' 24h Forecast P/U and run 5 1/2"liner-GBR torque turn(17K by 6000')-record down weights.)P/U BOT SLZXP record parameters as required.)RIH with 5"DP to 18040'and set SLZXP liner hanger/packer.)POOH L/D 5"DP and WEI CD subs Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.20 Time Log StartEnd Cum (h Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50 5.50 DRILL E 12 P Test BOP equipment to AOGCC requirements.)5 1/2"-Rams,choke manifold,TD valve to low 250/high 3500 psi.)Switch O to 4 1/2"tubular,test annular 1ow250/high 2500 psi.)Rams Iow250/high 3500 psi.)Blind rams to low 250/high 3500 psi.) Perform accumulate test.)Bob Noble waived witness of test.)Change out off driller's side brake band to new while testing. //" 5 05:30 07:30 - 2.00' 7.50 DRILL E 12 P R/D test equipment&UD test joint)Install wear bushing.)Blow down choke&TD. Is' 07:30 11:00 3.50 11.00 DRILL G 1 P R/U GBR tongs and torque tum equipment.)M/U 5 1/2"safety joint with TIW valve&stage in pipe shed. 11:00 19:30 8.50 19.50 DRILL G 4 P P/U 5 1/2".17#.L-80 Liner(Hydril 521)f/surface-t/2700')Torque tum connection 510-11K torque.)Dn wt.74K. 19:30 20:00 '' 0.50 20.00 DRILL G 25 P 'Service pipe skate&TD. 20:00 22:00 2.00 22.00 DRILL G 4 P P/U 5 1/2",17#.L-80 liner(Hydril 521)52700'53800'1 Torque tum connection 5 12.5K torque.\On wt.82K. 22:00 22:30 0.50 22.50 DRILL G 25 U Install Nabors heads with more die contact on tubular and repair linkage on tong control levels(Broke).\Re-calibrate GBR torque tum system. 22:30 00:00 1.50' 24.00 DRILL G 4 P P/U 5 1/2",179,L-80 liner(Hydril 521)f/3800'-54170'\Torque tam connection 5 12.5-K torque.\Dn wt.80K. Daily Contacts Position Contact Name Company Title E-mail - Office Mobile Drilling Supt. Jack Keener Eni Petroleum .DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 'eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 1111* * Eni E&P Division Ewen Name:o n-oz ENI Petroleum Co.Inc. Daily Re r 0 ft Well Code:25097 Field Name:Nikaitchuq • Date:12/1312010 - Report#: 49 APIIUWI:50-029-23431-00-00 2" "g page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(°) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 44.81 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(`F) Weather Wind 18,200.0 3,522.8 0.00 92.0 -9.9 Blowing Snow.WC- 196°SSW @ 12.9 30.6" mph Daily summary operation 24h Summary P/U 5 1/2" 17#L-80 Liner(/4172'-07424'-torque to 17K1 Damage two joints,tongs dies broke.I R/D GBR equipment&R/U Nabors Casing I Continue P/U 5 1/2"liner 1/7424'-09795'(reduce make torque to 12K).1 P/U SLZXP liner hanger/packer.\RIH on 5"DP(/9795'-1/13632'-Rotated(/13280'-1/13435'\Friction factor 0.30 while RIH and 0.18 rotating. Operation at 07.00 RIH 5 1/2'liner on 5"DP rotating 50 rpm @ 10-11K torque @ 150103 Started rotating stnng @ 14714'continuous. 24h Forecast RIH with 5"DP to set depth @ 18040'\Set SLZXP hanger/packer as per well plan./Test packer to 1500 psi.f/10 mins.(chart).\POOH L/D 5"DP and WEI CD subs. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 08.00 8.00 8.00 DRILL G 4 P P/U 5 1/2".17#,L-80 liner(Hydril 521)f/4170'-1/74243 GBR torque tum connection stage up to V17K torque by 5761'1 Dn wt.80K 1 Tong die broke and egg/gouged tubular on Jt.0 178 L/D\Reduce torque to 16.5K @ 73843 Second tong die broke-damaged Jt.#180 L/D same. 08:00 11:30 3.50 11.50 DRILL G 5 U R/D GBR tongs on floor./P/U&R/U Nabors Casing tongs&torque-turn equipment-calibrate tongs. 11:30 17:00 5.50 17.00 DRILL G 4 P P/U 5 1/2",17#,L-80 liner(Hydril 521)(/7424'-1/9746'\Nabors Casing torque-tum connection 1/12K torque @ 7424'(Consult with town)\Dn wt.72K\Ran 178 Tesco(5 1/2"x 7")Hydroform and 45 Weatherford(5 1/2"x 7")Lotorq centralizers. 17.00 1800 1.00 18.00 DRILL G 4 P P/U BOT SLZXP Liner hanger/packer-M/U to 5 1/2"liner\Fill liner wf'pal mix"and let setup for 30 mins.\Total length with setting tool 9795.41'. 18.00 00'00 6.00 24.00 DRILL G 4 P RIH with 5 1/2",17#,L-80 liner(Hydnl 521)on 5"drill pipe 1/9795'.1/136323 Establish parameters @ 9892',Up wt..125K- Dn wt.=65K-Rot wt.95K 120 rpm @ 4.4K torque-30 rpm @ 4.6K-40 rpm @ 4.9K torque levels.RIH on elevators with no problems 1/13280'.\Dn wt.65K I Rotated section(/13280'-1/13435'\40 rpm @ 7.5k torque to 13337'&increased to 60 rpm @ 8.5K torque to 13435'\Continue RIH(/13435'-V13632'on elevators.Up W.150K-Dn wt.60K-Rot wt.=105K. Friction factor 0.30 while RIH and with rotating 0.18. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum +Ddg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 DnIling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Dug Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Cnswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 filli* Eni E&P Division (Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • 2^ Date:12/14/2010 - Report 4: 50 APIIUWI:50-029-23431-00-00 I' II In I page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00, 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 45.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,200.0 3,522.8 0.00 90.0 -0.6 Cloudy,WC-11.9° 258°WSW @ 5.6 mph Daily summary operation 24h Summary RIH with 5 1/2"17#L-80 Liner&BOT SLZXP hanger(/13632'-t/14606'on elevators.\Rotated section(/13660'-U13730'\Continuously rotation(/14606'-t/18040'\60 rpm @ 15.2K torque final parameters. Operation at 07.00 The liner/hanger has been set and tested. POOH L/D 5"DP and WEI CD subs. 24h Forecast Set SLZXP Liner hanger/packer.\Test packer to 1500 psi f/10 mins./HRD running tool released from SLZXP hanger.\POOH L/D 5"DP and WEI CD subs. Lithology Shows MAASP Pressure(psi) Mud Weight(11)/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL G 4 P RIH with 5 1/2",176.L-80 liner(Hydril 521)on 5"drill pipe f/13632'-1/14606'on elevators with no problems./Rotated section(/13660'-1/137301 40 rpm @ 9-11K torque.RIH friction factor @ 0.30 and rotating @ 0.20\Fill every 10 stands. 01:30 15:00 13.50 15.00 DRILL G 4 P Rotate 5 1/2",176.L-80 liner(Hydril 521)on 5"drill pipe 1/14606'-1/18040'/40 rpm @ 9-11K torque.Increase to 60 rpm @ 10-11K torque @ 15240'/WOB=8-10K/Rotating FF @ 0.23\Fill every other stand&break circulate./Final parameters 60 uG rpm @ 15.2K torque./Rot wt.=105K. 15:00 22.00 7.00 22.00 DRILL G 7 U Drop 1.75 ball to set SLZXP liner hanger/packer./Circulating 2 drill pipe volumes with a rate of 84 gpm @ 180 psi.-ball would not seat to set./Increased rate V168 gpm @ 650 psi.2+drill pipe volume./Fluctuate pump pressure f/250-600 psi./ Rotated 10 revolutions with 15.2K torque and pumping 84 gpm @ 180 psi./Rotated 25 revolutions with 15.2K torque and pumping 84 gpm @ 189 psi.no success.\Increase rate to 294 gpm @ 1550 psi.1/3 drill pipe volume with no success./ Mud wt.=9.2 ppg./Consult with town on options./Mix-up 50 bbl Hi-vis sweep./Call for a 5"pipe(4.95"OD)Halliburton pipe wiper ball. 22:00 23:00 1.00 23.00 DRILL G 7 U Pumped 30 bbls.Hi-vis sweep(120 vis)-9.2 ppg./Pump rate 165 gpm @ 620 psi.1.25 drill pipe volumes./With no success. 23.00 00:00 1.00 24.00 DRILL G 7 U Pumped 20 bbls.Hi-vis sweep(120 vis)-9.2 ppg./Shut down and put 5"Halliburton pipe wiper./Pump rate @ 125 gpm @ 380 psi./Saw pressure increase U1150 psi with 3/4 drill pipe volume pumped(6101'pipe depth)-Bleed down and continue to pump 84 gpm @ 610psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Diilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipelroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Sach Bowe Eni Petroleum Mat'l Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,550.0 OEM Versapro 8.40 814.0 l Eni E&P Division Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq � APIIUWI:50-029-23431-00-00 2^ Date:12/15/2010 - Report#: 51 II 'I page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 46.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 18,200.0 3,522.8 0.00 87.0 -7.8 Partly Cloudy.WC- 178"S @ 6.4 mph 21.6" Daily summary operation 24h Summary Set 5 1/2"Liner shoe @ 18030'(10'high from plan-due to troubles setting SLZXP hanger/packer-0 Top liner @ 8245'1 Test liner packer V1500 psi for 10 mins./Circulate bottoms-up to remove Hi-vis pill.\ POOH UD 5"DP and WEI CD subs.f/f/8170'-1/73803 Service TD-tighten bolts on guard./Continue POOH UD 5"DP&WEI CD subs./fn380'-6HRD.1L/D HRD tool-recovered two 1.75"balls(No 5" HOWCO foam ball).\RIH w/4 1/2"DP V2000'. Operation at 07.00 POOH UD 4 1/2"DP./Vac out OBM at rig floor&pipe shed(ran wiper through tubular). 24h Forecast POOH UD 4 1/2"DP./Pull wear bushing./R/U Centrilift.GBR&Halliburton equipment on floor./Hold PJSM to run ESP completion assembly.\P/U ESP completion assembly. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL G 7 U Continue pumping 20 bbls.Hi-vis sweep(120 vis)-9.2 ppg.\Being chased with 5"Halliburton pipe viper(4.95"OD).\ Pump rate @ 84 gpm @ 600 psi./Encountered second pressure increase 1/992 psi.with 83%drill pipe volume pumped (6881'pipe depth-tool joint @ 6888')-pressure dropped down and continue to pump 90 gpm @ 580 psi.until 100%drill pipe volume pumped./increased rate 6165 gpm @ 685 psi.with no pressure spikes./Reduce to 84 gpm @ 235 psi.with total 125%drill pipe pumped. 0030 01:00 0.50 1.00 DRILL G 4 U Rotate string 1/18040'-5/180601 L/D WEI CD sub from stand./Drop second Baker 1.75 ball and put larger 7"Halliburton Foam Wiper Ball(6.89"OD)./M/U Top Drive and pull back to 18040'setting depth.(The 7"HOWCO wiper will wipe 5.5"to 1.375"and elongates under pressure and would have passed thru the 2.45"nipple above of the packer ball catcher). 01 00 02.00 1.00 2.00 DRILL G 7 U Pumped 1.5 bbls and pressure increased to 2076 psi.&stayed-bleed off pressure./POOH(/18040'-1/179653 Up wt.=190 -200K./Break connection&TD-Drained stand,seemed to have a lot more fluid volume than normal.Halliburton Foam Ball @ top of WEI CD sub(Second Baker 1.75 ball still in doll string).Halliburton foam ball was removed and connection made back-up to WEI CD sub.Rotate string back down to setting depth with 40 rpm @ 14-16K torque./Rot wt.=105K/WOB= 2K./Top Drive stalled @ 17.6K torque @ 180303 Back out torque from string./Movement of string may have dislodged Baker 1"ball or fall down on seat./P/U to 215K-slacked off to 50K-P/U to 220K-Slack off to 174K/Pressure up to 1900 psi.-3000 psi.-continue to 4000 psi.-pressure bleed down to 462 psi.in 5.5 mins.The 5 1/2"liner shoe @ 18030'and the top of the liner @ 8245'. 02.00 02:30 0.50 2.50 DRILL E 7 P Slack off to 60K/Closed annular to test liner packer-pressure up to 1500 psi and held for 10 mins.+(chart record)./Bleed 1 off pressure and blow down kill line./P/U V 8235'with HRD @ 150K to confirm free from liner./Rotate dog sub out and 1 0"od went through additional procedure measures to ensure SLZXP was set for confirmation on tool./Rack back one stand V 8170'. 02:30 03:30 1.00 3.50 DRILL E 7 P Circulated bottoms-up to remove Hi-vis from well bore./Stage pump rate to 380 gpm @ 850 psi. 0330 06:00 2.50 6.00 DRILL E 4 P POOH 1/8170'-(/7380'/L/D 5"drill pipe and WEI CD subs with Rep./Vac out pipe at rig floor and ran wiper through tubular in pipe shed. 06.00 07:00 1.00 7.00 DRILL E 25 P Service Top Drive-Bolts on traction motor guard was loose-tighten&reinstall save wire. 07:00 22:00 15.00 22.00 DRILL E 4 P Continue POOH-UD 5"drill pipe and WEI CD subs with Rep-f/7380'-V Baker HRD tool./Vac out pipe on ng floor and run wiper through tubular in pipe shed. 22:00 22:30 0.50 22.50 DRILL E 4 P L/D HRD and inspected.\Recovered two 1.75"ball from HRD,which one was broke in half with indication of deep wash areas and scares on ball.Halliburton Foam Wiper Ball(5")was not recovered from HRD tool.Tale tail on rotating dogs indicated weight was applied SLZXP for confirmation of setting procedure. 2230 0000 1.50 24.00 DRILL E 4 P RIH with 4 1/2"drill pipe with mule shoe(/2000'1 Up wt.=105k-Dn wt.=65k. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 907-715-6434 DnIling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 907-632-3058 Dolling@enipetrole u m.com En:representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Push Bruce.Simonson@Nabors.com 907-670-8539 Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(11KB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 01111411i1 Eni E&P Division 'Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2^ Date:12/16/2010 - Report#: 52 II II il page 1 of 1 Wellbore name. OP17-02 Well Header Permit/Concession N° Operator ENI Share(Vol Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 47.81 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,200.0 3,522.8 0.00 870 -14.3 Partly Cloudy.WC- 167°SSE @ 7.6 31' mph Daily summary operation 24h Summary RIH w/4 1/2"DP 84000'\Change over to 5"-RIH f/4000'-1/6101'1 Service rig\POOH L/D 5"and 4 1/2"drill pipe-Vac out OBM from pipe Operation at 07.00 Working on completion AFE#4641 24h Forecast Switch to Completion AFE#4641 @ 1200 hrs.for ESP Completion Assembly. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 03:00 3.00 3.00"DRILL E 4 P 'RIH with 4 1/2"drill pipe f/2000'-1/4000'1 Change to 5"handling equipment RIH with 5"drill pipe f/4000'-8 6101'1 L/D WEI CD sub\Up wt=80K-Dn wt.=105k. 0300 04:00 100 4.00 DRILL E 25P Service rig-draw-works and rough neck(tighten heads on iron rough neck)-check the efficiency of#3 mud pump-250 gpm @ 140 psi.(180 psi.difference from#2 mud pump.) 04.00 12.00 8.00 12.00'DRILL E 4 P •POOH-L/D 5"doll pipe and WEI CD subs with Rep.-(/6101'-84000'1 Change out to 4 1/2"handing equipment-continue POOH f/4000'-8 surface-L/D mule shoe.Vac out pipe on ng floor and run wiper through tubular in pipe shed. CHANGED WELL FROM DRILLING TO COMPLETION AT 1200 HOURS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Dulling Supt. Jack Keener Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Dolling Supt. David Smith Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-8581 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams©Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 liff* Eni E&P Division 'Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • 2^n Date:12/16/2010 - Report#: 1 II API/UW:50-029-23431-00-00 If II page 1 of 1 Wellbore name:,0P17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 COMPLETION 48.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 87.0 -14.3 Partly Cloudy.WC- 167`SSE @ 7.6 31" mph Daily summary operation 24h Summary Pull wear bushing/Clean&clear floor equipment\Load floor with Centrilift&R/U GBR-hang ESP&control sheaves in derrick(string with cable&line)\P/U TTC-XO,one joint of 4 1/2"tbg,DGU&XO\ Set pump.pack off&pressure test tool./Test to 1000 psi 8/15 mins./Pull test tool&set tbg.stop.\R/D Halliburton. Operation at 07.00 P/U Centrilift ESP assembly as per Well plan. 24h Forecast Switch to Completion AFE#4641 @ 1200 hrs.P/U ESP Completion Assembly and 4 1/2"tbg.(12.68 L-80 IBTM). Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 15:00 3.00 3.00 DRILL K 1 P Switched to completion AFE#4641-Pull wear bushing with Vetco Gray Rep.\Clean floor and clear of all 4 1/2"drill pipe equipment.\Prep to P/U ESP completion assembly. 15:00 19:00 4.00 7.00 DRILL K 5 P ,Load ng floor with equipment and tools-Centrilift&R/U GBR tongs./Hang ESP cable and control line sheaves in derrick, run lines through sheaves to rig floor./Spot Halliburton slick line trucks.\Held PJM for ESP completion. 19:00 20:30 1.50 8.50 DRILL K 4 P P/U&M/U TTC XO-joint of 4 1/2"tbg.-Discharge Sub with XO to torque spec. 20.30 00:00 3.50 12.00'DRILL K 1 P Hang Halliburton slick line sheave in blocks-run pump assembly on GS tool into TTC-tubing pack-off assembly\Set pressure test tool-test to 1000 psi f/15 mins.(chart record)/Pull pressure test tool&run tubing stop./R/D Halliburton. Daily Contacts Position Contact Name Company Title - E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Di-1g Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith •Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 / eum.com II Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-1226 Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib(gal) P Surf Applied(psi) Eq.Mud Weight(Ib(gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUWI:50-029-23431-00-00 2^n Date:12/17/2010 - Report#: 2 II Ii ii page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) _ - RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth)ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(11/hr) DFS(days) OP17-02 COMPLETION 49.00 Daily Information End Depth(f1KB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 0.0 88.0 -19.7 Partly Cloudy.WC- 161'SSE @ 0.0 19.7' mph Daily summary operation 24h Summary Make up ESP downhole pump assembly,integrity test same,test TEC line,test DGU,splice mle cable&test same,run 4.5"#12.6 ppf L-80 tubing to 6055"performing continuity checks every 1000' Operation at 07.00 Cont.Run in hole with ESP Completion on 4.5"#12.6 ppf L-80 Tubing,perform continuity checks every 1000' 24h Forecast Make up ESP downhole pump assembly,integrity test same,test TEC line,test DGU,splice mle cable&test same,run 4.5"#12.6 ppf L-80 tubing and perform continuity test every 1000' Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 08:00 8.00 8.00 COMP K 4 P Completion-Run ESP downhole pump,stand back in derrick w/3 pups,x-o,pressure discharge sub,x-o,1 jt.4 1/2"tubing. Pick up TTC cross-over w/screen intake,p/u upper&lower tandem seal sections,Motor centralizer,m/u same.Check rotation,fill w/oil,install pothead pigtail&1/4"TEC line,plug in MLE Umotor and perform electrical integrity test-ok.Cross- over coupling chipped when lowering TTC onto upper tandem seal section,test&connect 1/4"TEC line to pressure discharge sub,replaced it.LID 3 handling pups,p/u jt.#2,pups,x-o,pressure discharge sub,x-o.Installed 2-562 motor clamps.4-515 clamps,4-4500 MLE clamps,1-4500 half clamp.3-Christolizer clamps.2-S5 Bands. 0800 11:00 3.00 11.00 COMP K 12 P Completion-Run ESP downhole pump,splice MLE cable to ESP cable.and control line from 1/4"to 3/8",test cable-ok. 11.00 12:00 1.00 12.00 COMP K -4 P Completion-Run ESP downhole pump,run in hole with 4.5"#12.6 ppf L-80 IBTM Tubing from 141'to 384'average torque / @1800 ft/lbs.Average fluid losses from well bore at 1.25 bbls per hour(15 bbls for 12 hour shift). ,- 12.00 00.00 12.00- 24.00 COMP K '4 P 'Completion-Run ESP downhole pump,run in hole with 4.5"#12.6 ppf L-80 IBTM tubing from 384'to 6055'performing /continuity checks every 1000' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum 'Ddg Spvr. Enipetroleum.AK '907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. Scott Beauchamp Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Sach Bowe Eni Petroleum Matt Coord. 907-670-1226 Eni representative Jack Potter Eni Petroleum HOE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak OH Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 11191* Eni E&P Division (Well Name:OP17-D2 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • 2^„i Date:12/18/2010 - Report#: 3 APIIUWI:50-029-23431-00-00 II II ipage 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° /Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 COMPLETION 50.00 Daily Information End Depth(fiKB) End Depth(TVD)(1...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 87.0 -9.0 Mostly Cloudy,WC- 46"NE @ 8.4 mph 26.5` Daily summary operation 24h Summary Finish landing out hanger.run in lock down screws,test upper/lower hanger seals to 5k-10 minutes ok.Set BPV,nipple down bope stack&nipple up tree,lubricate out BPV,lubricate in 2WC and attempt to test hanger void with no success.Nipple down tree and change out NPT fitting,nipple up tree&test hanger void to 5000 psi for 10 minutes-ok. Operation at 07.00 Cleaning pits and prep for RDMO 24h Forecast Lubricate out 2WC,Rig up HP hoses from hotoil truck to tubing,LA to choke line.test all lines to 3000 psi.Hold PJSM and pump diesel down tubing&shear out disc in GLM,pump 177 bbls diesel down tubing taking returns up through I.A.through choke manifold to pits maintaining 1 1 retums.shut in welt blow down&ng down hoses,rinse&clean sf-obm from displacement from pits,prepare to rig down&move off#0P17-02. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 03:00 + 3.00 3.00 COMP K 4 P Cont.trip in hole with TTC-ESP Completion on 4.5"#12.6 ppf L-80 IBTm tubing from 6055'to 7766'with ESP&control lines,installing clamps. 03.00 04:30 1.50 4.50 COMP K 4 P Pick up&make up x-over,handling pup jt.2 each 4.5"x 5.5"VIT Tbg.Jts.Torque to 5k optimum.make up Vetco Gray landing joint on VG hanger with pup jt.and make up same&orient. 04.30 06:00 1.50 6.00 COMP K 5 P Vetco Gray&Centrilift install Penetrator in hanger.continuity check&make connector splice.Install in-line check valve on injection line below hanger. 06.00 09.00 3.00 9.00 COMP K 4 P Drain and rinse BOPE stack,land out hanger,run in lock down screws,test upper/lower hanger seals to 5000 psi for 10 minutes-ok,back-out landing joint and lay down same.Install BPV with T-Bar.Clean doll floor. 09.00 12.00 3.00 12.00 COMP K 5 P PJSM-Clean out and rig down catch can assembly.nipple down hope. 12.00 17.00 5.00 17.00 COMP K 5 P Cont.nipple down BOPE.choke&kill lines,mud lines to pumps,pull bell nipple&remove flow line,pick up BOPE stack ✓ and set back on stump.Remove VG riser. 17-00 21 00 4.00 21.00 COMP K 5 P PJSM-Centnlift perform continuity test-ok,perform phase to phase&phase to ground tests-ok.Nipple up tree.valves,flow cross,choke in well bay,pick up and make up VG lubricator and retrieve BPV.Lubricate in 2WC and attempt to test hanger void to 5000 psi with no success.Leaking off. 21 00 22.00 1.00 22.00 COMP K 5 U Nipple down tree and change out NPT fitting that was leaking. 22.00 00.00 2.00 24.00 COMP K 5 P Nipple up tree and retest hanger void to 5000 psi for 10 minutes-ok. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. Scott Beauchamp Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Sach Boise Eni Petroleum Marl Coord. 907-670-1226 Eni representative Jack Potter Eni Petroleum HSE Jack.Poner@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(fiKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 1 Eni E&P Division I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • 2^ Date:12/19/2010 - Report#: 4 APIIUWI 50-029-23431-00-00 II II page 1 of 1 Wellbore name: OP17-02 Well pleader Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(it) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 COMPLETION 51.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 88.0 -15.0 Mostly Cloudy,WC- 48 NE @ 5.2 mph 19" Daily summary operation 24h Summary Nipple up Tree&test to 5000 psi for 10 minutes-OK.Rig up to tree LRS to tubing&I.A.to choke,attempt to shear disc in GLM wino success,rig up Halliburton slickline&RIH to 2557'and work catcher, retrieve valve in GLM,POOH&r/d Hall.r/u and freeze protect Tbg.&I.A.r/d lines,clean pits&r/d prep rig for move.RIG RELEASED @MIDNIGHT 24.00 HRS. Operation at 07.00 RDMO from#OP17-02 to#OP03-05 24h Forecast RDMO from#OP17-02 to#OP03-05 Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 COMP C 5 P Test tree to 5000 PSI for 10 minutes on chart recorder-OK.Rig down testing equipment. 01:30 03:30 2.00 3.50 COMP C 5 P Nipple up Hero valve to top of tree per Vetco.Make up HP hose from choke to I.A.rig up LRS to Tubing on tree. 03:30 04:00 0,50 4.00 COMP K 9 P Hold PJSM with ng crew and LRS to test lines&pump diesel down tubing&shear out disc in GLM,displace tubing&I.A. from GLM to surface. 04:00 08:00 4.00 8.00 COMP K 9 U LRS test lines to 3000 PSI-OK,attempt to pump diesel down tubing to shear-out disc in GLM with no success.Pressure up tubing to 3500 PSI numerous times with no success of shearing out disc in GLM.Discuss with town to rig down LRS&rig up Halliburton slickline to go in and retrieve valve from GLM. 08:00 08:30 0.50 8,50 COMP R 1 U PJSM with Rig crew and Halliburton,ng up slickline tools. 08:30 12:00 3.50 12.00 COMP R 1 U Remove Vetco hero valve from tree,pick up and make up Halliburton spacer spool,slickline BOP,shieves,lubricator and downhole tools.Pressure test lines&lubricator to 500 psi with LRS-OK. 12:00 15:00 3.00 15,00 COMP R 4 U Halliburton slickline RIH and set catcher,pull valve from GLM,POOH with slickline&valve. / 15:00 18:00 3.00 18.00 COMP R 5 U Rig down Halliburton slickline lubricator,BOP,Vetco Gray remove 7"Otis flange,put test flange back on Vetco hero valve. 1// 18:00 20:00 2.00 20,00 COMP K 9 P Hold PJSM with Rig crew and LRS,ng up lines and test to 3000 PSI-OK.LRS Freeze Protect pump diesel down tubing taking returns up through I.A.to choke.LRS pump 179 bbls diesel at 1.75 BPM with 600 PSI until clean diesel back to surface,maintaining BHP and 1:1 retums through-out pump job.LRS shut down pump=Tubing PSI @200 I.A.PSI @200,O.A.PSI @200 20'00 21:00 1,00 21,00 COMP K 9 P Blow down lines and rig down same LRS,left choke manifold packed with diesel freeze protect. 21 00 00:00 3,00 24,00 COMP A 2 P Clean out mud system,clean last pits#6&#7,prepare pad for ng move,fill ecd manifold with diesel freeze protect with WEI Reps.Function rig jacks,clean well bay,blow down water lines in modules,move well bay equipment to next well,rig down flowline&choke line,blow down water lines on ng floor.RIG RELEASED AT 24.00 HOURS Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Dolling Supt. Scott Beauchamp Eni Petroleum Drlg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum,AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Sach Bowe Eni Petroleum Mall Coord. 907-670-1226 Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Eni representative i Mike Seward Eni Petroleum Proj Advisor 907-670-8581 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L80 8,245.6 18,030.0 12/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division I Well Name:0P17-02 ft* ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUW1:50-029-23431-00-00 2 If II�, Date:11/18/2010 - Report#: 24 page 1 of 1 Wellbore name OP17-02 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 19.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,460.0 3,554.3 940.00 3.57 263.3 88.0 12.4 Cloudy,WC 7' 189`5 @ 3.1 mph Daily summary operation 24h Summary Displace to VersaPro OBM as per Mud Engineer./Clean LSND mud from trough to pit#7,Waiting on weather(Phase 3-ENI Security reduce to Phase 1 @ 0535 hrs.)\Drill shoe track&cement 1/8418'- 58520'\Drill 30'new hole f/8520'-88550'\CBU for LOT/POOH 88550'-1/8412'\Perform LOT to 12.80 ppg EMW\RIH`/8412'-1/8550'\Drill ahead rotary steerable as per Schlumberger&ENI well plan 1/8550'-89040'. Operation at 07.00 Drilling ahead as per Schlumberger&well plan\Using WEI CD system during connection\Pre-treat mud&monitor for losses. 24h Forecast Drill production interval as per Schlumberger&ENI well plan f19040'to TD. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 7 P Displace from LSND(9.1 ppg)to VersaPro OBM(8.4 ppg)as per Mud Engineer 290 gpm @ 630 psi.\Reciprocate pipe.\ Up wt.=160K-Dn w1=.80K. 01:30 06:00 4.50 6.00 DRILL E 1 P Clean trough,possum bellies,under shakers and ditch going to pits of LSND mud,also Pit#7\Weather conditions-Phase 3 were drop to Phase 1 to KOC @ 0535 hrs,by ENI.Security. 06.00 11.30 5.50 11.50 DRILL E 3 P Drill float equipment 8 cement 1/8418'-88520'\Tag float collar @ 8418'and top of shoe @ 8503'\pump rate 500 gpm @ 1690 psi.\40 rpm @ 4.4-6.5K torque\WOB=6K\Up wt.=140K-On wt.=80K-Rot wt.=110K.\8.5 ppg mud wt.\ECD= 9.4 ppg. 11 30 13:00 1.50 13.00 DRILL E 7 P Drill f/8520'-88550'(TVD 3555')-30'new hole.\650 gpm @ 2600 psi.\50-60 rpm @ 5-7.5K torque\WOB=8K\Up wt.= 140K-Dn wt.=85K-Rot wt.=110K.\8.4 ppg mud wt.\ECD=9.8 ppg.\ADT=0.6 hrs.\Jars=104.5 hrs. 13.00 14:00 1.00 14.00 DRILL E 7 P Circulate and condition mud for LOT\650 pgm @ 2600 psi.\50 rpm @ 4.6K torque\Reciprocate&rotate\Monitor well. 14.00 14.30 0.50 14.50 DRILL E 4 P POOH f/8550'-88412'-blow down&R/U head pin for LOT. 14.30 -16.00 1.50 16.00 DRILL E 19 P Perform LOT test as per ENI procedure-LOT 12.8 ppg EMW-mud weight @ 8.4 ppg with 814 psi.pressure. 16.00 16.30 0.50 16.50 DRILL E 25 P Service Rig-Top Drive 16.30 17.00 0.50 17.00 DRILL E 25 TR04 Rig Down Time-Replace hydraulic motor for pipe handler gear box. 17.00 1800 1.00 18.00 DRILL E 4 P RIH(/8412'-88550'\Circulating-Schlumberger down link data to Xceed before drilling ahead. 18.00 00.00 6.00 24.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan(/8550'-89040'(TVD 3557')as per Schlumberger DD/ Pump rate 650 gpm @ 2710 psi.\120 rpm @ 6-6.8K torque\WOB=4-10K\Up wt.=130K-Dn wt.=70K-Rot wt.=100K./ 8.4 ppg mud wt.\ECD=10.59 ppg.\ADT=2.97 hrs.\Jars=105.1 hrs. Total ADT=3.57 hrs. Total Jar=105.1 hrs Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum 'Ng Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. David Smith Eni Petroleum Dog Spur. Enipetroleum.AK 907-670-8623 907-632-3058 Drilling@enipetroleum.com Eni representative Bernie Leas Eni Petroleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-575-9427 eum.com Eni representative Mike Nelson Eni Petroleum HSE Mike.Nelson@enipetroleum.com 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 ifill* Eni E&P Division I Well Name:0P17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • APIIUWI:50-029-23431-00-00 2�,,t Date:11/19/2010 - Report#: 25 I"'II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 20.81 Daily Information End Depth(ftKB) 'End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11.385.0 3.523.5 1,925.00 13.24 145.4 88.0 21.0 Cloudy,Light Snow, 83"E @ 7.9 mph WC 11.8' Daily summary operation 24h Summary Drill rotary Steerable(/9040'-511385'MD.3535 TVD. MWT 8.4. Losses to formation=68 bbls. Operation at 07.00 Drilling ahead as per Schlumberger&ENI well plan\Using WEI CD system during connection. Depth @ 0400 Hours 11,884'MD 24h Forecast Drill production interval as per Schlumberger&ENI well plan(/11,385'to TD. Lithology _ - - Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. '00'00 -12:00 12.00 12.00'DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan f19040'-510,273'MD(TVD 3535')as per Schlumberger DD\Pump rate 650 gpm @ 2930 psi.\120 rpm @ 6600-8800K torque\WOB=10-15K\Up wt.=135K-Dn wt.=65K- Rot wt.=100K.\8.4 ppg mud wt.\ECD=10.59 ppg. Shut pumps off 3 times for a total of 2 minutes bcause side flapper on the CD sub was leaking.Total losses for tour=43 bbls • Total ADT=7.49 hrs. Total Jar=112.6 hrs 12:00 '00:00 12.00 24_00'DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan f/10273'-511385'MD(TVD 3535')as per Schlumberger DD\Pump rate 650 gpm @ 3100 psi.\120 rpm\7600 torque off\9400K torque on\WOB=4-15K\Up wt.=138K-Dn wt.=62K-Rot wt.=102K.\8.4 ppg mud wt.\ECD=11.09 ppg.Total losses for lour=25 bbls Total ADT=5.75 hrs. Total Jar=118.3 hrs Daily Contacts Position Contact Name Company Title _ E-mail _ Office Mobile Drilling Supt. 'Jack Keener Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Dulling Supt. Gary Goedich Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Poser Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(f1KB) Run Date CASING 95/8 8,681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814,0 1i* Eni E&P Division �, I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2^ Date:11/20/2010 - Report#: 26 I' II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27.680.00 220.88 125.3 21.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13.824.0 3,542.7 2.439.00 12.25 199.1 90.0 19.0 Snow/Blowing Snow. 61"ENE @ 24.4 WC 2.5` mph Daily summaryoperation 24h Summary Drill rotary Steerable 1/11385'-5/13824'MD,3558 TVD. MWT 8.40.ECD 11.24. Losses to formation=50 bbls. Operation at 07.00 Drilling ahead as per Schlumberger 8 ENI well plan\Using WEI CD system during connection. Depth @ 0400 Hours 14,220'MD 24h Forecast Drill production interval as per Schlumberger&ENI well plan(/13824'to TD. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 8.45 Time Log Start End Cum Time Time Dur(hr)'Dur(hr) Phase Opr. _ Act. - Plan Oper.Descr. 00.00 12.00 12.00 12.00 DRILL 'E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/11385'-5/12785'MD(TVD 3535')as per Schlumberger DD\Pump rate 650 gpm @ 3100 psi.\120 rpm\8500 torque off\9500K torque on\WOB=4-15K\Up wt.=144K-Dn wt.=100K-Rot wt.=100K.\8.4 ppg mud wt.\ECD=11.40 ppg. Total ADT=6.20 hrs. Total Jar=124.5 hrs. 12.00 00.00 - 12.00' 24.00 DRILL •E .3 .P ,Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/12785'-813824'MD(TVD 3558')as per Schlumberger DD\Pump rate 650 gpm @ 3360 psi.\120 rpm\10000 torque off\ 12500K torque on\WOB=4-15K\Up wt.=168K-Dn wt.=100K-Rot wt.=140K.\8.4 ppg mud wt.\ECD=11.40 ppg.Shut pumps off for 20 seconds due to flapper valve. Loss to formation=50 bbls. Total ADT=6.05 hrs. Total Jar=130.6 hrs. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Dug Spvr. Enipetroleum.AK 907-670-8623 907-715-6434_-- Drilling@enipetroleum.com Drilling Supt. Gary Goerlich Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com En:representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.cam 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Willlams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 S 1°41 Eni E&P Division I Well Name:0P17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • Date:11/21/2010 - Report#: 27 APIIUWI:50-029-23431-00-00 ei o page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 000 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 22.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15,893.0 3,511.0 2.069.00 12.49 165.7 90.0 20.8 Partly Cloudy. 55°NE @ 18.3 mph Blowing Snow,WC 5.7" Daily summary operation 24h Summary Drill rotary Steerable(/13824'-t/15893'MD,3529 TVD. MWT 8.5,ECD 11.22. Losses to formation=80 bbls. Operation at 07.00 Drilling ahead as per Schlumberger&ENI well plan\Using WEI CD system during connection. Depth @ 0400 Hours 16,286'MD 24h Forecast Drill production interval as per Schlumberger&ENI well plan 1/15893'to TD. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03:00 3.00 3.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/13824'-1/14138'MD\3564'TVD as per Schlumberger DD\Pump rate 600 gpm\140 SPM\3000 psi-off\3150 psi-on\120 rpm\10K torque off\ 12K torque on 1 WOB=10K\ Up wt.=168K-Dn wt.=100K-Rot wt.=140K.\8.5 ppg mud wt.\ECD=11.30 ppg.Shut pumps off during one connection. Flapper valve not holding. Loss to formation=15 bbls. Total ADT=6.05 hrs. Total Jar=130.6 hrs. 03.00 03.30 0.50 3.50 DRILL E 7 P Circ and Cond with one pump while cleaning suction screen to#2 mud pump. 420 GPM @ 100 SPM.80 RPM,working pipe. 03.30 12.00 8.50 1200 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/14138'-8/15024'MD\3525'TVD as per Schlumberger DD\Pump rate 600 gpm 1 140 SPM\3240 psi-off\3260 psi-on\120 rpm\10K torque off\ 12K torque on\WOB=10K 1 Up wt.=180K-Dwn wt.=100K-Rot wt.=140K.\8.5 ppg mud wt.\ECD=11.22 ppg.Loss to formation=15 bbls. Total ADT=5.54 hrs. Total Jar=136.1 hrs. 12.00 00:00 12.00 24.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/15024'-1/15893'MD\3529'TVD as per Schlumberger DD\Pump rate 600 gpm\140 SPM\3370 psi-off\3380 psi-on\120 rpm\10K torque off\ 12K torque on\WOB=10K\ Up wt.=185K-Dn wt:100K-Rot wt=140K.18.5 ppg mud wt.\ECD=11.22 ppg.Shut pumps off 20 seconds for flapper @ 15106 MD. Pumps down 4 minutes total to check CD Manifold for blockage. Loss to formation=65 bbls. Total ADT=6.96 hrs. Total Jar=143.1 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 907-715-6434 D011ing@enipetroleum.com Drilling Supt. Gary Goedich Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.cum 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8.505,6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 1 Eni E&P Division (Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UW:50-029-23431-00-00 2^ Date:11/22/2010 - Report#: 28 in page 1 of 1 Wellbore name. OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0P17-02 DRILLING 10/30/2010 27680.00 220.88 125.3 23.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 17,750.0 3,517.9 1,857.00 10.04 185.0 90.0 31.5 Clear,WC 27.9' 211°SSW @ 4 mph Daily summary operation 24h Summary Drill rotary Steerable 1/15893'-1/17750'MD,3499 TVD. MWT 8.5,ECD 11.3. Losses to formation=122 bbls. Operation at 07.00 Drilling ahead as per Schlumberger&ENI well plan\Using WEI CD system during connection. Depth @ 0400 Hours 17,990 MD 24h Forecast Drill production interval as per Schlumberger&ENI well plan(/17750'to TD-18550'MD. CBU+/-7 times while back reaming slowly to intermediate casing shoe\600 GPM\140+RPM. CBU @ intermideate casing shoe+/-5 times.TIH to TD and CBU+/-5 times. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 I 12.00 12.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan(/15893'-t/16876'MD\3506'TVD as per Schlumberger DD\Pump rate 585 gpm\140 SPM\3500 psi-off\3540 psi-on\120 rpm 114-15K torque off\16-17K torque on\WOB= 4-18K\Up wt.=185K-Rot wt.=100K.\8.5 ppg mud wt.\ECD=11.3 ppg. Backing reaming 30'before connections. Losses to formation=42 bbls. Total ADT=5.4 hrs. Total Jar=148.5 hrs. 12.00 '22:00 10.00 22.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan(/16876'-1/17664 MD\3493'TVD as per Schlumberger DD\Pump rate 550 gym\145 SPM\3410 psi-off\3400 psi-on\120 rpm\16-17K torque off\18-20K torque on\WOB= 4-18K\Up wt.=210K-Rot wt.=102K.\8.5 ppg mud wt.\ECD=11.3 ppg. 22:00 23:00 1.00 23.00 DRILL E 7 P Lost signal from MWD.Traced problem to a bad cable,replaced same. 23:00 00:00 1.00 24.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan(/17664'-1/17750 MD\3499'TVD as per Schlumberger DD\Pump rate 550 gpm\145 SPM\3410 psi-off\3400 psi-on\120 rpm\16-17K torque off\18-20K torque on\WOB= 4-18K\Up wt.=210K-Rot wt.=102K.\8.5 ppg mud wt.\ECD=11.3 ppg. Pumps down for 12 minutes due to power loss. Losses to formation=80 bbls. Total ADT 4.63 hrs. Total Jars 153.1 - Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. Gary Goedich Eni Petroleum Dug Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 ft* Eni E&P Division (Well Name:0P17-D2 -I ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq 2^„ Date:11/2312010 - Report#: 29 • API/U W I:50-029-2 3431-00-00 II fl II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 24.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(It) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18.940.0 1.190.00 7.52 158.2 87.0 20.7 Overcast.WC 8.1" 329°NNW @ 13.1 mph Daily summary operation 24h Summary Drill rotary Steerable 0/17750'-1/19000'MD,(3499 TVD)TD. MMT 8.5,ECD 10.60. Losses to formation=122 bbls. Operation at 07.00 Circulating hole reciprocating 90' 24h Forecast CBU+/-7 times until clean as per KW model.BROOH to intermediate casing shoe pulling 10-20'per minute. CBU @ casing shoe+/-5 times. Tnp out of hole on elevators. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03.00 3.00 3.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/17750'-1/17990 MD\3522'TVD as per Schlumberger DD\Pump rate 550 gpm\143 SPM\3370 psi-off\3400 psi-on\120 rpm\17K torque off\ 19K torque on\WOB=4-18K \Up wt.=210K-Rot wt.=102K.\8.5 ppg mud w1.1ECD=11.3 ppg. 03:00 04:00 1.00 4.00 DRILL E 7 P Circulate and condition/reciprocate pipe while waiting on orders per directional and geological personnel 04:00 12.00 8.00 12.00 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan(117990'-1/18549 MD\3483'TVD as per Schlumberger DD\Pump rate 610 gpm\143 SPM 12950 psi-off\3050 psi-on\120 rpm\19K torque off\20K torque on\WOB=4-15K \Up wt.=240K-Rot wt.=100K.\8.5 ppg mud wt.\ECD=11.80 ppg.\Back ream 30' Total ADT=4.06 hrs. Total Jars=157.16 hrs. 12.00 18.30 6.50 18.50 DRILL E 3 P Drill ahead-Rotary Steerable as per Schlumberger DD/Well Plan 1/18549'-5/18940'MD-TD(3493'TVD)as per Schlumberger DD\Pump rate 550 GPM\145 SPM\3400 psi-off\3400 psi-on\80-120 rpm\19K torque off\21K torque on\WOB=4-18K\Up wt.=2284-Rot wt.=102K.\8.5 ppg mud w1.1ECD=11.28 ppg.\Back ream 30'of stand. Total ADT=3.46 hrs. Total Jars=161.4 1830 00:00 5.50 24.00 DRILL E 7 P Circulate and Condition hole until clean as per KM rep,recipricate 90'. Take on bottom survey\550 GPM\145 SPM\ 3400 PSI\120 RPM\17K TO\MINT 8.5\ECD 11.50 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Drip Spur. Enipetroleum.AK 907-670-8623 907-715-6434 Drilling@enipetroleum.com Drilling Supt. Gary Goedich Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 DnIling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8.550.0 OBM Versapro 8.40 814.0 Eni E&P Division 'Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq 09* • APIIUWI:50-029-23431-00-00 2�, Date:11/24/2010 - Report#: 30 II II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL _ Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG ___ Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27680.00 220.88 125.3 25.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 18,940.0 0.00 89.0 18.9 Partly Cloudy,Light 338`NNW @8.7 Snow,WC 8.1" mph Daily summary operation 24h Summary Circulated bottoms up while reciprocating until shakers clean. Well flowing. Increased OBM weight to stop flow, Back reamed slowly from TD to 15,795'MD periodically monitoring well flow. Total losses to formation 239 BELS. Operation at 07.00 Continued slow BROOH. Depth at 0400 hours 14,250'MD. 24h Forecast Continue slow BROOH to 9 5/8"casing shoe.Circulate-5 times bottoms up. TIH to TD on elevators and circulate again*/-5 times bottoms up until well is clean. Trip out of hole on elevators.. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. • 00:00 04:00 4.00 4.00 DRILL E 7 P Continue CBU @ 550 GPM/3480 PSI 1120 RPM 195 ROT-UP WT.Reciprocating pipe until shakers clean. Slow Pump Rate @ 18,940'MD(3555'TVD) Pump#1/2-25/35 SPM.CBU 7 times. 04:00 04:30 0.50 4.50 DRILL E 7 P Weight monitor well for 30 minutes. Flowing,10 BBL gain. 04:30 07:00 2.50 7.00 DRILL E 7 P 'Weight up OBM 8.5 PPG to 8.6 PPG,reciprocating pipe,circulating @ 500 GPN/120 RPM. 07:00 07.30 0.50' 7.50 DRILL E 7 P Weight monitor well for 30 minutes. Still flowing 10 BBL gain. 07.30 11'.00 3.50 11.00 DRILL E 7 P Circulate while reciprocating pipe. Same parameters. Wait on orders. Weight OBM up to 8.7 PPG in/out. Monitor hole for 20 minutes static. 11 00 12'.00 1.00 12.00 DRILL E 6 P Back ream(/18,940'to 18.700'MD @ 450 GPM/2700 PSI 1120 RPM/16-17K TO 1110 ROT-UP. Lost 109 BBLS for tour. 12.00 15.00 3.00 15.00'DRILL E 6 P Back reaming(/18.700't/17958'MD/120 RPM 116-17K TO/110 ROT-UP/MWT 8.7 PPG 1500 GPM 13100 PSI/130 SPM. 15.00 15:30 0.50 15.50 DRILL E 7 P Monitor well for 30 minutes 15.30 21:30 6.00 21.50 DRILL E 6 P Back ream slowly(/17.958'U16,460'MD/120 RPM/12-13 TO 1102K ROT/500 GPM/2500 PSI/130 SPM/MWT 8.7 lef 21 30 22:00 0.50 22.00 DRILL E 7 P Stopped back reaming and monitored well for 30 minutes due to losses change.Losses leveled and proceeded back reaming. 22.00 00:00 2.00 24.00 DRILL E 6 P 'Back ream slowly(/16.460' U15,795'MDI 120 RPM/12-13 TO 1102K ROT/500 GPM/2500 PSI 1130 SPM/MWT 8.7. Lost 130 BELS this tour. Daily Contacts Position Contact Name Company Tithe E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 .907-715-6434 Drilling@enipetroleum.com Dnlling Supt. Gary Goedich Eni Petroleum Ddg Spot. Enipetroleum.AK 907-670-8623 Drilfing@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat _ _ Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(MKB) .TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division f Well Name:0P17-02 Pi* ENI Petroleum Co.Inc. Daily Report •Well Code:25097 Field Name:Nikaitchuq • 2^ Date:11/25/2010 - Report#: 31 APIIUIM:50-029-23431-00-00 '� h page 1 of 1 wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27.680.00 220.88 125.3 26.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 18,940.0 0.00 90.0 8.2 Partly Cloudy,Light 338"NNW @ 10.5 Snow,WC-6.2° mph Daily summary operation 24h Summary Continue slow BROOH to 9.104'MD. Worked through tight spots at 13,215',12.835'and 12.780'-12,650'. 550 GPM\120 RPM\2100-2950 PSI\7-14K TQ\MWT 8.7+\ECD 10.17. Operation at 07.00 Cut/Slip drilling line and service top drive. Prep for TIH on elevators to bottom. 24h Forecast Continue BROOH to 9 5/8"casing shoe @ 8.520'MD.Circulate casing clean-5 times bottoms up. Pull BHA up inside casing. PJSM and cut/slip drilling line and service top drive. TIH to TD on elevators and circulate again+/-5 times bottoms up until well is clean. Displace to Solids Free Completion Fluid(Versapro SF). Clean mud pits. Trip out of hole on elevators. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.75 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08 30 8.50 8.50 DRILL .E 6 'P Back reamed slowly 1/15.795'1/12.650'MD\550 GPM\2950 PSI\120 RPM\10-14K TO\Pulling 20-30'FPM. Continuous pumping with CD unit. Encountered tight spot @ 13,215'and increased torque 7K,reamed up/down through. Encountered another tight spot @ 12,835'and increased torque 6K,same. F/12,780'to 12,650'varied torque 9.5 to 15K and reamed slowly. 08:30 09:00 0.50 9.00 DRILL •E 7 -P Circulated and reciprocated pipe to clean hole. Same parameters. 09:00 12:00 3.00 12.00 DRILL 'E 6 P Continued back reaming 1/12,650 511,759'MD\550 GPM\2570 PSI\120 RPM 18-10K TO 12:00 23:00 11.00 23.00 DRILL E 6 P Continued back reaming 1/11.759'1/9301'MD\550 GPM\2100 PSI\120 RPM\145 SPM\7-8K TQ\MWT 8.7+\ECD 10.2\Continuous circulation. 23:00 0000 1.00 24.00 DRILL -E 6 -P Back reamed 1/9,301'119,104'@ 3.4'per hr. CBU each stand 1145 SPM\550 GPM\2100 PSI\7-8K TO\102K ROT\ MWT 8.7+\ECD 10.17. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Drilling Supt. Jack Keener 'Eni Petroleum Ddg Spy, Enipetroleum.AK 907-670-8623 907-715-6434 DnIling@enipetroleum.com Drilling Supt. Gary Goerlich Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 DnIling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrcl 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division I Well Name:0P17-02 ENI Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq VI* � APIIUWI:50-029-23431-00-00 2^„ Date:11/26/2010 - Report#: 32 II II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 27.81 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18940.0 0.00 92.0 10.6 Mostly Cloudy,Light 338°NNW @ 2.4 Snow,WC 6.3' mph Daily summary operation 24h Summary Continue BROOH to 9 5/8"casing shoe @ 8,520'MD.Circulate casing clean-5 times bottoms up. Pull BHA up inside casing. PJSM and cut/slip drilling line and service top drive. TIH to 11,175'and tagged hard spot. Attempts to get past hard spot and back into original wellbore failed. POOH to 9,006'MD replacing 12 bad DP joints. Notified AOGCC for BOPE test @ 1430 hours Operation at 07.00 POOH.Current depth @ 0400 hours 7230'MD 24h Forecast Continue POOH to surface. UD BHA#5.Test BOPE. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 6 P Back reamed slowly(/9.102'08.700'MD 1 550 GPM 12400 PSI 1120 RPM/8-9K TQ 01:00 02:00 1.00 2.00 DRILL E 6 P BROOH to 9 5/8"casing shoe @ 8.500'MD.Circulated @ 400 GPM/1150 PSI 1140K UP-WT 02.00 02:30 0.50 2.50 DRILL E 6 P PJSM for cut/slip drill line. 02.30 04:30 2.00 4.50 DRILL E 25 P Cut 150'of drill line. 04.30 06.30 2.00 6.50 DRILL E 25 P Changed out saver sub. Greased top drive,drawworks and iron ruffneck. Calibrated crown saver. Cleaned up drill floor. Adjusted grabber foot. 06.30 09.00 2.50 9.00 DRILL E 4 P TIH on elevators 1/8,500'011,175'MD. 55-75K DWN-WT. Fill DP every 20 stands. 09.00 10:30 1.50 10.50 DRILL E 7 P Tagged hard spot at 11.180'MD. Attempted to ream through,still taking weight. Oriented directional tools to high side 1 550 GPM 12600 PSI. Attempted to ROT through hard spot. Reduced pump rate and continued efforts to drill through. Stopped rotation and attempted to push through,no luck. 10.30 11:00 0.50 11.00 DRILL E 7 P Racked back one stand. Circulated and reciprocated @ 300GPM 11075 PSI 140 RPM while waiting on orders. 11:00 12:00 1.00 12.00 DRILL E 3 P Rotary drill(/11,175'011,269'MD attempting to drill into old hole. P/U off bottom and take directional survey. Circ/Recip @ same rate while waiting on orders. 50 bbls fluid loss this tour, V 12:00 15:00 3.00 15.00 DRILL E 3 P Orientate XCEED lowsied 130"ight and attempted to regain original hole. Drilled/reamed down slowly f/11,170'MD @ 120 RPM 19500 TO 12K WOB 1550 GPM 12425 PSI to 11,195 MD.taking weight 10K. 15:00 00:00 9.00 24,00 DRILL E 4 XPO4 Back ream out using CD system 1 550 GPM 12525 PSI 1450 GPM\1750 PSI\120 RPM\8500 TQ 3-5 minutes per stand. POOH 09.006'MD\135 UP-WT\90 DWN-WT\100 ROT-WT. L/D and replaced 12 bad joints. 35 bbls fluids loss this tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 D d ll i n g@ e n i p e tro le u m.co m Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division (well Name:OP17-02 rilf* EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • APIIUWI:50-029-23431-00-00 2^ Date:11/27/2010 - Report#: 33 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 000 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27680.00 220.88 125.3 28.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,940.0 0.00 87.0 9.0 Overcast,WC-1.3° 338`NNW @ 6.1 mph Daily summary operation 24h Summary - - Continued to POOH to BHA. L/D bad DP,stand back good joints. Weighted up 0131/1 to 9.6 PPG.Total losses 52 bbls. Operation at 07.00 L/D BHA#5 and prep for BOPE tests. 24h Forecast L/D BHA#5,Clean drill floor and prep for BOPE test. AOGCC rep will witness BOPE tests. P/U DP and M/U BHA#6. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 6 U BROOM 1/9006'08400'MD 1450 GPM\1470 PSI 1 5K TO 1 100 RPM. UD 1 bad hard band joint. No tight spots. 01 30 12'.00 10.50 12.00 DRILL E 4 U Pump out of hole f/8400'113792'MD\250 GPM\300-700 PSI 1125 UP-WT. No swabbing,proper displacement. Inspected and UD bad hardbanded pipe,23 total bad joints laid down. Losses this tour 20 bbls. 12:00 13:30 1.50 13.50 DRILL E 4 U Trip out of hole 1/3792'03000'MD\350 GPM/600 PSI\102 UP-WT\95 ON-WT 13.30 14.00 0,50 14.00 DRILL E 7 U Monitored well fro 30 minutes. No gain/loss observed. 14:00 18.30 4.50 18.50 DRILL E 7 U Weight up OBM to 9.6 PPG\EMW 9.3. 18.30 00.00 5.50 24.00 DRILL E 4 U POOH on elevators slowly.checking for swabbing,none detected. Correct hole fill coming out. Stand back good joints DP in demck and L/D bad joints. UD 5 jts HWDP. Losses this tour 32 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Ddg Spvr. 'Enipetroleum.AK 907-670-8623 Dolling@enipetroleum.com Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter©enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams©Nabors.com 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division I Wett Name 0P17-02 PI* EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • API/UVN:50-029-23431-00-00 2^'I Date:11/28/2010 - Report#: 34 If II npage 1 of 1 Weltbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27.680.00 220.88 125.3 29.81 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 16,940.0 0.00 87.0 -1.7 Overcast,fog,WC- 338°NNW @ 5.1 8.9" mph Daily summary operation 24h Summary L/D BHA#5,Clean drill floor and prep for BOPE test. AOGCC rep John Crisp witnessed BOPE tests. Replaces rubbers on blind rams. Changed out wash pipe and replaced bad top drive sensor. Operation at 07.00 P/U 5"DP. 24h Forecast Complete work on swivel and rebuild pushing block. Adjust top drive backup gripper. P/U 5"DP to replace wom DP. M/U BHA#6. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 1 U PJSM to L/D BHA#5. 00:30 03:30 3.00 3.50 DRILL E 4 U L/D BHA#5 and remove source. Rack back drill collars 03:30 05:00 1.50 5.00 DRILL C 20 P Pull wear ring,M/U 4 1/4"x 5"test joint and install test plug 05:00 06:30 1.50 6.50 DRILL E 12 P Fluid pack BOPS,choke manifold and test joint. 06:30 12:00 5.50 12.00 DRILL E 12 P Test BOPE to AOGCC regulation,250 PSI low/3500 PSI high,hold for 5 minutes. Test bag 2500 PSI.charted. Witnessed by AOGCC rep John Crisp. Tested all alarms. Drawdown test 1900 PSI for 150 sec over all. 35 sec-200 PSI. 2900 PSI avg-bottles 12:00 13:00 1.00 13.00 DRILL E 12 P Blind rams failed high test. Function blinds.double block all valves,still failed. 13:00 17:00 4.00- 1700 DRILL E 12 P Pulled test plug and drained stack. Reset plug and RILDS. Monitor open annulus continuously. Blow down choke and kill lines. Open ram doors and remove blind rams,replace rubbers on blind rams and reinstall rams. Attempt to change out wash pipe,upper nut seized up. 17:00 17:30 0.50 17.50 DRILL E 12 P Test blind rams 250 PSI low/3500 PSI high for 5 minutes each. Recorded on chart. 17:30 18.30 1.00 18.50 DRILL E 5 P L/D test tool,pull test plug,set wear ring,drain stack,B/D choke manifold,choke,kill line and top drive. UD test joint. 18.30 00.00 5.50 24.00 DRILL E 5 P Install clamp on saver sub. Replaced bad top drive sensor. Change swivel packing,unable to turn upper nut on packing cartridge,obtained larger Portapower jack to break top nut on wash pipe. Remove old wash pipe and clean and dress threads. Circ across top of hole continuously with trip tank.had two bbl loss in 6 hours. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum DrIg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Drilling Supt. Gary Goedich Eni Petroleum Ddg Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrloleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mall Coord. 907-670-8581 907-240-2712 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 6,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 1Eni E&P Division ..} I Well Name:OP17-02 ENI Petroleum Co.Inc. Daily Repo ` Well Code:25097 Field Name:Nikaitchuq • API/UWI:50-029-23431-00-00 2^ Date:11/29/2010 - Report#: 35 II II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 30.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18.940.0 _ 0.00 86.0 -8.0 Clear,WC-15' Calm Daily summary operation 24h Summary Completed work on swivel and rebuilt pushing block. Adjusted top drive backup gripper.L/D 5"DP and CD valves. Operation at 07.00 Laying down 5"DP and CD valves. 24h Forecast Complete removal of 5"DP. Load pipe shed with 4 1/2"DP. M/U BHA#6. P/U and rack back 4 1/2"DP. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL E 25 P M/U and install new swivel packing assembly to topdrive. 01:00 02:00 1.00 2.00 DRILL 'E 25 P Installed new bushing locks. Adjusted topdrive gripper foot assembly. Cleaned up work area. 02:00 02:30 0.50 2.50 DRILL E 4 U PJSM.L/D bad/wom 5"DP and transfer good 5"DP/stands to driller side of pipe rack. 02.30 10:30 8.00 10.50 DRILL E 4 U L/D bad hard band jts. P/U good its from pipe shed. Rack back on drillers side from ODS pipe rack. L/D 34 bad hard band jts. 10.30 11:00 0.50 11.00 DRILL E 4 U PJSM for RIH with DP on ODS. 11 00 13:00 2.00 13.00 DRILL E 4 U TIH with DP T/3000',30 stds 13.00 20:00 7.00 20.00 DRILL E 4 U L/D 90 jts DPand remove CD valves. 20.00 21:30 1.50 21.50 DRILL E 4 U TIH 30 stands DP ` 21 30 0000 2.50 24.00 DRILL E 4 U L/D 42 jts DP and remove CD valves. �" Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Ddg Spur. Enipetroleum.AK 907.670-8623 Drilling@enipetroleum.com Drilling Supt. Gary Goerlich Eni Petroleum Ddg Spur. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245et enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipetroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mall Coord. 907-670-8581 907-240-2712 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 Eni E&P Division lWell Name:0P17-02 WI* EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name:Nikaitchuq • Date:11/30/2010 - Report 36 API/UWI:50-029-23431-00-00 e h page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P17-02 DRILLING 10/30/2010 27,680.00 220.88 125.3 31.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,940.0 0.00 85.0 7.7 Overcast,Light 202°SSW @ 12 Snow,WC-5.1° mph Daily summary operation 24h Summary Continued UD of 5"DP removing CD subs from bad hardbanded joints and installing CD subs on good DP. Loaded pipe shed with 4 1/2"DP. Testing rams and valves. Operation at 07.00 Performing 5"DP rack back and CD sub removal from bad hardband jts. 24h Forecast Complete 5"DP and CD sub management. Continue testing rams and valves 250 low/3500 high for 5 minutes. Single in hole 4-1/2"DP-255 joints. Circ and cond mud to 9.2 ppg in/out. POOH 85 stands 4-1/2"DP racking back. PU BHA#6 and TIH to 9-5/8"casing shoe. TIH to 9450'MD,circ and cond mud to 9.2 ppg. Begin rotary drilling sidetrack. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 U LID 47 joints 5"DP flagging joints with wom hardband. L/D CD valves-Had proper displacement 03:30 06.30 3.00 6.50 DRILL E 4 U RIH from derrek with 30 stands(3000')5"DP-Had proper displacement. 06:30 08:30 2.00 8.50 DRILL E 4 U L/D 5"DP and CD valves,flagging joints with worn hardband 08:30 09:00 0.50 9.00 DRILL E '25 U Change dies on top drive backup assembly 09:00 1230 3.50 12.50 DRILL E 4 U L/D 72 joints 5"DP flagging joints with wom hardband. L/D CD valves-Had proper displacement 12:30 13:30 1.00 13.50 DRILL E 4 U P/U 9 joints 5"DP,stand back w/CD subs 13:30 1600 2.50 16.00 DRILL E 4 U TIH 30 stands(3000')5"DP. L/D stand of D.C. 16:00 18:30 2.50 18.50 DRILL E 4 U POOH Install CD subs on each stand 18.30 2000 1.50 20.00 DRILL E 4 U TIH 30 stands 20.00 22:30 2.50 22.50 DRILL E 4 U POOH Rack back 30 stands,install CD sub on each stand 22:30 23:30 1.00 23.50 DRILL E 4 U TIH 19 stands 23:30 00:00 0.50 24.00 DRILL E 4 U POOH Rack back 5 stands. Install CD sub on each stand Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Gary Goerlich Eni Petroleum Dug Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potter@enipelroleum.com 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mat'l Coord. 907-670-8581 907-240-2712 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 11* Eni E&P Division I Well Name:0P17-02 EN!Petroleum Co.Inc. Daily Report Well Code:25097 Field Name: Nikaitchuq • Date:121112010 - Report#: 37 APIIUWI:50-029-23431-00-00 2" "II page 1 of 1 Wellbore name: OP17-02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 201-125 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 31.78 32.36 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) OP17-02 DRILLING 10/30/2010 27,680.00 220.68 125.3 32.81 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 18,940.0 0.00 84.0 -3.3 Overcast,WC-13.2' 284'WNW @ 4.6 mph Daily summary operation 24h Summary Completed 5"DP and CD sub management. Tested rams and valves 250 low/3500 high for 5 minutes.charted. Singled in hole 4-1/2"DP to 6003'MD. Operation at 07.00 Circ and cond mud-9.2 ppg in and out.Current depth 7,915'MD. 24h Forecast Continue single joint TIH to-7650'MD.Circ and cond mud to 9.2 ppg in/out. POOH 85 stands 4-1/2"DP racking back. PU BHA#6 and TIH to 9-5/8"casing shoe. Cut and slip drill line. TIH to 9450' MD.circ and cond mud to 9.2 ppg. Begin rotary dolling sidetrack. Drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL E 4 U Stage sub rack on drill floor 00.30 02:30 2.00 2.50 DRILL E 4 U POOH 14 stds installing CD subs. Rack back off drillers side. Proper hole fill as calculated. 02.30 05:30 3.00 5.50 DRILL E 4 U P/U 51 joints 5"DP 05.30 07:30 2.00 7.50 DRILL E 4 U POOH installing CD subs. Rack back. 07.30 09:00 1.50 9.00 DRILL E 12 U Clear and clean doll floor of sub racks and thread proctectors. Drain stack. Pull wear ring and install test plug. 09:00 10:30 1.50 10.50 DRILL E 12 U P/U 4-1/2"handling equipment. P/U safety valves and crossover. M/U test joint. Fill stack and test joint with water. 10.30 12.00 1.50 12.00 DRILL E 12 U Test BOPS,Rams and annular preventer with 4-1/2"pipe,TIW,Dart valves,250 psi low/3500 psi high,hold 5 minutes. charted.Test annular preventer to 2500 psi. 17 12:00 13:30 1.50 13.50 DRILL E 12 U Test 4-1/2"Dart valve.second 4-1/2"TIW failed,test lower VBRs with 4-1/2"test joint 250 psi low/3500 psi high for 5 minutes each,charted. 13:30 15:00 1.50 15.00 DRILL E 12 U Pull test plug,drain stack,B/D choke,set wear ring,L/D test joint. 15:00 00.00 9.00 24.00 DRILL E 4 U P/U 4-1/2"DP single joint TIH to 6003'MD,up-wt 110K,down-wt 85K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Gary Goerlich Eni Petroleum -Dog Spvr. Enipetroleum.AK 907-670-8623 Drilling@enipetroleum.com Eni representative Tom Norvig Eni Petrtoleum Rig Clerk Enipetroleum.AKRigClerks245e@enipetrol 907-670-8607 907-229-6100 eum.com Eni representative Jack Potter Eni Petroleum HSE Jack.Potler@enlpetroleum.com 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Push Michael.J.Williams@Nabors.com 907-670-8539 Eni representative Daniel Lee Eni Petroleum Mat'l Coord. 907-670-8581 907-240-2712 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 36.0 8,505.6 11/12/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,550.0 OBM Versapro 8.40 814.0 9 E NNQn NNN NINON V_n 22%48 N V V fd00 NNf1.1W N gyp^100 V N MED V ON CD8 V CON N W W W aa2 2Y,(SIT, Op�p(7 4f8O yyON�o<tOr N V,tQdp{P�,p 2222 Np�OP8 n-WW {pNp�;{OO�jpDDjNnd VV1g7"OIIN�"I �O(f Eq(' C N 22 W 2 W Wmm,22% d 2t2O2 t2O tO t2p tO tO t2O f2O tO=tO2 222 W AGO OnDt5i Cruz G4t5tnD 'aD, n O tO tO tO tO tO tO tO tO tO t0 0 J c00 0010 00000 t0 W t0t00 00000 0 W 0 W Op V O V V V d V d V O O V V V V O<p O V <V O V O 404°4( O O d 0 0 Q O Q O O Q i 4 E 8n RAN fOt181 t�'ttpy P888' W 12°' Oi4 W lhA 0 W NN0 0«N0 t00.OnOO, N (4 P 7,N� O N1 A I CJ d O T EWD OI §�N A .111:42 i ciNO Gn it�O i tmO Ny1 N m O OOi O i J gl0000 00000 00000 00000 88888 8c'8‘-' Nt7ddN aNw0,0 p 00000 NNNNN 00000 N N N N 00000 N NNN N 00.00 NNNNN N 00000 00000 ^0000 00000 00000 00000 00000 00000 O rrrtnpp rnnrr rnnn rrrrr nnnnn nrnnn nrnrpr yrnrrr �nO C NO"t7N NEDAO' 4814E, A4Pp'1pf �8�'Oo2 gN ,t,8814.8 S N{p4p 10�S IV817..ppbp A 7 tG888 n tU88t8 COGcOQ t' 8288 OO12 OM e0 E0Orm N%215p> ki4 A A * iga W 21221 O N f00 0 f00 24111 O ro 11 fO t0 t0 t0 t0 t0 t0 tO tG tG t0 NNNNN 211.4 N NNNNN NNNNN NNNNN NNNNN NNNNN O Ngg 00000 ..... ..... 0)000 0 Q, N4W80 NWOXV WN(0Wr 2872d88N01 OpRnh O44V r0800 0 LeggONgms0<VNtiWto gy,, NMNgWNOrOQ pNTA, RAR R 88888 tO8888 82888 08000 88888 88888 tO tO888 88888 0 NCNNN7124;38 0 N .2.220788 N 22VN nomnN Wtp n nWP281;1 NNCW 000C .- .-NfN .t7Vtl .- 2G. 6.-46N ONN'd NOMthO N4CCN W 00990 W TNNr9 00CC0M O W NNC RNtW000 �Oyi W n n 141:!2 42:7.144 V Cm pQQoo oioidvf t50,,04 ,tli ggOD H #n1 g4ggO ggg,4"4, ') SWIo� �) a L (yy CID 2=8842.°2 V W rNNN :24'432 N NO�NN M W dN W N,dOg noT2NN NNt7n N 0 'VctpCC OO�DppNN t08N0 . " c ? 'T/QQ9 //'.' 7 ' '- Nm'" .4'ON 88NASdw- oi EE E _,_1 p A E)'� 0 m N '2 O'ONdt`N8 Mt`0')it1PECOO W< tG8NNr 2122.1 pOCOn'�) N'w888 yyV KI8��V 8 t8 188A N GO CO AI-8222 to O O O COON 61E; " RHt000DA W�t��N NN t�f C) 00<1NO� (Oh A ODN O'N th V q E. Z g Z Z E g". ffi c`7,1 V E0{ o�Qt'0on 0 Emzpr � 2 pORNV t0oQfONx°pp°° Oo( 27VWpp rrnQON O<rAA WN 80AN^1.70p 2TN,R2 O'ir1QN 4 L OOON W'-NOoNpmO1NpNhtO 'N .1�NNN mMD8v Rp�hhtO psgp,RO 8r484 L 1 O 1 Z m g4 Ig O 1 y Ey E i 1 E E0)Z O 2 a Q O G W C i t C m i m l.1 O C m m ` 0 0 Ol m W'gO? 24 W AV.3:3), V.V.NtNO�t�Of d 12,84 V NOp21N OtNyy aZ i .9..1401 CAAO yO�ED thh . .7.14. V W J t t E C0 O0 N CG O ` e�y 0009)? "i". "lb5t0 CIC0CC. NNO� N NNCC0 ty)rd N' A d SAA 4t8VM • O V. O y C G ` CI t7 O N N{O n r ED 0 O n- n- CD OOI f/!i i 0 m 0 0 0 m C 0 VL7� ' O E U W W.E C W C C 2=00?= • N t eL ti G C W F W U W L"O-pWp Cl) m N>> 0 f 1-2 O 2 Z O I-J N --g3O ZO00 W D 142;:i v�ENr 47,P07.4 nA Dd N A'MN "•AW V W 88188 0O8N TN0?S 1 0 . • FOv-n-Nwoo - bW Nppy N 24, , TOtVT NRVNr09DO N NNr1084CN^rDe N �� N NNNNN NNNNN NNNNN N M O W CNNW OG pTONO L's8"a ppOhN' x0800 t:340282 4.8828 2M0:e8 N o(pf pp aty pq tw 1• W ' M 0p0T2A rz88100� 0217041 tO1�ODTN O-'Ag NNN TN NNNNN W N F "?':=741 l7 th d N tD W W O- 0 ....- ��N N NN N N N N N N N N N N N N N 0 LL W N$p• 8 0 0)0 4 0) T trE4 N A h h N 0 0 0 '48,%2 N 0 O V V N V28,184VN V 0 0 8 O e m N N ~ O W.,010 ST,NN NN828 NNNNN NNNN W W NON NNN TT 0M001- NW N N N N Q Wil N E NN-,-1- N N N NNN N NNNNN N N N NNN N N NNN N N N N N N QQ VV p N n E)OtO 8m M pCOf= N O n N p o m.N y 0 d N 0 to N^ y s O�t7N0 ED�N�fo MOM.. N W to tp� TNOtND nW �Tt7n n MTN � A r ONA VI N 0 4 Nm to) C ON OOIN NCN CD C 0d-el,. '040)7 w,.. VIW �} p C N O W p�E.O OCt-'M NIhvuic6 n'6.4 '4'4 tG tC� :JEGNNN NP• PRP V NN N 322 n A ED ,Ot L d N N N 2 1�Q N O NQ�j 0 t.QQ1Q §WoO*nQI C�OOY r 0�`t�1'�') O W Z O O O D O O t7 Z Z Z o O pp pppp pp t1oo ��{{ pp ttpp pp aa aa pppp {{pp 2 COEDNMA ANON° 8 V is .2 0,682 W h Nt0 V IG1No 1000EDOENpD1, 3p8g.tp3tD Igt.18 V O 0.2NN 8RNon 22E,:::= g-,8W28 NZ W O.-,reicritsi 6c6,- T TNt7<O A A nrtOAYNf�g E m N N N NNN N N NNN N N N W if) O:N m W C CCa y C .pp •C O O O;= C 0 ,. C M w E o� mo /� i . o s m i O u J O 9 O t.4 �i o Ili CV r oa a,:ao 1 `oc�to E V o a D L Y n^w v E m m - ' p p K V LL N;m=N N H V..J 0 O V IPJ PJ E N�^ANPJh 05 '3JPJ W nMWD ONW W.4' HH Pitt W20DPi HP; 80 p.40NO 17,1Q A WN 22888 EWAWW o0NMN W O00W*W WW WWWWW WWWWW W ESSStY 00et 04044 tette tette 40000 tette tette 44440 04444 00444 44'444 tet0e 0444 4° "°8 01N AfC AtO hM WWW NON°. M. A. E�.8 Wi .RA W . . . Q . I .". O W WWQ3 WLWW pN N Ling VN QN SWON WWW 2NQQ8 A•R 2.W W W�N P5.W NNNN NNNNN O1p; MM yOAnmOQQQ4 OQOQNNNNN. ...WW AWWAAAAAAW 0,38WW pC W W W W W 0000 N N N N N NNN N N NNN N N NNN N N NNN N N NNN N N NNN N N N N N N N NNN N .NNN. N NNN N N NNN N 1.1'4014 n OA^ 00000 OOOO 00000 00000 OOAO ^0 0 0 0 00000 00O0 00000 0 0 0 0 0 O O O O O OO OA83^O0 0 0 0 0 O0 O O O O O1Ay O O1`�g CyAppAW m800Vi . 21r82 8r2ON ;388giV4hAO112 NrNNO WNNp MMNNh 48 2 14 " 41" C4 g1"1 §1(a§ N AW WtOMV* VNFi0 01 ryW4 2QQ WtfhaRNNN NNN O000 O O O O O 0.100 00.10. .NN. N N N N 0 00010. ..O... 00.00 .N.N N.NNN 00000 NNN.. 0.000 .N.. NrN N. C 2:71R8NE pDWN2 pp2482N42,2436-28NNOO8 pOAQ2 APSAA4pt.-4O8222 T-82 RPQN 0AaiwOM AN54g.M* . paggV• A ,g8 NNn2AQOWW. gDWWWpNNA * .. ONNWgp1* NI,jNP p0§0 z RAM.) MMMMMM MMM(hM 1.1%Rt.Mt;AoinWMMM2 2222 22222 22222 22RoM M2RRMPRRPnRoO 88 88 888202802028 8 88 8 8 888 E8E82 8888E 080EE 880808888 00000080808888 00 N O.sR N N 01 0 1MD 0 W 0 0 m 0 O 0 W 3 R O IWD O N N N 0 O O A W N M 10 N t 8846'8 4 4 4-0 N O Im O 8 8'4448 A W t D C p 0 CN')O A W O O C C G O O G O,, 66666 O 1 f)NG C C C C O(V G 17 t G 1' O 660.-6 O N t7 O N O C l V O CRAE17 A011ND SI7 RA CO 0 CD hCDDR 03 CO 058'8 N WO NN W 1-3CO AM 1705018 W Ih C0 ANN W CMD*IMD1- O NON A A O-N A 4 to N 1D W OC VI;4 pppp O4 CCA -,t1QO A.N"W A gig NA CI AA 4.05p2, ANCA ..pp lh 7pWpQ l.') S W A M{p NQ 17N10O W Q N� W A I O Ny N N O W Abp. Ql7 W 8 W N� W N W N OCrl70 r V 801 7 WN W W O N M Q N W W NW 0� A W O 1") '4'4114 W 1 A W W O O 7 N ".4979'157 9 Q Q. W W W N 1.'f M �51171? � I? � li,c?I'K,Ih4 Y444� 44444 47777 77777 7777 �7��14 �7WW j CNCA 44 005 v nN *828* 205 V N.2 V CDI7m V 1WAIW70SM 8R202 IMONONN arNr ;4.7;73 A W M.10AW 801 QENMMWO 4.rtW WE RWtW pON IQN000 0C4Na01p� 00 87 -4‘7' ap NNNNN N NNNN pp0D. 108001:: W INp.1CD V 0 ^^AA 050 ,730381,; 8104,T4 R<8gy6AWpM38,1* * c7,88**N8** E W M04 T-4;42 14!L%28814!L%288 DOO MO024 0.'.1.A a vQ� WNpW7p ig" 3MppCNQOQa HRH Rill! RIM WWCmW OFpo. 2 =."ONa Cp N WD W Q ARA N 282 A W W NNO MCN 4C4828.=n mQ P%2p WI NV pA V pN ON opO oN C.22 AO NOW E • 24 OONWWWWN WWWAN ww6.-W 66660 ONOW8p' 2 4Np pOMNN W02 c,535 ^ N19*QWan i1700ALM mC2M2 Q4QQQQNNN 3�..DW2AWW W88W WWWAAAA. 3 WCCNSW 0232E 05p04.VW8 W,mf$p QOCOr ONN8:: n WWw 02p058 rpm�W N WWNV NW*<C oi6005 0Oi0MWyDNW 0305WNRRAAD0 0000W 3Nmi O0WWWWNA Mle8AO W3CNN NWW NAWWOM NNApO44O4 44440NNNN8 D.NNW 8WRWWW OWAAN RCN2M,N 005p30 81:30 CQY!2t13Q 8$05005 0) 3D N W0 N00D0 8050 N0 4�4n -AN NAWO1MMWzs,4h40C0aNW 10-0)0A26v4I� OCNpO0n NNN01 NNm NAWW OOOopO RSMMM MMNNN NNN M QAgAp APPA ADDDD DM028 hDDD0 DDhD 122882 24882 r-.%222 ^2822 CMO W01 R SN R M Q 2'8'8'24111yy2'8'8'24 N4 SR V M NN AO7Q E N4%448 W448 QN1M0 22g PEAAQR12 4 O QOWgMA MOVOh OuiMtig N*0NDARWWWOp000000000000 WA WmO0Omoms opOpoN7M MAAAAA7App33AAAAAA DDDMAA ARRANNNN NNNNN N a Q n 80 f r N AEN NDNRW NW BM M W A 2t CB RN7001 iDMBA:2 AM:e0! 2A8:38 058:38 ;NSQ g217421; AORM M W S.W S ON r WWWW WWWWO WWW MMNN NNAAAAAAS ASNMASSOSO NM.WW WW W^WWW M.W. WWW. E NNNN NNNNN NNNNN NNNNN NNNNN NNNNN NNNNN NNMMM MMMMM COMM.. MMMMM MMMMM COMM. Q C C n MYON; 222,%8 22WW22888 8822P! 48444, OF,IAOIAS DCREW p W V 08 10501,7 IC348N NQEOAi NO WM NE W OOM — .EEE EEEEE EEEEID DDMEID� n;REM ;;ERE EEEER EEEmro e2122a 8'oaBWW WWWBW WDWDroWm 8E88 i g8,9 Ngp4 t0 C• �p�pDOD1,00RWW NNS Ot2RN4 808 WS O W 7ME , MO�OfffVR A;NRIC 2880'34' 8W 4 34.1120 � C4<* 03ppO ...N Ay- OpO< 33g03OMf W�p O00142hOlv,* NWAWW WW0, NW O. NNNNN WWWW. WWWINNN ANAg.WSpOWWA3)88, WWWN 8888fm 0 % EO O 0) a H 1° 2 JCp 2 OE222 O W S 8 OQIR O O 7 RS§g7 2 8 4 V gHS2 NRiM 4SA V V pi0 �:2g882 N822g42 4 L O vOON. QWNA N.O0 NhN0A O84 NAOONO AO7, OANNd P288' AA a 7WAtNNOOW Nop < aV00000282 0000 N,Q00 NNWv0NWOM,,ErVaOOOel irE2 NNN NNNNN NNNNN NNNNN SSMMW 7ASAA PARAS SAPS? dWNQvv0W SMMMM WWW01O WWW2O 00020 40024 00000 Op02002220 02440 O'iWQ e vavaa aevav eevvv vevvv eovea aevea agave vvave vevev vevvv aaaaa aoaea v -8° g JN ONO 22 4 O ONNNNN2fm NN O<O S 2"S 247,222 7,2 2 2 4 A'2% 20 2 CN S t24g 8 EN M 0 2 T R 8 O CpNIC '< W 0O7i x20 N0 WN. 00,0,, 30, N W A4,W8 04 V. WA00f01 DIW0 ° m0 N4OM0 ww 8;4:°°° pWSA7 eOVOe 02E82 O82 PArn0 Ny228 SIASO ppppt7 g ON2N NNN NNNO ONONO NONONO 222 22 2NNNN 2NN NNONO O22O MMMMM OOOOOO 0 0'0'00^ 00000 WC NK oooOotOi 00000 0000 00000 00000 0000 0<t00EOD0W 0.I0At0 0140Md10180N100Od10 0tO0tO0t00 00000 0000 00000 0000 00000 0000 or0r00n 0A o 8VAVtD gpz. sa SD :AO22222 48402 8t8SM 2g822 22222 VAt82 2N248 2222T S2222 S W=E mWN 00 WN fM NO WNWOANW0 '"'"N"'"4" NN2p,7002 NWOMA 07222 A842 N < O80 O"'""" OOTWW M8822 Aot22 211DN NO28gAPAnr ,7,7020 ..222 00Wr000000 O O 2p.. 0 .OOO. OOOOO OOOOO OOOOO OOO0. „SEE OOOOO OOOOO OOOOO . 0000 O CO2 'AP' NSOv -p22" WNO"" N -O -TIT- 2822 084EN 2ONr� NN" O pAQ ES:r2 WOOnypSNaANAO O Ngg 80 8OA7Q my' O902 rgga O2N z O eeee0 _ _ _ NNNNN NNN ”yyO pgggs OSp0ggggagggpgpap8888 88888 8'880 88848 8888008888SSg80000g00ggAO 8 0 O tA0222 tAOEODNS.A-, PZA720 ,742g2E�OMN Mdo MWhoN t2tX2f Q2N�A AtlAj 1707 t0 VNnTOI S2282 t n G Or NONN QON lhN N OGNO lV O O .-6N614 O GN r NN NCtn O O QN NN N CI O - o O W�A O V g n A 2O22% pt7:*aQ' 284g2 S00A2 OONANO fO:p)CN V ON AN8,7a N,7 Npa07200 WyI.�$2S X2;22 W;NN O W W 2M NCON W02 "rg8 Bi ,70 '7gW re"; pyW 00 "224 t4t2WnNNAA OWWWW W WW OiO W ? 4W4T8$88 E,8080 0 2Cm O'NAO QOAS2 52480VNO44 82242 22442 WN700 N2 �O NpA2v 88^2OMeh" A00N0N ANO .. d . . p4 .4 00N A'O.SA y . 7 .r. tD. 22,7OOvN02' mp A CSPSO OdNN 44444 4442N 2N212 22. L7anON 222 A04NAN OAA A N,e0A0 22432 4°282S 00 S Pg2 W O 72002 000�0r0NA4Prz tv `'2'4 a O�Nr N 84 2 2 82 2 'IOt Q 2QM' pNAOQ SNQ"4pnA4-S2 8 0OOA 7;'6:282 2OA2N O$ p U AD .'22OOON pp2N7VN0 Nt70W AWW NMQOw AD0p AA 22222 222 NN0200010 001000 00000 ..... NNNNN NNNNt7 np 2,g,7 NA 2 Q v 1,22;e2 Ag22t2:244 002aO OAA t2 2484P. A W 222 A M0p Ne A p 4 M A 2M O A 48084 80774 N 2 Q n 2QCl �- 222 M lM GA}�p tfEp7pN 0001 ill0 SGA ((2002 Cf N OiA NOIh EGAthN t7�C pCA {G Man �lI ^ AAA W ED W aga gt02gE A W a00I Of OAf W O 0000 0000 *-"'W W D W N NNNgW NNNN' MM n * 2 1 yl gc51 N •n q O"'0 8 7 V MM01 N hA0 n 7 1 VE%N 2 A V AA1; R2223OE V V7 AD a vON AAhN S 2 70 4 W 7 V07t2 O .- pV A MN, O W S2S44; gANOEN44 NpWWAc pp .-coO A� n 0O2 2QQ22M 2S8W2 O000 88000 00888 6.88.-1: N AON NMdNN NNNNp M 9=N ceA 2080100 ShtON N • S vt.eqQM12:2812 XA 72 0 OA Q.00 4N4NOA((yy ONNN 22NNE **:;,,g4 SSM7M 00057 SV'QQ0 44:."440 4:147* lh l7NNNr d n 88888 88888 88888 nnnnn APAAA AAPPA APAAA ANAPA nnnnn 88888 nnnnn APPAP 12=8 072,7820 N 22.782 8024:1: Q V zIA Rt2 ON AE?02.A ;88881 OA7 W 82 W 5.1NA.2V 28 V ESD tA0 W WO. O x)8800 oWoo 2In AA 00228 ""g2222 "I" 2,722 I2"2 "I" g"" nA�2o� ro M 881288 8188AA AAAAA AAAAA AAAAA AAAAA AAAAA AAA AAAAA AAAAA AAAAA AAAAA A g E w NA NtAO,Q 22801021Z 127 Q NON A 2;881:-.8 '284V 2MOmN ;P.99,7'4 d,%t092 NCAD20e n re N O O W AY24 22500 F A Q N2CIr 2A42A ELiNCI CIr .-6666 NNNCI1M NO OOCI Nom- Grpf A 64446 AE6072A CIOOmtt) NrNMO 2 E M 1C3'`13' R1RR t7M17NCl CItES'tRRR MRAAAtldRttXWW N`ESRAA ttXRtC!' tRR WWWMM MAMAS 88888 SSSNN NNNNN Q yAA 82:".1V 02222 VNSnA SM2V8 OraVa SS242 A2e28 22A.t AM024 Nor NN AWN28 x,2888 88gSS 22228 82882 2mm22 22888 88882 2288g 22228 2888g 22mm8 rnWWmM m ��'{ND NN'M0 2 W V.“;t�-j 082 t�0IM2 N'NOO An W N2 '(0100 W O 2QACn .4 Meg! �0�� AOdi 1204 022 V V 2•NQt�yS A t' `,7'28'100 WO000 OOS'O� vv �4v v4� AagI$5 W8e2n Wp oilE M tM"`O' At'�I`FI Nal V �a$Q eYiet011 "I E O O N N NNNNN N N N 0 O i • 4 E E 0 9`"N N NN N W W OR 2OIh(N2'4'8.7,2 Op{I � A mm h 28'1'88 E iGWW 32282 WO AAA ........ 10.0)100) 10� 6 J .... SSSSS S Otte eeeee eeeee eoeee 4ee4e e4 . Op(107 , . . . NN. . QppQ. ��{{ � , . . . . . . , � � ��O0 � �(y� .4c4 ARAO rN7(n2 InEONESIG 2N2N 2N 2§4 2 W P. -J 8222 222 n� ) I � )I0h .....1011 Res .... WW�OWW ..... NHh.. W W li 0000 00000 0 00�O00 O^^^^ 0^0 0^ O^OAOto O ^ 0"10W 2 APGt4h 07p4.P2W2N0 20000 GS .jTGn 1OW pA—SIr0h 88888 NNr OpS21z 2�e0820000 Np - _Y 8888 0 0 0 pp N W W 0 88888 OOyOa 8888. eOOO M O WWWW 28WWW WWWW.W N.N.W W.NWW WW r�2a 48400 ,7, 28ON 8hh28 OVOOIW2P. -'EIN g''';" iq4 ier g*O. ooWW NNN hN oWpoaS O88 . (OO 0D.D 88 88 ' OD'y��W W SQ OppNN W 1:22,E.82 W t7e S2 NO cip�04� 8:1;,-.8$ 40�ON4 N r O OO�Ni�� O'-.-CM .-. .-46 C1N�Nf6 NNS stn tn0 r. L. WCWGW. . -...A 75�y70{p0 r®�,W. Mrf0010 aN W W SS m�W e a{m0 A CD2 mE rNtn t22IOA C8DOS1 aD.0.0- 0000 s N 0)O S 0 W n r W S S O N N N N N NN T N N N N N N " " . " " ' ! 222444 f'n o_o.aaan. tp _ 000000 0 N`.W m W W 24 W M7 202®O *go. rAn®0 �N O N x®W 'j..Or OO e r N r O V W hAO n�tNOSO O W OO W W 210N N tiA = .........„,D]m D]m D]4 N W v� Wr Wr,Tn P§22G Dom8ND2'Da 8E222 22288ro rom 222 ats2 m nrnnn0 WW2 0.100_0- w,GW ' �p ttpp 00000 IEGSAG M�AAN CS AS:I? S82�G2 20«rg 0,7, 0 0l' 2AP 2822W ;4'44'2 4404'2 G2233 2� 4 O CGW 0 0 22G GG r220y SOnONN W ANN tea Y.o 4 S Oaq pp 8P2< 44742 00400 2G223 2282ccici pQ�F .G Fc1(0o1N Y gg 23g 1 o § �n �p m 0.-.0OMAN- NA2 W N 10.-ON cpm.con WMONr O0 O Odd}(J�CJ m CDS)lnn N tGMr gglg f 0 .g, 0)ne�Cc V g.i W g n D X0:00013 > CDrr W W W N4O 4lh t'�Wth NNNNN �o W 0 2{100 ~ OSItI ' I u g`e�AP Pian P2i O<ea0 aa0v W a W WW W W T 2= >-,,,,_,dddd m 2 0) U' /1/1/1 0] -Cs > O p 002 '2E2882 10(48,0.22 0100)001 p2{C 800 A 201000 GIS. N p -0-- —888 E 8'8 8 0 2 2" 'm a7 W O ;',4 79. Z �O�O y�y� �O�O BO y�O OO B OO B OO y�B OO �O�O�O y��O �O�O�O�O y� y��O W 10 W 2 2 2 2 t7 10 10 10 10 8 W 10 8 W W W 10 10 10 10 10 t7 lh L, « p- N"0 O o p �O �O {p m A- w Wn g01NO V 4' A.I<M OOi (0{80002 N A<0 4 GOEI==AE{Np t*a q I C p V .. .. jj 2 2n W OJ 2 W W 2G Nc''N' W2222 22232 S$ A 0 V m 0 RRRR AAAAA RRRRR AAAA AAAAA AA o e, g m D> • !I" n Pm N•e3W2WO 2oeOrn 88222 ONWoe 8WWIn8 oo 0 w U .9 O :O 01- 1222 `NWAyy108O8p28108N A0282 NNm m m �ZW = r m�E NNNN NNNN NNNMN NNNNN NNNNN NN y0FzFE Z0NNWNN 5 9 t Q L = QQQQQ 0 >O A 0 y p (p (� w w' `0 'm 7 C` 8'412A W p22NNN lO Ntn41 {88(88O�ir.2 AN2N2 00 G O C7m - X 2 2 2 2 2 2 0 2 22222 8 2 2 88 8 82222 22 S ,2 10 m a mLLJ LL 0 m h n F Vi N O J M V m 1E4418 tONNyW I'Ormpc..,;aa 28822 22 hE§&222U= OWCCN VMOOC tGN2W8f ,. O t0WW100 wNreW WWW02 NNW<W21E118y�O mN 20 NWWW WoWW WWWWr N. N. W .-N m A 01 N i L g g 0 0 0 0 0y�0 m u 9 LL�0OO ,fOW o, `0 ,m 4' Y N A e g 1 ,Z',4 8-. o E E t Z m m 0 o tO 43▪e OAO OXO Ogp O§p2 N W tI rZ 8n1g% �M W gg Iy�wn ONDASOOND VN Ops m W E§ON CO- W W W Of0 Ste',-Oi O,.MQtNO 0MMO)r Of�Q ra N n S to 'r Q SANmm SM % RUHR iRrig iiiii A sR RI Rs sots s 82 cO tO,O� � &5c J 00000 QQQQ 04QWW 00000 QQQQ QOOQO 04004 Q 0O0 0 00004 0000 00000 00 . . . . . . . , . , . . . . , . . . . , . . . , . . . . . , . . . . , I e §W rA W , I § !!! QEWrgqggW WW8 O n Vs� ON 000 000000000 NNPNO ..... NNNNN N U)N N N N N ..... N N 00000 00000 00000 00000 RO 0OO 00000 0000 0000000000 0000 OO C NO" hN 4,7,88° 8NQ00 hOAVS pr00)N A2VOM NOc0 WV0nO SS NNie; NaaY gss gWgosw mSS8SSgRRR saRsg � Etdrr v i1L7i^NI'E filn 0...0 .....a ..... 00.0. It)It)W UO .....N ..... .....yItU ) ) C Me 8ODr P48s W r .°22,7,S:= 263828 88c7,22 OASP z; OrSS V AON W O SS i SSS RAAAA AAAAA AAAAA AAARR �� RR RARss AR R °gg s 8a8888888SS 88888 8-8888 88888 8888 82888 88888 8888 8888 JaNSOVy MS01 .e(s;SA NhW0OASAAY0'U rWWSN 882'4'8 7EN 0OZO-N -OVN .M.-Qh . C - C-OfV 0NCQQ C)<th th 0 O<Q<N .- • r. wi M W�0WW �QyO WOppppQW NpOWNpMWW N Q mA r7ltO NWONNqNDOOU) y -IVt0D ON N �AA SOSr6 �. yS mONh OoQ C. W N t V W ^ n a r W n N O O N tOO t{yy 0)W M W M r Q Q A O t y (y C M Q N v EE Z cOOQt?. SCh .1tp QQSO N.21WWz V0V2 t0 W Oh O ftf VDV tttypy<1<ttthDhN 0th $f2 tt�0 Nts ttOh n NOI OOC?�tn �7'1" O V'9'9'9 v7 Mt?N N�m'r NthQ(D W �,-NN NNMMM aY J /w� o .. O fV t+f A (y ',,822 G (� tV O� W itN= NN j=8 N V.M8 t'�tW+W{ppp 6.88°V tOSN(NN!INS, N IMS,oO aySay POi Op Vy c718�'pp aO t'228 WM N 2 4 a,8222 C Eo O 000 N O)rNNOJ <SSODN )C) �1 N NNC)fhth 08 V ttf S tb,7,OO W O C)NNth O� E° �i9Uo < tN o . d v s m Z.O. F$,z° W x C N•o 2 N N M g $o 0853=M t0h C W o.-m .-No S Z m H O N 3 (y p W(y pp a G 000,")) W nt'Y)O SAQSN NOAC) �NIOA NO0O W W O)rfh W ONNOO) Or = O N n tD t0 W lh ((yy{I�p (pp 0000 ttyy ttOp OWp pWWp�� <R 8 ttpp �Vp y 9F Q OOC'U) OrNN< tntNOMrN 1NNN Nn-thQ QerH0* WAc0 W O O0tV < Ng Z 2 El- 1 0 5 °�a i' o u 3 E Q O 'E SO1.. V dN O wvryNZO U OAOOQAOOAy� Q M228 AN OIA NA W P-!;;4`,1 NQ nQ_pp ANn< M Z > UOOYY .VEQCRo 00000 U;<WQ 0 )ONOOW49W<< GpA2 ofLjoon. ,SON0 Jd Nn WFAQW287,W2 UM00 1WSQhN rr rm E0OyO.Cddt WW` u00dCC Z mZ ' u O K a c=c c c c V V A7 C o« 8ug+Cd y (% c , v ;oi; amN WNNpN2"w__ x rOSA S(ACQSAprhWMN,mrMNp OAy y x10 p v hyO > 0 CO 041... D 1- O-4gm p6646g ;F:4;; p7.ypppWgM -N A WMOhOu gWWWN NNZNNN NNN NN NN O 14. O S PNi888G R(ptt8.{D98p)a m2FVS A8,7,,St= nyS8t�888 matu°ppp22 oo UQ�4ASS`�S��6i tii1:5ttpS8 SGg S I "?"':=.1Q t h o V l0 too 1:-.M,.--- 8818%."Z S I,W 8 N oo O N N N M N NNN N N NNN N N N I g("4 W O O S tp8 2. 8.7.trp�N}M (Ny8 p2N pO 16.:118 A3 Me ti pN N(Oy tOA;O ttOp)pNp mtAp Np00� t0 tpa r r4 pA<t O� El, - N N ~ O W t0 t0g t0 tn0 W th lh NgfW0 A A A0(O OD W W WOO OWOO2D W O)g Al N (V g N NN O) CO iO t G E N.-.- N N N NNN N N NNN N N NNN N N NNN N L V o n n .08 _ <7 Lt m N a O A N O S d` U) N 0 N{W )10,0 C SNO W r W CNUA M«OS wwmmw )0)O)ON p7�w tMy tpr Mp OWOSSN pA prp SN r pN ph c� M t0 1 NN A o 66,-.-n Mth V 0(6 n:664N tC'rt^' rrNNN NMthth V Q V NSh sgplzm W g 4q lh IL] L a D 0 0\O - 2:-Q th N(pp(ty O E .IQ h h g h y N°OA N 'C)ZZod w O ZOOODOZMZ Z ZZoo Op pp p pp (� t� p W 2=SOONMS AO1Nps t{aN MQOQr OD{Sp{8sg go-pig aSNS58.00 qW MNtrp W W g WAN100 O8 O r.-N th Q 3 f0 A W M)0�0 N*4 W W I�*g W N M sr p 0 8 1,.S 0 .t0 N U)) D E d j ,- N N N NNN N N N N OND N f+ ttAh -2- ° O) 0. C m Q 6 u g le= W C W j m L C d 0 W EA-12-7,10 )(��/ r0 x YO O d J 2 d d .� c'/ o oa �= 5oo'�u m gt T) tamma9 00 E w w w 2 w E 3 > >o °O o o 0 E tu KUILLrOgma WHUJJUU' U K 28 s Imp. nN(��O(§y N W�mN N (N(��pgp N�ONAy}01 - e{0,O0, p0,W ON th"lip n V W N1�NO tp� NO„NmOO} t0D'4 Vf00 N OfN -C,Oi W m 8.N 7,,p OOOpD p2(tR F NNp N(g Lo�(RO�tpO� fB�OA 71 Qiscp ^ g� g vvNMM Z2:1- 88:VV-,, A,000 O)000� N {hM O�tD � E m CmAD m CCPD O�D O W W N N W WWN g§§g8 3 3 $ $ N NNN N N NNN N N NNN N N m m m m OCC m m m m m m 666 of of of of of 66666 66666 oiO1 Oi Oi O) of of C Qi of Oi O1 Oi O1 C C of Oi C of 66666 of of of of of 60;666 of of of of of C o)Oi oiOI e e e a eee e e eee e e e e e e e e e e e e e e e e e eee e e e e e a e eee a eve-v.4 e e O e e a eee e e eee e 4° 8:28 pp ��pp t� p p_ (y tp a_ mp��pp 1p� e} p� {1(p� ppp {tpp 9 a 8OO ..§.M E.gf.D (Ip�;�j O(W(y R ,(2.28Dmp0p0 0. 000AM 882288 2 N N N N�1tpp�EEE pO E2{fig 8 A A I8/V 2 NfaW 2g rzO pit--00 S X CAD fe�J A t7N x V(O�FRIAR m(0i 00 7. Ai:V. O N O D ERG22 0 17 M 0 M.M7 lh e V Q Q e Q N iA N N N f 0 fN0 t O A A A 1� C D REM,OAD O�D A Ol 0 0 0 0 0 .0. NNNNN N NNN N ..... NNNNN ..... N NNN N ..... NNNNN ..... NNNNN ..... NNNNN 666 A10 A OOOOO A 0 0 O O O O O A E A A E 66666 AAA1�y0A A AA A OCpO O O O OAA O O ciaa O O O O O O O O O O AN A AA AAAA AAAAA AAAAA CppENNQOt rO {{Oph OAE0N0rNyyy NNc< ,-a09pr ppOArNN� N,r.mA,-NN 'e.,,-.,-. VOO� mCD N0Op1111 D NOf ,c“R iOO) tJ IpFt , 2OvMMV p8 p22p W ,0 a4V00 < Va MI+ANV n ' A 2N 2NANW ASNCtO Qe 7NO 0§000 0002NNV 00 00000 NNN NNNNN 00000 NNNNN NNNNN NNNNN 00000 NNNNN ....0 NNNNN N IO N N N NNNNN N NNN N C YDINO. MOON. 884OCD NrrEt7 :2S8R 7 tNONOUN 88242 .�0r. mnIEOAG W 8C8 E8 ONION g8882 2228 V Lir Cp�0pp t1h0 CCpp yy.pCpp .. 1p�. Cop.m.m Cy�Dj eCVD Cp RRA �C0(pD.tmO.Cp.m Cmp.m ppb Opp. tV O Q�j �e+pf am p�.pmt. gg O {A{pgg O' A N NN M17t7 ti IO N tNOtOA A , ,F,$ RA AR R t+1t7A ARR R R§t7A R's.'Ol Ol NOl 0'� Ol m 0100 Z t7MM tAh t8h t87187M MM MMS lBhMMM l8h MMM�M MMMMM 333 08883 38828 88882 8888 3 88888 8838 32888 88888 8888 88338 88888 8033 288833 8a383828888 3388 83883 N N,-OM NN N28::-V°2 AaVOpAO..N AOa78 Nr0Npmp008 VYW00r 1844 pppVe0 28 0083 h0o0W 1036,-6 OO. CCCC GGGnn V1 ANOV GGO�O �OtVO . thtO(h N�� C 06646 O�,- Vf7 GtVOC � *-- • ,rm5�3cAi 822 W to mAm A3 G8N Nt8O.��E OWN tNNv 2::C2E c�W ON Imp,t2y W 888P fVyA lop,P.'2 W IAO tAMN, vv h m CE ION O82 VR VN-- O El VN 8 E E. 112 W GA g6 og--OGAIO W.E.W OVNf S I777 ONA 77D 1 71 NNNN6 Pa'N 'AS' 0-6' CS C7 M t.TTtm+�l0 ii/I- _ ”O V O IWu39 N In IAN "?,,,In IAO IA tD tO( � T44 2 E r 0 Q A v A N N tO t0 I D I. N l7 r l7 r .-g330, W C O N M 0 N E Ol E t 7 0 l7 t p NON N m E ONi A r -..?0g 10 A N a°i .(h IQi N lnh m.,-e IAD a . . .a. p�1+.33 pmt tppthh . ep.�,TIIp�g(�gyIpp. .y. tpp. (y{pOer. pp pp. .y yy. {pp. • NNN mGS" AA1O W 8 ONi8000 �tAONNN ..ZT V. I(i1 282 r ECD CND8 OOrN�MI N4NgN NNN2N 17 f7 I717M PAA-. e N N .GS" 2c2:2:': c�CAppDtNONCC(:VV O A°QNpII�0$NI�NtCOOIO+pp�� Om V ttEyy��tW <E4.888 YI�pp orcg8,7!-SS Oe tNO GESS W 88E8:2 88 GEO V O Ve Ie-E2 2e228E E8�c2 00 IP8 ,-..8; 8p V I8CCpp; m�tl(OI1(p�p�yyE8 L VIAD ACD OINNNN NNNNN NMMt+SM the gpl Is. < 0000 Re.Og og hN..N N Im0310 INOINOIO(Ds t0t0t80lOfE0 RoNaz i p IyOeV Nr NN t MI = N0 �o - 'AC N * 28 AWNNO G8N: p OOmN: Y2828 AGap3OtepO Oy0W8 N,ONpN 4882EOmN i ;; pNpmrnIOEAOO2N8pDOOVN0( m flp;^ V IGIGtIAlAgFmO'4rt00oONNQ NNNNN hh2h A 788 CCeeO Oeeee e3A2NNONN O30N0 OOO O�OAA EPA" 4pQF O 0.E 1 3 5 sNm N�SS N.88;E:2 OENpp V 2884' m8<' eO0N20Ip 0I0 828' 2p m -OV e8N3 '"'"-"2"-"II.O� yy0.W NN. Av. -.No, < N� 7 AN Z G . p C0 $ V V lNRxOvN' 3E2Npr$NN<NNoo ttv� 77ae NN NN Nhi7 8% AO< <0VVVA SOVRN NN8 sNOO OpAO n VW Q. 00 VV wC1,7pCp�N�� ;p,:-i h fg:f i?z,R.1C01p0o Qom MII[0 wq,',r cr? NO tw?.! mO N N fit,t1(�h7Rm ON Om m O0 v0 NANO INo�IO01. e1'v057ItaA071t0 C4 t.. V II.?I.R IY0��O0IO(IOO m .00A0 i,q ,1 ~ N N tV N NNN tV dill t7 t7 N th M c7 HOB O l7 th th M M l+f t7 t7 e7 17 17 17 t7 t7 t7 Ih th t7 th 1 t7 th M N tN.�M th t7 th t+j M ' M f7 CN'f M„OCDN A V ON W NMmNCD 7IDONN (7.001, .NANO OOONe mmv r N 00m03m NW vrm OpNNE N18 W M. NOMI N IN00 RAE RREEE EEEg.R 82228 000.. ,,PRRR g4RR A gg A ,AAAA ,AAAA ggggg ggggg A RAE N N NNN N N !° ,88 E InO.N N OED.ODA Ol 3N E17180. A100.OND t2NNs10 NNMNr EA r3E 281882 ::88:=3 rn2e EM A 88G8D 80.102 I(I(OOpp {ppb .. .. {ppb Ip01 �pp�ppppppff.pp.pp. E NNN NNNe NNNNN NNNNN NN ER NNNNN NN N NN1717to MMMMM MMMMM ODAmmm mmmmN :1010,0 M M M M M MMM M M MMM M 8 � p p� C a r N W 88888 NNENO OO.Nr 000 V r O.st801A0 Gg1OCD 8E :28E G2:28 8N00AN 2488P: 84NO3 O V.Nh ... 88888 ....0 mm.Nn oE3w Cto.E. ....E ...Com m0m.m 0mm ALAS OpaWN ((� CEDNNOl OI R gN h V 4-.782E O8D W E12N {OrrN O 881888 V 01thN3 IAO ION IO vg-0.0 0-..:rth 180.E A 1010 INOOC'ICAD V 0e M30 r m IONtO 1A7 M.py1 t(O7yp Ily�y. Itch. [OpyD� p ty {p pp. p fpp Ip.Cp^p�.E fai IOO��f .(p,..tm7. tttVVV.p^p. (y p Ipp (ap_ m v:7..,..,,... O te4O Q e O IO s N N 0 N N 180 IO h 3 N tN0 t�0 t0 130 IO t0 t0 t0 t0 A,7 P.A R E.CD N m CD E3 OED CD CAD t0 8 2 0 2 N 0 N N N M i O g 0 0 U prn 822 N:11,28 88VfeR 8284 "82-8 Fro r90 ArS S $ Cq�m a7e �0i0... S�B�r ^�^ $e"G §'rn 2dQ�6 0 9?�N � r $m�� n- 8 t § r Fi �1yy MH Syy yy 3 NNNN NNNNN 00000 00102101AW x§ 00266660 66066 66666 60600 00606 60666 66666 SA�WmA WW �OIWWOI g§010 0010§§ 01010101 rn§rnrnol WI §§§§§ §mm§§ � 66000 m6606 00006 66666 66666 6666 0. vOYYO 44444 V <OdOVVV 000 V d4444.0 4V<O QV VV V 00 0.4 4 444-44 4 QV<VQO4OOV V V V VQQ<OO QpppeV QQ44444 0000 t E8v �p (((pppVmpppW$a 1G • Apy$ 8 ? ONaa10 (c°, yyyO pE( g108 -N/02 8 Z21 np0NSOVVVm8' NM P. AV 0SNNN 8717OT p 0Vy 0ypgOA J 22222 ry2222 00022 2%2222222SS22222222000 2220 0 00000 00000 0000 66666 OOOOOONOAO 66666 OOOOO 66666 OOA6O 66666 .66666OA000 OO6OO 000006 6 6 6O OOOO NANNN NANNAN NNNNNN Ca8,7.824hSV R2P-.28 NWrS; 8fli"NES 08482 rM28OSA8N4 8844E S24aN888 OrVrS 488p Qcgggg W Sgp pS N NNppS pSpSS popSS S0pSS SSpSpSSM VppVMS 0SpS p8SS0 pSpSS SS8a C ylA0uODN0V n0 4A°Rlry; OMnV',M O10�$ $,*. D O1D h CAD.O 11;• . S;84"4 O84V AO223 n,F8 M.9 O A 288* pa8§ 08 - p Y00 &1QNpyyyy1 88 Nry 08083 88ON N0 NARMNNNN 0RNSE yymAA 8mm88 SmRV F.1-4444 N'' V OAN o 0 7g.IOA. ' 7 00 W 7 v4.8.41888 8 RSDNM �AP.SR 288%4' O 8%V OmONA �vN22281 O 0- aAR.2 888P-'8 2000 MO--V MI-ON4- N Nn-M NO,-•-1- NONMN OOOn-O MMOOM .-04‘-00 On-Om-n- MN-N .n- N OCC 1- ON-‘-MN .0NO W e�1�.f(E�8 S A O SI �fNpp :1:11 tD� 2{S(�82A Oo8214�pp4 (Ay NCD.11 8(tS'48(S:2g aON'O RS tNp p4 psn So p.18418( ��fOOy22284 AOR 8p'p�2 <2,".22 G2,112 ��p1 t0 f08N (OQn n N^CJ COJ^ ^^^^^ CAD rS 888 2 188 822001 8E88 10888 10888 NOOE 00000 0000 2.gN777 77777 7777 w^mANNM 8A420 opffp. V.,.8:8 82822 8.7E ?N <g'228 10reS 00 W.TM SSAN '48::-SP. V x.288 g.°48841 V 884E2S N M80 § .,� gg 0em "Mn 2y0@ ,tgl0p .OQ ,* gynOISM �2 .7444v VO ON 2 OXGES 1 88 0, IZrASMnA 121,-,It A E Ev°1�7O2078 WNy E O�b28°,2,t G yA��2�f888 SA V AA .N}ONOtCCOOppD CCCOOOrg 1288 0 8',)NVVO1 n 01 8Rm�0 88 A8�pS RC2 C88 R A° :28714�P(App 14284 E'�{SSR U A N N A CO;-00 0 I W OCCO W 2828001 00008 0600 SG 00000 88,s'::::• 00 0�N V -CD-N N N N A 00 1882°4 CNODRSE 0]1717 m 4 =x0p 8Y8 4.8E4:: A22.8:= 2VO:= 00yy 0 0 88VAO SA8RS 1 2280„8 888 AV Sp 88 1°2128 2m 8 88 8 A8p 8 8 88 ' 4 MW NOE8- O0VVVRNN,i0oi,NN 6000V . OA0OONOOWAgFDADN0' AAArAisA0% m. A 00§0 0NT 0WsR NW8p0 0000_ ORO ,, Fv �, N NNSNp m82A M vc `a t 0 3 °E°'?".'""pp1-Q, 4011 OpD�O�+N1 �O{{0{tp§pO�V tO CDN MIS �00tOVOpp^O IO l+f 1O f0< OtD�10p0 oV fppOpp�t§71NCyJ 00(017{0pp tp�p t(Oyp 1AO p�� (O�n<OOO I�fy7 0ty7 yn p�N 1Cy��Hy7 VO W ' co N AA OCAD, R-58E82 888882 C28E§o01 00008 Wgg.00 00000 §8g.9.:: '-'',24'42, NMaN0 I�CDOINN NNNN NNN17 th t7 Ra',q g EpO N<t W Sa<aI0 V0 :2E0p0 t80 {1177ptSE1001Irz 8:22882i�( i�(} AANO 1(2121AO V 11001OOa2S 11G81Np�(m�p({§gyp {RpO(�(8O1.11 f11E 8:t.°:4:2 N8IGNO R1(�OMVyOD Mi�(8 ONWW 41401181(8y0 H 1(J 1x801pA�IOyOp OOj N<<010 Ann lO 1017M1717 017171717 A17171717 017INMOt70 l7 M M CN,)M 1717 A 1717 nA A 17 M CMJ CMJ8 MM M2 MM0 0171717 M t7[7 l7(+f O�MOO((O77MM MMMMM M §N_�gc4 , 178 NN1r0 000-1§7 x-00.0 0.Of•-AM N-NNN V W W NWOO 0O W iOQ W CDWm{0 1-00410,- O1§ONNA NlOA�m NmAM O AAAAR .AAAA .AAAA .AAAA .AAAA .AAAA .AAAA cF §§ § .AAAA .AAAA .AAAA AAAA 2°E28S 82 901�1y01- 64460 1(81(y�18 .V i0N120.0 O1(myyoiciRRNp 8 8888m 88R2.1.R(y(( (( ((S(PI(NE(S�S. 28881 82:21:2 S ppR°r.°ED 4481 120,120.212 OO2 G 10001.081�p8 O(pOy1CMD CpF2 E (7(71(7 f7{+1 1ht717RM CICNJCNJCNJtN7 M171717t7 MMMMM M(7 t7CJ17 t7(7CJ 1717 CJt7 t7 l7CC PJt+f(781(7) F117t7t7N N NNNN NRNCV N NNNN y �p p t Cp�O CJ p 11yy§§ pp {{pp 11++11 o 11yy 11OO pppppp C EO§<A O1�§N§O: 0t9901� V NON Irn Nf7I CDN Fi,`i lA5 V O:r90� NOi 8O M10r 1ON O:9A0 RON O(0 1 ;3880 O(.g8.1 o'1S$S§r �m8Nr9 m $O9rn mma'lFn'S $'��$ $$$§ ��me$ �w�09$$ $'$$Sg2. 1 ! �'�1Nss Smmmm O9o109� $09�� '1E884.82. (q8y V Me IO7t«v 8GI:MG yp022ES E 101r0�2r�0§pp f1zi,ltg1 JAG,• QO.pW.t �fRy71C222�t2 �§8'CD8 28'4R:= O'4 pW t:= N r0 p0R n�8+8ERRp V 148901•0 X1;.7. O W 8a. 00000 OOO R 17g06-4 10 N$' -.-,W,'; JA G,, N N Nt7M (7f7N 17 �'O'l? V V O O O .4 S,G 221 SS i[1 1 1 7 g i O f r 4 0 E 0 0 • NOW mo � O O' 222ON "gDO ' WVEO 2 s gCR Nn OmNW mglgA .-882V 'EA F mm pa gi in§i M3o NN ,J m; 0A s 0o0o AAC0 v 0, ,v ,,,,, 0,e,, v,-0, va0,0 „ ee tcF0rr0v m1� 2m253 MA gN 82 8 m NA0' = ANO0 NyNNn Noo772M SNAg. FA N _NOU F J � bNSgmmm I NRiHN NN h�N O 00000 OO00 O O O0 O O Q00000 O O O O N O p00000 �O O O O IZEVS �0000 • { to 2 -2 NNSNN m0) 228 m,g oO2N' 801282A4.t722 §N 2 22222 g§M Agggg sgsss 22222 2222 MI, 28224. VnA°reg� 882°°8 At882' 8tE2 )� NAno ',S-4 '44'8°8 1`4442 cr'g22 22°� a�'i 22222 XiX22 Jg0i NOOAO 2422GD POvON OgOaANl+)Ea'a 2828 00M .-6N.-46 '-Cl.-1V LV Cl<MNN ONNOLO NM.-4O 10N.-C r EN 22m8,17 °',-°2082c� 222;CI 22'1'228 `�4"422N 1822 7 g4gg 00 . o �'• 2N'gi``9d)`�” "?2" cg7i2NN ?422M4 n122 A LAA mamma . . . . . . . . . . . . . . . . . . . . . . . . . . . . . r N N N N N O 00000 t A A A A as a as p p .p m Qp ._ 00000 2E2 2'84 pp 8V18NALp 0 �r1y�NO 00)000 1EONN°D10 °°'te& p X$m V A,N W m ON0.410 g17f0'O 0Nmpapm Ng fpp gg,_ L mm m mm •.t•Qi W W N QQ f O h A h`1� O) m m t 1� E N N N N N C N 2 t` r$$$'M mmml°d2 2Ig°6g Egimm Lom�S8m mm8ig o 00099 m • mamma WY,$ , 00000 gEM 2MONO <ONLO2 °DSMNN g6-828 v N�NM 8280 LWT) 6 civil (p �p p (y p p cp p =rV O.- . O MMM Vr00 mO . c�l .c•-,0,NV GO AOV�y VNO oOp N�onp OmO op,C28 Q v ---- <V v N N1Nl)1010 i0 NN�NtD 101010v (O(^D LO LO L.ff 4a{)f Q =N 00 0.t y 0 3 ' o anaaa O EN mmmhl0 1p LOM NAWMN �{ M W MM°0 hi0m W A °)3333 ti 2 W�A 0 mh LO N �Np O).(,V 1GGNOOpp tm9p L?LO LONcgf2g OD 0o 10< 19 O.C4 CO m1011�Mj ~ 0 C7 CJ CJ 1p 1�N0oD0)00 O)N 10 10°I�°W� LMOg��g. NNtO 'ago T 2>-333TS ',1.1- 8 M M 2 M a e a v v v v v v v v 2 N 2 0 0 Z ”.9I mI mI P '. {1yy p y Ly p 1y p 1�a p p 1� rn 01N y N w m C EN 10100AVCO NNW 010 1010<1'00 c0�O0)W m 11')`tgD01 W< f0-s< fA 3 U g c2i°22AR na2AA AAAAA QMN 1"'422 Ai+ Agg Lgggg M MIMMMM M M M .�y L W « O: m a `48 o_ p ppQ�pp oG E = - E 2E2 88:482 O1Nh1SIR pNNNOr V mgEN RAISON V 8g2'.= 'y N A C O-2 .. W W F L4A AAAAA AAiAA AAAAAAAAAAAAA AAAA , 4° 000$ m B. y W t N 8 T W C _ {p 1p {p Ly y 2 1'n g a ` EV N V 2 V tO pA�NN1Iii y`� qN pCApp pN�Q g d Sei (�pOpM(� Cr')L2(Cpry1)N� tN1ppp�1a lV�ppp�tE ,Op tl� W j 1p j 0 Q Ti, E N o N N N 8i N N N N N N N N o N N N N N N N N N N N N N N N vR 4 1S CO f 1.:Z ` 9 d 0 Qa OS G CO CO O 0)) O= Q QQ¢Q Mit1 �. 0 W NhW 4. LL t 1`2 02;;E2pE2O288p2 2',W“3 ONyrWOFgWmm iommmSNNi mV0ON pMmm00ppN < Tm WWW J 15 1.0. C m,-m 0 In m U JW J< V C M o V 0 •oom 0 ' 1N0 pp (p L1yy a p N 21,;M Gtr -.ow.°D . OI°�o V.srI, 0 OV l"f CCO0 v V�v V N7AO f 10AON0 yy t9 �`Lr mg1$11Oo $ 1`cg§t9-� Rt r1r4 rP:1T,8gg" mm�A $2o v�mv<v Nm v �NOmm y N pp .C) O E0 G O N o W O Op 2 :=07,g a E w m m o Et o NM HORIZONTAL-OP17-02,1/2712011 10:29:24 AM MD(ftKB) TVD(ftKB) Incl(") Vertical schematic(actual) 25.9 3519.9 90.4 • . RKB;0.0-32.4;32.36;41/2;3.968;1.1 32.5 3,619.8 90.4 WI ,.-VETCO GRAY HANGER-MB247;32.434.3; 1.88;10 13/16;3.900;1-2 36.1 3 619.8 90.4 VETCO GRAY 95/8" CASING HANGER;36.0.38.6;2.66;96/8;8.745:3-1 ;i,' -TBG.X-0 PUP JT.;34.3.42.0;7.69;411'2;3.958;1.3 + . eer? Hanger;37.2-39.8;2.613;133/8;12.416;2.1 38.7 3,619.8 90.4 .n �11a VIT JT.4.6"X5.5";42.0.122.0;80.00;41/2;3.058;1-4 42.0 3,619.7 90.4 1,,,'CSG:37.1-161.0;123.92;20;18.250;1-1 ,.-TBG.X-O PUP JT.;122.0-123.4;1.42;41/2:3.958;1.5 123.4 3,619.2 90.4 CSG;39.8.2,162.4;2,122.56;133/8;12.415;2-2 , TUBING;123.4-2,566.3;2,431.91;41/2;3.958;1.6 1,749.7 3,607.8 90.4 Float Collar;2,162.4-2,163.8;1.42;133/8;12.415;2-3 2,163.7 3,604.9 90.4 :tom CSG;2,163.8.2,247.6;83.78;133/8;12.415;24 SHOE;2,247.6.2,249.5;1.91;13318;12.415;2.6 2,249.3 3504.3 90.4 TBG.PUP JT.;2,565.3.2,561.1;5.83;41/2;3.958;1-7 GLM-KBMG 4.5 X 1"STS-1 SV T•A2K;2,561.1.2,568.4;7.24;41/2;3.958;1.8 2,265.1 3,604.2 90.4 • TBG.PUP JT.;2,568.42,574.2;5.83;41/2;3.958;19 CSG;38.6-8,374.4;8,335.75;0 518;8.681;3-2 2,561.0 3,602.2 90.4 :. :s';'s* .%... TUBING;2,574.2-7,787.7:5,213.46;41/2;3.958;1-10 TBG.X-O PUP JT.;7,787.7-7,791.8;4.11;41/2;3.058;1-11 2,574.1 3,602.1 90.4 PRESSURE DISCHARGE SUB;7,791.8-7,794.2;2.38;41/2;0.000;1-12 SE. 7,791.7 3,565.6 90.4 TBG.X-O PUP JT.;7,794.2.7,798.3;4.11;4112;3.958;1.13 ' ' SE TUBING;7,798.3-7,840.8;42.50;4112;3.958;1.14 7,798.2 3565.6 90.4 TBG.X-OPUP JT.;7,840.8.7,850.7;9.90;41/2;3.958;1-15 EMI D TTC-X-O W/SCREEN INTAKE;7,850.7-7,861.1;10.47:5.67;0.000;1-16 7,850.7 3,565.2 UPPER SEAL SECTION GSB3-DB;7,861.1-7,868.0;6.89;5.13;0.000;1-17 all '...•:*:, LOWER SEAL SECTION GSB3•DB;7,868.0.7,874.9;6.89;5.13;0.000;1-18 7,868.1 3,565.1 90.4 - Nu MOTOR.126 HPMSP1.250;7,874.0.7,885.0;11.01;5.62:0.000;1-10 GAUGE HOUSING;7,885.9-7.888.6;2.67;41/2;0.000;1-20 7,885.8 3,565.0 90.4 - 11 I MOTOR CENTRALIZER;7,888.6-7,890.7;2.10;5.85;0.000;1-21 7890.7 3,565.0 90.4 ` 71 / SLZXP LINER HGR/PKR;8,246.6-8,266.5:20.97;51/2;4-1 XO,7"29#VAM 1-.P0-H8T BOXxS-112";8,266.5.8,268.0;1.45;5 112;4-2 8 266.4 3 562.3 90.4 SEAL BORE;8,268. ,272.5;4.50;5 1/243 ti 1 X0,5-1/2"HYDRIL 563 BOX x HYDRIL;8,272.6.8,276.1;3.66;5 1/2;4-4 8,272.6 3,562.3 90.4111 rBLANK LINER;8,276.1.8,484.4;208.23;51/2;45 ,/ CSG(Centralizer @ 10'f/FC on SR;8,374.4-8,417.9;43.51;9 5/8;8.681;3.3 $,374.3 3,561.6 90.4 J" / FLOAT COLLAR;8,417.9.8,419.4;1.49;9 5/8;8.681;34 CSG;8,410.48,460.7;41.29;9 5/8;8.681;3-5 8,419.3 3,561.3 90.4 f CSG(Centrtalizer @5'&8'f/shoe SR;8,460.7-8,603.7;43.03;95/8;8.681;3-6 ,--PUP JOINT,RESMAN TRACER SUB;8,484.4-8,407.0;12.58;5 1/2;46 8,484.3 3,560.8 90.4 ,, SHOE;8,543.7-8,505.8;1.90;10;3-7 8,503.6 3,560.7 90.4 SLOTTED LINER;8,407.0-9,444.0;947.00;5 1/2;4-7 1 HYDRILSWELL PACKER•BLANK;9,444.0-9,485.8:41.83;5 1/2;48 8,520.0 3,560.6 90.4 PUP JOINT,RESMAN TRACER SUB;9,485.8 9,498.4;12.61;5 1/2;49 SLOTTED LINER;9,498.410,961.1;1,462.74;51/2:4-10 9,485.9 3,554.5 89.0 1HYDRILSWELLPACKER-BLANK; 10,961.1-11,003.0;41.87;61/2;411 Is PUP JOINT,RESMAN TRACER SUB; 11,003.0.11,015.6:12.58;5 1/2;412 10,961.3 3,533.0 93.9 /SLOTTED LINER;11,016.6-11,771.1;755.48;51/2;4-13 11,015.4 3529.9 93.3 HYDRIL SWELL PACKER-BLANK;11,771.1-11,812.5;41.39;51/2;4-14 PUP JOINT,RESMAN TRACER SUB: 11,812.5-11,825.0;12.67;51/2:415 11,812.3 3,525.7 88.4 SLOTTED LINER;11,825.0.12,728.1:903.10;5 1/2:4-16 HYDRIL SWELL PACKER•BLANK;12,728.1.12,769.6;41.46;51/2;417 12,728.0 3,539.4 90.9 PUP JOINT,RESMAN TRACER SUB; 12,769.6.12,782.0:12.41;61/2;418 SLOTTED LINER;12,782.0-13,856.8;1,074.70;51/2;419 12,781.8 3,538.8 90.6 / HYDRIL SWELL PACKER-BLANK;13,856.8-13,897.0;41.14;61/2;420 PUP JOINT,RESMAN TRACER SUB;13,897.0-13,010.5;12.60;51/2:421 13,898.0 3,545.4 88.6 SLOTTED LINER;13,910.5-15,281.1;1,370.61;51/2:422 15,281.2 3528.4 92.9 HYDRIL SWELL;15,281.1.16,322.5;41.38;5 1/2;423 al PUP JOINT,HYDRIL521;15,322.5-15,335.0;12.53;51/2;4-24 15,335.0 3525.9 92.6 PUP JOINT.RESMAN TRACER SUB; 15,335.0.15,374.6;39.56;5 112;426 PUP JOINT,HYDRIL521;16,374.6-15,416.6;41.03;5 1/2;426 15,415.7 3,522.6 92.1 SLOTTED LINER;15,415.6-16,646.9;1,131.25;51/2;427 HYDRIL SWELL PACKER•BLANK;16,646.0-16,588.6:41.75;51/2;428 16,588.6 3,505.3 89.4 RESMAN TRACER;15,688.6-16,501.3;12.66;5 1/2;4-29 SLOTTED LINER;16,601.3-17,507.1;905.83;51/2;430 17,507.2 3,510.8 $7.7 SLOTTED LINER;17,507.1-18,028.1:521.04;5112:4-31 18,029.9 3,519.2 88.4 i SHOE;18,028.1.18,030.0;1.85;51/2;432 i SIOE, ic",\ LASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS P33HFAXONE3 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 (907)(907)276-7542279-1433 Marc D. Kuck Sr. Completion Engineer ENI US Operating Co. Inc. ( � 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP17-02 Sundry Number: 311-111 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel . Seamount, Jr. Y74 Chair DATED this day of April, 2011. Encl. Eni APR 0 4 20 Wks rid Gas Cana.C"...* '1/C8 CflOrege 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc D.Kuck Phone(907)865-3322 Email: Marc.Kuck@enipetroleum.com March 31,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP17-02 ESP Replacement Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP17-02. The well was originally completed on December 18, 2010 with an ESP completion. The ESP failed due to downhole i electrical issues on March 25, 2011. This sundry is for replacement of the ESP system to place the well back in operating condition.The estimated date for beginning this work is April 12,2011 . Please fmd attached for the review of the Commission forms 10-403 and supporting documentation If you have any questions or require further information,please contact me at 907-865-3322. Sincerely, Marc D.Kuck Sr. Completion Engineer c6.111 JqLI 4 RECEIVED STATE OF ALASKA APR 0 4 2O1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Masks Oil&Gas Cons.Commission 20 MC 25.280hnr•ror. 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool E Repair Well E • Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Development • Exploratory ❑ 210-125 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23431-00-00 . 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ OP17-02 - 9.Property Designation(Lease Number): 10.Field/Pool(s): / s 355024,373301, 391283. Nikaitchuq 6 , iLir44Ff , V4-i/ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): - Total Depth TVD(ft): - Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 18200 3523 18040 3522 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 154 20" 154 154 Surface 2249 13-3/8" 2249 2170 5,020 2,270 Intermediate 8505 9-5/8" 8505 3557 6,870 4,760 Production 9795 5-1/2" 18040 3519 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8505-18040 3557-3519 4-1/2" L-80 7888 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q X13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Development E Service ❑ 14.Estimated Date for 12-Apr-11 15.Well Status after proposed work: Commencing Operations: Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc D.Kuck Printed Name Marc D.Kuck Title Sr.Completion Engineer Signature ...z.... Phone 907 865-3322 Date//// COMMISSION USE ONLY J Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 -111 Plug Integrity ❑ BOP Test X Mechanical Integrity--re-,f- ,----- itTest ❑ Location Clearance ❑ Other: - ,3 SCO 'S4 50ha / S t- ..„. ers-60 (5,, Abi ...,1-..._ /..s-74— Subsequent Form Required: 16— Li r7 q !/ APPROVED BY Approved by: ¢' /// COMMISSIONER THE COMMISSION Date: DMS APR 0 8 �.1'-" \' `J'�� ...... ZL Form 10-403 Revised 1/2010 R I G 1111 i� 7� Y� 'hit in Duplicate 0‘•017�/ • o z t 6 ry A- '6 -I -I -I -I -I -I -I -I --' (n n C) n n l7 f) n f) �''. N w �. 5 -, a a, ID fD fD CD (1) ID -.I " . -a Nu) (WO o9. 0 a V) u) coED (.1) U)) (n (n CO v " a 1 C C C o C C C C =D p f) fn a- CT cr cr Cr Cr Cr Cr 0 K oo 5' CO*k *k *k *t tk *k *k *k p �*� V Ch N . W NJ /,, 00 cD N W fn Q1 0 cn 'LT ID 00 7.4 tD W ''Cr) O O 00 O W -a O O0 /.'. , Z\ IS ca) CO �� 1 a) . Li N N x op 1 ooKC'.nN � � Oa a) O 7 W 4, 7iii 0 vN p a) J - 5. C 7 Co -. N _CD u) Cn J Q -. !] (Q _ _ Cn c o _ p r CO00 _ cr. CD -I P CD N (/) p o 5 a) O a) -I w 3 O " - cQ 0) _ = U, (/� n 01 O� < W C o v K _. m -, .2. m m 0 N (no r (n u) o 5 fs � � 5' 73 v 5' co m co 2 m -a 0 v v -D ft p C v m a) CO x Cin CD 3Ca 5 CD n Z] • co 1 o Oo K n fn mo1 1111" : I- - III 1 N v * 5....1 * cp U) RI. 0 M irt W 0 D Wo Cl) -0 .• 9-.3 11 = y 0w � cn �� _ o73 rn UNo m H (fl p fp v � Q� p m G: cD c (fl •r•a co � , X 3 o m = ZO Q (D0 oa • r OP17-02 Workover - Additional Data Sheet Workover Objectives: • Objective of this workover is to pull the failed TTC-ESP tubing completion and run in with a new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. Well History: OP17-02 was originally completed by Eni Petroleum at Oliktok Point on December 18. 2010 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7888' MD. The well was started up for production on February 8, 2011. The well was operated for approximately 45 days when the ESP failed on March 25, 2011 due to an electrical fault with causes currently unknown. The well was shut down and restarted approximately 26 times during its operational period mainly due to facility shut-downs while starting up the new OPP production facility. The well was left with production fluid in the tubing and diesel cap in the inner annulus. BPV is currently not installed Pressure Data: This well is expected to have a static pressure of approximately 1600 psi (grad of—.45 at 3560 ft TVD)with an equivalent mud wt of 8.65 ppg. 8.8 ppg hot seawater with 3% KCI is planned as kill wt fluid for this workover. Operational Plan Summary: 1. MIRU Nabors 245E. 2. Shear GLM valve and circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to GLM to place pump at wireline reachable inclination. Rig up wireline and - pull tubing stop check valve. 5. Circulate out remaining production fluid through pump intake. 6. Continue POOH and LD ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, RILDS and test hanger. • 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. - 11. Pull BPV, install test plug and test tree. 12. Circulate Freeze protect through tree down IA taking returns up tubing. 13. Shut in well. 14. RDMO. • Schiumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No OP17-02/OP17-02PB1 Date Dispatched: 17-Dec-10 Installation/Rig Nabors 245E Dispatched By: Shailesh Prithani Data No Of Prints No of CDs OP017-02-Logs: 1 2 in MD 1 2inTVD 1 OP17-02PB1 -Logs 1 2 in MD 1 2 in TVD 1 /0-/0 j SO S A An c Received By: C-, Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan@enipetroleum.com LWD Log Delivery V2.1,03-06-06 CANRIG 301 EAST 92"°AVENUE,SUITE 2•ANCHORAGE,ALASKA 99515•(907)561-2465•FAx(907)561-2474 January 11, 2011 E0111005 Ms. Christine Mahnken AOGCC 333 West 7th Avenue Anchorage AK 99501 Re: Final DML Color Log Prints, Well Reports and Digital Data: Eni Petroleum, OP17-02 and OP17-02PB1, Nikaitchuq, North Slope Borough, Alaska Dear Christine: Enclosed with this letter is a replacement CD for the above referenced well. This CD has corrected LAS files for OP17-02 and OP17-02PB1. OP17-02 and OP17-02PB1 Description Final Digital Data on CD ROM (with Corrected LAS Files) 1 Most sincerely, 'Yt2 rC James R. Carson Alaska Division Manager Canrig Drilling Technology, Ltd. Rec ived by: ignature Title Date Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on Well: OP 17-02/Surface hole Oriented EOU Dimension Field: Nikaitchuq N Structure: Oliktok Point NoGo Region Anti-Collision rule used: Minor Risk-Se.aration Factor Date: August 17,2010 fD Z/p -/ZS North 350 `` 0 10 ... ....... r�� %fes• 20 -a>♦I �`• 4P02 33003.2)g1 'r 1��4,�i,,ur•n '? B2 c• , *Nib, APALAis, , •�i��r�_ ��320 , . ��.•4� ' `ejtl f 08 1PB1 P2 3,0 �♦Apre' m,IL. i1te��'41,4,401 ,4_,„tro,. ...„,,,.:,,, I�� I z p P03-P05PB2 300. �'vt i*`�,�I .. I, '", . 60 T 440,,,,„„4„,„,,,,,,,,,, . ♦. r J� 'e, / 106"L' ,,turailLV P05-06P B2 • (PS) ritirviigrsok741., ,llik 'IV 1 e .!; h.-- 4-ie'lh.4.•••'• - AD .� :.moi- 70 r� �i F !� �:,� L = <1 �l ;�;,� ; � -ter t,;.:-:t.-, -.,;. " *- 0 .ffe6at4RE14) 1:14-17104PetZli' ./fW '•';':.() /A_ g''4' -,l'''''::._.; « '9' 0114 80 280 IIIØlX11:til: k?421 X17.�� " 270 ltillIMIIII �_ 1'6>�" . n �� 90 - NNW n 7,?0,, i ° *� Off _., �i/ "\\ �v` tir�l�•.. 260 ♦♦ 5Ell //1111D o ♦ ♦ OW • ,Oo ° t. * 1s44.' i /inlay • •- w•giriffir * t 0 250 I.♦ 4.0° •`4,PAIIliattS•- 117 41NinipPAlkh.* 110 ,V*411240 �� . .�� alMae 0 lic ♦. 120 � 4.4kM/rid ♦♦I♦ ��N230 Tiri • ♦... 130 220 10 ••• ■■■••••♦• 140 210 ■■.01114110011r1 111 ,,50 20 .• 160 ■■ 190 180 170 Well Ticks Type: MD on OP17-02(P6) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 17-02/Intermediate Hole Oriented EOU Dimension Field: Nikaitchuq N Structure: Oliktok Point NoGo Region Anti-Collision rule used: - Minor Risk-Separation Factor Date: August 17,2010 North 350 0 10 340 =w=� 20 330 -� ��'`` 30 32041 20 '�! 19 0'-= 6 24 0 � `% 40 i,,�V10 - I �� 220 ``, , 310 �•';�'! , r� �� 200 �:� , 50 _;� '' �,,,,,��:�� 180 ��; ,` 30i• _ F`/IV , ...:� 160 �� , 60 ,,,,••.•�•� 120 4�140 `' � 290 ;,_i ,,,`,� �� ` 100 it",•♦��•. , 70 280it ''''6; .liet44.AttAt 60/�_4* 4**��S Ott 80 011ailitlealrai 111111iiiim ini 1 �-. o ;20 Arlt' ill___ �� 111 270 911111111111111131111111 "",1111■ ■� oQ ^`' ,` a �r ,,,1„ 90 'i1111 A 111111 260\1 'I 0 V` 41 gairiim fIvl%%a .iiI*4s% 400,, � o, ai4,4, im �u111 100 250 c',9' '�� ''+ .. �(` 11� �I,��,I 110 240 �� to ,1 2340 N 410441011 �,� 120 % KS 3 �� % !Imearilla ,a41141111111111.11110111�i� 140j 00 200 -.41111111141111111M111111111111111 160 190 180 170 Well Ticks Type: MD on OP17-02(P6) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=100.00 ft I Schlumberger 'TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 17-02/Production Hole Oriented EOU Dimension Field: Nikaitchuq Tf NoGo Region Anti-Collision rule used: Structure: Oliktok Point A- Date: August 17,2010 Minor Risk-Separation Factor North 350 0 10 340 w• � . 7�y�� 20 3�1al'`\ ` `Cae 30 320 �`�1,• .. `--/%/80 fi k .� 40 ,..01111111 of 310 ;:,•, 0�r 440 ------,:,1_ -'---.---/ f, /1lawri0 e` ;Awes* 400 50 `�r. �`_ �:�1,illiw360 / _ \A ,,, 300 ��. .��+�'`��/ 320 r • \ / \ 60 \:\ 70 290 ij/rl�! 3i==� r��`��i 240 .../ ` /Y� IairiV: ',..'..:'''*1a` 1'� `:*** 200 f `r /�r✓ \ '}✓ Ii/cam�� '�\\ �1 k` r' \ �� \ k ' i \ \ ._,,,,,—i a� t• IS 41 ,>(\ 160 r ! ;4\ 1/ 2so ;.�;..= \ +�:'4`►`��: '�+ 120 r ; �. 1 • �. t 80 Q0y�.:a � •�� ti• ' •i, A ( 2,‘„,_\„\-. ' yv .110i` 1 * •`• 40,'•► vA' --' 80 O , , 4 '__,A,,„..,_...\ iy intiltP- VVI 270 \ "7 �:4j►;! / �, 1 j i __ _.. 90 ' I i • . �► 444 i ' 260 ��• `\\\.t�� '•w� / O ti / 100 250 >4�[ iZi �'1;0 1 o° a / ! 110 4. 1': 1 11=��Ap! O� O� 240 , �.��► n: �.��K�r/ a'"" { o rn 120 `�:�`� ►:�� .11111 /r] f o 230'NI'',an!1,eL�1►'�1% ..4_,....--- _ --_`` e ` r' 130 d \�\r•fi _A--- .x; ' .tnt1L11Ur i--oir,,m,feallArditii iff 220 41411111111:1' 140 'WON:// 210 150 111 200 160 190 180 170 Well Ticks Type: MD on OP17-02(P6) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=200.00 ft SEAN PARNELL,GOVERNOR ALASKA OIL AND GASsiirma 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Maurizio Grandi FAX (907)276-7542 Well Operation Project Manager ENI US Operating Company, Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Undefined Oil Pool, OP17-02 ENI US Operating Company, Inc. Permit No: 210-125 Surface Location: 3156.3' FSL, 1653.9' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 1528' FSL, 4574' FEL, SEC. 25, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ENI US Operating Company, Inc. assumes the liability of any protest to the spacing exception that may occur. 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 3� day of September, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ' ` %V1 If FD AL A OIL AND GAS CONSERVATION COMM. ,ON ° r°� PERMIT TO DRILL :,H 0 ? ?0i 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑., , Service- Winj ❑ Single Zone [l , 51s,,Spesif if,v #Li opc(„s on Drill 2 ' Redrill El Stratigraphic Test ❑ Development-Gas El Service-Supply ❑ Multiple Zone ❑ Qoatte`'edeas n`hrate as 1 sSI0 Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ .,r;tt'-f•Sfile Gas ❑ 2.Operator Name: 5. Bond: Blanket 2 Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627' OP17-02 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 18534'' TVD: 3411' ' Nikaitchuq , 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3156.3 FSL 1653.9 FEL S5 T13N R9E UM ADL 355024,373301,391283' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: i 607 FSL 2068 FEL 31 T14N R9EUM ADL 417493 10/24/2010 • Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1528 FSL 4574 FEL 25 T14N R8EUM 1280 3'1 />bg_y.,i2 607'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.2 feet 15.Distance to Nearest Well Open Surface:x- 516626 • y- 6036509' Zone- 4 GL Elevation above MSL: 12 feet to Same Pool: 1180'East to OP-I2 16.Deviated wells: Kickoff depth: 350 feet ' 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1571 psig ' Surface: 1173 psig ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 2237 35 35 2272 2173 1210 sx 10.7#ASL,210 sx 12.5#Deeperete 12.25" 9-5/8" 47 L-80 BTCM 8415 33 33 8448 3565 yes;12.5#Deeperete / G65-5A IZ- 7•/SIo 8.5" 5.5" 17 L-80 DWC 10286 8248 3503 18534 3411 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 2 BOP Sketch Drilling Program Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑, Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 2 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maurizio Gr' "v randii Title Well Operation Project Manager l Signature 4"`-'�\d L4K• 1 Phone Date 4/12q4°11>1 Commission Use Only Permit to Drill API Number: ermit Appro See cover letter for other Number: /�� /Z`' 50-Oa"2-.f_31/ l J��_- Date: Q tq,) requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, s hydrates,or gas contained in shales: a Other: d 35vo /1st:, s c_ So P Samples req'd: Yes 1=1Nog Mud log req'd: Yes ❑ No 13" Z SCo V°S G Ain 7 j"fi, ( ) HZS measures: Yes❑ No['/ Directional svy req'd: Yes [r No ❑ Di,ve4er LJ•�J. L)e-t' e.--p/o•"0vei 20 AA c_ ZS"O3S 4)0) 7/30//6APPROVED BY THE COMMISSION DATE: . . ,COMMISSIONER 7/s•fd �4w.; ORG1NAL ! v.J•/0 Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate 09* Oliktok Point Nikaitchuq Field • n6 petroleum OP17-02 (P6) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 00 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res - Surface Cso Dir v 13-3/8" to Base Permafrost 1,823' 1,778' > 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning KOP:350' DLS: 1.5-4.5 deg/100' Hole Angle 36 13-3/8"Casing Point 2,272' 2,173' II 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 47 lbs/ft MW(ppg) Hole Cleaning i L-80,BTC-M 8.8-9.5 Torque&Drag Sail Angles: 80 degrees J N N "N"Sand Top 7,156' 3,388' a v v v m m o 0 IA m mw v v TOL 8,248' m 1D m m Hole Angle 88 9-5/8"Casing Point 8,448' 3,565' 12-1/4" 85"F LSND GR/RES Periscope/PWD Wellbore Stability Neutron/Density Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 17 lbs/ft MW(ppg) Xceed 675 L-80,DWC 8.8-9.0 (Geo-Steering) &hydril 521 5-1/2"Slotted Liner Hole Angle 89 TD/5-1/2"Lnr 18,536' 3,417' 8-1/2" 85"F MOBM C Petirolleum Emil 2n° Application for Permit to Drill OP17-02 Saved:26-Aug-10 Application for Permit to Drill Document Producer Well OP17-02 Table of Contents 1. Well Name 2 Requirements of 20 AA C 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AA C 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 6 Requirements of 20 AAC 25.005 (c)(10) 6 11.Seabed Condition Analysis 6 OP17-02 PERMIT Document.doc Page 1 of 7 Printed:26-Aug-10 r�` l� Enli• Petirolleuim 2n n Application for Permit to Drill OP17-02 Saved:26-Aug-10 Requirements of 20 AAC 25.005 (c)(11) 6 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 BOP and Diverter Configuration 7 Attachment 4 Cement Loads and CemCADE Summary 7 Attachment 5 Well Schematic 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: OP17-02 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3156.3 FSL 1653.9 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL Northings 603650927' Eastings: 516626.28' Pad Elevation 12'AMSL Location at Top of Productive Interval 607 FSL 2068 FEL 31 T14N R9EUM ("OA"Sand) OP17-02 PERMIT Document.doc Page 2 of 7 Printed:26-Aug-10 41111* • Eni Petirolleuim em Application for Permit to Drill OP 17-02 Saved:26-Aug-10 ASP Zone 4 NAB 27 Coordinates Measured Depth, RKB: 8448' Northings: 6039228.02' Eastings:510919.02' Total Vertical Depth, RKB: 3565' Total Vertical Depth, SS: 3513' Location at Total Depth 1528 FSL 4574 FEL 25 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 18533' Northings: 6045422 Eastings: 503264' Total Vertical Depth, RKB: 3411' Total Vertical Depth, 55: 3358' • Please see Attachment 7: Surface Platt and (0)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.44 psi/ft, or 8.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3554 ft TVD)(0.44 - 0.11 psi/ft) = 1,173 psi (B)data on potential gas zones; OP17-02 PERMIT Document.doc Page 3 of 7 Printed:26-Aug-10 00.00s • Eni Petirolleum 2n o Application for Permit to Drill OP17-02 Saved:26-Aug-10 The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(1) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X-65 Welded 120 36/ 36 120'/ 120' Cemented to surface Cemented to Surface with 1210 sx 10.7#ASLite Lead Yield 2.33 cu. Ft./sk, 13-3/8 16 68 L80 BTC 2273' 35 / 35 2408'/ 2173' 210 sx 12.5# DeepCRETE Tail Yield 1.54 cu.ft./sk Cement Top planned @ 6656'MD Cemented w/„5.7-8't-x 12.5# G°fSK 9-5/8 12-1/4 47 L-80 BTCM 8415' 33/ 33 8617'/ 3801' DeepCRETE Yield 1.54 cu.ft./sk 8-1/2"OA 5-1/2 Sand 17 L-80 DWC 10288' 8248'/ 3503' 18536'/ 3417' Slotted Liner-no cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration OP17-02 PERMIT Document.doc Page 4 of 7 Printed:26-Aug-10 Enli � 2n� Application for Permit to Drill OP 17-02 Saved:26-Aug-10 A 21-1/4", 2000 psi diverter with a 16"diameter diverter line and valve will be the diverter system used for drilling the surface hole. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point • Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Lateral Mud Program (Ml VersaPro LS Mineral (V 314 Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.0-9.3 Density(ppg) 8.8 - 9.5 Plastic Viscostiy Funnel Viscosity (CP) 15-25 (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15-20 (CP) 12 - 18 HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 sf) 200psi& 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical >600 Chlorides(mg/I) <500 Stability pH 9.0- 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(f) OP17-02 PERMIT Document.doc Page 5 of 7 Printed:26-Aug-10 • En Petirolleum ena Application for Permit to Drill OP17-02 Saved:26-Aug-10 Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. D;tied 1. Move in / rig up Nabors 245E. . • . . . - ." -• - - IF REQUIRED BY AOGCC) -and-funetien-test. .y r4""�� 2. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. - - --- :■ ' - ), install and test wellhead to 5000 PSI. • 5. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. '. 7. PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. • 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording - results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. , OP17-02 PERMIT Document.doc Page 6 of 7 Printed:26-Aug-10 �i st • Enil Petirolleum 2n� Application for Permit to Drill OP17-02 Saved:26-Aug-10 11. Run and cement 9-5/8", 47# L80, BTC Mod casing. Pump cement and displace with mud, land casing hanger and bum plug. 12. Install 9-5/8" packoff and test to 5000 psi. 13. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. - /o BMs 15. PU 8-1/2" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 16. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording - results. 17. Directionally drill 8-1/2" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 18. PU and run 5-1/2"slotted liner to TD. 19. Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. 20. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 21. Nipple down BOP, nipple up tree and test. Pull BPV. 22. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 23. Set BPV and Move rig off. 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt OP17-02 PERMIT Document.doc Page 7 of 7 Printed:26-Aug-10 • 1 Eo `0 Wj^ m m m m 0 N O 7,d 0 0 M a M r N mm 0 O O d dm 74,127 N d 0 d m 1Mm m mm 0 rPNNNNN NNNNN -0i0mN NOpNN ANN W SEdO,E0)Nm OEM'OSb0 NE0')Om0) CO a- $$$$$ gg,ogg Imm lmo mo lmTm ee13 22e21No 2flmlo lum mums vmi uri uri $212.74 a mmmm m ..... .mmmm ..... mmmm. ..... mmmMm ..... 2 a C y M MOO N N N v r W n::5—.1,x 8 S N m S M N 2 O M N r N m r a I D M V 10 8.°28,1718. 0000 00000 000000000 rO N 8. i LC0i00 .6pMoEri0 601,:MM rMNGO WA00rigpb4NNhm.- p 0,` 0NSSm NOVVO QOIgs rn0. ddmmN N )mm mmmn nrroro • z SASS'S mmmmmmS SmmSmSS8SmmmmmmSmmmG • mmmmm mmmmm 00000 00000 mmm00 mopom mmmmm 0m0m0 N N 0 C Wr04 0(0 N O NOlyy r .,.-0.2.1gLT 0401 SSMS2 0 00010 00ib,2On (00('.b V MNO r O C Oi Oi G.- NaMdd Id MI�OIOi MMVia aaviv of 'rigti IdCdr� TiMrM N Q N N N N N N N N N N M S M M d d m m m m m m r r r 0 O To t K W • • Y C 0 N OC Ott a4 Y m �a Q Q Q V X W 1 0 0 0 N d 0 r ON N ^.j N 2 S S N INm r O 84,222 W 0 0 2 N M M N G 0 rm N 0 m M 0 m�NOCGCGG fVEVIV ENMMM MMMMM MMaaa as,;as adadd aUhNNC F2r EU 0 G pp = m 0 0 0 0 0 0 0 0 0 0 88888 8 8 100 m N N N N N 8 88888 00008 88888 J o •O m m m m m N 0 0 D O Z6.- E V l V lV M M V I MMM M M MOO O 66664 aapdd 44444 aaaaa CD z C. CD MI F" ggggg gmzr rc %Kr C,Km KKKKN rcrcrcM xe4 �rcwrc rcrcnarcrc•- m5E:2 mmmmm m2O— pNd co mma mmMda .4.7.,-N mMIDNO rN<M 0a EE 2 On N M t.i ".- 66'm.- '.-G OOi m 040404 to M oui h N N C .r a CD =z�A m m Y Y ;7-1 3E88888 OOONN ,0m0dm rMmm10 MMmmm mNOmm `N10dm NOnSO N ,0 d 0 O m m N r m M MOM m m m m 0 d O n q m 0 221 . 2. .t t N W"" 0000"009'? C C G G C O G O Y f E D m O l V10,;242S M O l m A0 8 M N N Nm b la V N O S n S I O q U t.00 N N O C �Nqr� � NNM�t? .hqd q,n ''':- .T cOO-NM r- M ~ 2- 2c93 r A a m E , O O rN Nrr N M.iU' z O/ cM p g .n p04 N 041 M C C N V N N W m m F O N 3 0 Z` O M;m 7'NOM8N 0400 42'.;12g( M0 m rm 7.7.82,% dM7mO ONmOM n GCC7Ni 1dGuiC To.-.,G MviMEDy IdCwil�a 66KrGuiMMId GrvmM a Z 77'' E?ggqq 11. MMdm O7��N NN[''ig2 Q Y O C O C.E S= -.« 3 r: a A9E > t Y Nd IaE•�mYw £ d 4 cg O 1.1 O d 0 O W C C C 50C « C d 2 V O O m M m O y 0 0 0 m M O m 0 m m m m N IIOp m p N m IO m 0 O O m 0 Y 8 O O Y y s g Y y C j 0I W E 000- d 10 d0.- 4N0MI- mdoo 0 Z.;.48.2.m 0 W OrmN O>mmMm MONmn O (Q my�. CC2yN O.Oyy 'rgm m GGCG'7 ""i's;' �1 NM" EC^SSM Nr OmN' :IMF, ERM HUE E{pY0)NOE Q N C i E� L U' S�a G C p d N N N N MM p0'OO m rnm 00�" 3 y O C O L mm14r_ o .V. T N u Y m 9�LL b�'i� O U v A Q m L C O O A gr.. o a f s A A _ m Y A O A y A O'C p Y ^L' a m>>Z�U)f Hf 8§2 mFJ 2 --- 0 11 C t SSS AT M 24.1NS gY O 4 RSSr .=6"011 Ng 33288'0; 7Sf4m 42,6;:42 P. 66666 � p Sa0a yO4q.8pNt1S OmmaO7' A.,-422 mggnn 0. NNNNN N N N N N N N N N N N M O n (2' m^ NOOOr nmOdM N m 0d Mm mOm N N m mm0 0 a m 0r0r- 0',22S21.4 mNNO N rnrrM r 9 NQNP 0mod0 g0oSV NBNN (00S0 000 NN" AaMO N0NN NNNNN NN0, 44 IL A 00 m rn m n°N . C❑O a=0 N "° "'" ° 00 88800 ?8a N♦ nM�'•O 2.'442 2,',;^r.:2 arbNY,m.a '0-,14.2:7.g rlimm':AN [_ Oggmro0�N aamrn 000'aM OiCOC OCN�tVS2Maa R 00m d ENNNNN NNN N0 ...co NNN0000NN NNN NNNNN O a NbrdV a _ AW _ m E n N.,;lD a 0 A N i l'C OOmO2. OmOn . d0 Opp OImmMN O0n0Y N ,00 mOrM0 rmN00 N 0 O N O O O r m r "0" 0 0 0 0 . 0 0.0 0 m m n N 0 N m�r-0 O D r h b ro 10 0 M MMM f.i omyAMne CGC-ty "0" 0400" '01'GC q ' AW.jl4� SgPI:g O E R N S V?m N N N NNN N M M d 442.%07, m m r n m N g5 `.^:- A M O n 0 E =a o 0 0 40 o Q o to W Z 0 0 0 soZ z z O C p^ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 8 0 0 0 g.”.,',3.8. 0 0 0 0 oro 0 0 0 0 0 0 O o 0 o n f O O O O O O O O O O S 0 0 0 0 O N O O O O O o m 0 0 0,0 O O O O O O O O O O o d 0 O m O m O m 0 0 §8.28,7, 0 0 0 O m 0 0 0 O O O O O 8888 O O O O O 8222t; O M d d N m m m r m O-'' ^'''m '0 0 0 0 NN M d N m r m 0 N C r• N N NNN N N NNN N M MMM M V z E 02 ii r oi W N C W Y o1,65--4 D.C., G6YJo T«. U '' N EmEACjLL it.:' (kJ ! " i 3 zN UUqc O S 8 O T z-, O V C S c E 2 t 'C [ValugumQaZ12UJJTU8 KU 6 ZU U0 0 0 o M 15- Erg mM AMY Oma e02f MM FORE, yO�trO.N OCDOfOS ApO�Sr ro W�Sp V AadDSNM 8888 8 (8020 A�AOr Oi�SN[O N E o r m O N O tM+1 8W N N O n•p Y M q W M h1pD {Np(,p A t m m E N r E O E aWD�Wtpp�Ntpp N1�O M M N W N M N 0 "22E )O M M )N r V d "4"r N N aOD W= rr W W 8 dQ NN.- OOO)00 00000 00000 OOSAM M0Oe>m OI mOI OMI AQI OOOOr MtD t0 W OD EMD OD 0W W 0W Mnnnn a CO o 0 0 0 0 0 8 N N N N o N N N o o N N o o O o O o 0 0 0 0 0 0 0 8 8 8 8 8 8 vI 8 2 8 N N N N N 4]41 8 8 8 N NNN N N N N N N N NNN N N W W 8 8 8 N N N N N N NNN N C_ 880 000 r,A.pp.p M G V8NNNNN a .41HUE 00g0 M2Oo9OoWh MOMNN�NO £ p� raCM WWMW WWWWW mmmmm 22 2 m2 2mmM. m2 004 00daS pyaMO NdddO dWM d WOOOO OOOWO 0000W 02 000 00000 00000 MMOWW WWWWO 000W0 OOOOO 00200 00000 a C S' 80i88 �20Q�tpp 22 222:12 227,88 (8OM��N Ma'Q,nrn rrrzg2 222PO ONMrA 121-(77,2 (OMM�N trtrrrM Wim. r Q 22222 22222 ;2;gotw g;t22m mm Zmm mmmMM m WW mem mroErD EnDEWD mm2mm 222E% [it,>22 MMmmm w N c t 0a w p p a C Y 00000 NMBnm NNNNN -meg 77PAA M MtnO<0N 44444 42231 NN)(OO M tD 223[32 220 -NN Nrrrr O C 106)01010 630)000 0 t0t0 108 t0000 610000 100 0)010 06)010(0 01000 t0 010(000 010010/0 00000 0)01045)0 d r O � 8 0 0 88888 '000$88 88888 88888 88888 88888 mu 00000088 '08'0'08 88888 um 0 SSS O O O G O V<O Y d O N N H N tV N N !nun N N O N N lV O lV lV lV G lV lV N lV G fV N lV C EV N N O NNN O N N N N N N HON N fV G N N N N A V KK w.wwK wx(tw.8 ) ac K d'O-'O)JJ M2 nM Nn W NJMQapdUJJJ WQmw. 440 xx N0pN2 =^OIM dm288 =n22= 00=82 fAJJJ(q ::::: 0 r r r NEOOD MttppO W N d 0 W W O W ON W 80 W :: ::: :::: :: Wdpp 8O 2.74,!*P; mNt QM. dM B NOMNMMOgneWOM2tWOiONON NMNs '02W aa02NN 48 NNMM $nr� MNNNN 22D WaNN .2Y)2 addn4NB . nhTW4qvTV/VT qq4qW omoWW orrrrr /Nn maDmWm O. 0 N O �O Wn nM r d O O M 8 F012. 2 m dAN 8 M N d MM m n M W 0 8 W 2;42 N N S174:,=.71% OO W�NO W °-!g4.41. WWya IN r V NrWO 2,1:OM QO 4 ; 22 PNCO 02 , 2 thOI0n C008W nV2 ;; 8t0n0MM NNNNN NNNNN MMMMM MM� (M MM5O0 00444 4000)0 222202 NNN00 WO022 Oh O a 0 r '!! 8C ',;.21e!2,1 n td222,1:7. .Qa♦7,0 pp n m 8NN 4222:2 2:2428 W rr 210221°;= 2 AN m a0 32,T;-.2 O2ro M 1v1588trNOMa W2;77,0 M8222 E�N880MMMM Y-7,221 22t;22 88p80 88222 28/255 n rrrn nrMmm WDM22 MMMMM 22288 80a08 00000 QYQ N pp E NNM mNM,OO'NnQM - 0)0 W Q P2.7-".2, "O O NC ON2M 200)0 0 ;..1102.2.2 2 0) U)0♦ N 0N 0 N0 0)3) 0 'IL--24 2'6,12 4j2t;2O Ih.'328gOO'-NH6-02 IV222260 22.%NI.A 223:; 0 2W2a RIW 20 2 EC2OO -8 V87,C QA22 M82M88 :1MMMM 222MM ppMM1OtO :MMMM MMMMM MMMMM MMMMM 222 :7',74,1,17,MVMO g C O r00A 2888 N 1 81;p10;100 82880 8 8 8y 8 8 aNtWWWO�:88 OtdOMOIEMD 22228 17).2222 ).2 2001 OI 2V,822 ISN Q m W N dl�r PC m t^MO Mg OWD Omi O��r 1ry`N V N M MMM V V Mc9MM8 MOO i[IN NNN N NN�(OJN OON WQM END ORM MtnO tr0 20222 M MMM M M MMM M M M g M M N MMM M M M M 120 NM M M MMM M M MMM M M MMM M M MMM M M MMM M M MMM M ! 2— 8882 £.8822 82;28 888222 8888 88 47!:; 2 -,, 12800818 A A 00� 82800 8822-s s --W W M M 00202 r W m O O NNO 0102 Opal W Oi0)0 E8p1y 0i 0)00)0) 00 828 8 CNCOO N 888 CCOOC E NNN)0M MM MMM MMMM MMMMM 2220)0 MMMM. 2220)0 t�)t+)000N M MMMM MMOt1029 MN0N9029M MMMMM CC m 7,^'N 8 8 8 8 8 N 8 W O 2 8 O W N O W 0Wmm2 O22;2 8W42 WW5W5W8W0WW 22222 88888 NNm228 8M 8A 8OO 8OO 8OO 2Om 2dm 2N8 2N8 200 Ntm0g NNg NNgoN.2 225;2 25;2 1E 28888 8nn S8 8888.t! 228088 1882Ntp8pf 8(50228 82228. <MM81M0 28888 18.°22.8 8021288 18285 2800 88 �8 882ON OM NM Em0 O0i 029 M 88888 8OM Md n N W m N NM MMM EmD O0i OniMM O Qm W 0 58884 O MOO Onn W Or pp p as n n n n n n n n W 00 W W W W M W M M W W W W W m m m M 0 OWi m 0 0 0 0 0 0 0 0 0 0 N N N NNN N O O N y 00 O L 00 O O O O O O O O O O m to = t u� t� t� 20.- 20 Zo t o Zo Zo t to > OI E a O a 0 A O A - O A N O N M O 0 N d 0 A W 0 A cou N n 0o V A m O N 0 0 2 c2 2 t t 't s, Etat 'ts�e 8tsI cts 2 t s2t 2ts, vtsl ctrl 2 'c 0 0 .0 r W of 0 0)0 I- .UH 0Uf-- rw0 H .0E- WON W01- W Q M O T— T M W O O 42222 0101000 8.18 N OnNM 01001 aa8O 2 N o O d 28281 4bnOdN O M aNNMMMN5008ro nVCN' NbndOTr8Mwr OrNfAN« M O W NN10 N m0088101010E8E8n N1N00 0N88 810g 81010210 10 d 2 0 _ p pU) C N E M.8 E N O Y 2 2 n.8 E V 2 ;42'.'28 T.2 2 lg r 82228 a888 M N N 8 T 17>822 8 Y C ((p W g Nyy PONGC �N�pp;;gN ,t.Nn� Nt00�O) 01010100 OM ggg ed]M vg,r;; wArrO RI O M M M M M M MMM M M MMM M d d d 0 424 4 4 4 4 4 4 y 2 y b ;::2:: d d0 0 0 0 0 0 3 3 0o Obb bb b b b b b b b�ppM MO A m V N M M N M 22 22222 2 W Nd C O CY O d ;a K W 1. 11P-P-222 22282 28222 8 T N T 5 22222 O O O O O 82622 88 ; 'V V V V o'" oueoo 6.... Iri eui coIu (0(0(0Icro (0ro lc)cr rrrr•:nnnn 2222E r..:,-r�r n Zi 63 E a 2,188888 88888 88888 88888 88888 8888880 88888 88888 88888 8 0. 8 8 0 0 8 0 0 0 0 10 O O Q O 0040101(4 (111)0011) 0101040401 (1100101114 N(J N N O 010101001 ('11)001111 041500.104 010010101 O aaaa t 10000 gn n n n aaaa LL c JJJJyJ J N J J J J J J J J f D J J^i rn E J N K U2'4', R'N J N J J J N 1'K K N J J J N p ~.... �OONN 1020)20 Orrr W 28�nd dn,28 ��22' SNNN 10221010 2a MS O OOOU x010p • f V l V M n r O M L N N N N N • d apN N 0 V O f V l V NNN N 2222 2 2 2 Ip Ip • • MMMM M TNT TTT TTp p0 N Err 222 NNN = 0000 CNbIdD �« m 2222 x'888 N 0000 W'n,10 ri a 0 0 N O T n M2 MN 0 WmNr T8NTOe-n Orb2O 42.2dM MMT TNbTb NNMNM dnMn ro. iNN gMOrr 20d22 !!10!0 ! 2'4MNrMOOOOT -V- m0042ON2! 000 NONO-.EE .-66.,4 NM � 8f� ANb2 Ob0n rnN82r rr,BT MM N ' N '222E dNLOOc2 NO O N TnNT 7 g W MM;VO NOVO822117.2S 8822; 2d842 2212b nTMT 120 '22 N Q3 O o gQQ MNDiTt-' N"dg IV7lVNN gIUM Cg1iNDnG10N80CyNNG aCIhg2,2,- ".;741;6 ; ia2 a ( 0071+ + YLQOT0 2NTr 2T0c NnMN 4273d AAMMa1 22O4n 2deOO gNi 8 g 06 Y r c��33 0J m gI g1 Y N N DJ N N z Q"` N M M N M N d T M N T O M N M b NNN O N N M b N MO M N O M M O b'N O d T N N, O 1 Z O MN TaaD O ,4! M FO d T npN�pMp rr �N,s ,s. NMT 10288 E b�0 aD NM d d N ~ ed+)panp d O Y MI5 pnp V<a ra O V V�y W a n ad,)yn<V V y p y g RPM v i T A Oni MTM i ELM a a O 'i MMM M I h�M M[7 M M M M f 7 1RRRA M M M M a') M M M M M M MMM M M MMM M E M M N M r E T NKaNbMNMNN TDpp2N NM 2.2)712.81 82 88E 2..7 -.. 888 bn88 8 ,� Q AyMMM NNNNN ,N NNn--00 00027 l22Mr PA022 4M2, NNNN N n Ayyyaa yMMMy MMMdM MMMMd MyyMMM MMMMM MMMMM MayMa MMMMM M N W O D N `j6CN b T^n MNM ;-,.42.2. d210 2'N O N N10102NhNMC rdd, d a U r7 E MmMN M REM, C0CNN N NN MAR MAR NVNN NNN N Q C00005LV � N5 fL .4,3 LL 8888 (pzt8 Q O d,-. pp (�(y'87,.4. W aL.,7,!1 0 8 8 8 8 8 °2.1111 N 2 6-.888.8 r2-r r 8'a 8.1-'2.8c N 88282 8MM 8 8 8 2 2 0 N N M O O 4 G M LL a 0 0 0 pN r 2 2 2 27,;;;2 2 N 2 2 2 2; 2 22 2 2 2 2 2 8 2 8 r O n T T T N N T TNT T ;72;22 OOf T T T T T T T T T I N T T T T M MMM M M M M M M y N N ce NNd N M N LL N EMN- 2C 282Go,8 822888,888 42882 88822 ,'48282 882228928 828 4288'4 aro gr8828 tlii 22282 88888 88888 88882 88825 M O N T B 88888 88888 28888 M 0 6.64cV WC S m O 22228 88882 44824 2 88222 88888 822(08 33222 22222 22222 2 f ONq1 Tp N N NH ewTo e J p fELLso8210 d t c i 842 e I, o 0 8 O 0 8 0 O 2� 2� 2� 210 20 2 ' r�. m EN o 2, m U N V U N 0.5V 09 () M o9 U O p C_ 2 2 s 80 82 s '828 '20, 0s 82'10) ' 0 .? O 0 H WO f WO F WO I- WUf WOF W0H W0f W f N4) 0 o o co r) E "ii , S Q o o 7 o co co U) co .,-- 0 <-4 ci z. 0, i o o o o o o o o c.) o 9-- 8 z 3 ; 1 a .- 01 CO 0 n 0 in 12 W Ec. 0 o o 0 g . o o Tr 2 cr st CD i i 8 a lz MN 1.:I ci tp a g o 2=1 c o t. 0 .. 0 . cc, 1 r 0 E CL t t o 0 y, u 15 w 1 t w u = -1C . 0 al la= 0 E el CD '-. 0 a S.S. .. 0 G2 = f 8 ..1 .- 01 CO r- ....... Z .,- E i f. 0 0 0 11-1 0 c) s ii c E g ti i S 0 u" oi 2 u '4 t •'ca — — ci o a cC ii 0 0 .0 0,1 e4 , .. ...., ........... a CD •C... (NI 0 114 0 I.- 0.1 LS"',.•! '&7.. .:-:... :7.... e C3 .. .. 2 CO 02 o o 03 a) 2 co e 1 = I A o o o co S 5 II 2 E 0 0 0 0" 'LE 0 :'-' 0-) m <NI -1C , 015'8 g E ei .ia g P.A' co 02 w a c o o.• <L. o -z °A II co o) C- 2 g i!,, co t 9 t E c.) 5 a) T Li l'i 3 <1 z t u) — — 0 a -..... 0 To . o ... o cc . .g a o --- 'E CV 0.1 c it''g 2 s) 0 a) 5 > fi 2 1 a) u CO 0 o ra .c?r au (..) co v 2 c 2 to .r LIJ 0 0 > MI .61 0 I- o 1, o I' o •-• u ,- 0 1•= ii,-,-,',.,i ii .., z ,.- [ 4 c 0 - Zs. ..5. - 2 . o 0 1 2 o a o g 1 5 5 :4 Cs/ Csl 0 0 0 I.- 0 0 0 .5 •- z LI: a. o 0 g Q f.,' . ..- , , . . . 0 0 o o 0 0 o o 0 :, g 0 CA CO a a 0 5 0 o O .: 0 ti 0 0 ..?, S •. 1 Lil CO • 7 ,- (4)0001.:(1101. =ale°S ani 0 0 CO (4)0oz1.:(u!)[=9180s cvu_ E CoO =o o d o N | kei k ( ; o , . 4, CID _ § L k�� 6u CID H . ! -f \ - f \ W 0 CODt - O _ li / }}} a : : 00 /\\ ; A »\! § WO _ � , Z w /)! a /to• / . !� /° 0 / ! ' a = = o !§; ,! ,;§ ! ° cv §§\ : ` kms ,;/ t ! / �! ! , 2 2 ! !§! o u o ! . 3 § § m f o ; a. E2 U 0 7 ' , a z | . , ! v , , 2 • ° )��! ƒ . • ; E $ �& •a ! ,r, ' 3 !ti ' E / 0,t ! _� • 2 +& 2 / 8. -k w::\ | 'C `\ (»! / - w {-P � N g 1 / ( . • a 14 \ E e\ (/ p ° ! § f! < N U002a6=9120SS »> • 2n A OP17-02(P6)Proposal Report Schlumberger (Non-Def Plan) Report Date: August 17,2010-03:14 PM Survey I DLS Computation: Minimum Curvature/Lubinski Client: ENI �M7�I(��1471� Vertical Section Azimuth: 303.832°(True North) Field: Nkaitchug ction Origin: a=it.o.oao 8 atum: Rotary Table Well:Structure/Slat: Pont/OP77 O oo o[J1 V as TVDVD RefeVertical Reference Elevation: 53.200ft above MSL Borehole: OP17-02 ��j(�3s6C� Seabed l G round Elevation: 12.200 n above MSL 608. 50029noore Magnetic Declination: 21.767' Survey Name: OP17-02(P6) Total Field Strength: 57724.808 nT Survey Date: August 17,2010 Magnetic Dip Angle: 80.937° Tort 1 AHD IDDI I ERD Ratio: 174.110°116519.201 ft/7.169I4.573 Declination Date: September 02,2010 Grid Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet Magnetic Declination Model: BOOM 2010 Location Lot!Long: N 70 30'39.35735,W 149°51'50.20999" North Reference: True North Location Grid NIE YIX: N 6036509.370 6US,E 516626.2806US Grid Correction: 0.000° Grid Convergence Angle: 0.12825768° Total Con Mag North>True North: 21.767° Grid Seale Factor: 0.99990031 Local Coord Releren[ed To: Well Heed Exclusion Zone MD IMI Azlm True TVDSS TVD VSEL NS EW TF DLS Directional Exclusion Zone Northing Fasting Comments (8) (1 1°I (8) (ft) Inl (ft) go1°I 1°1100111 amoohy unsex Alert A"?;1 (nufi) (NUS) RTE 0.00 0.00 180.00 5320 0.00 0.00 0.00 0.00 180M N/A 000 Alert 9.01 6036508.37 516626.28 Cm 1.5/100 350.00 0.00 180.00 296.80 350.00 0.00 0.00 0.00 180M 0.00 0.00 Alert 9.01 6036509.37 51662628 400.00 0.75 180.00 346.80 400.00 -0.18 -0.33 0.00 180M 1.50 0.00 Alert 9.71 6036509.04 516626.28 Cry2.5/100 450.00 1.50 180.00 396.79 449.99 -0.73 -1.31 0.00 180M 1.50 0.29 (0.42 6036508.06 51662628 500.00 2.75 180.00 446.75 499.95 -1.76 -3.16 0.00 180M 2.50 0.94 11.61 6036506.21 516626.29 550.00 4.00 180.00 496.67 549.87 -3.40 -6.11 0.00 180M 2.50 1.39 12.81 6036503.26 516626.29 600.00 5.25 180.00 546.50 599.70 -5.64 -10.14 0.00 HS 2.50 1.73 1402 6036499.23 516626.30 Cry 31100 650.00 6.50 180.00 596.24 64944 -8.49 -15.26 0.00 117.076 2.50 2.00 1524 603649412 516626.31 700.00 5.97 19296 645.94 699.14 -11.00 -25.62 -0.58 104.196 3.00 2.22 14.94 6036488.75 516625.74 800.00 5.98 222.08 74542 798.62 -12.10 -29.56 -5.24 75.21R 3.00 2.53 1476 6036479.80 516621.10 Gyro Pt 900.00 7.34 245.40 844.76 897.96 -8.01 -36.09 -11.55 52.050 3.00 2.77 15.17 6036473.25 516611.81 1000.00 9.49 259.90 943.69 99699 128 4020 -28.48 3776 3.00 2.99 16.13 6036469.11 516597.89 1100.00 12.00 268.75 1041.94 109514 1573 -41.87 -46.99 29R 3.00 3.18 17.54 6036467.40 5165579.39 1200.00 14.70 274.49 1139.23 1192.43 3530 41.10 -70.04 23.41R 3.00 3.36 19.31 6036468.12 516556.34 1211.00 15.00 275.00 114986 120306 3776 40.87 -7285 15R 3.00 3.38 19.52 6036468.34 516553.53 1300.00 17.59 277.29 1235.28 1288.48 59.89 -3816 -97.67 12815 3.00 3.52 21.59 6036471.00 516528.71 Cry 0.5/100 1368.29 19.59 278.64 1300.00 1353.20 79.48 36.13 -119.23 15R 3.0D 362 23.25 6036473.98 516507.15 1400.00 19.75 278.76 1329.86 1363.06 89.15 33.51 -129.78 14896 0.50 3.66 23.37 6036475.57 516496.59 1500.00 20.23 27913 1423.84 1477.04 120.16 -28.19 -16355 14546 0.50 3.75 23.77 6036480.81 51646281 1600.00 20.72 279.49 1517.52 157072 151.98 -22.53 -198.06 14.2R 0.50 3.83 24.18 6036486.39 51642829 1700.00 21.20 279.83 1610.91 1664.11 184.61 -16.53 -233.33 13.896 0.50 3.90 24.58 6036492.32 516393.01 1800.00 21.69 260.15 170398 1757.18 218.05 -10.19 -269.33 13596 0.50 3.97 2499 6036498.58 516357.00 1900.00 22.17 280.46 1796.75 184995 252.30 3.51 -30608 133R 0.50 4.03 25.40 6036505.18 516320.24 Cry 4/100 1903.51 22.19 28047 1800.00 1853.20 253.52 3.27 -30738 16.496 0.50 4.03 2542 0036505.42 516318.94 200.00 25.91 282.98 1888.10 1941.30 269.96 4.78 345.86 14.26 4.00 4.13 28.57 6036513.38 516280.45 2100.00 29.81 284.95 1976.49 2019.69 333.91 16.11 -39118 12466 4.00 423 31.99 6036524.60 516235.11 2200.00 33.72 286.51 2061.50 2114.70 383.95 30.41 441.82 11.146 4.00 4.33 35.52 6036538.79 516184.43 13-38°Csg 2245.57 35.51 287.11 2099.00 2152.20 408_70 37.90 466.60 10.646 4.00 4.37 3715 603654622 516159.64 2300.00 37.65 287.77 2142.70 219590 43982 47.63 49755 10.116 4.00 4.42 39.13 6036555.88 51612868 2400.00 4160 288.83 2219.71 2272.91 50126 67.67 558.08 9.29R 4.00 4.51 4279 6036575.78 516068.11 2500.00 45.55 269.73 2292.15 2345.35 567.96 9044 -623.12 8.646 4.00 459 46.51 6036598.40 516003.02 2600.00 49.50 29052 2359.66 2412.86 639.61 11583 -692.35 8.16 4.00 467 50.26 6036623.63 515933.74 2700.00 5347 291.22 2421.92 2475.12 71585 143.71 -765.45 7.67R 4.00 4.75 54.03 6036551.35 515860.59 2800.00 5743 291.85 2478.62 2531.82 796.31 17395 -842.04 7.316 4.00 482 57.83 603668141 515783.94 2900.00 61.40 292.43 2529.49 2582.69 880.60 20.40 -921.76 7.016 4.00 489 61.64 6036713.68 51570416 3000.00 65.37 29297 2574.28 2627.48 968.30 240.90 -1004.22 6,776 400 4.96 65.46 6036748.00 515621.63 3100.00 69.35 293.47 261277 2665.97 1059.00 277.29 -1089.02 6.586 4.00 503 69.30 6036784.19 515536.76 3200.00 73.32 293.95 2644.77 2697.97 115225 315.38 -1175.74 643R 4.00 5.09 7315 6036822.09 515449.96 3300.00 77.30 294.41 267012 2723.32 1247.59 355.00 -1283.96 6,316 4.00 5.16 77.00 6036861.51 515361.66 End Cry 3370.47 80.10 29472 268393 2737.13 1315.79 38373 -1326.80 HS 4.00 5.20 79.71 6036890.09 515298.76 Cry 4/100 7295.93 80.10 29472 3359.01 341221 5134.01 2001.10 -4839.29 90.126 0.00 6.01 79.71 6038499.43 511783.01 7300.00 80.10 294.89 3359.71 341291 5137.98 2002.78 4842.94 90.09R 4.00 6.01 79.69 6038501.10 511779.36 7400.00 80.11 298.95 3376.90 343010 5235.75 2047.37 4930.76 89.46 4.00 6.04 7907 6038545.49 511691.45 7500.00 80.18 303.01 3394.01 3447.21 5334.13 2098.07 5015.21 88.76 4.00 6.07 78.50 603859600 511606.90 7600.00 80.30 307.07 3410.98 346418 5432.64 2154.64 5095.68 69.016 4.00 6.10 78.00 603865238 511526.11 7700.00 80.46 311.12 3427.70 3480.90 5530.80 2216.80 5172.38 87346 4.00 6.12 7755 6038714.36 511449.47 End Cry 7721.72 80.50 312.00 3431.29 348449 5552.02 2231.01 -5188.41 HS 4.00 6.13 77.46 603872853 511433.42 Cm 2/100 7921.72 80.50 312.00 3464.30 351750 5747.28 2363.00 5335.00 37R 0.00 615 77.46 6038860.18 511286.55 8000.00 81.75 312.95 3476.38 3529.58 5823.74 2415.23 -5392.05 38.656 2.00 6.17 78.55 6038912.28 511229.39 8100.00 83.35 314.16 3489.34 3542.54 5921.47 2483.55 -5463.90 36.76 2.00 6.19 79.86 6038983.43 511157.39 8200.00 84.96 315.36 3499.52 3552.72 6019.14 2553,60 5534.53 36.57R 2.00 6.20 81.38 6039050.31 511086.61 8300.00 86.57 316.55 3506.91 3560.11 6116.64 2625.28 -5603.86 36.49R 2.00 6.22 8280 6039121.83 511017.13 Target Heel 8374.65 8777 31744 3510.60 3563.80 6189.23 2679.80 -5654.71 36.44R 2.00 624 83.86 6038176.24 510966.16 8400.00 88.17 317.74 3511.50 3564.70 8213.84 2698.51 -5671.00 36.43R 2.00 6.24 84.22 6039194.90 510949.04 End Cry 8421.72 88.52 318.00 3512.12 3500.32 623490 2714.61 5686.36 HS 2.00 625 84.53 6039210.97 510934.44 9-598"Csg 8424.65 88.52 318.00 3512.20 356540 6237.74 2716.79 -5688.32 HS 0.00 6.25 84.53 6039213 14 510832.18 Cm 2/100 8444.72 88.52 318.00 3512.72 3565.92 6257.19 273169 5701.74 148.716 0.00 6.25 84.53 6039228.02 510819.02 8500.00 87.58 318.58 3514.60 3567.80 6310.69 277294 -573850 148.696 2.00 6.26 83.51 60392E918 510882.17 End Cry 8526.49 87.13 318.85 351582 3569.02 6336.26 279282 5755.96 HS 2.00 6.26 83.03 6039269.02 51086467 Cry 3100 8849.90 87.13 318.85 3532.03 3585.23 6648.24 303605 5988.51 43.936 0.00 6.30 83.03 6099531 74 510651.60 Tgt1 8896.64 87.80 319.50 3534.10 3587.30 669326 307138 5999.03 41R 200 6.31 83.60 6039567.00 51062100 8900.00 87.85 319.54 353423 3587.43 6696.50 3073.93 5001.21 40.996 200 631 83.65 603956555 510618.81 End Cry 8936.79 88.41 320.03 353543 3588.63 6731.85 3102.02 -6024.95 HS 2.00 6.32 84.13 603959758 510595.01 Cry 2/100 9378.53 88.41 320.03 3547.71 3600.91 7155.89 3440.41 -6308.63 74.88L 0.00 6.36 84.13 6039935.30 510310.61 1g12 9696.50 88.50 319.68 3548.20 3001.40 7173.16 345414 -632021 75.15L 2.00 6.36 84.27 6039949.00 510289.00 • 9400.00 88.52 319.61 354829 3601.49 7176.53 3456.81 -6322.48 75.143 2.00 6.37 84.30 6039951.66 510296.73 End Cry 9412.67 8858 319.37 3548.61 3601.81 7188.73 346644 -6330.70 HS 2.03 6.37 84.40 603996128 510288.48 Cm 2/100 9813.10 88.58 319.37 355851 3611.71 7574.40 3770.23 4591.38 20.616 0.00 6.41 84.40 6040264.45 510027.14 Tgt3 9888.79 90.00 316.90 355945 3612.65 764723 3827.69 -6640.40 18956 2.00 642 85.73 604032100 509978.00 9900.00 90.21 319.97 3559.43 3612.63 7658.00 3836.47 6647.62 1895R 2.00 6.42 85.93 6040330.56 509970.77 10000.00 92.10 320.62 355741 3610.61 7753.87 391339 -671148 18.96R 2.00 6.44 87.71 6040407.33 509906.74 End Cry 10059.53 93.23 321.01 355464 3507.84 781074 3959.48 5749.05 HS 2.00 6.45 88.77 6040453.33 509869.07 Cry 2/100 10348.85 93.23 321.01 353834 3591.54 8086.72 418400 -6930.80 148.433 0.00 6.48 88.77 6040677.42 509686.84 Tg14 1039753 92.40 32050 3535.95 3589.15 813323 422165 -6961.56 148.033 2.00 648 88.02 6040715.00 50965600 • 10400.00 92.36 320.47 353585 3589.05 8135.60 4223.56 -6963.13 148.033 2.00 648 87.98 6040716.90 50965442 End Cry 10447.49 91.55 319.97 3534.23 3587.43 8181.13 426003 -6993.49 HS 2.00 649 87.25 6040753.31 509623.98 Cm 2/100 1087434 91.55 319.97 352266 3575.86 859101 4586.76 -7267.94 13.71 R 0.00 6.53 87.25 6041079.38 509348.84 Tgt S 10897.38 92.00 320.08 3521.95 3575.15 8613.13 4601.41 -7282.73 14.556 2.00 6.53 87.68 6041097.00 509334.00 10900.00 92.05 320.09 3521.66 3575.06 861564 4606.42 -7284.41 14.55R 2.00 6.54 87.73 604109500 50933232 End Cry 10915.53 92.35 320.17 3521.26 3574.46 8630.53 4618.32 -7294.36 HS 2.00 6.54 88.02 6041110.89 509322.35 Cry 2/103 11279.90 92.35 320,17 3506.31 3559.51 8979.89 4897.92 -7527.54 176.26L 0.00 6.57 88.02 6041389.93 509088.56 1130000 91.95 320.16 350556 3558.76 8999.16 4913.34 -7540.41 178.263 2.00 6.57 87.62 6041405.32 509075.66 Tgt 6 1139752 90.00 320.10 3503.90 3557.10 909275 4988.17 -7602.91 91.013 2.00 6.59 85.70 6041480.00 509013.00 End Cry 11398.79 90.00 320,07 3503.90 3557.10 9093.97 4989.14 -7603.72 HS 2.00 6.59 85.70 6041480.98 509012.18 Crv2/100 11852.90 90.00 320.07 3503.90 3557.10 9529.95 533739 -7895.17 1.563 0.00 6.62 85.70 6041828.54 508719.99 • Tgt 7 11897.94 90.90 320.05 3503.55 3556.75 9573.20 5371.93 -7924.08 2.043 2.00 6.63 86.60 6041863.00 508691.00 11900.00 90.94 320.05 3503,52 3556.72 9575.17 5373.50 -7925.40 2.043 2.00 6.63 86.64 6041864.57 508689.68 End Cry 11979.19 92.52 319.89 3501.12 3554.32 9651.19 543416 -7978.26 HS 2.00 6.64 88.21 6041925.11 508638.69 Cry 2/100 12371.30 92.52 319.99 3483.86 3537.06 10027.43 5734.20 -8228.10 168.36R 0.00 6.67 8821 6042224.55 508386.21 Tgt8 12398.04 92.00 320.10 3482.80 3536.00 10053.09 5754.68 -8245.28 169.17R 2.00 6.69 87.68 6042245.00 508369.00 Onllinfioau 1009 1 743 0 nmmr..01.1aP,mwP17m0P11.10P11u2 trel m.o.3°9 vu Page 1 ax Exclusion Zone MD Incl Atim True TVOS8 TVD VSEL NS EW TF DLS Directional Exclusion Zone Northing Eaating Comments (R) P) P1 (N) (D) (BI (B) (/t) P) pn00h)DIMeufy Index Alen Anger (MS) (MIS) 2400.00 9196 320.11 3482.73 3535.93 10054.97 5756.19 -8246.51 16917R 2.00 668 8764 6042246.50 508367.74 [ End Cry 241498 91.67 320.16 3482.26 3535.46 10069.34 5767.68 -8256.11 HS 2.00 6.68 87.34 6042257.97 508358.12 Cry2/100 2856.38 91.67 320.16 346941 3522.61 10492.75 610648 -8538.75 2311 0.00 6.71 87.34 6042596.10 508074.75 Tgt9 289805 92.50 320.13 346790 3521.10 1053271 613844 -8565.43 2,061 2.00 6.72 88.17 6042628.06 508048.00 2900.00 92.54 320.13 346781 352101 1053459 613994 -8566.68 2.061 200 6.72 8821 6042623.49 508046.75 End Cry 2947.94 93.50 320.09 3465.29 351849 10580.54 6176.68 -8597.39 HS 2.00 6.73 89.16 6042666.16 508015.96 Cry2/100 332304 93.50 320.09 344241 3495.61 10939.96 6463.87 -8837.57 168.891. 0.00 6.75 89.16 6042952.79 507775.16 Tgt 10 3399.33 92.10 319.80 3438.75 349195 11013.16 652220 -8886.61 169791 2.00 6.76 87.72 604301100 507726.00 3400.00 91.99 319.80 3438.73 3491.93 11013.81 652271 -8887.04 169791 2.00 6.76 87.71 6043011.51 507725.57 End Cry 346923 90.62 319.55 3437.15 3490.35 1108039 6575.48 -8931.83 HS 2.00 6.77 8539 6043064.17 507680.67 Crv2/100 3680.62 90.62 319.55 3434.85 348805 11283.86 6736.34 -9068.96 85.041 0.00 6.79 86.39 6043224.70 507543.19 3700.00 90.66 319.17 3434.63 3487.83 11302.53 6751.04 -9081.58 85.041 200 6.79 86.48 6043239.38 507530.53 3800.00 90.83 317.17 3433.33 3486.53 11399.41 6825.54 -9148.27 85071 2.00 6.80 8693 6043313.72 507463.69 Tgt 11 3899.01 91.00 315.20 3431.75 3484.95 11496.11 6896.98 .9216.80 84.541 200 6.82 8738 6043385.00 507395.00 3900.00 9100 315.18 3431.73 3484.93 11497.08 689768 -9217.50 84.541 2.00 6.82 8738 6043385.70 507394.30 4000.00 91.19 313.19 3429.82 3483.02 1159542 6967.36 -9289.19 84.581 200 6.83 8786 6043455.21 50732246 End CM 4022.46 91.23 31274 3429.34 348254 11617.60 6982.66 -9305.62 HS 200 6.83 8796 6043470.48 507306.00 Cry2/100 407158 9123 31274 3428.23 3481.49 11666.11 701599 -9341.69 91981 0.00 6.83 8796 6043503.72 50726986 4100.00 9121 312.17 3427.68 3480.88 1168420 7035.17 -9362.65 91991 2.00 0.84 8803 6043522.85 507248.86 4200.00 91.14 310.17 3425.62 3478.82 11793.36 710099 -9437.90 92.031 200 6.85 8825 6043588.50 50717347 4300.00 91.07 308.18 3423.69 3476.89 1189290 7164.14 9515.41 92.071 2.00 6.86 88.48 6043651.47 507095.83 T9t 12 4398.81 91.00 306.20 3421.90 3475.10 11991.52 7223.86 -959411 92.761 2.00 6.88 88.71 6043711.00 507017.00 440000 91.00 306.18 3421.68 3475.08 1199271 7224.56 -9595.07 92.761 200 6.88 8871 6043711.70 507016.04 4500.00 90.90 304.18 3420.22 347342 12092.66 728216 9676.79 92791 2.00 6.89 88.92 6043769.11 506934.20 4600.00 90.80 302.18 3418.73 347193 12192.64 733688 -976047 92.821 200 6.90 89.13 6043823.63 506850.40 End Cr. 4688.46 90.72 300.41 341756 3470.76 1228100 7382.82 -9836.05 HS 200 691 89.31 6043869.41 506774.73 Cry2/100 5184.38 90.72 300.41 3411.35 3464.55 12776.00 7633.85 -10263.70 80.531 000 694 89.31 6044119.46 506346.56 5200.00 90.77 300.11 3411.15 3464.35 12791.59 764172 -10277.19 80541 2.00 6.94 8941 6044127.23 406333.06 5300.00 91.10 298.13 3409.52 346272 12891.23 7690.38 -10384.53 80.571 2.00 6.96 89.96 6044175.75 506245.61 T9t 13 5392.83 91.40 296.30 3407.50 346070 12983.41 773282 -1044706 80491 2.00 6.97 8937 6044218.00 506163.00 54023.00 91.12 298.16 3407.32 3460.52 1299052 7735.99 -1045349 80,491 200 6,97 89.33 6014221.15 506156.56 • 5500.00 9175 294.19 340455 3457.75 1308934 7778.50 -1054396 80.551 2.00 698 88.70 6044263.46 506066.01 5600.00 92.08 292.21 340121 3454.41 13187.56 7817.87 -10635.82 80.611 2.00 6.99 88.06 6044302.62 505974.07 End Cm 5635.50 92.20 291.51 3239.88 3453.08 13222.26 7831.06 -10668.74 HS 2.00 6.99 87.84 62306315.75 505941.12 Cry2/100 5857.82 9220 291.51 339136 344456 13439.31 7912.54 -10875.43 10.85R 0.00 701 87.84 6044396.74 505734.28 Tett 14 5893.67 92.00 292.20 3390.05 344325 13474.35 7925.87 -10908.68 106.74R 2.00 7.01 88.14 6044410.00 505701.00 5900.00 91.96 292.32 338983 3443.03 13480.55 7928.27 -10914.53 108.749 2.00 7.01 88.20 6044412.38 505695.14 End Cry 5922.74 91.83 292.76 3389.08 3442.28 13502.84 7936.98 -1093553 HS 200 7.01 8839 6044421.05 505674.13 Cry2/100 6349.96 91.83 292.76 3375.42 3428.62 13921.88 8102.16 -11329.28 2.451 0.00 7.04 8839 6044585.32 505280.04 18115 6393.38 9270 292.72 3373.70 3426.90 1396446 8118.92 -11369.29 2.11 2.00 7.04 8753 6044602.50 505240.00 6400.00 9283 29272 337338 3426.58 1397095 812148 -1137539 2.11 2.00 7.04 87.40 6044604.54 505233.89 End Cm 6423.72 93.31 292.70 337211 3425.31 1399419 8130.62 -11397.25 HS 2.00 7.05 8593 604461363 50521202 Cry 2/100 682916 9331 29270 3348.73 3401.93 1439133 8286.81 -11770.66 177.911 0.00 7.07 86.93 6044768.97 504838.30 Tgt16 689452 9200 292.65 3345.70 3398.90 14455.39 8311.98 -11830.91 178.221. 2.00 7.08 88.21 604479400 504778.00 6900.00 91.89 292.65 3345.51 3398.71 1446076 8314.08 -11835.96 178.221 2.00 7.08 88.32 6044796.10 50477294 7000.00 8989 292.58 3343.96 3397.16 14558.84 8352.53 -11928.25 178.221 2.00 7.09 8972 6044834.33 504680.57 End Cry 700495 89.79 292.58 3343.97 3397.17 14563.69 8354.43 -11932.82 HS 2.00 7.09 89.62 6044836.22 504676.00 Cm 2/100 738459 89.79 292.58 334535 3398.55 14936.04 850021 -12283.36 165.836 000 7.11 89.62 6044981.20 504325.17 Tett 18 7394.52 89.60 29263 334540 339800 14945.78 8504.03 -1229253 163.72R 2.00 7.11 89.42 6044985.00 50431600 740000 8949 292.66 3345.44 339864 14951.15 8506.14 -12297.58 163.728 2.00 7.11 89.31 6044987.10 504310.94 End Cry 7414.44 89.22 29274 3345.61 3398.81 14965.31 8511.71 -12310.90 HS 200 7.11 8902 6044992.64 504297.61 Cm 2/100 7889.59 89.22 292.74 3352.09 3405.29 15431.56 8695.38 -12749.08 21.041 0.00 7.14 89.02 6045175.31 503859.07 79119 7894.00 89.30 29271 335215 340635 19435.88 8697.08 -12753.14 20.311 200 7.14 89.11 6045177.00 50385500 7900.00 8941 292.67 335222 3405.42 1544177 869939 -12758.67 20.311 200 7.14 8923 6045179.30 503849.46 End Cry 7903.47 89.48 292.64 3352.25 3405.45 15445.18 8700.73 -12761.87 HS 2.00 7.14 89.30 6045180.63 503846.26 TD 8533.87 89.48 292.64 3358.00 341120 16063.56 894343 -13343.65 0.00 7.17 8930 604542200 503264.00 Survey Error Model: ISCWSA Rev 0"-3-D 95.000%Confidence 2.7955 sigmt Survey Program: MD From MD To EOU Freq(B) Survey Tool Type 88980104 8u Inl IM Wel 0000 900.000 1/1(0.000 SLB GYRO-MWD OP17-02/0617-02(66) 900.000 2245.571 1/100.000 SL8_MWD+3MAG 0917-02/0917-02(P6) 2245.571 8424.647 1/100000 SL8_MWD+GMAG 0617-02/0617-02(P6) 8424.847 18533.865 11100.000 SLB MWD+GMAG 0P17-02/0617-02(P6) Legal Description: Northing(Y) Muting(X) Surface:3156,3 PSL 1653.9 FEL S5 T138 R9E UM 6036509.370 516626.280 Target heel 554 FSL 2020 FEL 31 T14N R9EUM 6039176.240 510966.160 TD/891:1528 FSL 4574 FEL 25 T146 R8EUM 604542.1.000 503264.000 • Dr.Ing01.2.1100 Ne 1.401rxex Point.P17-0MP1]O]10P17-02,72, 8/24,2010.0 PN Pspe 2 of Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools,hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out, backreaming Drilling Hazards Summary.doc 6/3/2010 2:53:00 PM a 11 llii gili0 gs i gI oUIZ- Y~I-'-F- Jo� Y�� b ; c CO Z W CD W z Z CD W z p� ��n \z=O J \J-Z-•J a_Z \J Z J 1 JI : - ��3vN �m -03 "�cg� �Z�st- n¢uz- -oQ^ _'.amu L IRS yy t gin. F c C) 4-LO 0 �� C Y N � in 2 2 ^nC 2 II I I Y -,t -, N i E 1l Q- o m ..c°� acr o W o= Z i 1 g o a J -J L�� o -J J 10pti �W Y �(3 M U I U n I I l_ _ . _ _ 1 I W illt Z N O H l N Q -� 1 LJ I LJ L -J I L— Occ — 0 0 - 0 + – mkin CO J _ I P 7_711 �_ DOZ / � NV aro 1 1 fl\___ I ____ CC I- O N CO a coW a= J 3: occ wIoW� Lo oo eao U �O� , V \W CD U 1-U " g ' y ,,tr :;'s " : y ;F . # ' ; Y." ,i "4' . 7.'`'_, ;�� „t :`A >, . ' `«;:,s3.�, Ys; £%' ..0,,,,,e,,..,. ....„.„.„,,,,4-, a,,t •, ;.. �F•`fi. .VA , F ,,,1 ,1440.-4,1•';),-•a3;;L. "0ve;s ., x ,x . �,.;,,,,,-;•••:, .t:_.. :..3•,•0•4'4,...i _: ,.;." , '",,.,, F• .. .•, r.l"' cas a*,• '°;•i " .'t.a#: .4�`4•ij�5�?JY°.,I�....A44`3 ',.• ,�'�>T:i,�' • � �„ 4�i.'h;£0£;� .. `4`J;'r . -r.,�r.' •.a. • <.,R ;;M t: y �:E:„•�"'_; p” r.; ,\ .^ars' 'tiiz' is� ,. °�k".'[S; 440= r s. • < 4.0. ,at '. t4. '',c •5� ,;',-•-;*".. ,.:,*.. '`x, ,,t', s; 7,' .. t' ''part Jg�'w ^ �� `Y" •1,:' rip n' Y f•� •1>,Q :e''''' i •a PIC „ s r.Yj;,R.t.Ai\. ,<j ,'('' c�•'"., .:t, .^ii {ttk}t[{ ItA f ��;. ,',":4f,,,..„ , ,' , ,)?,,,,,,,,,,e„.., , ....„ ,.:4„ ,,,Niqfpr444.7,'.. ' , -....v— ',..., . ,,,,.....vit.,-, ‘,,,, it.,,,,, +4-1:...A.,-: , , , 'i xr•. • h..: :o' .€.t:=•�r ,,£ �`_ '� '� 7.':..` i:' 'i , ,..';.• WI •,'_ •;„,* ',..""jok.,•:;•;,,p,„4,40,t•,'''; ,, ,',,,', 1\1":".:. ..:,,,,,,, „—ay., liv VeTstO :- Y.. '%,,, - l',,,,,,,,,‘r,A,, ,,,t, ' 01,...„ • ,,,,,,c—,fri ' ' r U OO'a TZS 2i ; , © .yk ). y_• ,,Y' „':� i , h sw . ; :.- yr � A,y •',4';' ,y:, . .CCOOOOk :1•j''•: :G,,k »: ;E' `. ; C y ,3 h �L .,9 .ir 4• • > N ..it W �'—.. 7 •- ".• ", � ^•'i a > C Els 4) i iia } 7?fr d al > T N t'¢:,: `,x':,'.`• `: `r.r•":':•i3 g'.#rit'rfk'0,: �:::• %"{,'<.. ,•., 3 -f',,`z J _ E rO •, v''c>2 ,'.*t Z V•r d 1 f Q \ ..':yn,s y;' > z z .`. 0 e scii), . ;n • �`• � -^'''''' q.,' x' <a? .1# a>s,•,'r•z m+#'V”n.H gs••'3?;;`y' aft •• +''' Tz= G, 4's f �� ,^ # , • ,,, $ £%-,ee> >1:••••••' " ' x, .>. • •, ^>zs�'7�u��E� T • ,.'.,t'�:tc�.r.. «„�>A»iw '•��. �':�,;,v ip.:',:.:.,,‘*". 7'-''',' `>. .... E..atX16'F.' a $ § 1 i 4t�! $ z 111 § i 1 •g I! aiTlII o CC LC ; W acc▪ 0 = I w ,Illi 4Vla OZ Z� I " I tii, IIi .�a ct I• II iiiraiii OIC - Z i a ' __ mi k7 1a■.„,,l + I .SC U 1 a g 11 Qpm' `3 I Zig �i 1, N Z A N ■ • i' '::: :I---- - WICiIlISIii Ja! i w __ 111 illibil Z a. Irr Y m \IF w a . ,,, A ' 1 , LL_ ixn ,IN N N k ! 1 zU h \ sY 1._.?r N N n ,ti/{Y-.B N Schlumberger Ce m CAD E*well cementing recommendation for 13.375'm Surface Casing Operator : Eni Petroleum Well : OP17-02 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : North Slope-Alaska Proposal No. : Draft v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 8-26-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford@slb.com C. r C ffri 4./"ATE Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client : Eni Petroleum Well : OP17-02 S hiemberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2272.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi G ( 0 1 2 t_ Frac Pore • • • • Permafrost • •-- ' ( 4 . G t • •• • • • • Upper Ugnu } •. N. • G I M- VVell Lithology Formation Press. Page 2 0P17-02.cfw;08-26-2010: LoadCase Surface Casing;Version wcscem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2192.0 ft Casing/liner Shoe MD : 2272.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2272.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 224.0 % Mean OH Equivalent Diameter: 20.705 in Total OH Volume : 879.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (°/q) (in) 1823.0 16.000 275.0 21.634 2272.0 16.000 35.0 16.822 Page 3 OP17-02.cfw,08-26-2010: LoadCase Surface Casing Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumbrgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 38 deg Max. DLS : 8.232 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 180.0 0.000 350.0 350.0 0.0 180.0 0.000 400.0 400.0 0.8 180.0 1.500 450.0 450.0 1.5 180.0 1.500 500.0 500.0 2.8 180.0 2.500 550.0 549.9 4.0 180.0 2.500 600.0 599.7 5.3 180.0 2.500 650.0 649.4 6.5 180.0 2.500 700.0 699.1 6.0 193.0 -3.000 800.0 798.6 6.0 222.1 2.999 900.0 897.9 7.3 245.4 2.998 1000.0 996.8 9.5 259.9 3.005 1100.0 1095.1 12.0 268.8 2.997 1200.0 1192.4 14.7 274.5 3.005 1211.0 1203.0 15.0 275.0 2.975 1300.0 1288.4 17.6 277.3 2.998 1368.3 1353.1 19.6 278.6 2.996 1400.0 1383.0 19.8 278.8 0.520 1500.0 1477.0 20.2 279.1 0.496 1600.0 1570.7 20.7 279.5 0.506 1700.0 1664.0 21.2 279.8 0.495 1800.0 1757.1 21.7 280.1 0.504 1900.0 1849.9 22.2 280.5 0.494 1903.5 1853.1 22.2 280.5 0.580 2000.0 1941.2 25.9 283.0 3.998 2100.0 2029.6 29.8 285.0 4.007 2200.0 2114.6 33.7 286.5 3.995 2245.6 2152.1 35.5 287.1 3.999 2272.0 2173.4 37.7 287.8 8.232 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.00 8.43 Permafrost Sandstone 1823.0 12.00 8.43 Permafrost Sandstone 2357.0 13.00 9.20 Upper Ugnu Sandstone Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1867.0 1819.3 32 0.7 2272.0 2173.4 50 1.4 Page 4 OP17-02.cfw,08-26-2010: LoadCase Surface Casing.Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumkrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ft degF ft o- 0 I 40 60 I 50 500 —Geoth.Profile —Hori.Depart. I I D [7 - -- 4 \ —' ' 7 O ____ ci o ( Lr, o f—3 p o -_-i_ {-I CD u, l { O ca I x f o Li-3. 4 �= �- co mw :1111 o- o _ 'CEJ o I Ln I _t 111111111111111Ao ..__ cv o 01– N Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.50 lb/gal 'Dv: 12.000 cP Ty:7.00 lbf/100ft2 Displacement Volume 328.2 bbl Total Volume 987.0 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 Pv:24.000 cP Ty:10.00 lbf/100ft2 Lead Slurry 501.4 1823.0 10.70 k:1.67E-4 lbf.s^n/ft2 n:0.977 Ty:9.98 lbf/100ft2 12.5 DeepCRETE 57.4 449.0 1823.0 12.50 k:6.32E-3 Ibf.s^n/ft2 n:0.852 Ty:7.49 lbf/100ft2 Mud 328.2 0.0 9.50 Pv:12.000 cP Ty:7.00 lbf/100ft2 Page 5 0P17-02.cfw:08-26-2010: LoadCase Surface Casing,Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 SchlemIngcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Static Security Checks: Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2033 psi at 2192.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton ft (x 1000) psi o < J L > 0,_Hydrostatic 0 1 .5 —Frac —Pore 0 \ , 00— L \ \ '11, I I 0 o 1 1 i t0 0 CO— Fluid Sequence Static Well Security Page 6 OP17-02.cfw;08-26-2010; LoadCase Surface Casing;Version wcs-cem460_14 . . .......... .. ...... _ Client : Eni Petroleum Well : 0P17-02 S I krger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 501.4 100.3 501.4 80 13-Start Mixing Lead Slurry 12.5 4.0 57.4 14.3 57.4 80 16-Start Mixing Tail Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 300.0 35.3 300.0 80 49-Rig Pumps To Displace Mud 3.0 28.2 9.4 328.2 80 21-Bump Top Plug Total 03:09 987.0 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 4 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2033 psi at 2192.0 ft Burst 4837 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 74 degF Simulated BHCT 74 degF Max HCT Depth 2272.0 ft CT at TOC 62 degF Max HCT Time 03:09:18 hr:mn:sc Static temperatures: At Time I (hr:mn) (hr:mn) I Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 50 degF Page 7 0P17-02.cfw;08-26-2010; LoadCaseSurface Casing;Version wcs-cem460_14 • Client : Eni Petroleum Well : OP17-02 SckIIrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing o Acquired Pressure cv j li Calc.WHP _ j ' I l Ii i—ill , 1 ' = 1 I i i l � Hj 1 , 1 11 I I 0 25 50 75 100 125 150 175 200 Time (min) Fluids at 2272 ft ---o- Acquired 0 Out . —Acquired 0 In i 1 r---� I I I—1. 1 1 i 1 1 I *-,. _. 0 Out ,-- _ I - as It o I I f I 0 25 50 75 100 125 150 175 200 Time (min) Page 8 OP17-02.cfw:06-26-2010: LoadCase Surface Casing:Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Saillhrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well :OP 17-02 String : 13.375""Surface Casing District : Prudhoe Bay,Alaska Country : USA o Depth= 2272 ft �, Depth= 160 ft rj - —Frac -Pore Fixe -Hydrostatic -Hydrostatic LO • -Dynamic q -Dynamic 0 oIf --,rn 2 To rnI O ri �� y r a a 6 >" in C I =o- c Q— � Q o 6- o N y R a Lo IA GD Ori io n cd 1 t 0 100 200 0 50 100 150 200 4 Time(min) Time(min) a 0 Total Depth = 2272.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Sch'u erier Page 9 0P17-02.ctw,08-26-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 SchIinberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :2252.0 ft Casing Shoe :2272.0 ft NB of Cent. Used :31 NB of Floating Cent. :31 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1952.0 23 1/2 NW-TR-13 3/8-8-TR 3 W304 11.2 772.0 2272.0 8 1/1 NW-TR-13 3/8-8-TR 3 W304 76.4 2272.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.4 Total Drag Force :11 ton Hook load Down Stroke :86 ton Hook load Up Stroke :107 ton ft 0 ?n 40 60 80 100 -—Between Cent. I - - + 4At Cent. _. • a a ; LiP o � ch Pipe Standoff Page 10 OP17-02.ctw;08-26-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Sohl urger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing CemCADE Client :Eni Petroleum Well :OP17-02 String : 13.375'Surface Casing District :Prudhoe Bay,Alaska Country : USA ton ft 0 10 20 30 40 50 60 70 80 90 100 110 I Hooldoad Up —— Hooldoad Dow n - - Weight \, — — Drag Force \. O \• O \•. 0 1 \ e o \ • • • o � 0 N p o O 3 M Running Forces 0 Friction Factor=0.4 Total Depth = 2272.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger SCh'I erier Page 11 0P17-02.cfw;08-26-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II Simulator % ft a_ 0 7n 40 60 80 100 - Std Betw.Cern. { —Cement Coverage • o 0 o"' 0 0 o— cv 0 0 0 Cement Coverage Risk Mud on the Wall Fluids Concentrations 0 z § OJ z0 200- 200 200- 200 404= 640 600- 640 ;;^1. 600- .-. ., 600 600- 600 - 800- i� 800 r—. - 800 840 — 1000- 1000 1000- 1000 - - — r n 1200- — 1200 4 1200- 1200 a • - '?a o ID 1400- 1400 0• a 1400_ I I 1400 1600 '' -' 1600 1600- 1600 1600- levo 1800- — 1000 2000 2000 2000 - -- r,x - 2000 2200 2200 2200 2200 MI lb o P.o O z z = Mud 71 Lead Slurry MI High = Low 111111 12.5 DeepCRETE = MUDPUSH II 1 Medium ® None Page 12 OP17-02.cfw;08-26-2010; LuadCase Surface Casing Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : BINGHAM Pv : 12.000 cP At temp. :80 degF Ty :7.00 lbf/100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type :WBM Job volume : 328.2 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :96.0% Water : 0.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : BINGHAM Pv :24.000 cP At temp. :80 degF Ty : 10.00 lbf/100ft2 Gel Strength :(lbf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.67E-4 Ibf.s^n/ft2 At temp. :80 degF n :0.977 Ty :9.981bf/100ft2 Gel Strength :(lbf/100ft2) DESIGN BLEND SLURRY Name :ArcticSET Light Mix Fluid : 10.367 gal/sk Job volume :501.4 bbl Dry Density : 106.26 Ib/ft3 Yield :2.33 ft3/sk Quantity : 1209.69 sk Sack Weight : 100 lb Solid Fraction :40.4% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 10.367 gal/sk Page 13 OP17-02.cfw;08-26-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing 12.5 DeepCRETE DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :6.32E-3 Ibf.s^n/ft2 At temp. :60 degF n : 0.852 Ty :7.491bf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.181 gal/sk Job volume :57.4 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :209.69 sk Sack Weight : 100 lb Solid Fraction : 54.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 5.141 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D185 0.040 gal/sk blend Dispers. LT D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Page 14 0P17-02.cfw,08-26-2010: LoadCase Surface Casing.Version wcs-cem460_14 £?pI Cs� P'•4. Schlumberger CemCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP17-02 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr.Jason Brink Location : Nabors 245E Proposal No. : Draftv2 Service Point : Prudhoe Bay,Alaska Date Prepared : 9-10-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford@slb.com 4? �G,N O t7 a • VAT E Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. *Mark of Schlumberger Client : Eni Petroleum Well : OP17-02 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8448.0 ft BHST : 85 degF Bit Size : 12 1/4 in ft (X 1000) psi < . 0 1 2 3 — Frac I Pore Permafrost •Middle Ugnu 0 1 o-co Lower Ugnu • •• • • } o- `D N Swquence Top ti OA-2 a; Well Lithology Formation Press. Page 2 op17-02.cfw,09-10-2010; LoadCase 9-5/8 Intermediate Casing(ai,Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Seld mherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2272.0 13 3/8 68.0 12.415 Landing Collar MD : 8368.0 ft Casing/liner Shoe MD : 8448.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 8448.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Page 3 op17-02.cfw;09-10-2010; LoadCase 9-5/B Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Mean OH Diameter : 12.250 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 12.823 in Total OH Volume : 986.4 bbl (including excess) Max. Deviation Angle : 89 deg Max. DLS : 4.115 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 180.0 0.000 350.0 350.0 0.0 180.0 0.000 400.0 400.0 0.8 180.0 1.500 450.0 450.0 1.5 180.0 1.500 500.0 500.0 2.8 180.0 2.500 550.0 549.9 4.0 180.0 2.500 600.0 599.7 5.3 180.0 2.500 650.0 649.4 6.5 180.0 2.500 700.0 699.1 6.0 193.0 -3.000 800.0 798.6 6.0 222.1 2.999 900.0 897.9 7.3 245.4 2.998 1000.0 996.8 9.5 259.9 3.005 1100.0 1095.1 12.0 268.8 2.997 1200.0 1192.4 14.7 274.5 3.005 1211.0 1203.0 15.0 275.0 2.975 1300.0 1288.4 17.6 277.3 2.998 1368.3 1353.1 19.6 278.6 2.996 1400.0 1383.0 19.8 278.8 0.520 1500.0 1477.0 20.2 279.1 0.496 1600.0 1570.7 20.7 279.5 0.506 1700.0 1664.0 21.2 279.8 0.495 1800.0 1757.1 21.7 280.1 0.504 1900.0 1849.9 22.2 280.5 0.494 1903.5 1853.1 22.2 280.5 0.580 2000.0 1941.2 25.9 283.0 3.998 2100.0 2029.6 29.8 285.0 4.007 2200.0 2114.6 33.7 286.5 3.995 2245.6 2152.1 35.5 287.1 3.999 2300.0 2195.8 37.7 287.8 3.997 2400.0 2272.8 41.6 288.8 4.007 2500.0 2345.3 45.5 289.7 3.998 2600.0 2412.8 49.5 290.5 3.993 2700.0 2475.0 53.5 291.2 4.008 2800.0 2531.7 57.4 291.9 3.994 2900.0 2582.6 61.4 292.4 4.001 3000.0 2627.4 65.4 293.0 3.999 3100.0 2665.9 69.3 293.5 4.007 3200.0 2697.9 73.3 294.0 3.996 3300.0 2723.2 77.3 294.4 4.005 3370.5 2737.1 80.1 294.7 3.997 7295.9 3412.0 80.1 294.7 0.000 7300.0 3412.7 80.1 294.9 4.115 7400.0 3429.8 80.1 299.0 4.000 7500.0 3447.0 80.2 303.0 4.001 7600.0 3463.9 80.3 307.1 4.003 7700.0 3480.6 80.5 311.1 3.996 7721.7 3484.2 80.5 312.0 4.000 7921.7 3517.2 80.5 312.0 0.000 Page 4 op17-02.cfw;09-10-2010; LoadCase 9-5/B Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 8000.0 3529.3 81.8 313.0 1.997 8100.0 3542.3 83.3 314.2 2.000 8200.0 3552.4 85.0 315.4 2.004 8300.0 3559.8 86.6 316.5 2.000 8374.7 3563.5 87.8 317.4 2.000 8400.0 3564.4 88.2 317.7 1.972 8421.7 3565.0 88.5 318.0 2.007 8424.7 3565.1 88.5 318.0 0.000 8448.0 3565.7 88.5 318.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (Ib/gal) 120.0 11.50 8.30 Permafrost Sandstone 1900.0 12.00 8.30 Permafrost Sandstone 2721.0 13.00 8.30 Middle Ugnu Shale 5489.0 14.00 8.30 Lower Ugnu Shale 7156.0 14.00 8.30 N Swquence Top Shale 8448.0 14.00 8.30 OA-2 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1823.0 1778.5 32 0.7 2272.0 2173.5 50 1.4 8448.0 3565.7 85 1.8 Page 5 op17-02.cfw,09-10-2010; LoadCase 9-5/8 Intermediate Casing(a(,Version wcs-cem4tO_14 Client : Eni Petroleum Well : OP17-02 Schlolrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ft degF (x 1000)ft o_ 0 qn 60 90 n 9 5.0 7.5 –—Geoth.Profile I —Hod.Depart. • O v y i i^� o j i N l O O N X CA 0 O— CO - N 1. r \ CO W. l ~'}� CO — 1` Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 6,156'(1,000'above the"N"sand) Original fluid Mud 9.50 lb/gal Pv:20.038 cP Ty:20.59 Ibf/100ft2 Displacement Volume 612.6 bbl Total Volume 848.3 bbl TOC 6156.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 1003.9 5152.1 10.50 Pv:36.000 cP Ty:20.00 Ibf/100ft2 DeepCRETE 165.7 2292.0 6156.0 12.50 k:6.48E-3 lbf.s^n/ft2 n:0.848 Ty:7.24 lbf/100ft2 Mud 612.6 0.0 9.50 Pv:20.038 cP Ty:20.59 Ibf/100ft2 Page 6 op17-02.ctw;09-10-2010; LoadCase 9-58 Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Sehlhrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Static Security Checks: Frac 348 psi at 2272.0 ft Pore 135 psi at 2272.0 ft Collapse 4524 psi at 8368.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 70 ton ft (x 1000) psi 0 3 -Hydrostatic -Frac -Pore r o 1 %\ m o r ' rn- Fluid Sequence Static Well Security Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug DeepCRETE 5.0 165.7 33.1 165.7 80 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.0 580.0 72.5 580.0 80 19-Start Displacement Mud 3.0 32.6 10.9 612.6 80 21-Bump Top Plug Total 02:20 848.3 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 262 psi at 2272.0 ft Pore 135 psi at 2272.0 ft Collapse 4431 psi at 66.2 ft Burst 6452 psi at 0.0 ft Page 7 op17-02.cfw,09-10-2010: LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlomberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Temperature Results BHCT 83 degF Simulated Max HCT 85 degF Simulated BHCT 68 degF Max HCT Depth 8448.0 ft CT at TOC 69 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time 1 (hr:mn) 1 (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 1 76 degF Bottom Hole (degF) (degF) 85 degF o- — o —Pcquired Pressure in —Calc.WHP 1-8 I .Th...,._ / -- II 11 I ( of t t t 0 25 50 75 100 125 150 Time (min) Fluids at 8448 ft —Acquired 0 Out ▪ —Acquired 0 In ---f O Out CI In rel NMI/a' MOM= 0co'_ ii HE 9:1_ . • 0 0 25 50 75 100 125 150 Time (min) Page 8 op17-02.cfw;09-10-2010; LoadCase 9-5/8 Intermediate Casing Cal,Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 SeinIrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :OP17-02 String :9-5/8" Intermediate Casing District : Prudhoe Bay,Alaska Country : USA Depth= 8448 ft o Depth= 2272 ft_ -Frac of -Frac -Rare -Fore -Hydrostatic Lo - CN 1 .4. -Dynamic -Dynamic 0 (V co Lf) N f0 O 0 0) p)� a 4 4) 4) 3 = 7 • O > N / �� 4 J d0 vO O_ of E oi O- U in cci TA O --1 0 50100 150 0 50 100 150 Time(min) Time(min) N O i..- Total Depth = 8448.0 ft Top of Cement= 6156.0 ft *Mark of Schlumberger Scii er Page 9 op17-02.cfw;09-10-2010; LoadCase 9-5/0 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlifilihrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :6156.0 ft Bottom Cent. MD :8428.0 ft Casing Shoe :8448.0 ft NB of Cent. Used :57 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent.I Cent.Name Code Min.STO @ Depth (ft) Joint (%) (ft) 8448.0 57 1/1 NW-TR-9 5/8-6-TR 3A W090 61.5 6188.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-9 5/8-6-TR W090 9 5/8 12.850 11.591 No Hannover 11.625 775.59 5626.97 3A (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications ft % o— 0 911 0 60 80 100 -—Between Cent. I I I + +Ft Cent. co • o_ __ o o I l rn— Pipe Standoff Page 10 ap17-02.cfw;09-10-2010, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem400_14 Client : Eni Petroleum Well : OP17-02 Schihrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client :Eni Petroleum Well :OP17-02 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA ft ton 0 0 20 40 60 80 100 120 140 Hookload Up `. 1 —— Hookload Down N 1 ---- Weight 1— — Drag Force N •N N • N 1 N N 1 N 1 N • o O_ 1 \ M \ \ '1 I m \ . 1 1 \ I s \ 0 1 >F. I \ \ I \ '41- o \ / U • a co \ / • \ / r \ \ / El \ / • /O \ /OO O— O6 Running Forces N O o Friction Factor=0.3 Total Depth = 8448.0 ft Top of Cement= 6156.0 ft *Mark of Schlumberger S ddinibror Page 11 op17-02.cfw:09-10-2010: LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft % 2 I 75 100 Std Betw. Cert. --- - Cement Coverage 0 0 o- co O O O- SD O O O 67- Cement Coverage Fluids Concentrations Risk Mud on the Wall r $200 6200 $200 4 , -6200 GSM __ _ 6400 6400 -6400 6$00_s -Y-7- 6600 $500- -6600 6800- 6800 6800 -6800 7000- 7000 — f-- 7000 -7000 T t- 7200- 7200 `- "-- 7200-i -7200 `- S L S L a 7400- 7400 a a 7400 -7400 a o r o r 0 7600- 7600 0 0 7600 -7600 7600- 7800 7500-; -7800 8000 8000 8000 -8000 8200- 8200 8200 -8200 v00- 8400 8400 1 -8400 • g • • ; • -13 4 5 il 4 O O 2 2 ME Mud EJ High Low = DeepCRETE F-1 Medium El None 1-1 MUDPUSHII Page 12 ap17-02.cfw;09-10-2010; LoadCase 9-5/8 Intermediate Casing lal,Version wcs-cem460_14 1 Client : Eni Petroleum Well : OP17-02 Schlemberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : BINGHAM Pv :20.038 cP At temp. :80 degF Ty :20.59 Ibf/100ft2 Gel Strength :(lbf/100ft2) MUD Mud Type :WBM Job volume :612.6 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0 Oil :96.0% Water :0.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : BINGHAM Pv :36.000 cP At temp. :80 degF Ty :20.00 Ibf/100ft2 Gel Strength :(Ibf/100ft2) Job volume :70.0 bbl DeepCRETE DESIGN Fluid No:7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :6.48E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.848 Ty : 7.241bf/100ft2 Gel Strength :40.56 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.183 gal/sk Job volume • :-. ..1 Dry Density : 119.32 Ib/ft3 Yield : 1.54 ft3/sk Quantity :605.59 sk Sack Weight : 100 lb Solid Fraction : 54.9% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.133 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.129%BWOB Antifoam D185 0.040 gal/sk blend Dispers. LT D110 0.010 gal/sk blend Retarder D153 0.100%BWOB Antisettling Page 13 op17-02.cfw,09-10-2010. LoadCase 9-5/8 Intermediate Casing(al,Version wcs-cem460_14 Client : Eni Petroleum Well : 0P17-02 Schi bcrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl/min) (bbl) (min) (bbl) MUDPUSH II 5.0 70.0 14.0 70.0 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4-Drop Bottom Plug DeepCRETE 5.0 165.7 33.1 165.7 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18-Drop Top Plug Mud 8.0 580.0 72.5 580.0 19-Start Displacement Mud 3.0 32.6 10.9 612.6 21-Bump Top Plug Total Pumping Time : 02:20 hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats MIXING PREPARATION MUDPUSH II Volume : 70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.747 bbl D182 382.481 lb 6.000 lb/bbl of base fluid D046 12.749 lb 0.200 lb/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer DeepCRETE Volume : 130.8 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: _ 48044 lb Design Mix Water 59.0 bbl 10.0 bbl LAS Design D972 47815.238 lb Fresh water 58.434 bbl 9.905 bbl D167 119.538 lb 0.250%BWOB D185 19.126 gal 3.242 gal 0.040 gal/sk blend D046 61.682 lb 0.129%BWOB D110 4.782 gal 0.810 gal 0.010 gal/sk blend D153 47.815 lb 0.100%BWOB Page 14 op17-02.cfw,09-10-2010, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : OP17-02 SchlinIrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client :Eni Petroleum Well :OP 17-02 String :9-5/8"Intermediate Casing District :Prudhoe Bay,Alaska Country :USA Annulus ID:9.625 in-OD: 12.250 in III O -Mud -MUDPUSHII I � - DeepCRErE co O Co I • O - ,`,— Y N o 9 V) C to d In F - O � U 'C 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 : Flow Rate (bbl/min) o ■Mud Bingham:R/=20.038 cP Ty=20.59 lbf/100ft2 ■MUDPUSH II Bingham:R/=36.000 cP Ty=20.00 Ibf/100ft2 ■DeepCRETE Herschel:k =6.48E-3 lbf.s^n/ft2 n =0.848 Ty=7.24 Ibf/100ft2 'Mark of Schlumberger Page 15 op17-02.ctw;09-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcscem460_14 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 End E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of`Equivalent Mud Weight' (EMW): Imperial units EMW = +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). > SPEO IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. En! E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT)or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. *01 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 - -- Eni E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/06 JFC JMS Add New Well Conductor OP26 Oliktok . OLIKTOK 5 0 Point 0 INTAKE DOCK OPP N THIS MODULES.')CX 1 1:.• R) P� .5 SURVEY O N P^%r 16, DS-3R OP DEW LIME _ % i n SITE STP / I-- _I OLIKTOK POINT MODULES I --_ NOC STAGING AREA, T13N, R9E DS-3Q • ,,, � 18 V.):111'1...I ��.-' ,,_ c-; ,I.5 SCALE: ' 1" = 150' ''l1;AO Dq'30 19 5 ;:(^ �i' 1� U r. STD DAD VICINITY MAP 0 \ SCALE: 1" = 1 Mile 00 o,-o� r' \ 00-0 0-6,Q \ Q O o 0 00000 v'�? - \ 00� ,0�0�tP \� lPO 00/00^-0> > 0S o' \ 7/ .\,\ O � OLIKTOK 00 POINT PAD \ \ .• \ -8 0 / 0 \ \ \ SEE SHEET 3 FOR NOTES / \ \ o Existing Conductor LOUNSBURY • �� & nssociaTEs, INc. ..,W Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS P AREA: / MODULE: UNIT: Ein�ii PPtrrollktu��nn� OLIKTOK CONDUCTOR D Enlll ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: I PART: REV: LK680D1 10/9/08 NSK 6.80-di 1 OF 3 I 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149° 51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149° 52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149° 52'01.753" 2,127 1,681 12,2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 DISPOSAL WELLS • AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: •li fe , Enicirolle IInni WELLOCONDUCTOR Eno Pe L infill ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 2 OF 3 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. � �P OF q�s4i • SURVEYOR'S CERTIFICATE ��• �j� I HEREBY CER77FY THAT I AM PROPERLY s . ,h• i REGISTERED AND LICENSED TO PRACTICE I�.• LAND SURVEYING IN THE STATE OF j ROOKUS o ALASKA AND THAT THIS PLAT REPRESENTS ♦ c A SURVEY DONE BY ME OR UNDER MY TA tr' •., LS-803 � r DIRECT SUPERVISION AND THAT ALL ��'�$a p•,l(4 Z..3 QB•'��i DIMENSIONS ASA OF DECEMBER 23, 2008. ,OTHER DETAILS ARE ,1,� ``NA-\-,�•• CLOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS Cr412. AREA: MODULE: UNIT: aa POINT Era PPtroolleu nn WELLOK CONDUCTOR PAD Chill ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 3 OF 3 2 "'Oat C " Peiirolleum JL RECEVED • Eno SSP 0 2 2010 Alaska CM Gas Ceres.Commission 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com August 26,2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP17-02 Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Permit to Drill for the onshore production well OP 17-02. The well will be drilled and completed using Nabors rig 245E. The planned spud date is 10/24/2010. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Jason Brink at 907-865-3321. Sincerely, Ma rizio Grandi Well Operation Project Manager Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 15, 2010 10:48 AM To: 'Brink Jason' Cc: Davies, Stephen F (DOA) Subject: RE: OP17-02 Jason, The Diverter waiver is granted and will be stated in the PTD application conditions of approval. In future well permit applications ( Oliktok Point wells only) please request the diverter waiver in section 7 diverter equipment section) . Spy Island wells will need diverters until the Commission has enough data to consider waiving the requirement. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brink Jason [mailto:jason.brink@enipetroleum.com] Sent: Wednesday, September 15, 2010 10:11 AM To: Schwartz, Guy L(DOA) Subject: OP17-02 Guy A correction to request for PTD for OP17-02. The original PTD stated ENI would rig up surface hole diverter if required by AOGCC. ENI wishes to request a waiver to the diverter requirement per 20 AAC 25.035.(h)(2)for well OP17-02. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 9/15/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Brink Jason [jason.brink@enipetroleum.corn] Sent: Tuesday, September 14, 2010 4:38 PM To: Schwartz, Guy L(DOA) Subject: RE: OP17-02 .. revised Intermediate cement program ( PTD 210-125) Attachments: OP 17-02 Intermediate CemCADEv2.pdf Guy This is a revised plan, but will further be revised as I get the CBL data from the very next well. I will use the next well to calculate washout based on a rotary steerable BHA, which will be the standard. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, September 14, 2010 4:34 PM To: Brink Jason Subject: OP17-02 .. revised Intermediate cement program ( PTD 210-125) Jason, Please send me a revised cement program for this well (Intermediate casing only). Incorporate the changes we discussed in previous emails. I can pull the existing pages in the PTD and replace Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 9/14/2010 O O O O O oo M .0O O N • c o O O %— ti N Tr LL o LL W 0 Q o J O p r� c- Co Tr r O O N O CO il- 1 _ O "18:1IP Q 0 CC C) o v ^+ N W G O W 0 O O 43) L Co Co M Q eN• Q O a O W O O OO O O O O O O cp O O C) co OO O C) V) O0)LU O C 0)CO CO LO CO TRANSMITAL LETTER CHECKLISTWELL NAME A. ,71a/ r C Gt ce17-()?_ PTD# 2-1C" — i/ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /V !k'4/ {-c l POOL: L(I'll (Ji / 6e/ Circle Appropriate etter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING The permit is approved subject to f s pliance with 20 AAC EXCEPTION 25.055. Approval to perforate ano Iroduc. is contingent / upon issuance of a conservation . .a approvinga spacing exception. ' l(, , � �f T assumes the a� liability of any protist to th &pacing eiception' hatay 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 a) a I ._I N > U as D a) _ 3 @ a O > O co cc> n co O) ° 00 a) @-O a a) N- N > o c N U N N D M U •a E o No EUO U N@ N- C 0 N . a) O O@ Q C CA Cl) @ U a>) o 0 Cl) C fl 2 F (6 WL 0_ a US N co '3 aCO C @ O O CA _� 3 > @ LL C �, 3 ° ,..,co E o a N .,, .O E 'O W ._. L F U O O) ° E to E a ° C a) O ` N O a M co'0 LL O o - v n ai o a • C U C _c N N E O `c) a) ° r> o171 2 o 0) Cl -0 74 NaO °) Cl) C w LO 6 rn 2 Q @ @ u o L 0) 3a3inrn Cl- c - @ N c 3 a) (ri 2 .. 3 N 3 N• c 0 F o m U = -O E o o co o u) c @ 0 "o a) a>> c N a Cl E a C 0 N -o n@0 � d > N 'O .0 a) 0).5 N .k.,...'' 0 a) _ D 0) c 2 m 2 0 3 aa)co co 0 ° • �_ c o > o w N ° O N p _a Ca u) a a @ (0 - N E c o 3 (\ co o vi @ a o ° 3 0 0 °) O 'O W CA(n.0 a) N "O NO N 3 C (I) N 1.L. _ °- a0co c N °) c,,-,-, O C @ a o N °01 03 d @ 3 Cl_ - J 0 0 U - 3 o co Q LL 0 3 �°to' cO o �)aui °i O o W w N O in • Z c uu) ° 0 o co O w W o t- ui Q o o m 0 y °) 0 CO a) 0 = M W Q W r was "O ..N.. E N u) C N n= -0 = o W Z LL Z a) Q E -o ii o @ o c ° c = Hp LL m z U z ami c ° co c- _ _c w-° N co m 3 Q- rn Q w e O O E@ a1°i a> a of E 0 o a) @ axi co c 0 ° H o H U a> ° n n Q u) -ci ,n _� (n N Z C Z W @ W co C co L N EL'O. u) •O ° a)_ @ ° o . = U .- U v '- c_ 3 n a) Z 3 ° C x a X • c c a`) c (h m a) n Qj p CO ° W @ W (�i _o - a) •� 'N a °- a) aC) 00.0 C)) E C7 I E O c C7 w o O a Y E, °) ° ° E a)c axi Z ° F Z ° Z ° 5 n U ° o U m rn 0 0 .a U CT IA O CT ,E 0 LL N i) o C= C a) t Q o Q ° < < c ° x a) x 2 c a) > U) 3 6 Z ] - Cl- x LL o @ o m o > @ < o o x -°O-° N d a u) Z n u) a) Cl) Z n. U) E a o 2 2 z z W -0 COC o 0 0 o c @ w a�66 C o 2 o N @ LL N O) N < aN) U) O aa)) aN) o aN) aa>> aN) o aa)) a < < < < a) < aN) O O U) U) < a < U) aN) N) co co O < aN) as < < < a z >- >- z >- >- Z >- >- >- z >- >- Z Z Z Z >- Z >- Z Z >- >- Z >- Z >- >- >- >- >- Z Z >- >- Z z z T F iii O a) N _ T 0 @ C U o c Cl) = E 3 - E a) O U U •Z C N ° N C 4 U o O o N T n -> C L_c O _ d E o # ° T U m 3 E 3 0 a7 2 N U .>_••• (° O m M U C N 'i 0 J O a v 0 N E E a 0 Ow as 'C > @ ti N N •N m d U LL N O b++ z O LL C J N @ ° C O 7 _ _ 7 TD00 .k o ih > E N N Lit IX -0 l w C7 = _c rn 2 Z "m @ c 3 o U C o r 0. ci- c u) Q ° Q (n N af) rn_ • ° mo a) C 7ma Doc > CO oa) � c c Eo 0 o °ai > o a ai U 0 E E - "O c C E N O M C c N Hc 2 � UoD ec C a) L ) N C - m ci) 00 _ CA d C F Z o 0 o °) U n CL a) 6 n 3 0 > o'u > Y • _a ' � O yO ° @ @ . Q@ ° �u) CO ' NQ a a) a) 'E C v ) a >, C 7 7 @O @ p O 2 C E ( IT 3 a) o a) a) - a 0 CE � f l \U E n ` ° o oc n@o N ' a a 30 �o co >Z - e� a ° ° " Om@m a ° .:°� -§ -3aE aC0 Mno -F.) a . Z ° w o z`~jo Z ° > a .• o o v au) N aI m o t U O F O C 4a - @> OaQ -° o@Eoc OaOOc Cr o -O E @ Eo CA C 0 n N ° a) 0.3 IM a a_ a) oO a) r o (D ouca Q ° a@ ) a ° > > nc v ° n o a) a) o a) o m E Crn 83 =p oz Oc N o-° ) O N �° a) _ co c0. @@O@ON0)W U @ @ O O On N ..• 3 °CO O) n@@ ° T ° O= ° -8 >, O a)n 15 yCn n N . LL O@ Q - NNNUV! N 1 "OL a) ua) a) > D) °C a) CNT y ' U @ CE -O -O O (7) . -O Ou)0 ° m (9 p. C C " 23 o C o@@@m Oc (6CNC - ' -° 2@ = o @ (n@o0 1., m CO "E' 0.) E Usin � U a) ` ° E Z c a) .2, U U -E, N wN O c U a> o o - cr) @ •O CO@ co u 3 .0 UU -° UN O O O O O .0 .5 @ °. - N o = o > > > 7 4 3 a) C w w a) N ... n EN @ Na aL W Cl) C N o7 ° -0La) No COY > ' NNN7 P as `) `) N3 N o 2 2 2 N -@@ -O = o o 0 °- a) N C '5 @ 0 V 0_ "i n co o o aa U Q a z U cn U U U U Q a ' o CO CO U N 2 a o cn u) U W p N CO V l0 ° r Co CAO N M V (° (0 r _W A O N N MN N (N (O fN- W N cc,;') C) N M M OM M MI- U) CM v U O o . I 0 ° ' 03 a, rc c ) -c--.1 aJ N +' ON V O N_ @ N C _° N 0. o w ° E N N O Cl) CA � 0 E C u- u 0 O E a 0) a oa < a0 a LLa W c9 Well History File AR• ENRIX Infoi n ration of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infor ration. tows EnH P FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP 17-02 and OP17-02-PB1 OLIKTOK POINT, ALASKA Bo it ,• / • --� - 1011111110r CANRIG I)KILLIVG I I.CH\1111N.;Y 1.Tb. Approved by: Andrew Buchanan Compiled by: John Lundy Emil Opitz Zach Beekman Jeff McBeth Steven Pike Distribution: December 28, 2010 Date: December 9,2010 �al° -Fe\ 0\9 Doi eni OP 17-02 and OP 17-02-PB1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT&CREW 3 1.1 Equipment Summary 3 1.2 Crew 4 2 WELL DETAILS 5 2.1 Well Summary 5 2.2 Hole Data 5 2.3 Well Synopsis 6 3 GEOLOGICAL DATA 7 3.1 Target and Offset Well Data 7 3.2 Formation Tops. 8 3.2.1 Surface and Intermediate Section 8 3.2.2 Production/Lateral Section OP17-2-PB1 9 3.2.3 Production/Lateral Section OP17-2 10 3.3 Lithologic Descriptions/Stratigraphy 11 3.4 Connection Gas Summary 55 3.5 Trip/Wiper Gas Summary OP 17-02 55 3.6 Sampling Program and Sample Dispatch 56 4 PRESSURE AND FORMATION STRENGTH DATA 58 4.1 Pore Pressure Gradient Evaluation 58 4.2 Quantitative Methods 58 5 DRILLING DATA 59 5.1 Daily Activity Summary 59 5.2 Survey Data 63 5.3 Survey Data 67 5.4 Bit Record 73 5.5 Mud Record: Surface and Intermediate Hole 74 5.6 Mud Record: Production Hole OP17-02 75 5.7 Mud Record: Production Hole OP17-02 PB1 76 6 DAILY REPORTS 77 Enclosures 2"/100' Formation Log (MD and TVD) 2"/100' Gas Ratio Log (MD and TVD) 2"/100' LWD Combo Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and ND) Show Reports Final Data CD 2 CANRIG epi Eni Petroleum OP 17-02 and OP 17-02-PB1 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Downtime (hours) Comments Casing Pressure Cable to 1502 transducer for BOP 0 tests only. Computer—Drill Floor Monitor Azonics 0 Computer—Pit Monitor Azonics 0 Computer for Company Man, RigWatch Remote(HP Compaq) 12 Days GCI Phone camp network failure Computer for Company Man/ RigWatch Remote(HP Compaq) 0 Toolpusher, office (wireless) Computer for Mud Engineer RigWatch Remote(HP Compaq) 0 Computer for Toolpusher RigWatch Remote(HP Compaq) 15 Rig Report, Extract virus Computers for Mudloggers(3) Data editing, RigWatch Master, and 0 RigWatch Remote(all HP Compaq) QGM Agitator (Mounted in possum belly) Clean and service gas Ditch Flame Ionization Detector(FID) 2 trap Total Gas and Chromatography. Hook Load/Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes/Minute and 0 Pump Output Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 0 Pump stroke counters (3) 2 proximity sensors 0 Rate of penetration Draw Works Encoder 0 RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to RigWatch 0 Master Computer t.fli Eni Petroleum OP 17-02 and OP 17-02-PB1 1.2 Crew Unit Number: ML059 Unit Type: Arctic/Steel Mudloggers Years of Days at Sample Days at Technician Days at Experience OP17-02 Catchers OP17-02 OP17-02 John Lundy 18 12/04 Jeff McBeth 11 Allan Williams 2 Emil Opitz 3 11/13 Steve Franzen 11 Howard Lamp Jeff McBeth 2 8 Dan Sherwood 6 Zach Beekman 2 12 Deborah Bomar 11 Steven Pike 9 37 Greg Hammond 6 4 CANRIG OA erg Eni Petroleum OP 17-02 and OP 17-02-PB1 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OP 17-02/ API Index#: 50-029-23431-00-00/ OP 17-02PB1 50-029-23431-00-60 Field: Nikaitchuq Surface Co-Ordinates: 3,156.3 FSL 1,653.9 FEL S5 T13N R9E UM Borough: North Slope Primary Targets: OA Sand of the Schrader Bluff State: Alaska Primary Target Depth: 8085.0' MD; -3478.5'TVDSS Rig Name/Type: NAD 245E/Arctic/Triple TD Depth: OP17-02- 18200' MD; 3469.6' TVDSS Spud Date: October 30, 2010 TD Depth: OP17- 02PB1 18940' MD; -3441.22' TVDSS TD Date: December 9, 2010 Ground Elevation: 12.2' MSL Days Drilling: 40 RT Elevation: 53.25' MSL Classification: Producer TD Formation: Schrader Bluff OA Sand 2.2 Hole Data Maximum Depth Mud Shoe Depth LOT Hole TD Weight Dev. Casing/ (ppg) Section MD TVD Formation (o inc) Liner MD TVD (ft) (ft) (ppg) (ft) (ft) Conductor 160 160 Recent 20 160 160' 16" Surface 2265 2162 Ugnu 9.2 32.40 13 3/8" 2249 2170' 12.0 12-1/4" 8520 3556 OA Sand 9.4 87.26 9 5/8" 8505' 3556' Schrader Side- This8-1/2" 18940 3494 Bluff, OA 8.7 87.88 Not track 9460' Sand section cased at Schrader 3521.6 8-1/2" 18200 3522.8 Bluff, OA 9.25 a9.03TD 5'WO 18030 xxx N/A Sand 5 CANRIG leni En' Petroleum OP 17-02 and OP 17-02-PB1 2.3 Well Synopsis The OP17-02 well was spudded on the 30th of October 2010,entering a pre-set conductor pipe at a depth of 160'. New 16"hole was drilled to a depth of 2265'where 13-3/8",681b/ft-L80 surface casing was set at 2249.5' /2170.2' TVD/-2117.'TVDSS. The float equipment and shoe were drilled out and new hole was drilled to 2285".A Formation Integrity Test was performed to 12.1 ppg. The intermediate section was drilled with a hole diameter of 12-1/4" to a depth of 8520'MD. The hole was back-reamed to the existing casing shoe and circulated clean.After laying down the drilling assembly,9 5/8";471b/foot casing was set at 8505"MD/3555.6' TVD/ -3555.6'/-3503.1'TVDSS An 8.5" bit and drilling assembly were picked up and run in to the surface casing shoe. Casing shoe was drilled out with additional new hole to 8851'where a Formation Integrity Test was performed yielding 12.5 PPG/MWE. Normal drilling was resumed using an 8 1/2" PDC bit and the borehole extended to TD at 18940'MD.While back-reaming to clean the hole prior to running production liner the hole collapsed below 9460'MD.The bottom hole section was abandoned and an open hole sidetrack was performed at 9460' MD. The borehole was re-drilled to a new TD at 18200'/3522.8'TVD/-3469.6'TVDSS. The hole was again prepared by back-reaming and production liner was set at 18030'MD/ 3521.6' TVD/ -3468.4'TVDSS 6 CANRIG ;eni Ertl Petroleum OP 17-02 and OP 17-02-PB1 3 GEOLOGICAL DATA 3.1 Target and Offset Well Data OP17-2 Offset Well Data Original Zone or Horizon Prognosed OP3- OP-11 OP-12 OP26- Depth (ft) PO5PB1 PB01 DSPO2 MD TVD TVDSS TVDSS TVDSS TVDSS SV-4 706.2 705.1 -657.7 -659.1 SV-3 965.6 962.9 -907.6 -902.8 SV-2 1234.5 1226.7 -1174.0 -1169.0 -1163.2 SV-1 1731.4 1703.7 -1671.1 -1671.2 -1647.0 -1648.1 Permafrost Base 1809.2 1778.3 -1722.1 -1726.8 -1724.3 Ugnu Top(UG4) 2064.8 2018.0 -1984.8 -1984.8 -1931.5 -1957.2 13 3/8" SCP 2241.7 2173.3 UG-2 Coal Marker 2241.7 2173.3 -2512.7 -2488.2 -2422.0 -2428.2 L Ugnu 2662.5 2488.4 -3140.3 -3274.3 -3060.0 -3122.5 Schrader Bluff 5080.9 3080.7 -3387.3 -3511.3 -3341.9 -3325.0 N SequenceTop 6781.0 3377.1 -3470.7 -3596.2 -3382.6 3382.6 N Sand Bottom 7239.0 3452.5 -3523.5 -3640.5 -3424.4 -3423.3 OA Sand Top 7739.0 3512.6 -3789.6 -3518.2 -3536.4 0A2 8379.4 3568.7 0A3 8492.1 3578.5 9 7/8" ICP 8505.0 3419.1 Total Depth 8541.9 3582.7 7 CANRIG i IEni Petroleum OP 17-02 and OP 17-02-PB1 3.2 Formation Tops: 3.2.1 Surface and Intermediate Section Zone or Horizon Depth (ft) Current Prognosed Depth (ft) MD TVD TVDSS MD TVD TVDSS 20"Conductor Shoe 160.0 160.0 -106.8 120.0 120.0 -66.8 SV-4 714.4 713.0 -659.8 706.2 705.1 -651.8 SV-3 966.0 962.0 -908.8 965.6 962.9 -909.6 SV-2 1231.6 1219.9 -1166.7 1234.5 1226.7 -1173.4 SV-1 1727.0 1694.5 -1641.2 1731.4 1703.7 -1650.4 Permafrost Base 1816.4 1779.8 -1726.6 1809.2 1778.3 -1725.0 Ugnu Top(UG4) 2076.5 2019.0 -1965.8 2064.8 2018.0 -1964.7 13 3/8"Casing Shoe 2249.5 2170.2 -2116.9 2241.7 2173.3 -2120.0 TD 16"Surface Hole 2265.0 2183.5 -2130.2 2241.7 2173.3 -2120.0 UG-2 Coal Marker 2614.8 2459.0 -2405.8 2662.5 2488.4 -2435.1 Lower Ugnu 5043.0 3086.8 -3033.6 5080.9 3080.7 -3027.4 Schrader Bluff 6550.3 3342.1 -3288.9 6781.0 3377.1 -3323.8 N Sand Top 6872.0 3394.7 -3341.5 7239.0 3452.5 -3399.2 N Sand Base 7406.0 3480.0 -3426.8 7739.0 3512.6 -3430.3 OA sbll (Top) 8085.0 3531.8 -3478.5 8379.4 3568.7 -3515.4 OA sb12 8215.0 3541.1 -3487.8 8492.1 3578.5 -3525.2 OA sbl3 8350.0 3548.1 -3494.9 n/a n/a n/a 9 5/8"Casing Shoe 8505.0 3555.6 -3502.3 8541.9 3582.7 -3529.4 TD 12 1/4" Borehole 8520.0 3556.3 -3503.1 8541.9 3582.7 -3529.4 8 CANRIG erli Eni Petroleum OP 17-02 and OP 17-02-PB1 3.2.2 Production/ Lateral Section OP17-2-PB1 Zone or Horizon Depth (ft) Prognosed Depth (ft) MD TVD TVDSS MD TVD TVDSS OA sbl3 9,384.0 3,554.1 -3,500.9 Not Prognosed Sidetrack PB1 9,460.0 3,554.2 -3,501.1 OA sb12 9,755.0 3,546.3 -3,493.1 OA sb12 10,472.0 3,544.5 -3,491.3 OA sb13 10,703.0 3,549.3 -3,496.1 OA sb13 10,867.0 3,548.9 -3,495.7 Fault 17-02 PB1 1 11,049.0 3,546.6 -3,493.4 10985.1 3589.45 -3536.2 Base of OA11,310.5 3,535.6 -3,482.4 _OA sb14 11,379.0 3,529.2 -3,476.0 OA sb13 11,557.5 3,516.0 -3,462.8 Fault 17-02 PB1 2 11,667.0 3,511.6 -3,458.3 predicted Throw -21' DTW _OA Sand Top 11,979.0 3,516.5 -3,463.3 OA Sand Top 12,653.2 3,518.0 -3,464.8 Fault 17-02 PB1 3 12,724.0 3,517.7 -3,464.5 OA Sand Top 12,941.0 3,531.2 -3,478.0 OA sb12 13,032.0 3,539.5 -3,486.3 OA sbl3 13,225.5 3,551.2 -3,498.0 OA sbl3 14,357.0 3,545.6 -3,492.4 OA sb12 14,601.3 3,533.5 -3,480.3 Fault 17-02 PB1 4 15,585.0 3,521.0 -3,467.8 Throw -2' DTE OA sb13 15,720.0 3,524.9 -3,471.7 OA sbl4 16,394.0 3,532.5 -3,479.3 _OA sbl4 16,614.0 3,523.8 -3,470.6 OA sb13 16,899.0 3,501.9 -3,448.7 OA sb12 17,020.1 3,491.4 -3,438.2 Fault 17-02 PB1 AA _Minor 17,094.0 3,487.1 -3,433.9 Throw -3' DTW OA Sand Top 17,181.0 3,484.9 -3,431.7 OA Sand Top 17,289.0 3,485.9 -3,432.7 OA Sand Top 17,479.0 3,489.9 -3,436.7 OA Sand Top 17,671.0 3,497.7 -3,444.5 OA sb12 17,780.0 3,507.8 -3,454.6 OA sb13 17,859.0 3,513.5 -3,460.3 Fault 17-02 PB1 5 17,909.0 3,516.9 -3,463.7 predicted Throw - 36' DTE Base of OA 18,310.5 3,503.5 -3,450.3 OA sbl4 18,358.0 3,497.2 -3,444.0 OA sb13 18,508.0 3,484.1 -3,430.9 _OA sb13 18,720.0 3,485.0 -3,431.8 TD 8 1/2" PB1 18,940.0 3,494.2 -3,441.0 18652.9 3549.25 -3496.0 9 CANRIG 00+ ,eni Eni Petroleum OP 17-02 and OP 17-02-PB1 3.2.3 Production/Lateral Section OP17-2 Zone or Horizon Depth (ft) Prognosed Depth (ft) MD TVD TVDSS MD TVD TVDSS OA sbl3 9,384.0 3,554.1 -3,500.9 Not Prognosed Sidetrack PB1 9,460.0 3,554.2 -3,501.1 Not Prognosed OA sbl3 9555.0 3,555.6 -3502.4 Not Prognosed OA sbl3 10482.0 3,552.6 -3499.4 Not Prognosed OA sbl2 10736.0 3,541.9 -3488.7 Not Prognosed OA Top 10933.0 3,533.9 -3480.7 Not Prognosed Fault 17-02-1 11043.0 3,527.7 -3474.5 Not Prognosed Fault 17-02-2 11693.0 3,522.9 -3469.7 Not Prognosed OA sbl2 11778.0 3,524.3 -3471.1 Not Prognosed OA sbl3 12224.0 3,538.4 -3485.2 Not Prognosed Fault 17-02-3 12701.0 3,539.2 -3486.0 Not Prognosed OA sbl2 12870.0 3,537.3 -3484.1 Not Prognosed OA sbl2 13812.0 3,541.5 -3488.3 Not Prognosed OA sbl3 14153.0 3,548.2 -3495.0 Not Prognosed OA sbl3 15107.0 3,536.7 -3483.5 Not Prognosed OA sbl2 15368.0 3,523.9 -3470.7 Not Prognosed Fault 17-02-4 15611.0 3,516.0 -3462.8 Not Prognosed OA sbl2 16250.0 3,611.0 -3457.8 Not Prognosed OA sbl3 16729.3 3,506.0 -3452.8 Not Prognosed Fault 17-02-5 17110.0 3,557.6 -3455.4 Not Prognosed OA sbl3 17980.0 3,518.0 -3464.8 Not Prognosed Fault 17-02-6 18040.0 3,518.8 -3465.6 Not Prognosed Well Op17-02 TD 18200.0 3,522.8 -3469.0 Not Prognosed 10 CANRIG 0111 eni Eni Petroleum OP 17-02 and OP 17-02-PB1 3.3 Lithologic Descriptions/Stratigraphy The Permafrost section of the OP 17-02 consists of moderate beds of sand,conglomerate and claystone with thinner clay interbeds, particularly near the surface.This material is almost entirely included in the permafrost section and contained no oil shows; some minor methane hydrates were encountered. PERMAFROST AND RECENT/QUATERNARY DEPOSITS SURFACE TO 2076.5'MD/-1965.8'TVDSS This interval extends from surface down to the top of the Ugnu at 2076.5' MD and is comprised of a thick sequence of sands, conglomerates and claystones with occasional thin to massive siltstone and poorly developed coals and carbonaceous remains. Sand dominates the upper part of the section with claystone becoming predominant with depth Discrete fragments of sandstone were rarely observed, samples were typified by loose sand and conglomeritic pebble fragments with irregular globular clay masses. Clay masses commonly contained trace to abundant sand mechanically worked into the clay by drilling, circulation and shaker action and had a surface coating of imbedded loose sand. Formation consists of moderate to thick beds with locally abundant thinner interbeds. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 557.4 17.8 107.3 171 0 25.8 PEAKS Depth TG Cl C2 C3 C4I C4N C5I C5N 1357 13 3432 9 1487 123 28368 10 1520 171 39469 11 1636 147 34150 10 1750 126 29669 15 18 1787 144 33963 11 6 1902 63 15515 6 1988 54 14167 2038 46 9670 2064 36 7442 Sand (1000-1060) = light to very light gray; medium lower to medium upper grained; poorly sorted; sub- angular to angular; moderate to low sphericity; unconsolidated quartz sand;70-80%clear colorless to slightly milky white quartz; abundant brownish black to black chert nodules approximately 5-6mm in size; trace to common pyrite as individual grains and as growth on other grains;light gray clayey matrix; non-calcareous; no oil indicators. Sand(1065-1120)=translucent to clear with some white,very pale green, and pale yellowish brown, upper very fine to lower medium, poorly sorted throughout; very angular to sub-angular with some sub-rounded in places; moderate to high sphericity; mostly quartz grain sand matrix; abundant chert nodules, and pyrite crystals were observed throughout; no oil indicators were observed. Claystone (1125-1185) = medium light gray to light gray; clumpy to lumpy; very crumbly to slightly brittle; predominantly irregular fracture throughout;amorphous cuttings habit;very dull to earthy luster;clayey texture with some slightly gritty in places; moderate to thin, interbedded with thick lenses of loose quartz grain sand throughout; no oil indicators were observed. eni Eel Petroleum OP 17-02 and OP 17-02-PB1 SV-2 1231.6' MD/-1166.7' 'TVDSS Sand(1185-1270)= light gray to white with some clear to translucent and very pale blue, and pale yellowish orange,trace dark gray to black with dusky red to reddish brown; upper fine to lower medium,with some upper very fine;poorly sorted; rounded to sub-rounded with some sub-angular;moderate sphericity;very thick lenses of individual sand grains comprised of predominantly quartz sand matrix; interbedded with thin claystone beds; abundant pyrite crystals and as secondary growth on other mineral grains;abundant chert nodules observed throughout sample; no oil indicators were observed. Claystone(1275-1325)=dark gray to light gray,with some medium gray;mostly clotted to somewhat clumpy; mostly irregular fracture;amorphous cuttings habit;very earthy to somewhat dull luster;predominantly clayey texture with some very gritty; moderate to thin bedded, with thick lenses of individual quartz grain sand interbedded throughout; no oil indicators. Sand (1330-1415) = clear to translucent, with dark gray to black and dusky red to reddish brown, very pale blue, and grayish orange pink, and pale brown; upper very fine to lower medium grain; poorly sorted throughout; very well rounded to sub-rounded, with some sub-angular to slightly angular; moderate to high sphericity; some grains appeared to be frosted in places; predominantly individual quartz grain sand; interbedded with thin beds of sandy claystone; abundant pyrite crystals and pyrite as secondary growth on other minerals; abundant chert nodules throughout; no oil indicators were observed. Claystone(1420-1470) = dark gray to medium dark gray with some light gray; pasty to slightly clotted with some clumpy;brittle; irregular fracture;amorphous cuttings habit;very dull to earthy;predominantly clayey with some slightly gritty in places;thin beds of sandy siltstone interbedded with thick lenses of loose,mostly quartz sand; no oil indicators. Sand (1475-1550)=dark gray to gray,with some white, grayish brown, and clear, some translucent, dusky brown, black, and blackish red; predominantly individual quartz grain sand matrix; upper very fine to lower medium grain; poorly sorted; well rounded to sub-rounded, with some very angular to sub-angular; mostly moderate to slightly high sphericity; abundant chert nodules throughout; abundant pyrite crystals, and secondary pyrite growth covering other mineral grains; no oil indicators were observed; no sample fluorescence. Sand(1555-1605)=translucent to clear with black, dark gray,gray,white, blackish red,and dusky red hues; mostly loose unconsolidated quartz grain sand;upper very fine to upper fine;fair to well sorted;very angular to sub-angular, with some sub-rounded; moderate to high sphericity; lesser abundance of pyrite crystals and chert nodules; no oil indicators, or sample fluorescence. Claystone(1610-1665) = medium dark gray to dark gray with some medium light gray; pasty to somewhat clumpy; brittle; irregular fracture; amorphous cuttings habit; very dull to earthy luster; very clayey texture throughout with some slightly gritty in places; interbedded with thick lenses of loose quartz grain sand; some pyrite crystals scattered throughout; no oil indicators were observed. SV-1 1730.5' MD/-1644.5'TVDSS Sand (1670-1735) = predominantly clear to translucent with some white, light gray, pale yellowish brown, dusky yellowish brown, black,and blackish red hues; predominately loose unconsolidated quartz sand matrix; upper very fine to upper fine;fair to well sorted;very angular to sub-angular with some sub-rounded;moderate to high sphericity; lesser abundance of pyrite crystals and chert nodules; no oil indicators were observed; no sample fluorescence. Siltstone (1740-1795) = dark gray to medium dark gray, with some medium light gray; clotted to clumpy; crumbly; irregular fracture;amorphous cuttings habit;earthy to somewhat dull luster;clayey texture throughout with some slightly gritty; interbedded with thick lenses of loose quartz grain sand; some pyrite crystals scattered throughout; no oil indicators were observed. 12 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 PERMAFROST BASE 1816.4' MD/-1726.6'TVDSS Sand (1800-1870) = clear to translucent, with white, light gray, very pale blue, pale yellowish brown, black, blackish red,and very dusky red hues;mostly loose quartz grain sand matrix;upper very fine to upper fine;fair to well sorted;very angular to sub-angular,with some sub-rounded; moderate to high sphericity;thick lenses of loose unconsolidated quartz sand interbedded with thin beds of sandy siltstone; some pyrite crystals throughout; no oil indicators; no sample fluorescence was observed. Claystone(1870-1960)=light to medium light gray to dusky brown;soft to firm;slightly cohesive;moderately adhesive; clumpy to curdy consistency;greasy to slightly resinous luster;grades between silty claystone and clayey siltstone;clayey silty texture; light gray material seems to be clayey matrix and darker grains are more borderline siltstones; silty claystones are thin interbedded layers between larger silty sand layers; no visible structures present in claystone;trace individual micro-crystalline pyrite grains;trace brownish black to black chert nodules; non-calcareous; no oil indicators; no sample fluorescence observed. Claystone(1960-2050)=medium light to light gray overall; soft to slightly firm in part; moderately adhesive; slightly cohesive; samples consist of globular clayey masses containing reworked sand grains; dense malleable; greasy to slightly waxy luster; smooth clayey texture; no visible structures; reddish brown to brownish black coal; blocky fracture; resinous slightly greasy luster; silty carbonaceous shale interbedded; slightly splinter to wedge like; trace pyrite found in samples with amount decreasing with depth; non- calcareous; no oil indicators; no sample fluorescence observed. UGNU 2076.0' MD/-1965.2'TVDSS TO 6550.5' MD/-3289.6' TVDSS The Ugnu is an Upper Cretaceous and Lower Tertiary shallow marine and deltaic deposit. The Ugnu, in places, contains oil which is bitumen and extra heavy crude with API gravities between 8° and 12°. Upper Ugnu (also known as the "L" sand) was encountered at 1970.9' MD, continuing to the Lower Ugnu /( "M" sand)at 4612'MD and leaving the Ugnu at it's contact with Schrader Bluff at 5178" MD, Fault#1 having not been identified on logs. The Upper Ugnu is characterized by interbedded layers of sand, sandstone and claystone with occasional coal beds. The sands are primarily upper fine to lower medium in size. At 2818'MD the UG-2 Coal Bed Marker was encountered. The Lower Ugnu is an unconsolidated sand of upper fine to lower medium grains with thin beds of carbonaceous material. No recoverable hydrocarbons were encountered and only minimal oil indicators were seen. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 1711 3.2 154.3 79 0 15.7 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 2545 23 4672 2905 19 3966 3168 46 9454 3387 50 10165 3539 62 12747 3693 63 13140 5046 44 11260 5070 21 4768 5129 74 16704 Sand/Conglomeratic Sand(2050-2110)=very light to light to medium light gray quartz sand;medium lower to fine upper to medium upper and trace coarse lower; poor to moderately sorted;very angular to angular to trace sub-angular; loose unconsolidated sands to some firm;70-80%clear colorless to translucent milky white 13 CANRIG Eel Petroleum OP 17-02 and OP 17-02-PB1 quartz; trace to common orange jasper and small sheets of muscovite; non calcareous; no oil indicators; no sample fluorescence. UGNU TOP 2076.0' MD/-1965.2' TVDSS Claystone(2110-2170)=medium light to light gray;curdy pasty consistency;slightly dense tenacity;massive reworked globular masses containing reworked sand grains;waxy greasy luster; clayey silty to slightly gritty texture depending on amount of sand grains;no visible structure;clayey masses also contain reddish brown to brownish black splinter shale fragments and coal fines; non-calcareous. Sand/Conglomeratic Sand (2170-2265) = light to medium light to very light gray overall; medium lower to fine upper to medium upper and trace coarse lower; poor to moderately sorted; sub-rounded to rounded to trace sub-angular; loose unconsolidated sands;predominantly clear colorless quartz to translucent milky white to light gray quartz; common to abundant dark gray to black minerals/lithics; trace pyrite and orange jasper; common to abundant light bluish gray to pale blue green minerals; non-calcareous; no oil indicators. TD 16" BOREHOLE 2265.0" MD/-2130.2'TVDSS; 13 3/8 SCP 2249.5' MD/-2117.0' TVDSS Sand/Sandstone(2265-2410)=medium light to light to medium gray;cement contamination was abundant at top of interval; sample consisted mainly of quartz sand framework; medium lower to medium upper; poorly sorted;sub-rounded to sub-angular;moderate to high sphericity;predominantly disaggregated sands with soft to firm sandstones;trace sandstones cemented with pyrite;trace orange and yellow jasper,trace to common small muscovite sheets;predominantly clear colorless to translucent milky white quartz;5-15%grayish black to black lithics; trace to common pale blue green to moderate blue green lithics; no oil indicators; slightly to moderately calcareous. Sand/Sandstone/Conglomerate (2410-2530) = light to very light gray to light brownish gray throughout sample interval;medium upper to medium lower to coarse lower to fine upper;sub- angular to angular to trace sub-rounded; moderately to moderately well sorted; moderate sphericity; predominantly disaggregated sand with moderately cemented conglomerates and sandstones;firm to hard to trace very hard;trace to common amounts of silty/clayey matrix material throughout sample interval;abundant reddish brown to brownish black coal fragments found in the 2500'sample;blocky;slightly silty texture;trace amounts of pyrite as individual grains and as growth on other minerals;trace to common pale blue green to moderate blue green lithics; 60-70% clear colorless to translucent milky white quartz; no oil indicators; no sample fluorescence observed; very calcareous. Siltstone(2530-2650)=light gray to light brownish gray overall;very soft to soft;very slightly adhesive when prodded; irregular cuttings habit; dull earthy luster; silty to almost gritty texture to somewhat clayey in parts; trace thin micro-lamina only present in slight few grains;trace pyrite scattered throughout sample interval as individual grains; no oil indicators; no sample fluorescence; moderately to very calcareous. Ugnu-2 Coal Bed Marker 2614.0' MD/-2404.0'TVDSS Coal (2600-2620) = reddish brown to brownish black; firm to slightly hard crumbly brittle tenacity; hackly fracture; irregular splinter cuttings habit;earthy greasy to slightly resinous luster; smooth silty to slightly shaly texture; interbedded with thin sands and silts; no odor; no oil indicators; no sample fluorescence. Sand/Sandstone(2650-2730)= light to very light to medium light gray; fine upper to medium lower to trace medium upper; moderately to moderately well sorted;disaggregated to soft to friable;sub-angular to angular to trace sub-rounded;moderate to high sphericity;70-80%clear colorless to translucent milky white to slightly smokey quartz; trace pyrite as individual grains; trace to abundant pale blue green to moderate blue green lithics/glauconite; no odor; no oil indicators; no sample fluorescence; slightly to moderately calcareous. Sand/Sandstone (2725-2815) = light gray, white, clear, translucent, very pale blue; pale blue green, pale yellowish brown, and dark yellowish brown hues; predominantly quartz grain sand matrix; upper very fine to upper fine with some lower medium grain sand; moderate to well sorted throughout; well rounded to sub- rounded with some sub-angular;moderate to high sphericity;80%-90%clear to translucent loose uncemented 14 CANRIG cm Eni Petroleum OP 17-02 and OP 17-02-PB1 quartz sand; 10%calcareous cemented sandstone lenses interbedded with the loose sand;abundant pyrite as individual crystals and as secondary growth on other mineral surfaces;loose sand; no oil indicators;no sample fluorescence was observed. Sand (2820-2920)= predominantly clear to translucent with white, light gray, grayish blue green, light blue, pale green, moderate yellowish brown, dusky brown, dusky red, and blackish red hues; mostly quartz sand matrix; upper very fine to upper fine with some lower medium grain sand; moderate to well sorted throughout; very angular to sub angular with sub-rounded to very well rounded; moderate to high sphericity throughout; predominantly translucent to clear loose grain quartz sand,interbedded with 5%to 10%calcareous cemented sandstone with 15%-20% dark colored lithic fragments; abundant pyrite, as individual crystals and as secondary growth on other mineral surfaces; no oil indicators were observed; no sample fluorescence. Claystone(2925-2995) = medium gray to medium light gray; clumpy to clotted; mostly crumbly with some slightly brittle; irregular fracture; amorphous cuttings habit; predominantly earthy to slightly dull luster; very clayey with some gritty in places; very thin claystone, interbedded with thick lenses of loose, clear to translucent quartz sand; slightly calcareous; abundant pyrite, as individual growth crystal and as secondary growth on other mineral surfaces; no oil indicators; no sample fluorescence. Sand/Sandstone(3000-3110)=translucent to clear, with some milky white, light gray, pale blue, pale blue green, pale green,dark yellowish orange,dusky red,and blackish red hues;75%-80%loose unconsolidated quartz grain sand matrix; upper very fine to upper fine grain sand with some lower medium; moderate to well sorted;very angular to sub-angular with some sub-rounded to very well rounded;moderate to high sphericity; thick sand lenses interbedded with thin beds of sandy claystones and siltstones; 40%-60% loose unconsolidated translucent to clear quartz sand,with 10%-15%dark colored lithic fragments throughout;mica flakes throughout;abundant pyrite, both as individual crystals and as secondary growth on other minerals; no oil indicators were observed, no sample fluorescence. Siltstone(3115-3175)=medium gray to light gray;mushy to pasty;very brittle to somewhat crumbly;irregular fracture; amorphous cuttings habit; dull to slightly earthy luster; mostly silty to somewhat gritty texture; thin beds of sandy siltstone interbedded with thick lenses of loose uncemented quartz sand; abundant pyrite throughout; some light gray to very light gray mica flakes throughout; no oil indicators; no sample fluorescence. Sand(3180-3290)= predominantly clear to translucent,with milky white,grayish blue green, light blue, pale green, moderate yellowish brown,dusky brown,dusky red,and blackish red hues; mostly quartz sand matrix; upper very fine to upper fine with some lower medium grain sand; moderate to well sorted; very angular to sub-angular, with some slightly sub-rounded in places; moderate to high sphericity; very thick loose unconsolidated quartz sand lenses, interbedded with sandy siltstone,with some sandy silty claystone; 80%- 90%translucent to clear quartz sand with 10%-20%dark colored lithic fragments; some pyrite crystals,with some pyrite as secondary growth on mineral surfaces; light gray mica fragments throughout; no oil indicators were observed; no sample fluorescence. Siltstone(3295-3365)=medium gray to light gray with some light brownish gray;very pasty to slightly mushy; mostly brittle with some slightly crunchy; irregular fracture throughout; amorphous cuttings habit; earthy to somewhat dull;very silty texture to somewhat gritty;very thin sandy siltstones interbedded with thick lenses of loose unconsolidated quartz sand; abundant pyrite, as individual crystals,and as secondary growth on other minerals; some light gray, vitreous mica fragments throughout. no oil indicators; no sample fluorescence. Sand/Sandstone(3375-3480)=translucent to clear with some milky white,white, grayish blue green, light blue, pale green, moderate yellowish brown, dusky brown, dusky red, and blackish red hues; mostly quartz sand matrix; upper very fine to upper fine with some lower medium grain sand; moderate to well sorted throughout; very angular to sub angular with some sub-rounded; moderate to high sphericity; mostly loose unconsolidated quartz sand lenses, interbedded with sandy siltstone,with some sandy silty claystone; 70%- 80%translucent to clear quartz sand with 20%-30% dark colored lithic fragments; some pyrite as individual crystals,and as secondary growth on mineral surfaces; light gray mica fragments throughout; no oil indicators were observed; no sample fluorescence. 15 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 Claystone(3490-3545)=light gray to medium gray;mostly clumpy;brittle; irregular fracture;amorphous habit; dull to slightly earthy luster; mostly silty to somewhat gritty texture;thin beds of sandy claystone interbedded with thick lenses of loose uncemented quartz sand, and sandy siltstones; some light gray to very light gray mica flakes throughout; no oil indicators; no sample fluorescence. Sand/Sandstone(3550-3630)=mostly clear to translucent,with milky white,gray,pale blue,pale blue green, pale green, dark yellowish orange, dusky red, and grayish red hues; predominantly quartz grain sand matrix throughout; lower fine to lower medium grain sand;moderate to well sorted;angular to sub-angular,with some sub-rounded; moderate to high sphericity; interbedded with thin beds of sandy siltstones; some light gray to very light gray mica flakes throughout; pyrite present in both individual crystals,and secondary growth; no oil indicators were observed; no sample fluorescence. Siltstone(3635-3705)=light gray to medium light gray,with some medium dark gray;mostly mushy to slightly pasty; crumbly to brittle; irregular fracture; amorphous cuttings habit; earthy to dull luster; mostly silty to somewhat gritty texture; thin beds of sandy siltstone interbedded with thick beds of loose unconsolidated quartz sand; pyrite observed in both individual crystal and secondary growth; light gray vitreous mica flakes observed throughout; no oil indicators; no sample fluorescence. Sand/Sandstone(3705-3840)= light to very light gray to slight brownish secondary hues; medium lower to fine upper to medium upper grained; moderately sorted; sub-angular to sub-rounded to angular in part; moderate to low sphericity; predominantly loose disaggregated sand; soft to friable to moderately firm/hard; hard cuttings consist of very calcareous cement; trace to common vitreous mica fragments; sample predominantly consists of clear colorless to translucent milky white to very light gray quartz; about 20% brownish black to black mineral/lithics; larger sand lenses are interbedded with thinner lenses of siltstone and clays;siltstones grade between a clayey siltstone and silty claystone;varies from dense to brittle;very soft to crumbly; trace orange jasper; trace pale blue green to moderate blue green lithics/glauconite; samples are very calcareous; no odor; no oil indicators; no sample fluorescence is observed. Siltstone(3840-3910)=medium light to medium gray to brownish gray throughout sample interval;samples consisted of dense brittle to slightly crumbly in part; irregular fracture;dull earthy to somewhat resinous luster; texture grades between clayey siltstone and silty claystone; becomes more gritty to granular depending on amount of reworked sand grains; no structure visible;possibly slightly tuffaceous; no odor;no oil indicators; no sample fluorescence observed; no reaction with HCI. Sand/Sandstone(3910-4060)= light to medium light to medium gray overall; medium lower to fine upper to medium upper; moderately to poorly sorted; sub-angular to angular to sub-rounded in part; moderate to low sphericity; loose disaggregated sands;sandstone cuttings are soft to friable;trace pyrite as individual grains; clear colorless to translucent milky white to slightly smokey quartz predominates;20%brownish black to black minerals/lithics; interbedded siltstone lenses are increasing with depth of interval;trace orange jasper;trace coal fines; no odor; no oil indicators; slightly to moderately calcareous. Siltstone(3970-4060)=light gray to medium light gray to brownish gray throughout sample interval;clumpy to mushy; slightly brittle in part; irregular fracture; dull earthy luster; silty to gritty texture; trace to common brownish black to black coal fragments found in the 3970'sample;greasy resinous; hackly fracture;wedge like cuttings;very thin coal lens interbedded with the clayey siltstones; no odor; no oil indicators; non-calcareous. Sand (4060-4140) = light to medium light gray to light olive gray throughout sample interval; fine upper to medium lower grained; poor to moderately sorted; sub-angular to sub-rounded to few angular grains; loose disaggregated sands; predominantly clear colorless to translucent milky white to very light gray quartz sand; 20-30%brownish black to black mineral/lithics gives salt and pepper appearance;trace pyrite;trace orange and yellow jasper; trace to common very pale blue to pale blue green lithics;very slightly to non-calcareous; no oil indicators or sample fluorescence Siltstone(4140-4210)=light to medium light gray to light brownish gray;mushy to clumpy;very soft to slightly malleable;slightly adhesive when prodded;earthy greasy somewhat resinous luster;clumpy cuttings contain reworked sand grains;texture is silty to gritty; even finer grained grading toward clay possibly disturbed clay matrix from sand layers;varies between silty clay and clayey silts; no oil indicators or sample fluorescence;no reaction with HCI. 16 CANRIG Igh em Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand(4210-4300)=light to medium light gray with secondary light brownish hues;fine upper to fine lower to medium lower grained;moderately to moderately well sorted;sub-angular to sub-rounded to trace angular;low to moderate sphericity; loose disaggregated sands; interbedded with thin lenses of siltstone; 70-80% clear colorless quartz;trace orange and yellow jasper;common to abundant very fine brownish black to black lithics giving salt and pepper appearance; trace grayish blue green glauconite; trace vitreous mica fragments; no reaction with HCI; no odor and no oil indicators; no sample fluorescence observed. Sand/Conglomerate Sand (4300-4420) = light to medium light gray to light olive gray throughout sample interval;fine upper to medium lower;fine lower and medium upper;trace coarse lower;well to moderately well sorted;sub-angular to angular to trace sub-rounded; loose disaggregated sands;predominantly clear colorless to translucent milky white to smokey quartz;about 20-30%dark brown to brownish black mineral/lithics;trace vitreous mica fragments;trace orange and yellow jasper;trace to common pale blue green to moderate blue green glauconite; interbedded siltstones decreasing with depth in this interval; no odor or oil indicators; no sample fluorescence; samples are non calcareous. Sand(4420-4510)=medium light to light to light brownish gray throughout sample interval; medium upper to medium lower to coarse lower; moderate to poorly sorted; angular to sub-angular to trace sub-rounded; moderate to high sphericity; predominantly loose disaggregated sand; predominantly very light gray to translucent milky white to transparent quartz;compositionally immature;structurally immature; 10-20%dusky brown to black minerals/lithics;trace orange jasper;trace grayish blue green to dusky blue green glauconite; no odor; no oil indicators; no sample fluorescence observed; very slightly calcareous. Sand/Sandstone/Conglomerate Sand (4510-4600) = medium light to medium gray to light gray overall; medium lower fine upper; trace coarse upper and medium upper; poorly sorted; sub-angular to angular to trace sub-rounded; moderately spherical; predominantly loose disaggregated sands with few soft to friable sandstone cuttings;light gray to translucent milky white to transparent quartz predominates;very thin lenses of siltstone increasing with depth of interval;thin interbedded layer of coal found in 4570'sample;trace orange jasper;trace light blue to moderate blue green glauconite; no oil indicators; no sample fluorescence observed; no reaction with HCI. Siltstone (4610-4690) = light gray to light brownish gray to medium light gray overall; mushy lumpy; brittle crumbly tenacity; earthy fracture; dull earthy luster; silty clayey to slightly gritty in part; thin siltstone lenses interbedded within larger sandstone layers; interbedded with very thin silty shaly coals; trace pyrite as individual grains throughout sample interval;trace orange jasper and moderate blue green glauconite; trace amounts of metal shavings found in the sample interval; no odor; no oil indicators; no sample fluorescence observed; non-calcareous. Sand/Sandstone(4690-4780)=light to medium light gray to light brownish gray throughout sample interval; fine lower to fine upper to medium lower grained; moderately well to well sorted; angular to sub-angular to trace sub-rounded; moderately spherical;predominantly loose disaggregated sands;sandstone cuttings are friable to moderately hard; 80-90% transparent colorless to translucent milky white quartz; trace pyrite as individual grains; 5-10% very fine brownish black to black lithics giving salt and pepper appearance; interbedded with thin clays and siltstones; trace moderate blue green glauconite; no odor; no oil indicators; non-calcareous. Sand/Sandstone (4780-4860) = clear to translucent, with white, light gray, pale blue, pale green, and moderate yellowish brown; predominantly quartz grains sand matrix; upper very fine to upper fine;well sorted throughout; very well rounded to sub-rounded with some slightly sub-angular; moderate sphericity; mostly 70%-80% loose unconsolidated quartz sand interbedded with calcareous cemented sandstone, and sandy claystones and sandy siltstones; some pyrite in crystal form was observed throughout; no oil indicators were observed; no sample fluorescence. Claystone(4865-4930)-medium gray to medium light gray;mostly clotted to somewhat pasty;brittle;irregular fracture;amorphous cuttings habit; predominantly earthy to slightly dull;very clayey to gritty texture;thin beds of sandy claystone interbedded with thick beds of 60%-70% loose uncemented quartz sand, with very fine grained sandstone, and sandy siltstone; abundant pyrite crystals throughout; no oil indicators; no sample fluorescence was observed. 17 CANRIG l Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand/Sandstone(4935-5020)=mostly translucent to clear,with some white,pale blue,pale green,and dark yellowish orange;predominantly loose quartz grain sand matrix; upper very fine to upper fine;moderate to well sorted;well rounded to sub-rounded with some grains slightly sub-angular;moderate to high sphericity;60%- 70%loose unconsolidated quartz sand interbedded with calcareous cemented fine grained sandstone,sandy claystone and sandy siltstone;abundant pyrite,both as individual crystals and as secondary growth on mineral surfaces; no oil indicators were observed; no sample fluorescence. Siltstone (5020-5085) = medium light gray to light gray; slightly mushy to pasty; brittle; irregular fracture; amorphous cuttings habit; dull to earthy luster; mostly silty to gritty; sandy siltstones interbedded with thick beds of 50%-60% loose uncemented quartz sand, with very fine grained sandstone, and sandy siltstone; abundant pyrite crystals throughout; no oil indicators; no sample fluorescence was observed. LOWER UGNU 5043.0 MD/-3033.6 TVDSS Claystone(5090-5155)=dark gray to medium light gray;mostly mushy to somewhat clumpy;brittle;irregular fracture; amorphous cuttings habit; mainly very dull to earthy;very clayey to gritty texture;thin beds of sandy claystone interbedded with thick beds of 50% -60% loose uncemented quartz sand, with very fine grained sandstone,and sandy siltstone;abundant pyrite crystals throughout;dark brown free oil and oil stain on some sand grains; very slight dull yellow green sample fluorescence, 5% - 10%. Sand(5165-5250)=predominantly clear to translucent,with some white,pale blue,pale green,dark yellowish orange, and dusky red hues; mostly loose uncemented quartz grain sand; upper very fine to upper fine;well sorted; very angular to sub-angular with some sub-rounded; moderate to high sphericity; 60% - 70% unconsolidated sand, interbedded with thin beds of sandy claystones and sandy siltstones;abundant pyrite,in both crystal form secondary growth; dark brown free oil on individual sand grains and on shaker; 15%-20% patchy dull yellow green sample fluorescence; very delayed milky white solvent cut. Claystone (5255-5315) = light gray to medium light gray; pasty to lumpy; irregular fracture; amorphous cuttings habit; very dull to somewhat earthy; very clayey to gritty texture; thin beds of sandy claystone interbedded with thick beds of 60% - 70% loose uncemented quartz sand, with calcareous cemented sandstone,and sandy siltstone;abundant pyrite,both as crystals and secondary growth; no oil indicators were observed. Sand/sandstone(5315-5355)=light to medium light gray;fine upper to medium lower disaggregated sands; fine lower calcareous cemented sandstone cuttings. Sand/sandstone/conglomerate(5355-5410)=light gray to medium light gray;medium upper to coarse lower to coarse upper; trace medium lower; sandstone cuttings are fine upper; sub-angular to sub-rounded; moderate sphericity; drill rate increased with new bit and decrease in calcareous cement; no oil indicators or sample fluorescence; no reaction with HCI. Siltstone(5410-5470)=pale brown to dark yellowish brown to brownish gray;cuttings are moderately hard to hard to trace easily friable; irregular to slightly hackly fracture;amorphous cuttings habit;dull earthy luster;silty to gritty texture;thin dark brown micro-lamina present on the softer cuttings;trace pyrite and orange jasper in sample interval; no oil indicators or sample fluorescence. Siltstone(5470-5530)=medium gray to medium dark gray to dusky yellowish brown;moderately hard to hard cuttings; irregular fracture; amorphous cuttings habit; dull earthy with a slightly sparkling luster; silty gritty texture; thick beds of hard siltstone with thin interbedded sands/sandstones; at base of interval trace light brown oil staining; no odor; trace faint pale yellow sample fluorescence. Sand/sandstone/conglomerate sand(5530-5620)=medium dark to medium to medium light gray overall; medium upper to coarse lower;trace medium lower and trace coarse upper; predominantly milky white to gray to light bluish gray quartz; sub-rounded to rounded; moderate to sub-spheroidal; sandstone cuttings are calcareous cemented and fine grained; trace pyrite grains; trace orange jasper and moderate blue green glauconite; 5590' sample contains about 10% brownish black coal fine/carbonaceous shale fragments; no 18 CANRIG las eni Eni Petroleum OP 17-02 and OP 17-02-PB1 odor;trace light brown oil staining in samples;trace very pale yellow sample fluorescence;possibly dead oils; slightly to moderately calcareous. Sand/sandstone(5620-5720)=medium light to light gray to medium gray;medium lower to fine upper;poorly to very poorly sorted; sub-angular to angular; low to moderate sphericity; structurally immature; loose dis- aggregated sands; sandstone cuttings are fine to very fine cemented grains; 70-80% clear colorless to translucent milky white to very light gray quartz; trace pyrite and orange jasper; trace amounts of metal shavings found in sample trays; trace brown oil staining; trace very faint yellow fluorescence; no cut to very slow very faint yellowish white cut fluorescence; moderate brown residue with bright yellow residual fluorescence; non-calcareous. Sand(5720-5800)=light to medium light gray to medium gray; medium lower to fine upper grained; poorly to moderately sorted;sub-angular to sub-rounded to trace angular; loose dis-aggregated sands; predominantly clear colorless to milky white to gray smokey quartz; trace orange jasper; trace pyrite as individual grains; trace light green to light blue green glauconite; about 10%grayish black to black very fine grained lithics; no odor; no oil indicators or sample fluorescence. Sand/sandstone/conglomerate sand (5800-5860) = medium light to medium gray to light gray; medium lower to fine upper to medium upper;trace coarse lower and larger;sandstone cuttings calcareous cemented; sub-rounded to sub-angular;disaggregated;friable to moderately hard;trace light brown oil staining; no odor; trace faint yellow sample fluorescence; moderately calcareous. Siltstone(5860-5950)=light brownish gray to light gray to pale yellowish brown;very soft;mushy;amorphous cuttings habit; dull greasy luster; silty to gritty texture; thin lenses of silt interbedded with larger sand layers; samples consist of reworked sand grains; non-calcareous; no oil indicators or sample fluorescence. Sand/sandstone(5860-5980) = light to medium light gray with brownish secondary hues; fine upper to medium lower to trace medium upper; moderately to moderately well sorted; angular to sub-angular; low to moderate sphericity; loose disaggregated sands; sandstone cuttings are fine lower and calcareous cemented; 70-80% clear colorless to translucent milky white quartz;trace amounts of pyrite grains; no odor; trace oil staining; trace faint yellow sample fluorescence; possible mud additive. Sand/sandstone(5980-6040)=medium light to light gray to light brownish gray; medium lower to fine upper to medium upper; moderately to poorly sorted; angular to sub-angular to trace sub-rounded; predominantly loose dis-aggregated sands;firm to moderately hard sandstone cuttings;calcareous cement;trace light brown oil staining; very faint yellow sample fluorescence; possible mud additive contamination. Siltstone(6050-6105)= medium gray to medium light gray, with some light brownish gray; pasty to mushy; brittle; irregular fracture; amorphous cuttings habit; mostly dull to somewhat earthy; very silty, with some slightly clayey to very gritty texture; thin siltstone beds interbedded with thick beds of sand and sandstones, with sandy claystone; no oil indicators were observed; no sample fluorescence. Sand/sandstone (6110-6185) = mostly translucent to clear, with some white, light gray, greenish gray; brownish gray, pale blue,and pale green hues; predominantly quartz grain sand matrix; upper very fine grain to lower medium; moderately sorted throughout; sub-rounded to well rounded with some sub-angular; moderate sphericity; 60% - 70% loose unconsolidated quartz sand, interbedded with, slightly calcareous cemented sandstone,sandy siltstone,and sandy claystones;some pyrite crystals throughout;no oil indicators; no sample florescence. Claystone (6190-6250) = medium dark gray to brownish gray, with some medium gray; mostly mushy to slightly pasty;very brittle throughout; irregular fracture;amorphous cuttings habit; mostly earthy to somewhat dull;very silty,with some slightly clayey to very gritty texture;thin siltstone beds interbedded with thick beds of sand and sandstones, with sandy claystone; no oil indicators were observed; no sample fluorescence 19 CANRIG la eni Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand/sandstone (6255-6335) = translucent to clear, with some milky white, light gray, greenish gray; brownish gray, pale blue, and pale green, dark gray, blackish red, and dusky red hues; mostly quartz grain sand matrix; upper very fine grain to lower medium; moderately sorted throughout; sub-rounded to rounded with some slightly sub-angular; moderate sphericity; 60% - 80% loose unconsolidated quartz sand, interbedded with,slightly calcareous cemented sandstone,sandy siltstone,and sandy claystones;abundant pyrite crystals; no oil indicators; no sample florescence. Siltstone (6340-6395) = light brownish gray to brownish gray, and light gray; mostly mushy to pasty throughout; irregular fracture;amorphous cuttings habit;earthy to somewhat dull luster;very silty,with some very gritty to slightly gritty texture;thin siltstone beds interbedded with thick beds of sand and sandstones,with sandy claystone; abundant pyrite crystals throughout; no oil indicators were observed; no sample fluorescence. Sand/sandstone(6405-6480)=clear to translucent,with some white; light greenish gray, black,dusky brown and moderate yellowish brown hues; predominantly quartz grain sand matrix; upper very fine grain to lower medium; moderately sorted throughout; sub-rounded to well rounded with some sub-angular; moderate sphericity;30%-40%loose unconsolidated quartz sand, interbedded with,thicker beds of siliceous cemented sandstone, sandy siltstone, and sandy claystones; abundant pyrite crystals; no oil indicators; no sample florescence. Siltstone(6485-6555)=light gray to light brownish gray; mushy to somewhat clumpy;crumbly to very brittle; irregular fracture; amorphous cuttings habit; earthy to somewhat dull luster; mostly silty, with some slightly gritty texture; very thin siltstone beds interbedded with thick beds of sand and sandstones; abundant pyrite crystals throughout sample;20%-30%bright dull yellow green sample fluorescence;very slow straw yellow solvent cut; no free oil in sample; no petroleum odor. SCHRADER BLUFF 6550.5 MD/-3289.6' TVDSS TO 8085.0'MD/-3480.3'TVDSDS Drill Rate(ft/hr) _ Total Gas (units) Maximum Minimum Average Maximum _ Minimum Average 210.5 2.5 112.7 924 4 155.3 PEAKS Depth TG Cl C2 C3 C4I C4N C5I C5N 6909 382 109736 1541 378 729 209 456 38 6986 383 223421 2888 782 1480 433 978 67 7059 370 217153 2559 762 1312 776 903 38 --- 7219 144 28987 420 185 277 77 354 - 7373 172 52647 555 234 228 93 318 20 7985 58 17547 139 92 102 114 32 14 8101 426 117254 1954 2612 1443 2077 1197 836 8129 574 168985 3736 4750 2701 3827 2222 1564 8173 723 167400 3741 4662 2496 3526 1995 1399 8269 681 155050 2947 4362 2500 3615 2118 1482 8400 924 223056 5310 6728 3677 5153 2879 1989 8499 878 199012 4093 5975 3576 5330 3524 2609 The Schrader Bluff formation is the zone of interest in this well. At this location, it consists of two main sands, the"N"Sand and the"OA"Sand. The Schrader Bluff is an Upper Cretaceous turbidite deposit formed as sand lobes. In general, the"OA" Sands contain viscous crude with an API gravity between 16° and 19°. The"N" Sand was encountered at 6664' MD. The portion of this section above the intermediate casing point was drilled using water/gel mud ranging to 9.2 ppg.After casing point the hole was displaces to Versi-Pro oil base mud at 8.4ppg and the hole was drilled to TD in an under balance condition to attempt to optimize porosity/permeability factors.While attempting to complete the well,the hole collapsed below 9400'MD and 20 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 an open hole sidetrack was performed at 9460'.After the sidetrack mud weight was increased to a range of 9.1 to 9.3 ppg to maintain hole integrity. The sidetrack has been maintained as OP17-02 and was TDd at 18200'. The original hole has been re-named OP17-02-PB1 and TDd at 18940'. Sand/sandstone (6560-6635) = translucent to clear, with some pale green, pale blue, black, blackish red hues; mostly quartz grain sand; upper very fine to upper medium; fair to poorly sorted; very angular to sub- angular, with some slightly rounded to sub-rounded; moderate sphericity; moderately thick beds of quartz sand, and sandstone, interbedded with thin beds of sandy siltstone; abundant pyrite crystals throughout sample; 15% -20% bright yellow green sample fluorescence; slow straw yellow solvent cut; no free oil; no petroleum odor; some sand grains exhibited dark brownish black staining. N SEQUENCE TOP 6664.0' MD/-3308.1'TVDSS Siltstone (6645-6715) = brownish gray to light brownish gray; mostly pasty to somewhat mushy; brittle to crumbly; irregular fracture; amorphous cuttings habit; mostly dull to earthy luster; predominantly silty, with some slightly gritty texture; very thin siltstone beds interbedded with thick beds of sand and sandstones; abundant pyrite crystals throughout sample; 20% - 30% bright greenish yellow sample fluorescence was observed; slow milky straw yellow solvent cut; no free oil; no petroleum odor. Sand/sandstone(6720-6825)=translucent to clear with some white,milky white,pale green,pale blue,black, reddish black, and dusky red hues; predominantly quartz grain sand; upper very fine to upper medium grain sand;fair to poorly sorted;angular to sub-angular with some sub-rounded in places;moderate sphericity;very thick sand and sandstone beds, interbedded with thin beds of sandy siltstone; 40% - 50% loose unconsolidated quartz sand,with friable to very hard siliceous cemented sandstone;abundant pyrite in crystal form throughout the sample;30%-40%bright greenish yellow sample fluorescence;slow straw yellow solvent cut; some sand grains appeared to have a dark brownish black stain; no free oil was observed; no petroleum odor. Claystone (6830-6875) = brownish gray to light brownish gray; pasty to mushy; very crumbly to brittle; irregular fracture;amorphous cuttings habit;very earthy to somewhat dull luster;mostly silty,with some slightly gritty texture; 10% - 15% dull green yellow sample fluorescence; slow straw yellow solvent cut. N SAND TOP 6872.0' MD/-3342.6'TVDSS Sand/sandstone(6880-6950)=clear to translucent,with some white, light gray,pale green,pale blue,black, moderate yellowish brown,and dusky brown hues; predominantly quartz grain sand matrix; upper very fine to upper medium; fair to poorly sorted; very angular to sub-angular,with some slightly sub-rounded; moderate sphericity;85%-95%bright yellow sample fluorescence; instantaneous milky white solvent cut;some free oil in sample; strong petroleum odor; abundant pyrite crystals. N SAND SUBLOBE 2 6934.0' MD/-3353.3' TVDSS Sand/sandstone(6955-7050)=translucent to very light gray to medium light gray with some light bluish gray, greenish gray and white hues; upper fine to lower medium fine grain progressing to upper very fine to lower fine grain;predominantly unconsolidated disaggregated quartz grains;very well to well sorted;sub-rounded to rounded with fair amount of sub-angular; moderate to high sphericity; 85%-95% bright yellow to orangish yellow fluorescence;strong petroleum odor;abundant to trace amounts of free oil;trace to common amounts of oil stained quartz grains; instantaneous milky white cut; bright yellow to yellowish orange to bright orange residual cuts; trace amounts of chert and siltstone. N SAND SUBLOBE 3 6978.0' MD/-3360.9' TVDSS Sand/sandstone (7055-7160) =very light gray to medium light gray with light bluish gray to greenish gray hues and common to abundant translucent grains; loose disaggregated sand; lower fine to upper very fine; very well to well sorted; sub-rounded to sub-angular with some rounded; moderate to high sphericity; rare to occasional chert and siltstone fragments;even orangish yellow to bright yellow sample fluorescence;moderate 21 CANRIG Lena Eni Petroleum OP 17-02 and OP 17-02-PB1 to strong petroleum odor; scattered amounts of free oil; spotty to patchy light to medium visible staining; instant strong to moderately strong milky white cut; moderately strong yellow to yellowish orange residual cut; clear to pale brown visible cut;very pale to pale brown residual cut in plain light;scattered to common amount of free oil on shakers. N SAND BOTTOM 7103.0' MD/-3381.9'TVDSS Sand (7165-7250) = light gray to medium gray with light bluish to medium bluish gray hues; loose unconsolidated quartz grains; lower medium to upper very fine grained; moderate sorting;sub-round to sub- angular; moderate to low sphericity;trace amounts of very coarse sized chert and siltstone;spotty amount of light to moderate brown visible staining; strong petroleum odor;common amount of free oil on shakers;even to patchy, moderate to bright yellow to orange fluorescence; instant strong to moderately strong cut fluorescence; moderate yellow to light orange residual cut; clear to pale brown visible cut; very pale to pale light brown residual cut in plain light. LOWER N MARKER 7206.0' MD/-3399.3' TVDSS Sand (7255-7350) = very light gray to medium light gray with light bluish gray hues with translucent; unconsolidated fine aggregate quartz grains; upper very fine to upper fine grained;well sorted;sub-angular to angular; low to moderate sphericity;trace amounts of chert,siltstone,jasper and pyrite;scattered to common amounts of oil on shakers; moderate to strong petroleum odor in sample; spotty to patchy amount of light brown to moderate brown visible staining;even to patchy amount of bright to moderate yellow and dull orange sample fluorescence; pale to nearly clear brown visible cut; moderately bright yellow with some dull to moderately bright orange residual cut; pale brown visible cut. N SEQUENCE BASE UNIT TOP 7406.0' MD/-3426.8' TVDSS Claystone (7470-7525) = light brownish gray to very light gray; clotted to slightly pasty; mostly brittle to crumbly; irregular fracture;amorphous cuttings habit;earthy to slightly dull;very clayey with some very gritty in places;20%-30%dull green sample fluorescence;very slow straw to milky white solvent cut;abundant pyrite crystals throughout sample; slight petroleum odor; no free oil in sample. Sand/sandstone(7530-7605)=predominantly translucent to clear,with some light gray,white,pale blue,pale green, black, blackish red, and dusky red hues; predominantly quartz grain sand matrix; lower fine to upper medium grain sand; fair to poorly sorted; angular to sub-angular,with some slightly sub-rounded; moderate sphericity; 10%-20%dull yellow green sample fluorescence; very slow milky white solvent cut; no free oil in sample; no petroleum odor;thick beds of sand and siliceous cemented sandstone, interbedded with very thin beds of sandy siltstone and sandy claystones. Siltstone (7615-7690) = medium light gray to brownish gray; mushy to pasty; crumbly to brittle; irregular fracture; amorphous cuttings habit; mostly earthy with some dull to waxy; predominantly silty to somewhat gritty; very thin beds of sandy siltstone, interbedded with thick beds of sand and siliceous cemented sandstones, with sandy claystone; dull green yellow sample fluorescence approximately 30% - 40%; no solvent cut; no free oil was observed in sample; no petroleum odor; abundant pyrite crystals. Sand/sandstone(7695-7780) = clear to translucent, with white, pale blue, pale green, moderate yellowish brown,dusky brown,dusky red,and black; mostly quartz grain sand; upper fine grain to upper medium grain sand; poor to moderately sorted; very angular to sub-angular, with some slightly sub-rounded in places; moderate to low sphericity; very thick beds of loose uncemented quartz sand, and siliceous cemented sandstone, interbedded with thin beds of sandy siltstone, and sandy claystones; very faint sample fluorescence,5%-10%; no solvent cut: no free oil was observed in the sample;no petroleum odor;abundant pyrite crystals throughout the sample. Claystone (7790-7865) = light gray to medium gray with some brownish gray; lumpy to mushy; brittle to crumbly; irregular fracture; amorphous cuttings habit; mostly earthy to dull luster; predominantly clayey,with some slightly gritty texture; very thin claystone beds interbedded with thick beds of loose uncemented sand, 22 CANRIG Ln'Eel Petroleum OP 17-02 and OP 17-02-PB1 and slightly calcareous cemented sandstone,with sandy siltstones;abundant pyrite crystals throughout; dull pale green yellow sample fluorescence, 5%- 10%; no solvent cut; no free oil in sample; no petroleum odor. Sand/sandstone(7870-7950) =translucent to clear,with light gray,white, pale green, pale blue, moderate yellowish brown, blackish red,very dusky red, and black; predominantly quartz grain sand matrix; lower fine grain to upper medium; fair to poorly sorted; mostly well angular to sub-angular, with some sub-rounded; moderate sphericity; mostly thick loose uncemented quartz sand beds, with slightly calcareous cemented sand, interbedded with very thin beds of sandy siltstone, and sandy claystone; dull yellow green sample fluorescence, 5% - 10%; slow straw yellow solvent cut. Siltstone (7955-8010) = brownish gray to medium gray with some light gray; mostly mushy to somewhat pasty; irregular fracture; amorphous cuttings habit; mostly earthy to dull luster;very silty to gritty texture;thin beds sandy siltstone, interbedded with thick beds of loose unconsolidated sand, and siliceous, to slightly calcareous cemented sandstone;bright yellow green sample fluorescence,20%-30%;trace amounts of light brown oil stains. Claystone(8020-8084)=light gray to medium gray;mushy to pasty;fairly cohesive;slightly adhesive;mushy to pasty;amorphous cuttings habit; dull to earthy luster; irregular fracture;clayey to silty texture; interbedded with loose disaggregated sands,some sands derived from slightly calcareous cemented sandstone;no free oil in sample; trace to spotty amount of medium to light staining; 30-40% dull yellow fluorescence; fast cut to moderately strong dull milky white fluorescence; clear visible cut; pale to very pale yellowish green residual cut; no petroleum odor. OA SAND TOP 8085.0' MD/-3480.3'TVDSS Sand/sandstone=(8105-8230)=light gray to medium gray with light bluish hues and translucent;upper very fine to lower medium grained;very well to well sorted;sub-angular to sub-rounded;moderate to low sphericity; loose disaggregated sands,some grains exhibit slight calcareous cementing;common to abundant dark brown to dark black lithics give salt and pepper appearance;trace presence of pyrite and siltstone;abundant amount of free oil on shakers;strong to moderate petroleum odor; patchy to even,medium to dark staining in sample; 80-100%even moderate to bright yellowish green sample fluorescence; instant strong to moderately strong milky white cut fluorescence; pale straw to straw viscosity cut; pale to moderate intensity light brown straw residual cut in plain light; moderate to moderately strong intensity greenish yellow residual cut fluorescence; trace to fair amount of free oil in samples. OA SUBLOBE 2 SAND TOP 8211.0' MD/-3489.2'TVDSS Sandstone/silty sandstone (8235-8315) = medium light gray to medium gray with some light bluish gray; disaggregated to firm; lower fine to upper very grain; very well to well sorted; sub-angular to sub-rounded; moderate sphericity; sparse amounts of pyrite and jasper; no free oil in samples; moderate petroleum odor; 30-50%light to medium visible staining;60-80%dull to moderate greenish yellow to yellowish orange sample fluorescence; instant moderately strong to strong bright milky white with greenish hues;pale straw visible cut; abundant amount of free oil on shakers. OA SUBLOBE 3 SAND TOP 8350.0' MD/-3496.8'TVDSS Sand/sandstone(8320-8415)= medium gray to light gray with light bluish hues and translucent; upper very fine to lower fine grained; very well to well sorted; sub-angular to sub-rounded; moderate to high sphericity; loose disaggregated sands, trace amount of calcareous cemented sands; common to trace amounts of siltstone;abundant amount of free oil on shakers;strong petroleum odor; 100%even greenish yellow sample fluorescence; 80-100% even uniform medium to dark visible staining; straw to amber visible cut; instant moderately strong to strong intensity yellow to bright milky white sample cut fluorescence; bright yellowish orange residual cut fluorescence; moderate to dark straw visible residual cut ring. 23 CANRIG cot ,en'Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand/sandstone (8415-8520) = light medium gray to medium gray and translucent; loose disaggregated sand; upper very fine to upper fine;very well to well sorted;sub-angular to angular;moderate to low sphericity; trace amounts of jasper and siltstone; abundant amount of free oil on shakers; trace amount of free oil in sample; 90-100%even, medium intensity visible staining; 100%even greenish yellow sample fluorescence; instant moderately strong intensity bright milky white sample cut fluorescence;pale straw visible cut;orangish yellow residual cut fluorescence; pale straw visible residual cut; strong petroleum odor. SCHRADER BLUFF LATERAL SECTION(OP17-02,TD 18200'MD;API#50-029-23431-00-00) 8520'MD/- 3558.24'TVDSS TO FINAL TD AT 18200' MD/--3522.8'TVDSS Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 626.3 1.7 254.9 911 TRACE 268.2 PEAKS Depth TG Cl C2 C3 C4I C4N C5I C5N 8586 419 57741 401 182 70 65 13 0 8649 436 59917 469 264 80 89 43 31 9082 401 83795 683 385 168 201 76 54 9608 568 93303 838 428 135 148 61 37 9700 542 87422 831 413 131 156 64 25 9816 583 93807 914 490 174 211 105 73 10068 527 84518 1040 619 232 278 127 96 10272 499 84972 959 655 262 324 153 102 10470 533 98995 1058 698 278 345 169 95 10645 544 100282 1105 708 301 385 171 117 10842 518 107370 1115 666 265 342 165 98 11059 371 93124 1078 715 311 393 210 128 11672 357 75168 822 540 227 285 162 104 11970 257 60847 741 522 216 278 134 96 12071 383 60592 659 453 194 240 140 107 12381 416 70774 840 553 267 325 192 151 12528 407 74589 733 421 181 222 124 93 12643 527 100356 1009 577 257 311 175 124 13035 424 73237 747 431 202 255 130 83 13427 445 83052 822 472 211 255 141 98 13740 508 90517 932 542 245 293 159 109 14127 573 117276 1298 753 361 439 217 163 14352 535 97432 986 547 249 308 169 110 14645 554 105225 852 730 361 430 231 194 15032 438 89954 1055 546 271 309 179 114 15741 482 108522 1253 694 260 305 161 107 15926 676 120922 1421 884 381 444 205 134 16005 897 160802 2389 1104 470 558 288 187 16138 693 92709 1075 698 325 389 194 132 16508 632 103536 1316 1013 547 620 346 219 16824 642 97879 1092 674 276 353 184 132 17297 750 110715 1308 763 296 346 154 109 17409 622 94666 1037 592 231 280 144 94 17488 676 97808 1343 755 285 328 155 103 17607 698 96033 1092 662 248 288 136 105 17716 733 103661 962 723 271 327 150 115 17790 604 87349 903 612 236 277 130 89 17879 691 98829 1382.806 736 295 347 153 117 17969 580 84927 1153.630 688 260 300 144 117 24 CANRIG ,i Eel Petroleum OP 17-02 and OP 17-02-PB1 Sand(8520-8650)=translucent to light gray to medium gray quartz grains; upper very fine to upper fine;very well sorted throughout sample interval; sub-angular to sub-rounded with moderate to low sphericity; approximately 5-8%fine grained black lithics; 5%moderate green to brilliant green lithics; no to slight oil odor above OBM; no visible oil staining on sand grains; no to trace even dull yellowish-white sample fluorescence; no cut fluorescence visible; clear to very pale straw visible cut; light clear to pale straw visible residue; faint white residual fluorescence. Sand/Sandstone(8650-8740)=light to medium gray to translucent to milky-white quartz grains; upper very fine to upper fine; very well sorted; sub-angular to sub-rounded with moderate sphericity; approx 5-8%fine grained black lithics, giving salt and pepper appearance; approx 3-5% moderate green to brilliant green lithics; moderate orange pink to pale yellowish orange shell fragments;slight to no oil odor noticeable above OBM; no visible oil staining; 10-30% patchy dull yellow sample fluorescence; immediate faint white cut fluorescence; straw visible cut; light clear to pale straw visible residue; faint white residual fluorescence. Sand/Sandstone(8740-8860) =very light gray to medium gray to translucent to clear quartz grains; upper very fine to upper fine throughout sample interval;very well sorted;sub-angular to sub-rounded with moderate sphericity;approx 5%fine black lithic grains;approximately 5% moderate green to brilliant green lithic grains; occasional pale yellowish orange to moderate orange pink shell fragments occurring near end of sample interval; slight to no oil odor above OBM; no oil staining on free sand grains. Sandstone cuttings have dark brown staining within when split open; 20-50% patchy bright to dull yellow to dark orange sample fluorescence;streaming bright white cut fluorescence;amber visible cut; medium amber,visible residue;dull yellowish-white residual fluorescence. Siltstone(8750-8900)= medium gray to olive gray to dark gray to medium-light gray; easily friable to firmly friable cuttings;tough and dense to crunchy, and brittle tenacity varying with hardness; sub-blocky fracture; tabular wedge-like cuttings habit; dull earthy luster; smooth silty to gritty texture depending on sand grain content; some black to dark brown thin laminations visible. Sand/Sandstone (8860-9010) = very light gray to medium gray to translucent to occasional clear grains; individual sand grains are disaggregated; upper very fine to upper fine;very well sorted; sub-angular to sub- rounded with moderate sphericity; 5-10%fine grained black lithics throughout sample interval;5% moderate green lithics, fine grained; intermittently occurring pale yellowish orange to moderate orange pink shell fragments throughout sample interval;slight oil odor; no visible oil staining on free sand grains,dark brown oil staining within sandstone cuttings when prodded apart; 20-50% patchy moderately bright yellow to orange sample fluorescence;streaming bright white cut fluorescence;amber to dark brown visible cut;medium amber residual ring; dull white residual fluorescence. Sand/Sandstone (9010-9100) = light gray to translucent to clear to medium light gray; upper very fine to upper fine; very well sorted; sub-angular to sub-rounded with moderate sphericity; 5-10%fine grained black lithics giving salt and pepper appearance; approximately 5% brilliant green to moderate green fine grained lithics; sandstone cuttings are easily friable to firmly friable; faint oil odor above OBM; no oil stain visible on free sand grains,dark brown oil staining within prodded apart sandstone cuttings;20-40%patchy moderately bright yellow to yellowish orange sample fluorescence;streaming bright white cut fluorescence;amber visible cut; amber visible residue; dull yellow residual fluorescence. Sand/Sandstone(9100-9220)=translucent to light gray to clear to medium gray throughout sample interval; sandstone cuttings are easily friable to firmly friable; upper very fine to upper fine; very well sorted; sub- rounded to sub-angular; moderate to high sphericity; approximately 7-10% fine grained black lithics; 5% moderate green to bluish-green fine grained lithics; higher incidences of shell fragments throughout this sample interval compared to the previous interval, moderate orange pink to pale yellowish-orange; slight oil odor; no oil staining on free sand grains, dark brown oil staining within sandstone cuttings when split open; 100%even dull yellowish-white sample fluorescence;slow blooming dull white cut fluorescence; light amber 25 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 visible cut; light straw to dark straw visible residue; faint yellowish-white residual fluorescence. Sand/Sandstone (9220-9400) = very light gray to translucent to medium gray to occasional clear grains; individual sand grains are disaggregated;sandstone cuttings are easily friable to firmly friable;upper very fine to upper fine throughout sample interval; very well sorted; sub-angular to sub-rounded; moderate sphericity; approximately 10% fine grained black lithics; 5% moderate green to brilliant green fine grained lithics; moderate orange pink to pale yellowish orange shell fragments occur throughout sample interval; slight oil odor; no visible oil staining on free sand grains, dark brown oil staining within sandstone cuttings when split open; 100%dull to moderately bright yellowish-white background sample fluorescence;some samples exhibit 20-30% patchy dull yellow sample fluorescence; streaming bright white cut fluorescence; amber to dark amber visible cut;light amber visible residue;medium moderately bright yellowish white residual fluorescence. OA SUBLOBE 3 9384' MD/3500.9' TVDSS Sand/Sandstone(9400-9490)=translucent to light gray to clear to medium gray throughout sample interval; sandstone cuttings are easily friable to firmly friable; upper very fine to upper fine; very well sorted; sub- rounded to sub-angular; moderate to high sphericity; approximately 10-15% fine grained black lithics; 5% moderate green to brilliant green fine grained lithics; moderate orange pink to pale yellowish orange shell fragments scattered throughout sample interval;slight oil odor above OBM;no oil staining on sand grains,dark brown oil staining within sandstone cuttings when split apart; 10-30%patchy dull to moderately bright yellow sample fluorescence;slow blooming dull white cut fluorescence;straw to pale straw visible cut; light straw to dark straw visible residue; faint to dull white to yellowish-white residual fluorescence. OA SUBLOBE 3 9555' MD/3500.2.4'TVDSS Sand (9500-9640)=clear to very light gray to translucent; light greenish to brownish to reddish to bluish to black hues throughout sample interval; predominantly upper very fine to lower fine with occasional upper fine grains; very well sorted; sub-angular to angular to sub-rounded; moderate sphericity; sands occur as unconsolidated in sample interval; moderate orange pink to pale yellowish orange shell fragments;fine grain- sized pyrite crystals, —2%; fine grained black lithics giving salt and pepper appearance, 7-10%; moderate green to light bluish green fine grained lithics, approximately 5%;faint oil odor; no visible oil staining;100% even dull yellow sample fluorescence; no cut fluorescence; pale straw visible cut; no visible residue; no residual fluorescence. Sand/Sandstone (9640-9760) = light gray to very light gray to clear to translucent to milky white; light greenish to light bluish to reddish to brownish hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded; sandstone is friable to easily friable to firmly friable; sandstone cuttings are calcareously cemented; pale yellowish orange to moderate orange pink shell fragments; moderate green to brilliant green to black fine grained lithics throughout sample interval;fragrant oil odor; no visible oil staining on unconsolidated sand grains; light brown to dark brown oil staining within sandstone cuttings when split open; 100%even dull yellowish-white background with 20-40% patchy bright yellow sample fluorescence throughout this interval; slow-streaming dull to moderately bright white cut fluorescence; straw visible cut; no visible cut residue; no residual fluorescence. Sand/Sandstone (9760-9880) = clear to light gray to translucent to milky white to very light gray unconsolidated sand grains; greenish to dusky reddish to yellowish brown to bluish hues through entire sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate to occasionally high sphericity; sandstone is easily friable to firmly friable and calcareously cemented; pale yellowish orange to moderate orange pink shell fragments; fine grained black to moderate green to brilliant green lithics; slight to fragrant oil odor observed; no visible oil staining on free sand grains; light brown oil staining within sandstone cuttings when prodded open; 100%even dull to bright white sample fluorescence with 10-20% patchy moderately bright yellow in this interval; immediate dull white cut fluorescence; dark straw to light amber visible cut; light pale straw visible residue; dull yellow residual fluorescence. Sand/Sandstone(9880-10030) = clear to translucent to milky white to very light gray unconsolidated sand grains;black to brownish to greenish to bluish hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to sub-rounded to angular with moderate sphericity; sandstone cuttings are friable to firmly friable;sandstone cuttings are calcareously cemented;black to moderate green to light bluish 26 CANRIG ni Eni Petroleum OP 17-02 and OP 17-02-PB1 green to brilliant green fine grained lithics; pale yellowish orange to moderate orange pink shell fragments decrease in abundance as depth increases; slight to fragrant oil odor; no visible oil staining on free sand grains; light brown to greasy luster within sandstone cuttings when prodded apart; 100%even bright to dull white to yellowish white sample fluorescence; immediate moderately bright cut fluorescence; dark straw to light amber visible cut; straw visible residue; dull to moderately bright yellow to yellowish white residual fluorescence. Sand/Sandstone(10030-10180)=clear to translucent to very light gray to milky white;blackish to greenish to yellowish brown hues throughout sample interval in unconsolidated sands; upper very fine to upper fine;very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; sandstone cuttings are friable and calcareously cemented; pale yellowish orange to moderate orange pink shell fragments; black to moderate green to brilliant green fine grained lithics;sandstone cuttings occasionally grade to silty sandstone and sandy siltstone; faint oil odor; no visible oil staining on free sand grains; light brown to a greasy luster within sandstone cuttings when prodded open; 100%even moderately bright to bright sample fluorescence; immediate moderately bright white cut fluorescence;light amber visible cut;medium dark straw visible residue; moderately bright yellowish white residual fluorescence. Sand/Sandstone(10180-10300)=very light gray to translucent to clear to milky white;light greenish to dusky brownish to brownish yellow to blackish to light bluish hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; sandstone is friable and calcareously cemented;sandstone grades between silty sandstone and sandy siltstone; black to brilliant green to moderate green fine grained lithics; scattered pale yellowish orange to moderate orange pink shell fragments;faint to moderate oil odor; no visible oil staining on unconsolidated sand grains;greasy luster to light brown oil staining within sandstone cuttings when split open; 100%even moderately bright to bright yellowish white sample fluorescence; streaming bright white cut fluorescence; light amber visible cut; dull yellow residual fluorescence. Sand(10300-10420)=clear to very light gray to translucent; light greenish to dusky yellowish to brownish to reddish to blackish hues throughout sample interval; upper very fine to upper fine; very well sorted; sub- angular to angular to sub-rounded; moderate sphericity; rare pale yellowish orange shell fragments; black to moderate green to brilliant green to light bluish green fine grained lithics scattered through this interval;slight to fragrant oil odor; no visible oil staining on free sand grains; 100%even bright to dull white to yellowish white sample fluorescence;slow streaming dull white cut fluorescence;straw visible cut;light straw visible residue; faint to dull yellowish white residue fluorescence. Sand(10420-10510)=clear to very light gray to translucent to light gray;black to greenish to dusky brownish to yellowish brown hues throughout interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded;moderate to high sphericity;scattered pale yellowish orange to moderate orange pink shell fragments; black to moderate green to brilliant green fine grained lithics; fragrant to slightly strong oil odor; no visible oil staining on unconsolidated sand grains; 100%even bright white to yellowish white sample fluorescence; immediate bright white cut fluorescence; dark amber to brown visible cut; medium light amber visible residue; moderately bright yellow residual fluorescence. Sand (10510-10600) = clear to very light gray to translucent; brownish to light greenish to light bluish hues throughout sample interval; upper very fine to upper fine;very well sorted; sub-angular to angular; moderate sphericity;pale yellowish orange to moderate orange pink shell fragments;black to moderate green to brilliant green fine grained lithics; slight oil odor; no visible oil staining on unconsolidated sand grains; 100%even moderately bright white to yellowish white sample fluorescence;immediate bright white cut fluorescence;dark amber visible cut. Sand/Sandstone (10600-10740) = light to very light gray overall; slight brownish secondary hue; samples collected as loose disaggregates sand with occasional small friable fragments of sandstone and occasional siltstone fragments;friable;moderately well to well sorted;sub-angular to angular and sub-spheroidal;medium lower to fine upper, very fine upper and medium upper grain; trace angular coarse quartzite and occasional small pebble fragments;predominantly translucent white to clear colorless quartz;trace to common very light to light gray smoky quartz and lithics;trace brown, light to medium green and gray-green lithic mineral grains; common dark gray to black mafic mineral grains; trace brick red jasper and biotite mica; scattered microcrystalline pyrite masses;occasional micro-fine pyrite imbedded in quartz;slight brown oil stain masked 27 CANRIG epi Eni Petroleum OP 17-02 and OP 17-02-PB1 by OBM; 100%medium yellow-white sample fluorescence cuts to bright white; moderate amber residue ring cuts immediately to bright white. OA SUBLOBE 3 10736' MD/3488.7'TVDSS Sand/Sandstone(10740-10860) = light to very light gray overall; slight brownish secondary hue; samples collected as loose disaggregate sand; occasional small fine grain partially lithified sandstone fragments; friable;well sorted overall; locally moderately well sorted;fine upper to medium lower,fine lower and very fine grain; scattered medium upper and coarse angular quartz; translucent white and clear colorless quartz abundant; trace to common light gray smoky quartz; common dark gray to black mafic mineral/lithics; trace brown and green lithic/mineral grains;trace biotite and brick red jasper;trace to common brownish white shell; slight brownish oil stain bleeds when washed with base oil; no notable oil odor above OBM odor; 100% medium yellow-white fluorescence cuts to bright white; moderate amber residue ring cuts immediately to bright white; samples are very calcareous due to heavy calcium carbonate mud additive contamination. Siltstone(10910-11050)=very light gray with a slight brownish secondary hue;sample collected as sand size disaggregated fragments with scattered small well indurated fragments; firm to very firm; angular irregular cuttings habit;earthy luster with a micro-sparkly appearance due to included mica; non-to very-sandy texture; moderately cohesive; non-to slightly-adhesive; hydrophilic;grades to silty sandstone;slight oil stain on fresh partings;trace fragments with tarry dead oil blebs on bedding; very slightly calcareous; heavy SAFE-CARB (CaCo3)contamination continues. OA TOP 10933' MD/3480.7'TVDSS Sand/Sandstone(11010-11100)=very light to medium light gray;samples collected as disaggregated loose sand with common hard silty/clayey well-indurated fragments; moderately well to well sorted; friable in part; sub-angular to angular and sub-spheroidal; trace moderately rounded grains;fine upper to medium lower and fine lower;trace very fine;scattered to common medium upper;trace coarse;occasional dark gray-black chert pebble;predominantly translucent white to slightly smoky and clear quartz;trace to common dark gray to black mafic mineral/lithics common to abundant shell fragments;common small angular pyrite masses;trace blue- green, green and brown lithic/mineral grains;trace brick red and rose jasper; no notable oil odor above OBM odor; 100% medium yellow-white fluorescence cuts to bright white; moderate amber residue ring cuts immediately to bright white; samples are very calcareous due to heavy calcium carbonate mud additive contamination. FAULT 17-02-1 11043' MD/3474.5' TVDSS Sand/Sandstone(11100-11250)=very light to light gray; distinct very light green secondary hue when well washed; slight brownish hue due to oil stain;firm to very firm in rare intact sandstone fragments;friable;well sorted; fine upper to fine lower and medium grain; scattered medium upper and rare coarse grain; predominantly translucent white, slightly smoky and clear colorless quartz;common dark gray to black mafic mineral/lithics; common to abundant light to very light green and greenish gray mineral/lithics;trace brown lithics, rose and brick red jasper occasional moderately blue-green grains;scattered to locally common pyrite; primarily grain supported;trace matrix supported fragments; 100%medium yellow sample fluorescence cuts immediately to bright white;moderate brownish residue ring cuts immediately to bright white;no detectable oil odor above background OBM odor;slight oil stain still present after washing;slightly calcareous;SAFE-CARB contamination continues. Sand/Sandstone(11250-11400)=very light to light gray;distinct very light green secondary hue when well washed; slight brownish hue due to oil stain; scattered intact sandstone fragments in loose disaggregated sand;friable;well to moderately well sorted;fine upper to fine lower, medium lower and very fine upper grain; scattered to trace medium upper and coarse; translucent white to slightly smoky and clear colorless quartz predominate;common to abundant green lithic and green-stained quartz grains;common to trace dark gray to black lithic/mafic mineral grains;common dark gray chert grains; trace brown and light gray lithics;trace rose jasper and blue green grains; trace to common shell fragments; occasional thin, hard gray-brown siltstone intervals; 90 to 100% medium yellow sample fluorescence cuts immediately to bright white; slight to moderate brownish residue ring cuts readily to bright white; no detectable oil odor above background OBM odor slight oil stain still present after washing; SAFE-CARB contamination continues. 28 CANRIG eni Eel Petroleum OP 17-02 and OP 17-02-PB1 Sand/Sandstone(11400-11540) = medium light to light gray; distinct very light green secondary hue when well washed; slight brownish oil stain; friable; well to locally moderately well sorted; samples are loose disaggregated sand; fine upper to fine lower, medium lower and very fine grain; sub-angular to angular and sub-rounded/sub-spheroidal; translucent white, slightly smoky and clear colorless quartz predominate; common to abundant dark gray to black mafic mineral/lithics and dark brownish gray chert; very abundant green and green stained grains; scattered rose and brick red jasper;trace mica and pyrite;occasional trace bright white ash/clay;appears to be primarily matrix supported;occasional very thin siltstone intervals; 100% medium yellow sample fluorescence cuts readily to bright white;slight brownish residue ring cuts immediately to bright white; SAFE-CARB contamination continues. Sand/Sandstone(11540-11650) = medium light to medium gray; distinct greenish secondary hue; sample collected as loose disaggregated sand; moderately well sorted; fine upper to medium lower and fine lower predominate;trace to locally common medium upper; scattered coarse; sub-angular to angular;translucent white, slightly smokey and clear quartz with abundant to very abundant green and green mineral/lithics and green stains quartz grains; common dark gray to black mineral/lithic grains;trace shell fragments;trace very fine muscovite mica; trace phlogopite mica; trace rose and brick red jasper; trace limonite encrusted sand; trace to common soft white clay/ash; material appears to be primarily grain supported; 100% medium yellow sample fluorescence cuts immediately to bright white; slight to moderate brownish residue ring cuts immediately to bright white; SAFE-CARB continues to contaminate samples. FAULT 17-02-2 11693' MD/3469.7 TVDSS Sand/Sandstone(11650-11770)=clear to light gray to translucent;yellowish brown to greenish to bluish to blackish hues throughout sample interval;sands are unconsolidated; upper very fine to upper fine;very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; moderate orange pink to pale yellowish orange shell fragments decreasing in abundance as depth increases; black to moderate green to brilliant green fine grained lithics throughout sample interval; sandstone cuttings are easily friable to firmly friable; occasionally grade to silty sandstone;calcareously cemented;fragrant oil odor; no visible oil stain on free sand grains; light brown to dark brown oil staining within sandstone cuttings when prodded open; 100% even moderately bright white to yellowish white sample fluorescence; slow streaming dull white cut fluorescence; light amber to amber visible cut; no visible residue; faint white residual fluorescence. OA SUBLOBE 2 11778' MD/-3471.1' TVDSS Sand/Sandstone(11770-11890)=light gray to clear to very light gray to translucent to milky white;greenish to reddish to brownish to yellowish brown hues throughout sample interval;sands are unconsolidated; upper very fine to upper fine;very well sorted;sub-angular to sub-rounded to angular with moderate sphericity; rare shell fragments in this interval; black to moderate green to brilliant green fine grained lithics; sandstone cuttings are easily friable to firmly friable;sandstone cuttings occasionally grade to silty sandstone and sandy siltstone; sandstone is calcareously cemented; slight to fragrant oil odor; no visible oil staining on free sand grains; light brown to dark brown oil staining within sandstone cuttings; 100%even moderately bright white to yellowish white sample fluorescence;slow blooming dull white cut fluorescence;amber visible cut;light straw visible residue; dull white residual fluorescence. Sand/Sandstone (11890-12040) = light gray to translucent to clear to medium light gray; greenish to brownish to reddish hues throughout samples;sand is unconsolidated;sandstone cuttings are easily friable to firmly friable;sandstone is calcareously cemented and grades to silty sandstone;upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; pale yellowish orange to moderate orange pink shell fragments; black to moderate green to light bluish green fine grained lithics;slight oil odor; no visible oil stain on free sand grains; light brown to dark brown oil staining within sandstone cuttings when broken apart; 100%even moderately bright yellowish white to white with some samples exhibiting 20- 30%patchy dull yellow sample fluorescence; slow streaming dull white cut fluorescence; dark amber visible cut; no visible residue;faint white residual fluorescence;samples are heavily contaminated with SAFE-CARB mud additive. Siltstone/Shale(12050-12220)=olive black to brownish black to medium gray to olive gray with secondary brownish to yellowish brown to light grayish hues throughout sample interval;friable to moderately hard;brittle crunchy to crumbly tenacity; irregular fracture; sub-tabular to wedge-like to irregular cuttings habit; greasy 29 CANRIG eni En! Petroleum OP 17-02 and OP 17-02-PB1 waxy luster; silty gritty to clayey texture depending on silt content; some thin black to reddish brown laminations visible in lighter colored cuttings;cuttings grade between siltstone and silty shale and shaly silt;no oil indicators above OBM. Sand/Sandstone(12100-12250)=light gray to clear to translucent to medium light gray unconsolidated sand grains; greenish to reddish to brownish to yellowish brown hues throughout sample interval; sandstone is easily friable to firmly friable and calcareously cemented; sandstone grades between silty sandstone and sandy siltstone; upper very fine to upper fine; very well sorted; sub-angular to angular with moderate sphericity; occasional pale yellowish orange to moderate orange pink shell fragments; black to light bluish green to moderate green fine grained lithics; no observed accessory minerals in this interval;slight to fragrant oil odor; no visible oil staining on free sand grains; light brown to dark brown oil staining within sandstone cuttings when prodded open; 100% even moderately bright white to yellowish white sample fluorescence. Siltstone (12220-12400) = olive gray to brownish black to medium gray to olive black with secondary brownish to yellowish brown to light grayish hues throughout sample interval;friable to moderately hard;brittle crunchy to tough tenacity; irregular fracture;sub-tabular to wedge-like to irregular cuttings habit;greasy waxy luster; silty to gritty texture depending on silt and sand content; cuttings grade to sandy siltstone and silty sandstone; no oil indicators above OBM. Sand/Sandstone(12250-12490)=medium light gray to light gray to clear to translucent;greenish to reddish to brownish to yellowish brown to bluish hues throughout sample interval;sandstone cuttings are easily friable to firmly friable; sandstone is calcareously cemented; upper very fine to upper fine; very well sorted; sub- angular to angular to occasionally sub-rounded; moderate sphericity; pale yellowish orange to moderate orange pink shell fragments scattered through interval;black to moderate green to brilliant green fine grained lithics; slight oil odor; no visible oil staining on free sand grains; light brown to dark brown oil staining within sandstone cuttings; 80-100% even dull to moderately bright white to yellowish white with some samples exhibiting 20-30% patchy dull yellow sample fluorescence; streaming bright white cut fluorescence; dark amber visible cut; light amber visible residue; moderately bright yellow residual fluorescence. Sand/Sandstone(12490-12610)=clear to medium light gray to light gray to translucent;greenish to reddish to bluish to brownish to yellowish brown hues throughout sample interval;sandstone cuttings are easily friable to firmly friable;sandstone grades to silty sandstone and sandy siltstone;sandstone is calcareously cemented; upper very fine to upper fine; very well sorted; sub-angular to angular with moderate sphericity; black to moderate green to brilliant green fine grained lithics; slight oil odor; no visible oil stain on unconsolidated sands;dark brown to light brown oil staining within sandstone cuttings when split apart; 100%even moderately bright white to yellowish white sample fluorescence; slow blooming dull white cut fluorescence; straw visible cut; light pale straw visible residue; dull yellowish white residual fluorescence; samples still heavily contaminated by SAFE-CARB mud additive. FAULT 17-02-3 12701' MD/3486.0' TVDSS Sand/Sandstone (12610-12730) = light gray to clear to medium light gray to translucent unconsolidated sand grains; greenish to bluish to reddish to brownish hues throughout sample interval; sandstone is easily friable to firmly friable, becoming firmer as it grades to silty sandstone and sandy siltstone; sandstone is calcareously cemented; upper very fine to upper fine;very well sorted;sub-angular to angular to sub-rounded; moderate sphericity;black to brilliant green to light bluish green fine grained lithics;slight oil odor;no visible oil staining on free sand grains; light brown oil staining within sandstone cuttings when split open; 100% even moderately bright sample fluorescence;streaming bright white cut fluorescence;dark amber visible cut;dark straw visible residue; bright white residual fluorescence; samples contaminated with SAFE-CARB. Sand/Sandstone(12730-12850)=very light gray to clear to translucent to light gray unconsolidated sand grains;greenish to bluish to brownish to reddish hues;sandstone is easily friable to firmly friable;sandstone is calcareously cemented;sandstone grades to silty sandstone and sandy siltstone; upper very fine to upper fine; very well sorted;sub-angular to angular with moderate sphericity;scattered pale yellowish orange to moderate orange pink shell fragments; black to light bluish green to moderate green fine grained lithics; slight oil odor; no visible oil stain on free sand grains; light brown to dark brown oil staining within sandstone cuttings when prodded open; 100%even dull white to yellowish white sample fluorescence; slow blooming bright white cut fluorescence; dark amber to brown visible cut; samples contaminated heavily by SAFE-CARB. 30 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 OA SUBLOBE 2 12870' MD/-3484.1'TVDSS Sand/Sandstone (12850-13000) = medium light gray to light gray with a slight brownish secondary hue; samples collected as loose disaggregated sand with scattered intact sandstone siltstone fragments;friable in part; moderately well sorted;sub-angular to angular and sub-spheroidal;trace sub-rounded;fine upper to fine lower and medium lower grain; locally very fine upper to fine lower and very silty; individual grains are predominantly translucent slightly smokey to translucent white and clear colorless quartz;common dark gray to black mafic mineral/lithics;trace light to medium gray lithics;trace green mineral grains;trace rose jasper; trace limonite/hematite fragments;trace to common very fine mica suspended in wash oil; apparent contact between sand and silt; occasional very light gray-white mottled tuff/clay flakes; 100% medium yellow-white sample fluorescence cuts readily to bright white;very slight brownish residue ring fluoresces dull gold and cuts immediately to bright white; no odor over OBM background; sandstone and silt fragments are slightly to moderately calcareous; samples continue heavily contaminated with SAFE-CARB. Siltstone/Shale(13000-1360) = medium light to light gray to light tan; mottled in part; gritty/sandy to clean shaly texture;shale is fissile and contains variable amounts of long splintery black inclusions;moderately hard to very firm;sandy in part;silt-stone grades to silty sandstone;slightly to moderately calcareous;slight oil stain on some fragments; trace black dead oil blebs and carbonaceous inclusions; trace shell fragments. Sand/Sandstone (13000-13220) = medium to medium light gray; slight brownish secondary hue; loose disaggregated sand and scattered intact sandstone fragments moderately well sorted;fine upper to fine lower and medium lower predominate;trace very fine sharply angular matrix supported sandstone;trace medium upper; scattered coarse grains;angular to sub-angular and sub-spheroidal;translucent smokey and white to clear colorless quartz predominate; common black to dark gray lithic/mafic mineral grains; trace green lithic/mineral grains and biotite;trace lignite and lignite encrusted ironstone fragments;trace shell;occasional thin to moderate ironstone interbed/concretion zones and thin shale/siltstone intervals; 100%medium to dull greenish yellow sample fluoresce with a fair streaming bright white cut;very slight residual ring fluorescence; fair streaming bright white cut; very slight residual ring fluoresces dull gold and cuts immediately to bright white; no notable oil odor over OBM background; sandstone fragments are slightly calcareous; samples continue heavily contaminated with SAFE-CARB. Sand/Sandstone(13220-13350)=medium gray with a slight brownish secondary hue; loose disaggregated sand with scattered firm to moderately hard intact sandstone fragments;friable;well to moderately well sorted; sub-angular to angular;trace sub-spheroidal;fine upper to fine lower grain;trace medium and coarse angular grains;trans-lucent smokey to clear and translucent white quartz predominates;trace dark gray to black mafic mineral/lithics;scattered biotite;occasional rose-tinted sandstone fragments;scattered pyrite;trace very fine mica flakes suspended in wash oil; 100% medium to dull greenish yellow sample fluoresce with a fair streaming bright white cut;very slight residual ring fluoresces yellow and cuts immediately to bright white; no notable oil odor over OBM background;sandstone fragments are slightly calcareous;samples continue to be heavily contaminated with SAFE-CARB. Sand/Sandstone(13350-13500)=medium gray with a slight brownish secondary hue; loose disaggregated sand with rare firm to moderately hard intact sandstone fragments; friable; well sported; sub-angular to angular; rare sub-spheroidal;fine lower to very fine upper and fine upper grain;trace medium lower;scattered larger grains;translucent white to smokey and clear colorless quartz predominate;trace to common dark gray to black mafic mineral/lithics;trace medium to;light brown grains; scattered green grains; trace to scattered clear amber colored mineral grains; trace medium to coarse grain size microcrystalline pyrite masses and smaller limonite flakes;trace brick red to orange jasper;appears to be entirely grain supported; 100%medium dull greenish yellow sample fluoresce with a fair streaming bright white cut;very slight residual ring fluoresces medium yellow; cuts immediately to bright white; no notable oil odor over OBM background; sandstone fragments are slightly calcareous; samples continue heavily contaminated with Safe-Carb. Sand/Sandstone(13500-13620)=medium gray with a slight brownish secondary hue; loose disaggregated sand;friable;well sorted;sub-angular to angular and occasionally sub-spheroidal grains;fine lower to very fine upper grain; trace medium and larger grains; predominantly translucent white to smokey and clear colorless quartz;trace to common dark mafic mineral/lithics;trace to scattered dark to medium brown and brownish gray lithics;trace mica,and limonite flakes;scattered small microcrystalline pyrite masses;trace clear amber and green mineral grains; trace red-brown and orange jasper; appears to be entirely grain supported; 100% medium to dull greenish yellow sample fluoresce with a good to fair streaming bright white cut; very slight 31 CANRIG Enl Petroleum OP 17-02 and OP 17-02-PB1 brownish residue ring fluoresces medium yellow and cuts immediately to slightly milky yellow white; samples continue heavily contaminated with Safe-Carb. Sand/Sandstone(13620-13740)=medium gray with a slight brownish secondary hue; loose disaggregated sand;friable;well sorted;sub-angular to angular and occasionally sub-spheroidal grains;fine lower to very fine upper grain;trace medium and larger grains; predominantly translucent white to smokey and clear colorless quartz; common dark to medium brown and gray-brown lithics; common to trace dark mafic mineral/lithics; trace pyrite; trace mica and limonite; occasional green mineral grain and clear amber grains; entirely grain supported; 100%medium yellow-green sample fluorescence cuts readily to bright milky yellow white;slight to moderate brownish residue ring cuts immediately to milky yellow-white; safe carb contamination continues. Sand/Sandstone(13740-13840)=clear to light gray to translucent unconsolidated sand grains; greenish to bluish to occasional reddish hues;sandstone is easily friable to friable;sandstone cementation is calcareous; upper very fine to upper fine;very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity; rare pale yellowish orange to moderate orange pink shell fragments;<5%black to light bluish green to moderate green to brilliant green fine grained lithics;fragrant oil odor;no visible oil stain on free sand grains; dark brown to light brown oil staining within sandstone cuttings when split open; 100%even dull white sample fluorescence;slow streaming dull white cut fluorescence;dark straw to light amber visible cut;medium straw visible residue; dull yellowish white residual fluorescence; samples are contaminated by Safe-Carb mud additive. OA SUBLOBE 2 13812' MD/-3488.3'TVDSS Sand/Sandstone(13840-13960)=clear to light gray to translucent to medium light gray unconsolidated sand grains; greenish to brownish to reddish hues throughout sample interval; sandstone is easily friable to moderately hard;cementation is calcareous;occasionally grades to silty sandstone and sandy siltstone; upper very fine to upper fine;very well sorted; sub-angular to angular to sub-rounded; moderate to high sphericity; pale yellowish orange to moderate orange pink shell fragments; <8%black to light bluish green to moderate green fine grained lithics; slight oil odor; no visible oil staining on free sands; light brown oil staining within sandstone cuttings when prodded open; 100%dull white sample fluorescence; blooming moderately bright white cut fluorescence;straw visible cut; light straw visible residue;faint yellow residual fluorescence;samples are contaminated by Safe-Carb mud additive. Siltstone(14000-14050)=medium dark gray to olive black to brownish gray;firmly friable to moderately hard to friable; tough dense to brittle crunchy to crumbly tenacity; irregular fracture; wedge-like to sub-tabular to irregular cuttings habit; greasy waxy luster; silty to slight gritty texture, varying with sand content;occasional thin black laminations noticeable in lighter color cuttings; siltstone grades to sandy siltstone and silty sandstone; no oil indicators above OBM; samples are contaminated by Safe-Garb mud additive. Sand/Sandstone(14050-14200)=light gray to clear to translucent to occasionally milky white unconsolidated sand grains; greenish to brownish to occasional reddish hues; sandstone is easily friable to firmly friable to occasionally moderately hard; sandstone cement is calcareous; sandstone grades to silty sandstone and sandy siltstone; upper very fine to upper fine with some medium grains scattered throughout sample interval; well to very well sorted; sub-angular to sub-rounded to angular; moderate to high sphericity; scattered moderate orange pink shell fragments; brilliant green to moderate green to black to light bluish green fine grained lithics, 15%; slight oil odor; no visible oil stain on free sand grains; dark brown oil stain within sandstone cuttings; 100% even dull to moderately bright white to yellowish white sample fluorescence; blooming bright white cut fluorescence; dark straw visible cut; no visible residue; faint white residual fluorescence; Safe-Garb continues to contaminate samples. OA SUBLOBE 3 14153' MD/-3495.4'TVDSS Sand/Sandstone(14200-14290)=clear to light gray to translucent unconsolidated sand grains; brownish to greenish to bluish hues; sandstone is easily friable to firmly friable; sandstone cement is calcareous; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; moderate green to black fine grained lithics, 5-10%;fragrant oil odor; no visible oil stain on free sand grains; dark brown to light brown oil staining within sandstone cuttings; 100% even moderately bright white to yellowish white sample fluorescence;blooming bright white cut fluorescence;dark amber to brown visible cut; light straw visible residue; dull yellowish white residual fluorescence; Safe-Garb contaminates samples. 32 CANRIG ,oni Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand/Sandstone(14290-14440)=medium light gray to light gray to clear to translucent unconsolidated sand grains;greenish to bluish to brownish to occasionally reddish hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity; sandstone cuttings are easily friable to firmly friable; cement is calcareous; cuttings are crumbly; irregular fracture;sub-discoidal to sub-spherical cuttings habit;greasy oily luster;gritty texture;no structures;grades to silty sandstone and sandy siltstone;pale yellowish orange to moderate orange pink shell fragments;moderate green to black to brilliant green fine grained lithics, approximately 10%; slight oil odor; no visible oil stain on free sand grains; light brown to dark brown oil stain within sandstone cuttings when split open; 100%even bright to moderately bright white sample fluorescence; slow blooming bright white cut fluorescence; light amber visible cut; no visible residue; faint white residual fluorescence. Sand/Sandstone (14440-14590) = light gray to clear to translucent to medium light gray unconsolidated sands; bluish to greenish to brownish secondary hues; upper very fine to upper fine; very well sorted; sub- angular to angular to sub-rounded; moderate to high sphericity; sandstone is easily friable to firmly friable; cement is calcareous; grades to silty sandstone; predominantly crumbly tenacity; irregular fracture; sub- discoidal to sub-spherical cuttings habit; greasy oily luster; gritty to silty texture; scattered pale yellowish orange to moderate orange pink shell fragments;brilliant green to black to moderate green fine grained lithics; slight oil odor; no oil stain on free sand grains;light brown to dark brown oil staining within sandstone cuttings when split apart; 100%even dull to bright white to yellowish white sample fluorescence;blooming bright white cut fluorescence; dark amber visible cut; light pale straw visible residue; moderately bright white residual fluorescence. Sand/Sandstone(14590-14710)=light gray to clear to translucent to occasionally milky white unconsolidated sand grains; greenish to brownish to occasional reddish hues; sandstone is easily friable to firmly friable to occasionally moderately hard; sandstone cement is calcareous; sandstone grades to silty sandstone; upper very fine to upper fine;very well sorted; sub-angular to angular to sub-rounded; moderate to high sphericity; moderate green to black to brilliant green fine grained lithics;slight to moderate oil odor; no visible oil staining on free sand grains; light brown oil staining within sandstone cuttings; 100% even moderately bright to dull white to yellowish white sample fluorescence;blooming bright white cut fluorescence;dark straw visible cut;no visible residue; dull white residual fluorescence. Sand/Sandstone(14710-14830)=clear to light gray to translucent to medium light gray unconsolidated sand grains; greenish to brownish to reddish hues throughout sample interval; sandstone is easily friable to firmly friable;cementation is calcareous;occasionally grades to silty sandstone and sandy siltstone;upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity; scattered pale yellowish orange to moderate orange pink shell fragments; black to light bluish green to moderate green fine grained lithics;slight oil odor; no visible oil staining on free sands;dark brown oil staining within sandstone cuttings when prodded open; 100%dull white sample fluorescence; blooming moderately bright white cut fluorescence; straw visible cut; dark straw visible residue; moderately bright yellowish white residual fluorescence. Sand/Sandstone (14830-14890) = light gray to clear to very light gray; light greenish to brownish hues; sandstone is easily friable to firmly friable and calcareously cemented; upper very fine to upper fine;very well sorted; sub-angular to angular to sub-rounded with moderate sphericity;occasional pale yellowish orange to moderate orange pink shell fragments;moderate green to black to brilliant green fine grained lithics throughout sample interval. Sand/Sandstone(14890-15100)=light to medium gray;disaggregated sand with scattered intact sandstone fragments;friable;fine upper to very fine upper grain predominate;trace medium grain;scattered larger grain; sub-angular to angular and sub-spheroidal;trace moderately rounded grains;translucent white to clear quartz predominate; quartz grains appear frosted with cementation residues; common pale to dark green grains; trace brown and light gray to gray-brown lithics;trace dark gray to black mafic mineral/lithics;occasional small microcrystalline pyrite masses;trace mica and limonite flakes; intact sandstone fragments are well cemented, slightly to moderately calcareous; occasional ironstone and dolomitic concretions; 100% dull to medium greenish yellow sample fluorescence cuts readily to slightly milky yellowish white;fair brownish amber residue ring fluoresces medium yellow and cuts immediately to slightly milky yellow white; no oil odor above OBM background; slight brownish stain; samples continue heavily contaminated with Safe-Carb mud additive - CaCO3. 33 CANRIG one Eel Petroleum OP 17-02 and OP 17-02-PB1 Siltstone/Sandy Siltstone(15060-15180)=medium light to medium gray with a marked brownish secondary hue;firm to hard;angular flaky to irregular slightly tabular cuttings habit;grainy silty to very sandy texture;dull earthy to gritty luster;apparent gradational contact with associated sandstone;contains variable amounts of very fine sand in the same mineral range as the above described sandstone;trace thin black lamina;slightly to moderately calcareous; note: adding quantities of Safe-Carb to mud system. OA SUBLOBE 2 15107' MD/-3483.5'TVDSS Sand/Sandstone (15100-15250) = light to medium gray; disaggregated sand with rare intact sandstone fragments; friable; fine upper to very fine upper grain predominates; trace medium grain; scattered larger grain;sub-angular to angular and sub-spheroidal;translucent white to clear quartz predominate;quartz grains appear frosted with crystal over-growth;common pale to dark green grains;trace brown and light gray to gray- brown lithics; trace dark gray to black mafic mineral/lithics; occasional small microcrystalline pyrite masses; trace mica and limonite flakes; rare intact sandstone fragments are well cemented and slightly calcareous; occasional ironstone and dolomitic concretions; 100%dull greenish yellow sample fluorescence cuts readily to slightly milky yellowish white; fair brownish amber residue ring fluoresces medium yellow and cuts immediately to slightly milky yellow-white;no oil odor above OBM background;slight brownish stain;samples continue to be heavily contaminated with Safe-Carb. Sand/Sandstone (15250-15400) = light to medium gray with a slight brownish secondary hue; soft disaggregated loose sand with rare intact hard sandstone fragments;friable in part;appears increasingly silty; fine lower to very'fine upper grain; locally very fine low vine lower;trace larger grains;sub-angular to angular; rare sub-spheroidal; frosted clear colorless to translucent white and slightly smokey quartz predominate; common light to medium light gray lithics,some with a metallic white appearance;trace to common medium to dark brown lithic/mineral grains; common to abundant light to medium and dark green mineral and green stained quartz grains;trace mica and limonite flakes;trace rose and brick red grains;interbedded with/grading to thin brownish gray siltstone; material appears to be at least partly silt matrix supported; 100%dull greenish yellow sample fluorescence cuts to weakly murky yellow-white; slight to fair brownish residue ring fluoresces medium yellow and cuts to milky yellow-white; Safe-Carb contamination continues. OA SUBLOBE 2 15368' MD/-3470.7'TVDSS Siltstone/Sandy Siltstone(15400-15510)=medium light to light gray;firm to very firm and soft;angular flaky to irregular fragments; dull earthy luster with a marked sparkly appearance due to abundant fine mica; sandy/gritty texture apparent gradational relationship with the associated sandstone; contains variable amounts of very fine to fine sand in the same mineral range as the above described sandstone; trace thin black laminar inclusions; trace apparent glass shards; slightly calcareous; note: Safe-Carb contamination. Sand/Sandstone (15400-15640) = light to medium gray with a slight brownish secondary hue; soft disaggregated loose sand with rare intact hard sandstone fragments;and abundant sandy siltstone fragments; friable in part; appears variably silty; very fine upper to fine lower grain; trace larger grains; sub-angular to angular; rare sub-spheroidal; frosted clear colorless to translucent white and slightly smokey quartz predominate; common light to medium light gray lithics, some with a metallic white appearance; trace to common medium to dark brown lithic/mineral grains; common to abundant light to medium and dark green mineral and green stained quartz grains; trace mica and limonite flakes; trace rose and brick red grains; interbedded with/grading to thin brownish gray siltstone; material appears to be at least partly silt matrix supported; 100% dull greenish yellow sample fluorescence cuts to weakly murky yellow-white; slight to fair brownish residue ring fluoresces medium yellow and cuts to milky yellow-white; Safe-Carb contamination continues. FAULT 17-02-4 15611' MD/3462.8'TVDSS Sand/Sandstone (15640-15790) = light to medium gray with a slight greenish secondary hue; soft disaggregated sand with rare intact hard sandstone fragments and abundant sandy siltstone fragments;friable in part; variably silty; very fine upper to fine lower grain; trace larger grains; sub-angular to angular; frosted clear colorless,translucent white and slightly smokey quartz predominate;common light gray lithics,some with a metallic white appearance may be hard face material from drill string;common medium brown lithic/mineral grains; abundant light to medium and dark green mineral and green stained quartz;trace mica and limonite flakes;trace pyrite and chalcopyrite;trace black pyritic concretion fragments trace rose and brick red grains; interbedded with/grading to thin brownish gray siltstone; material appears to be at least partly silt matrix 34 CANRIG 101 Eni Petroleum OP 17-02 and OP 17-02-PB1 supported; 100% dull greenish yellow sample fluorescence cuts to weakly murky yellow-white; slight to fair brownish residue ring fluoresces medium yellow and cuts to milky yellow-white; Safe-Carb contamination continues. Sand/Sandstone (15790-15910) = light to medium gray with a slight brownish secondary hue; soft disaggregated sand with rare intact silty sandstone and sandy siltstone fragments;friable;appears slightly silty throughout; very fine upper to fine lower grain; trace larger grains becomes common below 15875'; sub- angular to angular;frosted clear colorless,translucent white and slightly smokey quartz predominate;common light gray lithics, some with a metallic white appearance may be hard face material from drill string; trace medium brown lithic/mineral grains; common to trace green mineral grains and green stained quartz; trace mica; scattered limonite flakes; trace pyrite and chalcopyrite; trace black pyritic concretion fragments trace rose and blue-gray grains; interbedded with/grading to thin brownish gray siltstone; material appears to be primarily grain supported with thin silt matrix intervals; 100%dull greenish yellow sample fluorescence;cuts to milky yellow-white; slight to moderate brownish residue ring fluoresces medium yellow and cuts to milky yellow-white; Safe-Carb contamination continues. Sand/Sandstone (15910-16040) = light to medium gray with a slight brownish secondary hue; soft disaggregated sand friable; appears slightly silty throughout; very fine upper to fine lower grain;trace larger grains becomes common below 15875';sub-angular to angular;frosted clear colorless,translucent white and slightly smoky quartz predominate;common light gray lithics,some with a metallic white appearance may be hard face material from drill string; trace medium brown lithic/mineral grains; common to abundant green mineral grains and green stained quartz; trace mica; scattered limonite flakes;trace pyrite and chalcopyrite; trace black pyritic concretion fragments trace rose and blue-gray grains; inter- bedded with/grading to thin brownish gray siltstone; dull to moderate greenish yellow sample fluorescence; milky yellowish white cut fluorescence. Sand(16040-16150)=clear to light gray to translucent unconsolidated sand grains; light greenish to brownish hues throughout sample interval; upper very fine to upper fine;very well sorted;sub-angular to angular to sub- rounded; moderate to high sphericity; scattered pale yellowish orange to moderate orange pink shell fragments; approximately 5% black to light bluish green fine grained lithics; slight oil odor; no visible oil staining on free sand grains; 100% even dull to moderately bright yellowish white to white sample fluorescence; blooming bright white cut fluorescence; dark amber visible cut; light pale straw visible residue; bright bluish white residual fluorescence. Sand(16150-16240)=light gray to medium light gray to clear to milky white;brownish to greenish hues; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity throughout sample interval; occasional pale yellowish orange to moderate orange pink shell fragments; 5-10% black to moderate green to brilliant green fine grained lithics; slight oil odor; no visible oil stain on sand grains; light brown oil staining within sandstone cuttings; 100%even moderately bright yellowish white sample fluorescence; blooming bright white cut fluorescence;dark amber visible cut; light straw visible residue; moderately bright white residual fluorescence. OA SUBLOBE 2 16250' MD/-3457.8'TVDSS Sand/Sandstone(16240-16360)=clear to light gray to medium light gray; brownish to greenish to reddish secondary hues throughout sample interval; sandstone is easily friable to friable;crumbly tenacity;cement is calcareous; upper very fine to upper fine; very well sorted; sub-angular to sub-rounded to angular with moderate sphericity; moderate orange pink to pale yellowish orange shell fragments;approx 5%fine grained black lithics; slight oil odor; no visible oil staining on free sand grains; light brown oil stain within sandstone cuttings; 100% even moderately bright to dull yellowish white sample fluorescence; blooming moderately bright white cut fluorescence with amber to dark amber visible cut; medium dark straw visible residue; moderately bright white residual fluorescence; samples contaminated by Safe-Carb mud additive. Sand/Sandstone (16360-16510) = clear to light gray to translucent to medium light gray; brownish to yellowish brown to reddish to greenish secondary hues throughout sample interval;sandstone is easily friable to firmly friable; crumbly to brittle tenacity; sub-spherical to nodular cuttings habit; cement is calcareous; occasional grading to silty sandstone and sandy siltstone; upper very fine to upper fine;very well sorted;sub- angular to angular to sub-rounded with moderate to high sphericity throughout sample interval; scattered 35 CANRIG Iona Eni Petroleum OP 17-02 and OP 17-02-PB1 moderate orange pink shell fragments;5-10%fine grained black to moderate green lithics;slight to fragrant oil odor; no visible oil staining on free sand grains;sandstone cuttings have light brown oil staining within; 100% even bright to moderately bright yellow to yellowish white sample fluorescence; blooming bright white cut fluorescence; amber to dark amber visible cut; light straw visible residue; dull yellow residual fluorescence. Sand/Sandstone (16510-16630) = medium light gray to clear to light gray to milky white; brownish to occasionally reddish and greenish secondary hues; sandstone is easily friable to firmly friable; crumbly tenacity; sub-spherical to sub-discoidal cuttings habit; cement is calcareous; grades to silty sandstone and sandy siltstone in middle of sample interval; upper very fine to upper fine;very well sorted;sub-angular to sub- rounded to angular with moderate sphericity; rare moderate orange pink shell fragments; approximately 5% black to moderate green fine grained lithics; slight oil odor; no visible oil staining on free sand grains; dark brown to light brown oil staining within sandstone cuttings when split open; 100% even moderately bright yellow sample fluorescence; immediate bright white cut fluorescence; dark brown visible cut; medium straw visible residue; moderately bright yellowish white residual fluorescence. Siltstone (16540-16675) = olive black to medium dark gray to brownish gray to dark gray; friable to moderately hard;crunchy brittle to tough to crumbly tenacity; irregular to sub-blocky fracture;irregular cuttings habit;greasy waxy luster;silty to gritty texture;thin black to reddish brown to dark brown laminations visible in light colored cuttings. OA SUBLOBE 3 16729' MD/-343452.8' TVDSS Sand/Sandstone (16690-16840) = clear to light gray to translucent to milky white to medium light gray; greenish to bluish to yellowish brown to brownish to reddish secondary hues throughout sample interval; sandstone is easily friable to firmly friable;crumbly tenacity;cement is calcareous;grades to silty sandstone to sandy siltstone throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity;scattered pale yellowish orange shell fragments;5- 10% black to moderate green to brilliant green fine grained lithics; slight to fragrant oil odor; no visible oil staining on free sand grains;light brown oil staining within sandstone cuttings; 100%even moderately bright to dull yellow to yellowish white sample fluorescence;slow blooming bright white cut fluorescence;amber visible cut; light pale straw visible residue; dull yellowish white residual fluorescence. Sand/Sandstone(16840-17020)=clear to light gray to medium light gray to milky white;brownish to greenish to reddish secondary hues;sandstone is easily friable to friable;cementation is calcareous;crumbly tenacity; occasional grading to silty sandstone and sandy siltstone; upper very fine to upper fine and very well sorted; sub-angular to sub-rounded to angular with moderate to high sphericity; pale yellowish orange to moderate orange pink shell fragments;fine grained black to light bluish green to moderate green to brilliant green lithics; pyrite crystal growths and fine to medium sized individual grains; muscovite sheet fragments noticed this interval; fragrant oil odor; no visible oil staining on unconsolidated sand grains; light brown to dark brown oil staining within sandstone cuttings; 100%even moderately bright yellowish white with 20%patchy dull yellow at 16900' sample fluorescence; immediate dull white cut fluorescence; amber to dark amber visible cut; medium dark straw visible residue; dull yellowish white residual fluorescence. FAULT 17-02-5 17110' MD/3455.4' TVDSS Sand/Sandstone(17020-17200)=medium gray;slight brownish to greenish secondary hue;samples consist primarily of loose disaggregated sand to 17140'where recovered material is firm to hard well indurated calcitic sandstone; locally friable;fine lower to very fine upper grain;scattered larger grains;sub-angular to angular; translucent white to frosted clear colorless and translucent slightly smokey quartz;common to abundant light to dark green mineral grains; trace to common brown mineral/ lithics; trace dark gray to black mafic mineral/lithics and light gray lithics;trace rose lithics;trace dull gray-brown mottled and tan tabular dolomite/ siderite/ironstone concretion fragments; material is silty in part grading to micaceous sandy siltstone; 100% medium to medium dull yellow sample fluorescence cuts immediately to milky medium yellow-white; slight brownish residue ring fluoresces dull yellow and cuts immediately to medium yellow-white; no odor above OBM background; slight brownish stain on sample wash; Safe-Carb contamination continues. Sand/Sandstone (17200-17350) = medium to medium gray with a slight brownish to greenish hue; soft disaggregated loose sand with scattered hard sandstone fragments;friable in part;appears variably silty;very fine upper to fine lower grain; trace larger grains; sub-angular to angular; rare sub-spheroidal; frosted clear 36 CANRIG Oft eni Eni Petroleum OP 17-02 and OP 17-02-PB1 colorless to translucent white and slightly smokey quartz predominate; common light to medium light gray lithics, trace to medium and dark brown lithic/mineral grains; common to abundant light to medium and dark green mineral and green stained quartz grains; trace mica and limonite flakes; trace rose and red-brown grains; interbedded with/grading to thin brownish gray siltstone;occasional thin concretion zones;trace shell fragments and pyrite; 100%medium to medium dull sample fluorescence cuts easily to milky medium yellow- white;slight brownish residue ring fluoresces dull yellow and cuts immediately to milky medium yellow-white; no odor over OBM background. Sand/Sandstone (17350-17500) = medium to medium gray with a slight brownish to greenish hue; soft disaggregated loose sand;scattered hard fine grain sandstone fragments friable;occasional sandy siltstone; fragments;very fine upper to fine lower;trace fine upper;sub-angular to angular; rare sub-spheroidal;frosted clear colorless to translucent white and slightly smokey quartz;common light to medium light gray lithics;trace medium to dark brown and red-brown lithic/mineral grains; abundant light to dark green mineral grains and green stained quartz;trace mica and limonite\flakes;trace rose and orange jasper;occasional light to medium light grayish brown sandy micaceous siltstone;occasional trace shell fragments;trace small pyrite masses and occasional pyrite laminated black mineral grains; 100% medium to medium dull sample fluor-escence; streaming milky yellow-white cut; slight brownish residue ring fluoresces dull yellow and cuts immediately to milky yellow-white; no odor over OBM residue ring fluoresces dull yellow and cuts immediately to milky medium yellow-white; no odor over OBM background; Safe-Carb contamination continues. Sand/Sandstone (17500-17620) = medium to medium gray with a slight brownish to greenish hue; soft disaggregated loose sand;scattered hard fine grain sandstone fragments;friable;occasional sandy siltstone fragments; very fine upper to fine lower; trace fine upper; sub-angular to angular; frosted clear colorless to translucent white and slightly smokey quartz;common light to medium light gray lithics;trace medium to dark brown and red-brown lithic/mineral grains;common to abundant light to dark green mineral grains and green stained quartz;trace limonite and mica flakes;trace rose and orange jasper;trace medium light grayish brown sandy micaceous siltstone; yellowish green sample fluorescence; milky yellowish white cut. Sand/Sandstone (17620-17740) = clear to translucent to light gray to medium light gray unconsolidated sands; greenish to brownish to reddish to yellowish brown secondary hues; sandstone cuttings are easily friable to friable; cement is calcareous; upper very fine to upper fine; very well sorted; sub-angular to sub- rounded to angular with moderate to high sphericity throughout sample interval; occasional pale yellowish orange to moderate orange pink shell fragments;approximately 10%black to moderate green to brilliant green fine grained lithics;muscovite sheet fragments;slight oil odor; no visible oil staining on free sand grains; 100% even moderately bright yellow sample fluorescence; blooming bright white to bluish white cut fluorescence; dark amber to brown visible cut; straw visible residue; bright yellow to yellowish white residue fluorescence; samples are contaminated by Safe-Carb mud additive. Sand (17740-17860) = light gray to clear to medium light gray to translucent to milky white unconsolidated sand grains; brownish to greenish to reddish hues throughout sample interval; upper very fine to upper fine; very well sorted;sub-angular to sub-rounded to angular with moderate to high sphericity;scattered moderate orange pink shell fragments; approximately 7-10% black to moderate green to brilliant green to light bluish green fine grained lithics; muscovite sheet fragments and pyrite crystals noted in samples; slight oil odor; no visible oil staining on free sand grains; 100%even moderately bright yellow sample fluorescence; blooming bright white cut fluorescence; dark amber visible cut; light pale straw visible cut; moderately bright yellow residual fluorescence; samples are heavily contaminated by Safe-Carb mud additive. Sand(17860-17980)=clear to light gray to translucent to medium light gray unconsolidated sands;brownish to greenish to reddish secondary hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity; pale yellowish orange to moderate orange pink shell fragments; approximately 6-8% black to brilliant green to moderate green fine grained lithics; trace amount of pyrite seen; muscovite sheet fragments observed throughout the sample interval; slight to fragrant oil odor; no visible oil staining on free sand grains; 100%even moderately bright to dull yellow to yellowish white sample fluorescence; blooming bright yellowish white cut fluorescence; brown visible cut; no visible residue; faint yellow residual fluorescence; samples contaminated by Safe-Carb mud additive. OA SUBLOBE 2 17980' MD/-3464.8' TVDSS 37 CANRIG IA ci Eni Petroleum OP 17-02 and OP 17-02-PBI FAULT 17-02-6 18040' MD/3465.6' TVDSS Sand/Sandstone(17980-18200)=clear to light gray to medium light gray to translucent unconsolidated sand grains; greenish to bluish to reddish to brownish secondary hues throughout sample interval; sandstone is easily friable to firmly friable; calcareously cemented; generally crumbly when prodded; grades to silty sandstone to sandy siltstone to siltstone as depth increases; upper very fine to upper fine; well to very well sorted; sub-angular to angular to sub-rounded with moderate to high sphericity; pyrite abundance increases with depth; small muscovite sheet fragments; slight oil odor; 100% even moderately bright yellowish white sample fluorescence; blooming bright white cut fluorescence; dark amber visible cut; light pale straw visible residue; dull yellow residual fluorescence; samples continue to be contaminated by Safe-Carb. Siltstone/Shale(18000-18200)=olive black to medium dark gray to brownish gray to light gray to light brown; easily friable to moderately hard; crumbly to brittle crunchy tenacity; irregular to sub-blocky fracture; sub- tabular to irregular cuttings habit; dull earthy to greasy luster; clayey to silty to gritty texture depending on silt and sand content; thin black to reddish brown laminations. SCHRADER BLUFF LATERAL SECTION (0P17-02-PB1, TD 18940'MD;API#50-029-23431-00-60) 9460' MD/-3518.2.1'TVDSS TO FINAL TD AT 18940' MD/-3440.8' TVDSS Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 408 1.4 253.9 930 trace 210 PEAKS Depth TG Cl C2 C3 C41 C4N C51 C5N 9585 637 153260 1426 955 418 717 401 574 9834 829 95808 918 578 233 387 209 229 9925 924 113134 1028 631 299 498 278 391 10027 882 55531 532 325 144 232 130 195 10147 794 66951 804 848 405 684 441 576 10254 809 82014 1073 1345 764 1354 776 1167 10541 614 124341 1134 805 351 621 457 562 10758 667 108657 1122 672 249 402 206 277 11048 362 64108 795 750 325 575 426 497 11325 173 85050 943 1112 623 1222 1150 1683 11426 254 64108 668 561 299 554 514 795 11628 372 72509 774 471 194 315 147 215 12008 361 74382 913 792 369 688 591 882 12650 370 66512 782 694 326 606 515 772 12968 307 56455 641 484 201 315 249 250 13474 487 106305 1076 566 255 373 204 275 13824 562 85585 777 390 192 222 111 71 14001 458 76534 703 359 167 190 109 73 14405 358 58347 485 297 150 167 120 72 15778 307 48240 397 457 209 347 345 213 16798 536 78236 1095 589 235 286 143 96 16951 195 34554 328 215 64 92 61 45 17171 369 56861 330 173 83 93 64 50 17437 392 77224 654 364 132 175 83 61 17735 441 71072 789 487 204 256 107 91 17897 340 59712 660 379 155 193 110 84 18407 337 69500 3122 1986 990 1264 649 646 18543 478 123726 803 473 210 272 137 115 18828 514 92011 918 540 213 269 111 83 18910 346 53678 534 310 113 147 81 54 OA SUBLOBE 3 9384' MD/-3500.9'TVDSS 38 CANRIG Ift ,! ni Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand/Sandstone(9400-9490)=translucent to light gray to clear to medium gray throughout sample interval; sandstone cuttings are easily friable to firmly friable; upper very fine to upper fine; very well sorted; sub- rounded to sub-angular; moderate to high sphericity; approximately 10-15% fine grained black lithics; 5% moderate green to brilliant green fine grained lithics; moderate orange pink to pale yellowish orange shell fragments scattered throughout sample interval;slight oil odor above OBM;no oil staining on sand grains,dark brown oil staining within sandstone cuttings when split apart; 10-30% patchy dull to moderately bright yellow sample fluorescence;slow blooming dull white cut fluorescence; straw to pale straw visible cut; light straw to dark straw visible residue; faint to dull white to yellowish white residual fluorescence. Siltstone/Shale(9500-9540)=medium gray to olive gray to brownish black;easily friable to moderately hard; tough and dense to brittle and crumbly tenacity depending on hardness; blocky to irregular fracture;tabular wedge-like cuttings habit;dull earthy to greasy waxy luster;smooth clayey to silty and gritty texture;shale has thin black to reddish brown laminations. Sand/Sandstone (9565-9640) = clear to translucent, with some white, light gray pale blue, pale green, blackish red,and dusky red; predominantly quartz grain sand matrix;upper very fine to upper fine grain sand; moderate to well sorted throughout; very angular to sub-angular, with some very rounded to sub-rounded; moderate sphericity; thicker beds of fine grain sandstone interbedded with thinner beds of sandy siltstones, some sand grains exhibited dark brown to black oil staining; some pyrite crystals throughout. Siltstone(9645-9705)=dark gray to gray with some medium light gray;stiff to somewhat firm;slightly dense to brittle or crumbly; mostly blocky with some planar and irregular in places; massive to slightly platy cuttings habit; greasy to somewhat waxy luster; thin beds of sandy siltstone interbedded with thick beds of very fine grained quartz sandstone and sand; some pyrite crystals throughout; shell fragments throughout. Sandstone/Sand (9710-9780) =translucent to clear, with some milky white, light gray, very dusky red, blackish red, and black hues; upper very fine to upper fine grain sand; moderate to well sorted; very well rounded to sub-rounded with some sub-angular to angular; low to moderate sphericity; predominantly quartz grain sand matrix, interbedded with thinner beds of sandy siltstone; pyrite crystals were observed throughout the sample; shell fragments; some dark brown to black oil staining was observed on sand grains. OA SUBLOBE 2 9755' MD/-3493.1'TVDSS Siltstone(9785-9840) = dark gray to light gray with some medium light gray; mostly firm to stiff; brittle to crumbly; irregular to slightly blocky fracture; amorphous to somewhat platy fracture; very greasy to slightly waxy luster; thin beds of sandy siltstones, interbedded with thick beds of very fine grained quartz sandstones and sands; some pyrite crystals and shell fragments. Sandstone/Sand (9845-9930) = clear to translucent, with white, light gray, pale green, pale blue, very dusky red, blackish red, and black hues; mostly quartz grain sand matrix; upper very fine to upper fine grain sand with some lower medium; moderately to poorly sorted; very well rounded to sub-rounded with some sub-angular; moderate sphericity; thicker beds of fine grain siliceous cemented sandstone and loose quartz sand, interbedded with thinner beds of sandy siltstones; some shell fragments throughout; some pyrite crystals; dark brown and black oil staining observed on some sand grains. Siltstone(9935-10000) = light brownish gray to brownish gray with some medium gray to light medium gray; stiff; mostly brittle to crumbly; predominantly irregular fracture with some slightly planar; amorphous to somewhat platy cuttings habit; greasy to slightly waxy luster; very silty texture with some very gritty; thinner beds of sandy siltstone interbedded with thicker beds of fine grain, siliceous cemented quartz grain sandstone; some shell fragments throughout. Sandstone/Sand (10005-10080) = mostly translucent to clear,with white, light pale blue, pale green, moderate yellowish brown, very dusky red; blackish red, and black hues; mostly quartz grain sand matrix throughout; upper very fine to lower medium sand grains; moderate to poorly sorted; very well rounded to sub-rounded with some grains very angular to sub-angular; moderate sphericity; predominantly quartz grain sand and siliceous cemented sandstone, interbedded with thinner beds of sandy siltstone; some shell fragments throughout. 39 CANRIG gni Eni Petroleum OP 17-02 and OP 17-02-PB1 Siltstone(10085-10135)= medium gray to gray with some brownish gray; slightly stiff; very brittle to crumbly; blocky fracture; amorphous to somewhat platy fracture; very greasy to slightly waxy luster; thin beds of sandy siltstones, interbedded with thick beds of very fine grained quartz sandstones and sands; some pyrite crystals and shell fragments. Sandstone/Sand (10140-10215) = mostly clear to translucent, with milky white, pale blue, pale green, moderate yellowish brown, very dusky red; blackish red, and black hues; mostly quartz grain sand matrix throughout; upper very fine to lower medium sand grains; moderate to poorly sorted; sub-rounded to well rounded,with some sub-angular to very well angular; moderate sphericity; thicker beds of siliceous cemented sandstone and quartz sand, interbedded with thin beds of sandy siltstone; abundant shell fragments throughout sample. Siltstone(10220-10270) =dark gray to light gray with some brownish gray; mostly firm to stiff; brittle to crumbly; irregular to slightly blocky fracture; amorphous to somewhat platy fracture; very greasy to slightly waxy luster; thin beds of sandy siltstones, interbedded with thick beds of very fine grained quartz sandstones and sands; abundant shell fragments. Sandstone/Sand (10275-10355)=clear to translucent, with white, light gray, pale blue, pale green, moderate yellowish brown, very dusky red; blackish red, and black hues; quartz grain sand matrix throughout; upper very fine to lower medium grain sand; moderate to poorly sorted; very angular to sub- angular, with some sub-rounded to rounded; moderate sphericity; thick beds of fine grained siliceous cemented sandstone, and loose uncemented quartz sand, interbedded with thinner beds of sandy siltstone and silty shale; abundant shell fragments throughout. Siltstone(10360-10415) =dark gray to medium gray; predominantly stiff; very brittle to crumbly; blocky fracture; amorphous to somewhat platy fracture; very waxy to slightly greasy luster; thin beds of sandy siltstones, interbedded with thick beds of siliceous cemented sandstone and loose quartz grain sands, and thin beds of silty shale; abundant shell fragments throughout sample. Sandstone/Sand (10420-10495)= clear to translucent, with white, light gray, pale blue, pale green, moderate yellowish brown, very dusky red; blackish red, and dark grayish black hues; predominantly quartz grain sand matrix throughout; upper very fine to lower medium grain sand; moderate to poorly sorted; sub-rounded to well rounded,with some angular to sub-angular; moderate sphericity; thicker beds of siliceous cemented sandstone and loose quartz sand, interbedded with thinner beds of sandy siltstones; abundant shell fragments throughout. OA SUBLOBE 2 10472' MD/-3491.3' TVDSS Siltstone (10500-10565) = light gray to dark gray with some medium gray; stiff; predominantly crumbly to brittle; somewhat irregular fracture with some slightly planar; amorphous to somewhat platy cuttings habit; greasy to slightly waxy luster; very silty texture with some very gritty; thinner beds of sandy siltstone interbedded with thicker beds of fine grain, siliceous cemented sandstone, and quartz grain loose uncemented sand; abundant shell fragments throughout. Sandstone/Sand (10570-10640)=clear to translucent, with some white, light gray pale green, pale blue, very dusky red, blackish red, and grayish black hues; predominantly quartz grain sand matrix; upper very fine to lower medium grain sand; moderate to poorly sorted; sub-angular to very angular, with sub-rounded to rounded; moderate sphericity; thicker beds of siliceous cemented sandstone, and loose quartz grain sand, interbedded with thinner beds of sandy siltstones; shell fragments throughout sample. Siltstone(10645-10695) = medium gray to light gray with some dark gray; mostly stiff; very brittle to crumbly; blocky fracture; amorphous to somewhat platy fracture; very greasy to slightly waxy luster; thin beds of sandy siltstone interbedded with thicker beds of quartz sand, and siliceous cemented sandstone; some shell fragments throughout the sample. OA SUBLOBE 3 1070' MD/-3496.1' TVDSS Sand/Sandstone(10640-10810) = clear to translucent to very light gray with black to gray to brown to green hues throughout sample interval; sandstone is easily friable to firmly friable; upper very fine to upper 40 CANRIG 10* Eni Petroleum OP 17-02 and OP 17-02-PB1 fine grain size;very well sorted; sub-angular to angular; poor to moderate sphericity; 10%fine grained black lithics; 5% moderate green to brilliant green to bluish green fine grained lithics; slight to moderate oil odor above OBM; no visible oil staining on free sand grains; dark brown oil staining within sandstone cuttings when prodded open; 90-100% even moderately bright to dull yellow to yellowish white sample fluorescence with occasional 10-20% moderately bright patchy yellow fluorescence; blooming bright white cut fluorescence; light amber to amber visible cut; light straw visible residue; dull yellowish white residual fluorescence. Sand (10810-10930) =very light gray to translucent to clear to milky white with black to brown to red to green to gray hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular with low to moderate sphericity; 10-15%fine grained black lithics giving salt and pepper appearance; approximately 5% moderate green to bluish green fine grained lithics; slight to no to moderate oil odor; 80-100%even dull to moderately bright yellow sample fluorescence; slow blooming moderately bright white cut fluorescence; straw to dark straw visible cut; light dark straw visible residue; dull to moderately bright yellow residue fluorescence. OA SUBLOBE 3 10867' MD/-3495.7'TVDSS Sand (10930-10990) = light gray to clear to translucent to medium light gray; upper very fine to upper fine; very well sorted throughout sample interval; sub-angular to angular with low to moderate sphericity; 10- 15%fine grained black lithics; 5% brilliant green to moderate green fine grained lithics; slight to moderate oil odor; no visible oil stain on free sand grains; 90-100% even dull to moderately bright yellow sample fluorescence; slow blooming dull white cut fluorescence; dark straw to straw visible cut; light straw to pale straw visible residue; dull yellowish white residual fluorescence. Sand/Sandstone(10990-11080) = light gray to translucent to medium light gray to clear; quartz grains have red to brown to black hues throughout sample interval; sandstone is easily friable to firmly friable; upper very fine to upper fine; very well sorted; sub-angular to angular with low to moderate sphericity; 10- 15%fine grain black lithics; 5% moderate green to bluish green fine grained lithics; slight oil odor above OBM; no visible oil staining on free sand grains, dark brown oil staining within sandstone cuttings when split open; 80-100%even moderately bright yellow sample fluorescence; slow blooming dull white cut fluorescence; dark straw visible cut; light straw visible residue; dull yellowish white residue fluorescence. FAULT 17-02 PB1 -1 11049' M D/3493.4' TVDSS Shale(11060-11200) = brownish black to olive black to black to dark gray; moderately hard to friable with occasional hard cuttings; tough dense tenacity; sub-blocky to sub-planar fracture; tabular wedge-like cuttings habit; waxy earthy luster within cuttings when split open, greasy exterior of cuttings due to OBM; smooth clayey to silty texture; occasional thin black laminations noticeable in lighter colored cuttings; none to slight oil odor; no visible oil staining; 0-20% patchy dull yellow sample fluorescence; slow streaming bright white cut fluorescence; dark straw visible cut; light pale straw visible residue; no to faint white residual fluorescence. Shale/Siltstone(11200-11290)= brownish black to olive black to medium gray to olive gray; moderately hard to friable to hard; tough dense to occasionally crunchy tenacity; shale has sub-blocky fracture; siltstone has irregular fracture; predominantly wedge-like and tabular cuttings habit; earthy dull waxy luster; smooth clayey to silty gritty texture; occasional thin black laminations noticed; none to slight oil odor above OBM; no visible oil staining; 0-5% patchy dull yellow sample fluorescence; pale straw visible cut; no visible residue; faint to no white residual fluorescence. BASE OF OA SAND 11310.5' MD/-3482.4' TVDSS Shale(11290-11380)= brownish black to olive black to black to dark gray; moderately hard to friable with occasional hard cuttings; tough dense tenacity; sub-blocky to sub-planar fracture; tabular wedge-like cuttings habit; waxy earthy luster within cuttings when split open, greasy exterior of cuttings due to OBM; smooth clayey to silty texture; occasional thin black laminations noticeable in lighter colored cuttings; none to slight oil odor; no visible oil staining; 0-20% patchy dull yellow sample fluorescence; slow streaming bright white cut fluorescence; dark straw visible cut; light pale straw visible residue; no to faint white residual fluorescence. 41 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 OA SUBLOBE 4 11379.0' MD/-3476.0'TVDSS Shale/Siltstone(11380-11530)=olive black to black to brownish black to dark gray; moderately hard to firmly friable to friable with occasional hard cuttings; tough dense to crunchy tenacity; sub-blocky to planar fracture in shale cuttings, irregular fracture in siltstone cuttings; shale cuttings habit is tabular and wedge- like and typically sub-discoidal; waxy earthy to vitreous luster; smooth clayey to silty texture that varies with composition grading between siltstone and shale; occasional thin black laminations, carbonaceous, in cuttings; none to slight oil odor above OBM; no visible oil staining; no other oil indicators. Sand/Sandstone(11400-11590) = clear to translucent to very light gray with black to gray to brown to green hues throughout sample interval; sandstone is easily friable to firmly friable; upper very fine to upper fine grain size; very well sorted; sub-angular to angular; poor to moderate sphericity; 10%fine grained black lithics; 5% moderate green to brilliant green to bluish green fine grained lithics; slight to moderate oil odor above OBM; no visible oil staining on free sand grains; dark brown oil staining within sandstone cuttings when prodded open; 30-50% patchy dull yellow sample fluorescence; blooming moderately bright white cut fluorescence; amber visible cut; straw to dark straw visible residue; dull yellowish white residue fluorescence. OA SUBLOBE 3 11557.5' MD/-3462.8'TVDSS Shale/Siltstone(11530-11650) = olive black to brownish black to dark gray; firmly friable to moderately hard to hard; tough dense tenacity; sub-blocky to irregular fracture; tabular wedge-like cuttings habit; vitreous greasy to waxy luster; smooth clayey to silty texture; few thin black carbonaceous laminations; slight oil odor; no visible oil staining on shale cuttings; 10-20% patchy dull yellowish white sample fluorescence. FAULT 17-02 PB1 -2 11667' M D/3458.3' TVDSS Shale(11650-11740) = brownish black to olive black to black to dark gray; moderately hard to friable with occasional hard cuttings; tough dense tenacity; sub-blocky to sub-planar fracture; tabular wedge-like cuttings habit; waxy earthy luster within cuttings when split open, greasy exterior of cuttings due to OBM; smooth clayey to silty texture; occasional thin black laminations noticeable in lighter colored cuttings; none to slight oil odor; no visible oil staining; 0-5% patchy dull yellow sample fluorescence; no other oil indicators. Shale/Siltstone(11740-11830)= olive black to black to brownish black to dark gray; moderately hard to firmly friable to friable with occasional hard cuttings; tough dense to crunchy tenacity; sub-blocky to planar fracture in shale cuttings, irregular fracture in siltstone cuttings; shale cuttings habit is tabular and wedge- like and typically sub-discoidal;waxy earthy to vitreous luster; smooth clayey to silty texture that varies with composition grading between siltstone and shale; occasional thin black laminations in cuttings; none to slight oil odor; no visible oil staining; 0-2% patchy dull yellow sample fluorescence; no other oil indicators. Shale/Siltstone(11830-11890) = brownish black to black to olive black to dark gray; moderately hard to firmly friable to friable; tough dense to occasional crunchy tenacity in cuttings; sub-blocky to irregular fracture; shale cuttings habit is wedge-like to tabular and sub-discoidal; siltstone cuttings habit is massive and irregular; greasy vitreous exterior due to OBM;waxy dull luster in split open cuttings; thin carbonaceous black laminations rarely visible in lighter colored cuttings; no oil odor; no visible oil staining; no other oil indicators above OBM. Shale/Siltstone(11890-11950) = olive black to black to brownish black to dark gray; hard to firmly friable to moderately hard; tough dense tenacity; sub-blocky to sub-planar to irregular fracture; tabular wedge-like cuttings habit; vitreous waxy luster; occasional shell fragments; no oil indicators above OBM. 42 CANRIG SIA emm Eni Petroleum OP 17-02 and OP 17-02-PB1 OA SAND TOP 11979.0' MD/-3463.3' TVDSS Sandstone/Sand (11955-12035)= mostly translucent to clear with some medium gray, white, pale green, dark gray, blackish red, very dusky red, and black; predominantly quartz grain sand matrix; upper very fine to upper fine,with some lower medium; moderate to poorly sorted throughout;well angular to sub-angular, with some sub-rounded; moderate sphericity; little or no sample fluorescence other than the OBM; thicker beds of siliceous cemented sandstone, and mostly loose uncemented quartz sand, interbedded with thicker beds of sandy siltstones; some pyrite crystals were observed in the sample. Siltstone( 12040-12100)= medium dark gray to dark gray; slightly stiff; very brittle to somewhat crunchy; irregular to slightly blocky fracture; amorphous to somewhat platy cuttings habit; waxy to dull luster; predominantly silty with some very gritty texture; thicker beds of sandy siltstone, interbedded with loose unconsolidated quartz sand, and siliceous cemented sandstone; no sample fluorescence, other than the OBM; some pyrite crystals throughout the sample. Sandstone/Sand (12105-12190) = clear to translucent,with white, dark gray, blackish red, very dusky red, and black; mostly quartz grain sand matrix; lower very fine grain to upper fine,with lesser amounts of lower medium grain sand; poor to moderately sorted; very angular to sub-angular, with some sub-rounded to well rounded; moderate sphericity; very little to no sample fluorescence, other than the OBM fluorescence; thicker beds of siliceous cemented sandstone, and loose uncemented quartz sand, interbedded with very sandy siltstone; some shell fragments, and some pyrite crystals throughout the sample. Siltstone (12195-12260) = dark gray to medium dark gray, with some medium gray; mostly firm to slightly stiff; crunchy to slightly brittle; irregular to slightly blocky fracture; amorphous to slightly platy cuttings habit; waxy to dull luster; predominantly silty with some very gritty texture; thinner beds of sandy siltstone, interbedded with loose uncemented quartz sand, and siliceous cemented sandstone; no sample fluorescence, other than the OBM; some pyrite crystals throughout the sample. Sandstone/Sand (12265-12355) =white, light gray, pale green, dusky red,with blackish red, dark gray, and black hues along with predominantly translucent to clear sand grains; predominantly quartz grain sand matrix throughout; lower very fine to upper fine with very little lower medium grain sand; poorly sorted; very angular to sub-angular,with some sub-rounded to rounded; moderate sphericity; very little 5%-10%, sample fluorescence other than the OBM; thicker beds of siliceous cemented sandstone, and mostly loose uncemented quartz sand, interbedded with thicker beds of sandy siltstones; some pyrite crystals and shell fragments were observed throughout the sample. Siltstone(12360-12430)= medium dark gray to dark gray; slightly stiff to somewhat firm; mostly brittle to crumbly; irregular fracture; amorphous to very slightly platy cuttings habit; greasy to slightly dull luster; thicker beds of sandy siltstones, interbedded with loose unconsolidated quartz sand, and siliceous cemented sandstones; no sample fluorescence, other than the OBM fluorescence; abundant shell fragments and pyrite crystals observed throughout the sample; no other oil indicators above OBM. Sandstone/Sand (12435-12520) =clear to somewhat translucent, with milky white, light gray, pale green, dusky red,with blackish red, dark gray, and black hues; predominantly quartz grain sand matrix; lower very fine to upper fine grain sand; moderate to well sorted; sub-angular to well angular with some very well rounded to sub-rounded; moderate sphericity; thicker loose unconsolidated quartz sand with thinner beds of siliceous cemented sandstone, and thinner beds of sandy siltstone; little or no sample fluorescence 5% -10%, above OBM; no other oil indicators were observed; abundant shell fragments and pyrite crystals throughout sample. Siltstone(12525-12580)=dark gray to medium dark gray; firm to stiff; crumbly to somewhat brittle; irregular fracture; amorphous cuttings habit; greasy to dull luster; very silty texture with some very gritty; thinner sandy siltstone beds, interbedded with increasingly thicker beds of loose uncemented quartz sand, with thinning beds of sandstone; no oil indicators above OBM. Sandstone/Sand (12580-12645)= light gray to dark gray, with white, clear, translucent, black, very dusky red, and blackish red hues; predominantly quartz grain sand matrix; lower very fine to upper fine grain 43 CANRIG Joni Eni Petroleum OP 17-02 and OP 17-02-PB1 sand; poorly sorted; very well rounded to sub-rounded, with some sub-angular to well angular; moderate sphericity; little or no sample fluorescence above OBM was observed; shell fragments and pyrite crystals were observed throughout the sample. OA SAND TOP 12653.2' M D/3464.8'TVDSS Siltstone(12650-12705)= dark gray to medium dark gray; stiff to slightly firm; mostly irregular fracture; amorphous cuttings habit; greasy to somewhat waxy luster; silty to very gritty; sandy siltstone beds thickening, and interbedded with thin lenses of siliceous sandstone, and loose unconsolidated quartz sand; abundant shell fragments, with some pyrite crystals; no oil indicators above OBM. FAULT 17-02 PB1 -3 12724' M D/3464.5' TVDSS Sandstone/Sand (12710-12765) = clear to translucent,with white, dark gray, blackish red, very dusky red, and black; mostly quartz grain sand matrix; lower very fine grain to upper fine; fair to moderately sorted; sub-angular to very angular, with some very well rounded; moderate sphericity; little or no sample fluorescence above OBM; abundant shell fragments and pyrite crystals throughout the sample. Siltstone(12770-12830)=dark gray to medium dark gray; slightly firm; mostly crumbly to brittle; irregular to slightly blocky fracture; amorphous to planar cuttings habit; waxy to dull luster; predominantly silty with some very gritty texture; thinner beds of sandy siltstone, interbedded with loose uncemented quartz sand, and siliceous cemented sandstone; no sample fluorescence, other than the OBM; some pyrite crystals throughout the sample. Sandstone/Sand (12835-12880)=clear to translucent, with white, dark gray, blackish red, very dusky red, and black; predominantly quartz grain sand; lower very fine to upper fine; moderate to well sorted; very angular to sub-angular, with some sub-rounded to well rounded; moderate sphericity; no sample fluorescence above OBM; some shell fragments and pyrite crystals. Siltstone (12890-12950) = medium dark gray to dark gray; mostly stiff to firm; crumbly to brittle; irregular to slightly blocky fracture; amorphous to planar cuttings habit; very dull to waxy luster; predominantly silty with some very gritty texture;thinner beds of sandy siltstone, interbedded with loose uncemented quartz sand, and siliceous cemented sandstone; no sample fluorescence, other than the OBM; some pyrite crystals throughout the sample. OA SAND TOP 12941.0' MD/-3478.0' TVDSS Sandstone/Sand (12955-13025)= mostly clear to translucent, with white, light gray, dark gray, blackish rd, and black; predominantly quartz grain sand; lower very fine to upper fine; moderate to well sorted; very angular to sub-angular, with some sub-rounded to well rounded; moderate sphericity; very thin beds of siliceous sandstone and loose unconsolidated sand, interbedded with thicker beds of sandy siltstone; no oil indicators above OBM; some shell fragments, and lesser amounts of pyrite crystals. OA SUBLOBE 2 13032.0' MD/-3486.3'TVDSS Siltstone(13030-13095)= dark gray to medium dark gray; slightly firm; mostly brittle to crunchy; irregular to slightly blocky fracture; amorphous to blocky cuttings habit; waxy to dull luster; predominantly silty with some very gritty texture; thinner beds of sandy siltstone, interbedded with loose uncemented quartz sand, and siliceous cemented sandstone; no sample fluorescence, other than the OBM; some pyrite crystals, and shell fragments throughout the sample. Sandstone/Sand (13100-13185)= mostly clear to translucent, with milky white, light gray, dark gray, blackish red, dusky red, and black hues; mostly quartz grain sand matrix; lower very fine to upper fine, with some lower medium sand; moderate to poorly sorted; sub-angular to angular,with some rounded to sub-rounded; moderate sphericity; beds of siliceous sandstone, and loose uncemented sand getting thicker, and interbedded with thinning beds of sandy siltstone and silty shale; dull greenish yellow sample 44 CANRIG Ione Eel Petroleum OP 17-02 and OP 17-02-PB1 fluorescence, 40% -60%; no free oil was observed in the sample; some shell fragments and pyrite crystals throughout the sample. Siltstone(13190-13250)= medium dark gray to dark gray; slightly firm to stiff; crumbly to very brittle; irregular to slightly blocky fracture; amorphous to somewhat planar cuttings habit;waxy to dull luster; predominantly silty with some very gritty texture; thinner beds of sandy siltstone, interbedded with loose uncemented quartz sand. OA SUBLOBE 3 13225.5" MD/-3498.0' TVDSS Sand/Sandstone(13185-13360) = clear to light gray to translucent to milky white with green to red to black to brown hues throughout sample interval; sandstone is easily friable to friable with occasional firmly friable cuttings; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded; low to moderate sphericity; 10-15%fine grained black lithics giving salt and pepper appearance; 5-8% bluish green to moderate green to brilliant green fine grained lithics; moderate to slight oil odor; no visible oil staining on free sand grains. dark brown stain within sandstone cuttings when prodded open; 90-100% moderately bright to dull yellow to yellowish white sample fluorescence, some samples exhibited 10-20% dull patchy yellow fluorescence; slow blooming dull white cut fluorescence; dark straw visible cut; no visible residue; no residual fluorescence. Sand/Sandstone(13360-13480) =very light gray to clear to milky white to translucent to light gray quartz grains; black to brown to red to green hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular with moderate to low sphericity; sandstone cuttings are easily friable to firmly friable; 10-15%fine grained black lithics; 5-7% moderate green to brilliant green to light bluish green fine grained lithics; moderate to fragrant oil odor; no visible oil staining on free sand grains in samples; dark brown oil staining within sandstone cuttings when split in half; 100% bright to moderately bright white to yellowish white sample fluorescence; immediate very bright white cut fluorescence; very dark brown visible cut; heavy pale straw to straw visible residue; moderately bright yellowish white residue fluorescence. Sand/Sandstone(13480-13600) = clear to milky white to light gray to translucent to very light gray; black to green to reddish hues; upper very fine to upper fine to lower medium; very well to well sorting throughout sample interval; sub-angular to angular to sub-rounded with moderate sphericity; 5-8%fine grained black lithics; 3-4% brilliant green to moderate green to light bluish green fine grained lithics; slight to moderate oil odor; no visible oil stain on sand grains; dark brown oil staining within sandstone cuttings; 60-100% even dull yellowish white sample fluorescence throughout sample interval; slow blooming dull white cut fluorescence; dark straw to light amber visible cut; light straw visible residue; faint to dull yellowish white residual fluorescence. Sand/Sandstone(13600-13720) =clear to light gray to milky white to translucent with brownish, reddish, greenish hues throughout sample interval; sandstone is easily friable to firmly friable to moderately hard on occasion; upper very fine to upper fine to lower medium; very well sorted; sub-angular to angular with moderate to low sphericity; 10-15%fine grained black lithics giving a salt and pepper appearance; 5-8% bluish green to moderate green to brilliant green fine grained lithics; moderate to slight oil odor; no visible oil staining on free sand grains. dark brown oil stain within sandstone cuttings when split open; 100% moderately bright to dull yellow to yellowish white sample fluorescence, some samples exhibited 10-20% dull patchy yellow fluorescence; slow blooming dull white cut fluorescence; dark straw visible cut; light straw visible residue; dull yellow to yellowish white residue fluorescence. Sand/Sandstone(13720-13840) =very light gray to milky white to clear to translucent to light gray quartz grains; green to black to reddish hues throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular with moderate to low sphericity; sandstone cuttings are easily friable to firmly friable; 10-15%fine grained black lithics; 5-7% brilliant green to moderate green to light bluish green fine grained lithics; moderate to slight oil odor; no visible oil staining on free sand grains; dark brown oil staining within sandstone cuttings when broken open; 40-80%even dull yellowish white sample fluorescence in samples; slow streaming moderately bright white cut fluorescence; dark straw to light amber visible cut; medium dark straw visible residue; dull yellow to yellowish white residue fluorescence. 45 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 Sand/Sandstone(13840-13960)=clear to translucent to very light gray with black to gray to brown to green hues throughout sample interval; sandstone is easily friable to firmly friable; upper very fine to upper fine grain size; very well sorted; sub-angular to angular; poor to moderate sphericity; 10%fine grained black lithics; 5% moderate green to brilliant green to bluish green fine grained lithics; moderate orange pink to pale yellowish orange shell fragments throughout sample interval; slight to moderate oil odor above OBM; no visible oil staining on individual sand grains; dark brown oil staining within sandstone cuttings when broken open; 80-100%even moderately bright to dull yellow to yellowish white sample fluorescence; slow streaming bright white cut fluorescence; amber visible cut; medium straw visible residue; dull yellowish white residual fluorescence. Siltstone(13800-14000) =olive black to brownish black to dark gray to moderate yellowish brown; easily friable to moderately hard to friable; tough dense to brittle and crunchy tenacity; irregular fracture; nodular discoidal cuttings habit; vitreous greasy to waxy luster; silty gritty to clayey silty texture; no visible structures. Sand/Sandstone(13960-14110) =very light gray to clear to milky white to translucent to light gray quartz grains; black to brown to red to green hues throughout sample interval; upper very fine to upper fine to lower medium; very well sorted; sub-angular to angular to sub-rounded with moderate to low sphericity; pale yellowish orange to moderate orange pink shell fragments; 5-8%fine grained black lithics giving salt and pepper appearance; approx 5% brilliant green to moderate green fine grained lithics; slight to no oil odor; no visible oil staining on individual sand grains; dark brown oil staining within sandstone cuttings when broken open; 20-80%even dull yellow to yellowish white sample fluorescence; slow streaming dull white cut fluorescence; dark straw visible cut; light straw visible residue; dull yellow to yellowish white residue fluorescence. Sand/Sandstone(14110-14230) = light gray to translucent to milky white to clear quartz grains; reddish brown to black to greenish to grayish hues throughout sample interval; upper very fine to upper fine with medium grains scattered throughout this sample interval; well sorted; sub-angular to angular with moderate sphericity; approximately 10%fine grained black lithics; 3-5% brilliant green to bluish green to moderate green fine grained lithics; pale yellowish orange to moderate orange pink shell fragments occur occasionally throughout this sample interval; slight oil odor; no visible oil staining on individual sand grains; dark brown oil staining within sandstone cuttings when broken apart; 100%even bright to moderately bright yellowish white sample fluorescence; immediate bright white cut fluorescence; dark brown visible cut; Sand/Sandstone(14230-14290) =clear to milky white to light gray to translucent throughout sample interval; upper very fine to upper fine; very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; few medium to coarse grain sized crystals of pyrite in samples; approx 10%fine grained black lithics; 5-7% light bluish green to moderate green to brilliant green fine grained lithics. Siltstone(14305-14365)=dark gray to medium dark gray; slightly stiff to moderately firm; very crumbly to slightly brittle; irregular to very slightly planar fracture; mostly amorphous cuttings habit; greasy luster; some dull yellow green sample fluorescence, 15%-20%; delayed milky white solvent cut; thinner beds of sandy siltstone, interbedded with slightly siliceous cemented sandstone and loose uncemented quartz sand. OA SUBLOBE 3 14357.0' MD/-3492.4'TVDSS Sandstone/Sand (14370-14450) = clear to translucent, with white, light gray, pale green, pale blue, moderate yellowish brown; dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; very angular to sub-angular, with some sub-rounded; moderate sphericity; increasingly thicker beds of loose unconsolidated fine grain quartz sand, interbedded with siliceous cemented sandstone, and thin beds of sandy siltstones; bright yellow green sample fluorescence, 10%- 15%; no solvent cut was observed. Siltstone(14455-14510)= medium dark gray to dark gray with some medium gray; mostly stiff to somewhat firm; mostly crunchy to somewhat brittle; mostly irregular to slightly planar fracture; slightly 46 CANRIG 101 'eni Eni Petroleum OP 17-02 and OP 17-02-PB1 platy to mostly amorphous cuttings habit; waxy to somewhat greasy luster; very silty with some very gritty in places; no oil indicators above OBM; some shell fragments throughout sample. Sandstone/Sand (14515-14595) = mostly translucent to clear, with white, light gray, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; very sub-angular to very angular with sub-rounded; moderate sphericity; increasingly thicker beds of loose unconsolidated fine grain quartz sand, interbedded with siliceous cemented sandstone, and thin beds of sandy siltstone; no sample fluorescence above OBM was observed; some shell fragments throughout sample. OA SUBLOBE 2 14601.3' MD/-3480.3'TVDSS Siltstone(14600-14660)= dark gray to gray with some medium dark gray; slightly firm to mostly stiff; brittle; mostly irregular to slightly planar fracture; mostly amorphous to slightly planar cuttings habit; greasy to somewhat waxy luster; very silty with some really gritty in places; no oil indicators above OBM; some shell fragments throughout sample. Sandstone/Sand (14655-14730)=clear to translucent, with white, light gray, green, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; very sub-angular to very angular with sub-rounded; moderate sphericity; thicker beds of loose uncemented very fine grain quartz sand, interbedded with siliceous cemented sandstone, and very sandy siltstone; little or no sample fluorescence above OBM was observed; some shell fragments throughout sample. Siltstone(14710-14795) = gray to medium dark gray to dark gray; slightly firm to stiff; very crumbly to crunchy; predominantly irregular fracture with some slightly planar in places; mostly amorphous to slightly planar cuttings habit; very waxy to somewhat greasy luster; very silty with some mostly gritty in places; no oil indicators above OBM; some shell fragments throughout sample. Sandstone/Sand (14800-14875)= mainly translucent to clear, with light gray, green, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine,with some lower medium sand grains; moderate to poorly sorted; very sub-angular to very angular with sub-rounded; moderate sphericity; thicker beds of loose unconsolidated quartz sand, interbedded with very friable siliceous cemented sandstone, with very sandy siltstones; little or no sample fluorescence above OBM; some shell fragments throughout. Siltstone(14880-14925) = medium dark gray to dark gray; slightly firm to moderately stiff; mostly crumbly with some brittle in places; mainly irregular fracture; slightly platy to mostly amorphous cuttings habit; waxy to somewhat greasy luster; very silty with some mostly gritty in places; no oil indicators above OBM; some shell fragments throughout sample. Sandstone/Sand (14935-15015)= mostly translucent to clear, with white, light gray, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium sand; moderate to poorly sorted; mostly sub-angular to very angular with sub-rounded; moderate sphericity; thicker beds of loose uncemented quartz sand, interbedded with mostly friable, siliceous cemented sandstone, and very thin bedded sandy siltstones; no noticeable sample fluorescence, other than the OBM; some shell fragments throughout sample. Siltstone(15020-15095) = gray to dark gray, with some moderate dark gray; mostly stiff to somewhat firm; very crunchy to crumbly; predominantly irregular fracture, with some slightly planar; mostly amorphous cuttings habit with some platy in places; greasy to dull luster; mostly silty throughout with some gritty texture; thinner sandy siltstone beds interbedded with loose unconsolidated quartz sand, and very fine grained sandstones; little or no visible sample fluorescence above OBM; no other oil indicators were observed; some shell fragments were observed throughout the sample. Sandstone/Sand (15105-15190) = clear to translucent with some milky white, light gray, pale green, pale blue, yellowish brown; dusky red, and black hues; upper very fine to upper fine,with some lower medium grain sand; moderate to poorly sorted; very angular to sub-angular, with some sub-rounded; moderate sphericity; increasingly thicker beds of loose unconsolidated fine grain quartz sand, and very friable fine 47 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 grained sandstone; bright yellow green sample fluorescence 30% -50%; instant milky white solvent cut; no free oil was observed in the sample; some shell fragments throughout the sample. Siltstone(15195-15260) = medium dark gray to gray; mostly firm to stiff; very crunchy to crumbly; predominantly irregular fracture with some slightly planar in places; mostly amorphous to slightly planar cuttings habit; very waxy to somewhat greasy luster; very silty with some slightly gritty in places; dull yellow green sample fluorescence; instant milky white solvent cut; no free oil was observed in the sample; shell fragments throughout sample. Sandstone/Sand (15265-15350) = mostly clear to translucent,with white, light gray, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium sand grains; moderate to poorly sorted; mostly sub-angular to very angular with sub- rounded; moderate sphericity; thicker beds of friable siliceous sandstone, and loose quartz sand, interbedded with sandy siltstones; right yellow green sample fluorescence; instant milky white to straw solvent cut; no free oil was observed in the sample; shell fragments throughout the sample. Siltstone(15355-15425)=gray to medium dark gray and dark blackish gray; mostly stiff to slightly firm in places; very crumbly to crunchy with some slightly brittle; predominantly irregular to somewhat planar fracture; amorphous to platy cuttings habit; waxy to dull; mostly silty texture with some very gritty; interbedded with thick beds of loose uncemented quartz sand, and very friable fine grained sandstone; bright yellow green sample fluorescence; instant straw to milky white solvent cut; no free oil was observed; some shell fragments. Sandstone/Sand (15435-15525) = mostly translucent to clear, with light gray, pale green, pale blue, moderate yellowish brown; dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; very angular to sub-angular, with some sub-rounded; moderate sphericity; increasingly thicker beds of friable siliceous cemented sandstone, and loose unconsolidated quartz sand, interbedded with thinner beds of sandy siltstone; bright yellow green sample fluorescence; instant milky white or straw solvent cut; no free oil was observed in the sample; some shell fragments throughout the sample. Siltstone(15530-15580) =dark gray to medium gray with some medium dark gray; mostly stiff to firm; crumbly to brittle; predominantly irregular fracture; amorphous to slightly platy cuttings habit; dull to waxy; very silty throughout grading to very gritty; bright yellow green sample fluorescence; instant straw to milky white solvent cut; no free oil was observed in the sample. FAULT 17-02 PB1 -4 15585.0' MD/-3467.8' TVDSS Sand/Sandstone(15600-15670) = clear to translucent to light gray; pale green to brown to reddish brown to medium gray to light blue hues throughout sample interval; upper very fine to upper fine; well sorted; angular to sub-angular with low to moderate sphericity; small sheet fragments of muscovite visible; approx 5%fine grained black lithics; moderate to slight oil odor; no visible oil stain on individual sand grains; dark brown oil staining within sandstone cuttings when broken open; fast blooming bright white cut fluorescence; amber to dark amber visible cut; light amber to amber visible residue; moderately bright yellowish white residual fluorescence. Siltstone (15650-15800) =olive black to dark gray to brownish gray; friable to moderately hard to easily friable; crumbly to crunchy to tough tenacity; regular fracture; amorphous to occasionally sub-nodular and platy;waxy to vitreous dull luster; silty clayey to slightly gritty texture; no visible structures. OA SUBLOBE 3 15720.0' MD/-3471.7'TVDSS Sand/Sandstone(15670-15850) =clear to milky white to translucent to light gray with reddish brown to light green to light blue to blackish hues throughout sample interval; upper very fine to upper fine with occasional medium sized grains; angular to sub-angular with low to moderate sphericity; some pyrite noticed at 15700'; 5-8%fine grained black lithics giving salt and pepper appearance; 5% light bluish green to brilliant green to moderate green fine grained lithics; occasional moderate orange pink to pale yellowish orange shell fragments; sandstone is soft to firmly friable with some moderately hard cuttings; sandstone is calcareously cemented and effervesced moderately when placed in HCI; slight oil odor; no visible oil 48 CANRIG ...._.....__.._.._.__. ....... 001 coi Eni Petroleum OP 17-02 and OP 17-02-PB1 staining on individual sand grains; dark brown oil staining within sandstone cuttings; very slow streaming moderately bright white cut fluorescence; dark straw visible cut; no visible residue; no residual fluorescence. Siltstone(15800-16000) = brownish black to olive gray to olive black to dark gray with yellowish brown to medium gray hues throughout sample interval; easily friable to moderately hard to firmly friable; crumbly to crunchy to tough and dense; irregular to occasional sub-planar fracture; amorphous to sub- nodular cuttings habit; dull waxy to vitreous and greasy luster; silty to gritty texture depending on sand grain content; frequently grading between silty sandstone and sandy siltstone; no real oil indicators above OBM. Sand/Sandstone(15850-16060) = clear to light gray to translucent to milky white with light green to light bluish to dusky reddish hues; upper very fine to upper fine with occasional medium sized grains; rare coarse to very coarse sized dusky yellowish brown chert grains; well sorted unconsolidated sand grains; angular to sub-angular with low to moderate sphericity; sandstone cuttings are friable to moderately hard and calcareously cemented; moderate to moderately strong oil odor; no visible oil staining on individual sand grains; light brown oil staining within sandstone cuttings when broken open; 80-100% even moderately bright yellow to yellowish white sample fluorescence; slow streaming dull white cut fluorescence; dark straw visible cut; no visible residue; faint yellowish white residue fluorescence. Sand/Sandstone(16080-16210) = light gray to clear to milky white to translucent with light greenish to dusky reddish to light bluish hues; upper very fine to upper fine;well to very well sorted; sub-angular to angular with moderate to low sphericity; 5-8%fine grained black lithics; 5% light bluish green to brilliant green to moderate green fine grained lithics; pale yellowish orange to moderate orange pink shell fragments throughout sample interval; slight oil odor; no visible oil staining; 100%even moderately bright to dull yellowish white sample fluorescence; immediate dull white cut fluorescence; dark straw visible cut; no visible residue; faint yellow residual fluorescence. Siltstone(16150-16250)= brownish gray to olive black to medium gray to dark gray with yellowish brown hues; easily friable to firmly friable with few moderately hard cuttings; crumbly to crunchy and brittle tenacity; irregular fracture; amorphous to sub-nodular cuttings habit; dull waxy to vitreous luster; silty clayey to silty gritty texture corresponding to grading between silty sandstone and sandy siltstone and siltstone. Sand/Sandstone(16210-16330)=very light gray to clear to translucent to milky white; upper very fine to upper fine with occasional medium sized grains throughout sample interval; well sorted; angular to sub- angular with low to moderate sphericity; moderate orange pink to pale yellowish orange shell fragments; 5- 8%fine grained black lithics; 5% light bluish green to brilliant green to moderate green fine grained lithics; slight oil odor; no visible oil staining on individual sand grains; 70-100% even moderately bright to dull yellow to yellowish white sample fluorescence; slow streaming dull white cut fluorescence; dark straw visible cut. OA SUBLOBE 416394.0' MD/-3479.3'TVDSS Siltstone(16355-16430) = medium gray to medium light gray, with some dark gray; mostly stiff to somewhat firm; very crunchy to crumbly; predominantly irregular fracture, with some slightly planar; mostly amorphous cuttings habit with some platy in places; greasy to dull luster; mostly silty throughout with some gritty texture; thinner sandy siltstone beds interbedded with loose unconsolidated quartz sand, and friable siliceous cemented sandstone; bright yellow green sample fluorescence, 30%-50%; instant milky white solvent cut; some shell fragments throughout the sample. Sandstone/Sand (16440-16525)= mostly translucent to clear, with white, gray, green, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; mostly sub-angular to very angular with sub- rounded; moderate sphericity; thicker beds of loose uncemented quartz sand, interbedded with friable siliceous cemented sandstone, and sandy siltstones; bright yellow green sample fluorescence,40%- 49 CANRIG ,cni Eni Petroleum OP 17-02 and OP 17-02-PB1 50%; instant milky white solvent cut; no free oil was observed in the sample; some shell fragment throughout. OA SUBLOBE 4 16614.0' MD/-3470.6' TVDSS Siltstone(16530-16610) = medium dark gray to gray with some dark gray; mostly stiff to somewhat firm; very crunchy to crumbly; predominantly irregular fracture,with some slightly planar; mostly amorphous cuttings habit with some platy in places; greasy to dull luster; mostly silty throughout with some gritty texture; thinner sandy siltstone beds interbedded with friable siliceous sandstone, and loose uncemented quartz sand; 40%-50% bright yellow green sample fluorescence; instant milky white solvent cut; lesser amounts of shell fragments in sample. Sandstone/Sand (16615-16690) =clear to translucent, with some white, light gray, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium size grains; moderate to poorly sorted; angular to sub-angular, with sub-rounded to well rounded sand grains; moderate sphericity; thicker beds of friable siliceous sandstone, and loose quartz sand, interbedded with thinner beds of sandy siltstone; bright yellow green sample fluorescence 40%-50%; instant milky white solvent cut; no free oil in sample. Siltstone(16700-16775)=dark gray to gray with some very dark gray; mostly stiff to slightly firm; predominantly crunchy to crumbly to brittle; irregular to slightly planar fracture; mostly amorphous cuttings habit with some slightly platy in places; greasy to waxy luster; mostly silty texture with some very gritty; thinner beds of sandy siltstone, interbedded with loose unconsolidated quartz sand, and very friable sandstone; bright yellow green sample fluorescence; instant milky white solvent cut; no free oil was observed in the sample. Sandstone/Sand (16780-16860) = mostly translucent to clear, with light gray, green, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium sand grains; moderate to poorly sorted; very sub-angular to very angular with sub-rounded; moderate sphericity; thicker beds of loose uncemented quartz sand, and very friable siliceous cemented sandstone, interbedded with very thin beds of sandy siltstones; bright yellow green sample fluorescence 40%-50%; instant milky white solvent cut; no free oil was observed in the sample. OA SUBLOBE 3 16899.0' MD/-3448.7'TVDSS Siltstone(16870-16945) =gray to dark gray with some medium dark gray; mostly stiff to slightly firm; crunchy to brittle with some crumbly; irregular to slightly planar fracture; mostly amorphous cuttings habit with some slightly platy;waxy to somewhat dull luster; mostly very silty grading to very gritty throughout; thicker beds of sandy siltstones, interbedded with very thick lenses of unconsolidated quartz sand, and friable siliceous cemented sandstone; dull yellow green sample fluorescence; instantaneous milky white solvent cut; no free oil was observed in the sample. Sandstone/Sand (16955-17035)=clear to translucent with white, light gray, green, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium sized sand; moderate to poorly sorted; mostly angular to sub-angular,with rounded to sub- rounded; moderate sphericity; thicker beds of loose uncemented quartz sand, interbedded with friable siliceous cemented sandstone, and sandy siltstones; bright yellow sample fluorescence, 60% -70%; instant milky white to straw colored solvent cut; some shell fragments. OA SUBLOBE 2 17020.1' MD/-3438.2'TVDSS FAULT 17-02 PB1 —AA MINOR 17094.0' M D/-3433.9'TVDSS Siltstone(17040-17120)= light brownish gray to brownish gray with some gray and dark gray; mostly firm to stiff; crunchy to crumbly with some brittle; irregular fracture with some slightly planar; amorphous 50 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 cuttings habit; very waxy to somewhat dull luster; mostly silty texture grading to slightly gritty; thinning beds of sandy siltstone interbedded with thicker lenses of loose quartz sand, and siliceous cemented sandstone; bright yellow green sample fluorescence, 70%-80%; instantaneous milky white solvent cut; some shell fragments throughout the sample. OA SAND TOP 17181.0' MD/-3431.7'TVDSS Sandstone/Sand (17125-17205)= mostly translucent to clear, with light gray, green, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium sized grains; moderate to poorly sorted; very sub-angular to very angular with sub-rounded; moderate sphericity; thicker beds of loose uncemented quartz sand, and very friable siliceous cemented sandstone, interbedded with increasingly thicker beds of sandy siltstone; bright yellow green sample fluorescence, 80%-90%; instant milky white solvent cut; some shell fragments. Siltstone(17210-17270) = dark gray to gray with some very dark gray; mostly stiff to slightly firm; predominantly crunchy to crumbly to brittle; irregular to slightly planar fracture; mostly amorphous cuttings habit with some slightly platy in places; greasy to dull luster; very silty with some grading up to gritty; thickening beds of sandy siltstones, interbedded with very friable siliceous cemented sandstone, and loose quartz sand; bright yellow green sample fluorescence. OA SAND TOP 17289.0' MD/-3432.7'TVDSS Sand/Sandstone(17230-17350) = light gray to clear to milky white to translucent; upper very fine to upper fine;well sorted; angular to sub-angular with low to moderate sphericity; sandstone cuttings are easily friable to firmly friable; sandstone cuttings are calcareously cemented; medium to coarse grain sized crystals of pyrite rarely noticed; slight to moderate oil odor; no visible oil staining; very dull to moderately bright yellowish white sample fluorescence, intensity increased with depth; immediate moderately bright white cut fluorescence; dark amber visible cut; amber visible residue; moderately bright white residual fluorescence. Sand/Sandstone(17350-15500) = clear to light gray to translucent to milky white with dusky reddish to light greenish to dusky yellowish hues throughout sample interval; predominantly upper very fine to lower fine with occasional upper fine to medium sized grains; very well sorted in this interval; sub-angular to angular with moderate sphericity; fine to coarse grain sized pyrite scattered throughout this sample interval, <1%; 8-10%fine grained black lithics; approximately 5% light bluish green to brilliant green to moderate green fine grained lithics; pale yellowish orange to moderate orange pink shell fragments throughout this sample interval; sandstone cuttings are calcareously cemented; slight oil odor; no visible oil staining on individual sand grains; light brown oil staining within sandstone cuttings; 80-100% even moderately bright to dull white to yellowish white sample fluorescence; immediate bright white cut fluorescence; amber to dark amber visible cut; light pale straw visible residue; faint yellowish white residual fluorescence. OA SAND TOP 17479.0' MD/-3436.7'TVDSS Siltstone(17500-17650)= olive black to brownish gray to brownish black to dark gray with brownish to yellowish brown to grayish hues; friable to easily friable to firmly friable; predominantly crumbly to crunchy to brittle; irregular fracture; amorphous to sub-tabular to sub-nodular cuttings habit; dull waxy to greasy vitreous luster; silty to gritty texture varying with sand/silt ratio; no visible structures; no oil odor; no visible oil staining; no sample fluorescence; no other oil indicators. Sand/Sandstone(17500-17670) = light gray to clear to milky white to translucent; upper very fine to upper fine;well sorted; angular to sub-angular with low to moderate sphericity; sandstone cuttings are easily friable to firmly friable; sandstone cuttings are calcareously cemented; moderate orange pink to pale yellowish orange shell fragments throughout sample interval; 5% light green to bluish green to moderate green fine grained lithics; 5-10%fine grained black lithics; no oil odor; no visible oil staining; faint to no sample fluorescence. 51 CANRIG X91, cni Eni Petroleum OP 17-02 and OP 17-02-PB1 OA SAND TOP 17671.0' MD/-3444.5'TVDSS Sand/Sandstone(17670-17800)=very light gray to clear to translucent to light gray with light greenish to brownish hues; upper very fine to upper fine with occasional medium sized grains throughout sample interval; well to very well sorted; sub-angular to angular to sub-rounded with moderate sphericity; pale yellowish orange to moderate orange pink shell fragments; 10%fine to medium grained black lithics; 5% light bluish green to brilliant green fine grained lithics; moderate oil odor; no visible oil staining on individual sand grains;100% even moderately bright white to yellowish white sample fluorescence; fast blooming bright white cut fluorescence; light pale straw visible residue; faint yellow to yellowish white residue fluorescence. OA SUBLOBE 2 17762.0' MD/-3453.0'TVDSS Siltstone(17740-17850)=olive gray to brownish black to dark gray to medium gray; easily friable to firmly friable; predominantly crumbly tenacity to occasionally slightly crunchy and brittle; irregular fracture; amorphous cuttings habit; dull waxy to vitreous greasy luster; texture varies between silty and gritty depending on quartz sand grain content; no visible structures; no oil odor; no sample fluorescence; no other oil indicators. OA SUBLOBE 3 17859.0' MD/-3460.3'TVDSS Sand/Sandstone(17800-17950) =very light gray to clear to milky white to translucent with light greenish and dusky yellowish and light bluish hues; upper very fine to upper fine with some medium sized grains throughout sample interval;well to very well sorted; sub-angular to angular to sub- rounded with moderate to low sphericity; sandstone is easily friable to firmly friable and is calcareously cemented; 5% light bluish green to moderate green fine grained lithics; 10%fine grained black lithics; pale yellowish orange to moderate orange pink shell fragments; slight oil odor; no visible oil staining on free sand grains; 80-100% even moderately bright yellowish white sample fluorescence; slow streaming dull white cut fluorescence; amber to light amber visible cut. FAULT 17-02 PB1 -5 17909.0' M D/3463.7' TVDSS Siltstone (17965-18040) = dark gray to gray with some medium dark gray; mostly firm to slightly stiff; crumbly to very brittle; mainly irregular fracture with some slightly blocky; amorphous to slightly planar cuttings habit; waxy to somewhat dull luster; mostly silty texture grading up to somewhat gritty; increasingly thicker beds of sandy siltstone, interbedded with thinner lenses of loose quartz sand, and cemented sandstone; very little or no sample fluorescence above OBM; no solvent cut; some shell fragments throughout sample. Sand/Sandstone(18045-18130)= mostly clear to translucent, with light gray, white, dark gray, pale green, pale blue, yellowish brown, dusky red, and black hues; upper very fine to upper fine,with some lower medium grain sand; moderate to poorly sorted; mostly angular to very sub-angular with sub- rounded; moderate sphericity; very thin beds of loose uncemented quartz sand, interbedded with friable siliceous cemented sandstone, and sandy siltstones; no sample fluorescence above OBM was observed; no solvent cut; no free oil was observed in the sample; some shell fragments throughout the sample. Siltstone (18135-18195) = dark gray to light gray with some medium light gray; mostly firm to stiff; brittle to crumbly; irregular to slightly blocky fracture; amorphous to somewhat platy fracture; very greasy to slightly waxy luster; very thick beds of sandy siltstones, interbedded with thin beds of very fine grained quartz sandstones and sands; no sample fluorescence above OBM; no solvent cut; some shell fragments throughout the sample. 52 CANRIG eni Eel Petroleum OP 17-02 and OP 17-02-PB1 Sandstone/Sand (18200-18280) = mostly translucent with some milky white, light gray, pale green, pale blue, yellowish brown; dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; very angular to sub-angular,with some sub-rounded to rounded; low sphericity; very thinner beds of loose uncemented predominantly fine grain quartz sand, and very friable fine grained sandstone; little or no sample fluorescence, above OBM; no solvent cut; no free oil was observed in the sample; some shell fragments were observed throughout the sample. BASE OF OA 18310.5' MD/-3450.3 TVDSS Siltstone (18290-18350) = medium dark gray to gray; mostly stiff to slightly firm; very crunchy to crumbly; predominantly irregular fracture with some slightly planar in places; mostly amorphous to slightly planar cuttings habit; mostly waxy to somewhat greasy luster; very silty with some slightly gritty in places; no sample fluorescence above OBM; no solvent cut; no free oil was observed in the sample; shell fragments throughout sample. OA SUBLOBE 4 18358.0' MD/-3444.0' TVDSS Sand/Sandstone(18360-18430)=clear to translucent with light gray, white, gray, pale blue, pale green, moderate yellowish brown, dusky red, and black hues; upper very fine to upper fine, with some lower medium sand; moderate to poorly sorted; mostly sub-rounded to very rounded with sub-angular; moderate sphericity; very thin beds of friable siliceous sandstone, and loose quartz sand, interbedded with thicker beds of sandy siltstone; no sample fluorescence above OBM; no solvent cut; some shell fragments throughout sample. Siltstone(18440-18505)= dark gray to medium dark gray with some grayish black; mostly stiff to slightly firm; brittle to crumbly and crunchy; irregular to slightly blocky fracture; amorphous to slightly platy fracture; very greasy to slightly waxy luster; very thick beds of sandy siltstones, interbedded with thin beds of very fine grained quartz sandstones and sands; no sample fluorescence above OBM; no solvent cut; some shell fragments throughout the sample. OA SUBLOBE 3 18508.0' MD/-3430.9'TVDSS Sandstone/Sand (18510-18570) = mostly translucent with some clear, white, light gray, pale green, pale blue, yellowish brown; dusky red, and black hues; upper very fine to upper fine, with some lower medium grain sand; moderate to poorly sorted; very angular to sub-angular, with some very rounded to sub- rounded; poor to moderate sphericity; little or no sample fluorescence above OBM; no solvent cut; some shell fragments throughout the sample. Siltstone(18580-18650)= blackish gray to dark gray to medium dark gray; mostly firm to somewhat stiff; brittle to crumbly; mostly irregular fracture with some slightly planar; amorphous to platy cuttings habit; greasy to dull; mostly silty grading to gritty; thinner sandy siltstone beds interbedded with thicker siliceous cemented sandstone, and loose quartz sand; no sample fluorescence above OBM was observed; no free oil in the sample; some shell fragments were observed throughout the sample. Sandstone/Sand (18655-18740) = clear to translucent,with light gray, milky white, light pale green, pale blue, yellowish brown; dusky red, and black hues; upper very fine to upper fine, with some lower fine sand grains; moderate to poorly sorted; well rounded to sub-rounded with sub-angular to very angular; moderate to low sphericity; thicker beds of friable siliceous cemented sandstone with loose quartz sand, interbedded with thinning beds of sandy siltstones; little or bright yellow green sample fluorescence, 40% -60%; very slow to no solvent cut; no free oil was observed in the sample; shell fragments throughout the sample. OA SUBLOBE 3 18720.0' MD/-3431.8'TVDSS 53 CANRIG ni En! Petroleum OP 17-02 and OP 17-02-PB1 Siltstone(18750-18310)= medium dark gray to gray; mostly stiff to slightly firm; very crunchy to crumbly; predominantly irregular fracture with some slightly planar in places; mostly amorphous to slightly planar cuttings habit; mostly waxy to somewhat greasy luster; very silty with some slightly gritty in places; bright yellow green sample fluorescence; no solvent cut; shell fragments throughout the sample. Sand/Sandstone(18800-18940)= light gray to clear to milky white to medium gray with light greenish to light bluish to reddish hues throughout sample interval; predominantly upper very fine to lower fine with some upper fine to medium sized grains;well to very well sorted; angular to sub-angular with moderate sphericity; sandstone cuttings are easily friable to firmly friable; sandstone is calcareously cemented; fine to medium grain sized pyrite in samples; 8-10%very fine to fine grained black lithics; 10-13% light bluish green to moderate green fine grained lithics; pale yellowish orange to moderate orange pink shell fragments; slight oil odor; no visible oil stain; 100% even moderate bright sample fluorescence; immediate dull white cut fluorescence; light brown cut. 54 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 3.4 Connection Gas Summary 1 Unit=0.05% Methane Equivalent Depth (ft) Background Units C-1 C-2 C-3 C-4 C-5 Gas Above MD TVDSS (Units) Background (ppm) (ppm) (ppm) (ppm) (ppm) 11225 275 90 11330 150 292 11431 200 85 11545 200 50 3.5 Trip/Wiper Gas Summary OP 17-02 Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVDSS MD TVDSS (units) (hours) 2265 Surf - 26 43 Run 13 7/8" Casing 5355 -2107.2 Surf - 55 19 Trip for NB3 8520 Surf - 123 36 Run 9 5/8" Casing OP 17-02-PB1 1 Unit=0.05% Methane Equivalent Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVDSS MD TVDSS (units) (hours) 2265 Surf - 26 43 Run 13 7/8"Casing 5355 -2107.2 Surf - 55 19 Trip for NB3 8520 Surf - 123 36 Run 9 5/8" Casing 55 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 3.6 Sampling Program and Sample Dispatch Sample Program Dry samples: (2 sets) Every 30'from 1000'to TD(18,200' MD). No Wet Samples Sample Dispatch OP17-02 Set Processed As Frequency* Interval* Dispatched to Washed, spin dried, stored Fugro Data Solutions In sample vials. A Reference Samples. 30' 9460'to 18200' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, spin dried, stored AOGCC B In sample vials. 30' 9460'to 18200' 333 W. 7TH Ave., Suite 100 Reference Samples. Anchorage, AK 99501 Set Owner: State of Alaska Iso-Tubes Weatherford Laboratories C Gas Samples 500' 9460'to 18200' 8845 Fallbrook Drive Owner: ENI Houston, TX 77064 Sample frequency and interval may be altered locally according to on-site geologist. 56 CANRIG ,gym Eni Petroleum OP 17-02 and OP 17-02-PB1 Sample Dispatch OP17-02-PB1 Set Processed As Fre�c uency* Interval* Dispatched to Washed, dried, stored In envelopes. Fugro Data Solutions A Reference Samples. 30' 1000'to 8520' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, dried, stored AOGCC B In envelopes. 30' 1000'to 8520' 333 W. 7TH Ave., Suite 100 Reference Samples. Anchorage, AK 99501 Set Owner: State of Alaska Washed, spin dried, stored Fugro Data Solutions In sample vials. Reference Samples. 30' 8520'to 18940' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, spin dried, stored AOGCC In sample vials. D Reference Samples. 30' 8520'to 18940' 333 W. 7THAve., Suite 100 Set Owner: State of Alaska Anchorage, AK 99501 Iso-Tubes Weatherford Laboratories F Gas Samples 500' 6909'— 18940' 8845 Fallbrook Drive Owner: ENI Houston, TX 77064 Sample frequency and interval may be altered locally according to on-site geologist. 57 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 4 PRESSURE AND FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Top Of Interval Pore Pressure Trend Indicators Lithology (%) Lithology(%) u (EMW, ppq) MD TVDS Min Max Trend S Permafrost Sd/Cgl 60% Sltst/Clyst 40% 8.8 9.2 Up(SL) BG,CG, MW, ECD Ugnu Sd/Cgl 60% Clyst/Sltst/Sh 2076 1965 8.8 9.2 Up(SL) BG,CG,TG, MW 40/° Schrader Bluff Sd/Sltst 80% Sltst 20% 6550.5 -3496 8.4 9.3 Even BG, CG, TG, MW 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW)and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas(CG), lost circulation(LC),and magnitudes of trip gas(TG)and wiper gas(WG). Regional pore pressure trends from sonic data,provided by client,and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU)+(0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping establish a PPG range,when establishing trends, as with DXC data, with data points in shale intervals. 58 CANRIG leni Eel Petroleum OP 17-02 and OP 17-02-PB1 5 DRILLING DATA 5.1 Daily Activity Summary 10/29/2010 Work on CD unit and plumbing for CD unit. Calibrate block height, fill hole and slip and cut drill line as of midnight. 10/30/2010 Pick up 5" HWDP and stand back in derrick. Pick up BHA for cleaning out the conductor and rat hole for drilling BHA. Pick up drilling BHA and drill from 160'to 747'as of midnight. 10/31/2010 Continue drilling ahead from 747'to 2240'MD with no issues. High gas for the day was 170u. 11/01/2010 Continue drilling ahead from 2240'to TD at 2265'md. Circulate 3+ bottoms up. Backream from 2265'to 630'with no tight spots. Circulate until shakers clean. Trip in hole on elevators to 2265'. Circulate and condition hole. Pull out of hole and lay down BHA. Rig up and run 13 3/8"casing.Verify landing at depth of 2249'. Rigging up for cement as of midnight. 11/02/2010 Rig up cementers. Perform cement job. Test lines to 3000 psi and drop plug. Clean all pits. Nipple down riser and nipple up BOP. Start making up pipe as of midnight. 11/3/2010 Pick up drill pipe and install CD valves on stand 38-92. Test choke manifold. Test CD manifold. Pick up test tools and install wear ring. Make up test joint and set test plug. 11/4/2010 Test BOPs. Remove and install wear ring. Lay down test tools and equipment. Pick up BHA#3. Trip in hole to 2145'and tag cement. Circulate and test casing to 2500psi for 30 minutes. Drill out cement, plugs, float, and new hole to 2284'. Circulate and condition mud to 9.2ppg. Perform FIT test to 12ppg EMW. Displace to new 8.8ppg LSND mud. Clean pit 7, shakers, and possum belly. 11/5/2010 Continue drilling ahead from 2379'to current depth as of midnight without any issues. Checking flow every connection. High gas for the day was 125u. 11/6/2010 Continued drilling from 4410'to 5330'with no issues. From 5330'to 5355', drilling was hard and ROP dropped off. Circulated 1.5 bottoms up then decision was made to pull out of hole for bit. 11/7/2010 Lay down BHA. Monitor the well. Pick up and make up the new BHA. Clear derrick of ice. Run in hole to bottom. Drill on hard spot at 5355'to 5380'. Continue drilling from 5380'to 5800'md with no issues. 11/8/2010 Drilling ahead from 5800'-7290' MD with no issues/no losses to formation. 11/9/2010 Drilled ahead to 8520' MD with no losses and no issues. Circulating 5X BU @ TD. 59 CANRIG , ni Eni Petroleum OP 17-02 and OP 17-02-PB1 11/10/2010 Circulate and condition 5X BU. Backream from 8051-shoe @ 2249'. Circulate and condition 2.5X BU @900 gpm. 1300 psi. POOH on elevators. LD BHA. 11/11/2010 LD BHA. PU test tools. Test BOPS's. 10.74" rams failed. Installed new rubbers and retest 250/3500 for 5 mins ea. LD test tools. RU to run casing. Run 9.625"casing as per running order to shoe. Circulate 5X BU @5 bpm/150 psi. 11/12/2010 Run casing break circulation every 200'. LD Franks tool and MU cement head. Test lines to 3000 psi. Pump 70 BBLs/10.5 ppg mud push. Drop plug. Pump 300 BBLs 12.5 ppg cement. Drop plug and displace with rig pumps @ 330 gpm/650 psi. Bumped plug at 6150 stx. RD cement and CSG equip. Set and test Pack Off to 5000 psi. Freeze protect 150 BBLs @ 2 BBLs/min 1350 psi. 11/13/2010 Change top RAM's to 7". Test BOP's to 3500 psi for 5 min. Good. Install wear ring. L/D drill pipe sucking each joint out before laying down. Pick up D/P. 11/14/2010 Cut&Slip drilling line. Service Top Drive, draw works, crown. BOP testing. P/U drill pipe. 11/15/2010 P/U DP singles and stand back. Draw works Elmago brake broke down. Waiting on replacement from Deadhorse to arrive. 11/16/2010 Continue replacing/repairing Elmago brake. 11/17/2010 Finish testing Elmago brake. Calibrate Blocks. P/U and M/U BHA, RIH. Test MWD tools. Pressure test casing. Waiting on weather conditions; currently Phase III. 11/18/2010 Displace to OBM. Drill out cement to 8550'. Prepare for and conduct LOT. LOT performed to 12.8 ppg. Service Top Drive. RIH and Drill ahead. 11/19/2010 Continue drilling ahead from 9080 to 11420. 11/20/2010 Drilled ahead from 11420'to 13824'. Re-Calibrated gas detection equipment. 11/21/2010 Drilling Ahead from 13824. Issues with pump pressure, cleaned suction screens to pumps @ 14138'. 11/22/2010 Drill ahead from 15910'. Work on cable for survey tools @ 17664'. Resume drilling. 11/23/2010 Drill ahead to TD of 18940', Circulate and condition mud. 11/24/2010 60 CANRIG eni Eni Petroleum OP 17-02 and OP 17-02-PB1 Circulate 7x bottoms up to clean hole. Weight up mud to 8.7 to stop flow. Back-reaming to 15760'as of midnight. 11/25/2010 Continue back-reaming out of hole to intermediate casing shoe. Tight spots @ 13215, 12835, and 12780- 12650. 11/26/2010 Continued back-reaming out of hole to casing shoe @ 8500'. RIH and hit hard spot @ 11180'. Tried to pump and rotate through, orient directional tools high side per DD. Didn't work. Drill ahead from 11175'to 11269'trying to get back to old hole. Didn't work. Resume back-reaming out of hole. 11/27/2010 Continue to POOH, laying down bad joints. 11/28/2010 L/D BHA. Rig up for BOP tests. Blind RAMs failed. Replace rubbers on blind RAMs and reinstall. BOP test OK. Work on Saver Sub and Wash Pipe on Top Drive. 11/29/2010 LD bad 5"joints. Change out swivel packing. Trip in hole and POOH LD DP removing CD valves. 11/30/2010 P/U and L/D DP flagging bad joints. Install CD subs. 12/01/2010 PU 51 joints of 5" DP. Test BOP's. PU 4.5" DP. 12/02/2010 Finish picking up 4.5" DP. Circulate and condition mud up to 9.2ppg as per mud engineer. POOH. Make up BHA and run in hole. Cut and slip drill line. Calibrate blocks. 12/03/2010 Service Top Drive. RIH on elevators to 9448'. Attempt open hole sidetrack beginning @ 9475'. POOH to shoe to fix Top Drive. 12/04/2010 Repair Top Drive. Replace encoder. Remove wash pipe and bounce bearing, then replace. Trip in hole and drill ahead. 12/05/2010 Change out bad sub. Changed out SLB sensor. Drilling ahead. 12/06/2010 Drilling ahead. Problem with Top Drive. Fix and resume drilling. 12/07/2010 Drill from 14631'to 16893'. 12/08/2010 Drill ahead from 16893'to TD of 18200' MD. 12/09/2010 Circulate and condition mud; 8x BU. Pull 1 stand every BU. Backream to shoe. 12/10/2010 61 CANRIG Eni Petroleum OP 17-02 and OP 17-02-PB1 Continue back-reaming out of hole. Tight spot encountered @ 10983'. RIH to 11318'and CBU 3x. Continue back-reaming to shoe. Cut and slip. Bring on 9.4ppg mud. 12/11/2010 Cut new mud weight to 9.2ppg from 9.4ppg and then displace. POOH on elevators. LD BHA. Test BOP's 12/12/2010 Finish BOP testing. R/U to run liner. RIH with liner, currently at 5500' 12/13/2010 RIH with liner. Currently TIH with 5" DP. Tight spot encountered @ 13280'. 12/14/2010 Continue RIH tubing. Drop and pump ball to set hanger. Didn't work. Pump 20bbl sweep to get ball to bottom. Didn't work. Drop wiper ball to try to get ball to set. 12/15/2010 Finished setting hangar. POOH and lay down 5" DP. 12/16/2010 Finish L/D 5" DP. Remove wear ring. R/U for tubing. Work on pump assembly. 12/172010 Begin monitoring production procedures/running into hole with tubing and production assembly. 62 CANRIG ,Ii Eni Petroleum OP 17-02 and OP 17-02-PB1 5.2 Survey Data OP 17-02 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 N/A 106.88 0.21 288.41 106.88 0.19 0.06 -0.19 0.20 166.20 1.03 166.13 166.20 -0.10 -0.42 -0.16 1.95 202.31 1.92 164.29 202.29 -0.80 -1.32 0.08 2.47 292.96 3.10 169.37 292.86 -3.66 -5.19 0.94 1.32 359.78 3.88 162.70 359.55 -6.67 -9.12 1.95 1.31 450.25 3.81 167.80 449.82 -11.20 -14.98 3.49 0.39 543.00 4.22 188.83 542.35 -14.84 -21.37 3.62 1.64 635.20 5.61 212.12 634.21 -16.37 -28.54 0.70 2.61 732.25 6.73 230.05 730.71 -14.88 -36.21 -6.18 2.28 827.38 7.39 236.67 825.12 -10.90 -43.15 -15.56 1.10 922.45 9.40 255.43 919.18 -3.32 -48.46 -28.19 3.55 1019.07 10.49 263.36 1014.35 8.66 -51.47 -44.56 1.81 1116.47 14.75 269.79 1109.38 25.74 -52.54 -65.78 4.60 1178.10 16.56 273.54 1168.73 39.87 -52.02 -82.39 3.36 1271.87 16.66 278.54 1258.59 63.62 -49.20 -109.02 1.53 1367.59 16.58 282.98 1350.31 88.83 -44.10 -135.90 1.33 1463.98 16.33 279.76 1442.76 114.10 -38.71 -162.66 0.98 1559.91 16.36 280.27 1534.81 138.85 -34.02 -189.24 0.15 1655.71 17.64 280.55 1626.42 164.60 -28.95 -216.79 1.34 1750.55 16.92 281.25 1716.98 190.59 -23.63 -244.45 0.79 1846.84 18.53 282.09 1808.70 217.79 -17.69 -273.16 1.69 1941.46 23.02 285.87 1897.15 249.42 -9.48 -305.68 4.95 2037.51 26.62 286.39 1984.31 287.88 1.73 -344.40 3.75 2133.58 28.87 288.26 2069.33 330.82 15.08 -387.08 2.51 2182.50 29.12 288.91 2112.12 353.72 22.63 -409.55 0.82 2307.81 32.32 290.29 2219.83 415.84 44.14 -469.83 2.61 2404.06 36.70 291.47 2299.13 469.02 63.60 -520.76 4.60 2499.82 40.74 294.90 2373.83 527.92 87.24 -575.76 4.78 2594.64 44.31 294.62 2443.70 591.24 114.07 -633.95 3.77 2689.55 48.89 293.85 2508.90 659.27 142.35 -696.82 4.86 2786.19 52.58 292.74 2570.05 732.87 171.92 -765.54 3.92 2881.84 56.00 292.80 2625.87 809.14 201.98 -837.14 3.58 2976.87 59.97 292.25 2676.24 888.21 232.83 -911.56 4.21 3072.94 64.72 290.24 2720.82 971.30 263.62 -990.85 5.28 3168.70 68.77 289.48 2758.62 1056.75 293.50 -1073.58 4.29 3264.27 73.00 290.31 2789.91 1144.47 324.23 -1158.47 4.50 3359.68 77.25 290.43 2814.40 1234.22 356.32 -1244.90 4.46 3454.41 79.73 291.78 2833.30 1324.84 389.74 -1331.49 2.97 Surveys(continued) 63 CANRIG lik cni Eni Petroleum OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 3551.06 80.57 291.06 2849.84 1417.93 424.52 -1420.13 1.14 3648.00 80.77 289.84 2865.55 1511.09 457.94 -1509.76 1.26 3746.20 80.74 289.77 2881.33 1605.22 490.78 -1600.95 0.08 3845.59 80.97 288.69 2897.13 1700.29 523.10 -1693.60 1.10 3943.45 80.92 287.97 2912.53 1793.52 553.49 -1785.34 0.73 4042.41 80.88 287.72 2928.18 1887.58 583.43 -1878.35 0.25 4140.40 80.86 287.51 2943.73 1980.59 612.71 -1970.56 0.21 4238.60 80.89 289.05 2959.30 2074.11 643.12 -2062.62 1.55 4337.50 80.57 288.80 2975.23 2168.54 674.78 -2154.96 0.41 4435.78 80.86 290.29 2991.09 2262.64 707.23 -2246.36 1.53 4535.87 80.83 291.22 3007.02 2358.99 742.24 -2338.76 0.92 4633.91 80.83 291.89 3022.64 2453.65 777.80 -2428.78 0.67 4731.92 80.98 291.82 3038.13 2548.41 813.83 -2518.60 0.17 4829.53 80.86 291.79 3053.54 2642.76 849.63 -2608.09 0.13 4927.98 81.00 292.96 3069.06 2738.13 886.64 -2697.99 1.18 5026.66 81.09 293.68 3084.42 2834.05 925.23 -2787.50 0.73 5126.15 81.00 293.22 3099.91 2930.79 964.34 -2877.66 0.47 5224.16 80.89 292.75 3115.33 3025.93 1002.13 -2966.76 0.49 5322.20 81.25 296.31 3130.55 3121.56 1042.34 -3054.86 3.61 5420.44 77.72 297.67 3148.48 3217.49 1086.16 -3140.92 3.84 5518.60 77.44 292.95 3169.60 3312.33 1127.13 -3227.55 4.70 5617.59 81.05 296.50 3188.08 3408.39 1167.81 -3315.85 5.07 5715.66 79.42 294.40 3204.71 3504.06 1209.34 -3403.11 2.69 5813.89 80.12 293.86 3222.16 3599.42 1248.86 -3491.33 0.89 5910.98 81.16 295.85 3237.95 3694.10 1289.12 -3578.25 2.29 6008.45 81.02 295.16 3253.05 3789.44 1330.59 -3665.16 0.71 6107.91 81.10 295.20 3268.50 3886.64 1372.39 -3754.07 0.09 6212.32 80.67 295.38 3285.04 3988.65 1416.43 -3847.28 0.45 6305.21 79.51 295.84 3301.03 4079.27 1455.98 -3929.79 1.34 6410.60 80.09 296.56 3319.69 4182.13 1501.78 -4022.86 0.87 6503.51 80.61 295.51 3335.27 4272.93 1541.98 -4105.16 1.25 6607.42 80.56 296.33 3352.27 4374.53 1586.79 -4197.36 0.78 6699.56 80.70 293.85 3367.27 4464.43 1625.33 -4279.68 2.66 6798.95 80.50 293.90 3383.50 4561.09 1665.02 -4369.35 0.21 6897.56 79.83 295.13 3400.35 4657.03 1705.33 -4457.75 1.40 6995.40 80.30 296.94 3417.23 4752.56 1747.63 -4544.34 1.88 7094.56 80.38 298.75 3433.87 4849.82 1793.29 -4630.77 1.80 7192.10 80.15 302.16 3450.37 4945.80 1842.01 -4713.63 3.45 7290.57 81.60 308.60 3466.00 5042.92 1898.28 -4792.85 6.62 7388.45 83.76 310.72 3478.47 5139.45 1960.23 -4867.57 3.08 Surveys(continued) 64 CANRIG cik epi Eni Petroleum OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 7487.63 85.31 312.58 3487.92 5237.19 2025.84 -4941.34 2.43 7584.15 85.62 313.96 3495.55 5332.03 2091.79 -5011.39 1.46 7684.48 85.53 315.06 3503.29 5430.25 2161.92 -5082.73 1.10 7782.13 85.59 316.58 3510.85 5525.39 2231.74 -5150.58 1.55 7879.35 85.77 316.60 3518.17 5619.84 2302.16 -5217.20 0.19 7977.67 85.68 316.11 3525.50 5715.46 2373.11 -5284.87 0.51 8077.20 85.54 315.85 3533.12 5812.39 2444.47 -5353.83 0.30 8174.73 85.94 316.09 3540.37 5907.38 2514.40 -5421.43 0.48 8272.63 87.05 317.17 3546.35 6002.57 2585.43 -5488.53 1.58 8369.56 87.22 317.54 3551.20 6096.60 2656.64 -5554.11 0.42 8441.65 87.23 316.92 3554.69 6166.57 2709.50 -5603.01 0.86 8547.30 87.60 318.41 3559.45 6268.93 2787.51 -5674.08 1.45 8645.87 89.97 318.79 3561.54 6364.11 2861.43 -5739.25 2.44 8744.45 91.77 316.37 3560.04 6459.74 2934.19 -5805.73 3.06 8842.54 91.23 315.76 3557.48 6555.47 3004.80 -5873.77 0.83 8941.44 89.42 313.57 3556.92 6652.52 3074.32 -5944.10 2.87 9040.37 89.83 311.99 3557.56 6750.17 3141.50 -6016.71 1.65 9138.50 91.34 316.51 3556.56 6846.57 3209.95 -6086.97 4.86 9237.43 90.60 315.87 3554.89 6943.10 3281.33 -6155.45 0.99 9336.13 89.91 316.97 3554.45 7039.33 3352.83 -6223.49 1.32 9433.93 90.40 316.06 3554.18 7134.65 3423.79 -6290.79 1.06 9482.17 89.00 316.24 3554.43 7181.73 3458.58 -6324.21 2.93 9580.77 88.34 315.77 3556.72 7277.99 3529.49 -6392.68 0.82 9679.63 88.77 317.16 3559.22 7374.33 3601.13 -6460.75 1.47 9778.17 91.29 324.29 3559.16 7468.42 3677.36 -6523.08 7.67 9876.67 89.93 325.91 3558.12 7560.04 3758.14 -6579.43 2.15 9975.59 90.43 326.26 3557.80 7651.43 3840.23 -6634.62 0.62 10073.43 90.46 323.67 3557.04 7742.52 3920.33 -6690.79 2.65 10173.07 90.17 321.45 3556.50 7836.74 3999.44 -6751.36 2.25 10270.88 90.06 316.88 3556.30 7930.93 4073.42 -6815.29 4.67 10368.62 90.83 317.01 3555.54 8026.02 4144.83 -6882.02 0.80 10468.65 91.32 314.86 3553.66 8123.71 4216.69 -6951.57 2.20 10566.77 92.69 315.71 3550.23 8219.73 4286.37 -7020.56 1.64 10665.41 92.80 317.36 3545.51 8315.74 4357.88 -7088.34 1.67 10763.09 92.17 318.47 3541.27 8410.29 4430.31 -7153.74 1.31 10860.89 91.72 322.20 3537.95 8503.87 4505.53 -7216.12 3.84 10959.07 93.90 323.00 3533.14 8596.57 4583.43 -7275.68 2.36 11057.31 92.77 323.29 3527.42 8688.98 4661.90 -7334.50 1.19 11155.89 90.72 321.74 3524.42 8782.17 4740.08 -7394.46 2.61 11254.60 90.09 321.43 3523.72 8876.05 4817.42 -7455.79 0.71 Surveys(continued). 65 CANRIG 111 _eni Esti Petrolewn OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 11353.13 89.97 320.96 3523.67 8969.96 4894.21 -7517.54 0.49 11449.78 90.80 318.29 3523.02 9062.83 4967.83 -7580.14 2.89 11548.06 90.17 318.77 3522.19 9157.78 5041.47 -7645.22 0.81 11647.04 89.00 319.68 3522.91 9253.09 5116.42 -7709.86 1.50 11745.72 89.52 322.17 3524.18 9347.27 5193.01 -7772.05 2.58 11844.76 87.91 322.26 3526.40 9441.09 5271.26 -7832.71 1.63 11943.62 87.11 322.93 3530.70 9534.46 5349.72 -7892.71 1.06 12043.29 88.83 323.47 3534.23 9628.28 5429.47 -7952.37 1.81 12141.88 88.57 323.42 3536.47 9720.98 5508.65 -8011.08 0.27 12238.77 88.00 321.66 3539.37 9812.57 5585.52 -8069.98 1.91 12337.61 89.14 321.33 3541.83 9906.59 5662.84 -8131.49 1.20 12434.65 90.49 321.09 3542.15 9999.07 5738.48 -8192.28 1.41 12533.62 90.43 319.13 3541.35 10093.94 5814.41 -8255.75 1.98 12632.00 90.49 319.22 3540.56 10188.70 5888.85 -8320.06 0.11 _12729.85 90.92 320.43 3539.36 10282.63 5963.61 -8383.18 1.31 -T2629.44 90.37 320.70 3538.24 10377.87 6040.52 -8446.44 0.62 92 126.97 90.69 323.18 3537.33 10470.42 6117.31 -8506.56 2.56 13026.43 90.46 322.71 3536.34 10564.25 6196.68 -8566.49 0.53 13125.73 88.60 321.47 _ 3537.15 10658.41 6275.01 -8627.49 2.25 13222.14 88.74 321.143539.39 10750.21 6350.24 -8687.75 0.37 13320.84 89.83 320.67 3540.62 10844.43 6426.83 -8749.98 1.20 _ 13418.60 90.40 321.43 3540.42 10937.68 6502.86 -8811.44 0.97 13517.76 90.69 319.13 3539.48 11032.64 6579.12 -8874.80 2.34 13616.72 91.00 317.19 3538.02 11128.40 6652.84 -8940.80 1.99 13714.81 88.77 316.24 3538.22 11223.92 6724.24 -9008.05 2.47 13812.03 86.69 314.37 3542.07 11319.03 6793.29 -9076.37 2.88 13911.10 88.86 314.88 3545.91 11416.18 6862.82 -9146.82 2.25 _ 14007.16 88.74 314.98 3547.93 11510.34 6930.65 -9214.81 0.16 14106.11 90.17 309.49 3548.87 11608.12 6997.13 -9288.04 5.73 _ 14206.71 89.97 307.75 3548.74 11708.33 7059.92 -9366.64 1.74 14304.94 90.37 308.14 3548.45 11806.27 7120.32 -9444.10 0.57 14403.63 90.63 309.46 3547.59 11904.55 7182.16 -9521.01 1.36 14501.41 90.83 308.59 3546.35 12001.88 7243.72 -9596.96 0.91 14600.17 91.12 307.07 3544.67 12100.35 7304.28 -9674.95 1.57 _14699.00 89.54 303.00 3544.10 12199.12 7361.00 -9755.85 4.42 14797.95 89.17 300.82 3545.21 12298.02 7413.30 -9839.84 2.23 14894.65 91.77 300.24 3544.42 12394.57 7462.41 -9923.12 2.75 14993.40 91.23 298.15 3541.83 12492.99 7510.56 -10009.29 2.19 15091.18 93.20 296.10 3538.05 12590.07 7555.11 -10096.25 2.91 15189.96 92.75 292.85 3532.92 12687.46 7595.97 -10186.02 3.32 Surveys(continued) 66 CANRIG Oils ni Eni Petroleum OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 15288.27 92.92 291.68 3528.06 12783.74 7633.17 -10276.88 1.20 15386.45 92.32 292.30 3523.57 12879.81 7669.90 -10367.82 0.88 15484.14 91.63 293.08 3520.21 12975.69 7707.56 -10457.90 1.07 _15583.30 91.63 295.05 3517.39 13073.44 7747.97 -10548.40 1.99 15682.13 91.89 295.66 3514.35 13171.20 7790.28 -10637.67 0.67 15780.44 91.37 294.65 3511.55 13268.41 7832.05 -10726.62 1.16 15878.48 89.43 292.33 3510.87 13364.92 7871.12 -10816.52 3.08 15978.64 90.00 290.95 3511.37 13462.91 7908.05 -10909.62 1.49 16075.28 89.74 292.02 3511.59 13557.40 7943.45 -10999.54 1.14 16174.57 89.80 291.83 3511.99 13654.65 7980.52 -11091.65 0.20 16273.25 90.89 292.10 3511.39 13751.30 8017.43 -11183.16 1.14 16371.20 92.26 291.94 3508.70 13847.23 8054.14 -11273.93 1.41 16470.64 91.29 292.03 3505.62 13944.59 8091.35 -11366.09 0.98 16568.35 89.26 294.77 3505.15 14040.74 8130.15 -11455.75 3.49 16666.17 89.86 296.00 3505.90 14137.56 8172.08 -11544.12 1.40 16765.73 88.97 297.67 3506.92 14236.42 8217.02 -11632.95 1.90 16865.01 88.32 296.86 3509.27 14335.07 8262.49 -11721.18 1.05 16962.15 90.46 300.36 3510.30 14431.82 8308.99 -11806.43 4.22 17062.73 90.14 300.69 3509.77 14532.25 8360.08 -11893.07 0.46 17159.73 91.37 299.01 3508.50 14629.04 8408.35 -11977.19 2.15 17259.12 90.37 297.27 3506.99 14727.96 8455.22 -12064.82 2.02 17356.87 89.92 298.87 3506.74 14825.26 8501.21 -12151.07 1.70 17454.54 87.77 297.40 3508.71 14922.46 8547.25 -12237.17 2.67 17553.84 87.60 294.04 3512.72 15020.73 8590.31 -12326.55 3.39 17652.52 87.94 291.83 3516.56 15117.63 8628.73 -12417.35 2.26 17750.84 89.20 290.16 3519.01 15213.55 8663.94 -12509.11 2.13 17848.09 90.86 289.26 3518.96 15307.96 8696.74 -12600.66 1.94 17946.62 90.23 287.73 3518.03 15403.09 8727.99 -12694.09 1.68 18045.55 88.09 285.07 3519.48 15497.58 8755.92 -12788.97 3.45 18130.54 89.03 282.50 3521.61 15577.52 8776.16 -12871.48 3.22 18200.00 89.03 282.50 3522.79 15642.32 8791.19 -12939.28 0.00 5.3 Survey Data OP 17-02-PB1 67 CANRIG IA ,,cni Eni Petroleum OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 0 0 0 0 0 0 0 0 106.88 0.21 288.41 106.88 0.19 0.06 -0.18 0.20 166.20 1.03 166.13 166.20 -0.10 -0.42 -0.16 1.94 202.31 1.92 164.29 202.30 -0.79 -1.32 0.08 2.49 292.96 3.10 169.37 292.85 -3.62 -5.20 0.95 1.32 359.78 3.88 162.70 359.55 -6.61 -9.13 1.95 1.32 450.25 3.81 167.80 449.82 -11.10 -15.00 3.50 0.39 543.00 4.22 188.83 542.34 -14.69 -21.39 3.63 1.64 635.20 5.61 212.12 634.21 -16.15 -28.56 0.71 2.61 732.25 6.73 230.05 730.70 -14.55 -36.26 -6.18 2.28 827.38 7.39 236.67 825.12 -10.46 -43.17 -15.56 1.10 922.45 9.40 255.43 919.18 -2.76 -48.49 -28.19 3.55 1019.07 10.49 263.36 1014.35 9.33 -51.49 -44.56 1.81 1116.47 14.75 269.79 1109.38 26.54 -52.56 -65.78 4.60 1178.10 16.56 273.54 1168.73 40.75 -52.05 -82.39 3.37 1271.87 16.66 278.54 1258.59 64.62 -49.23 -109.02 1.53 1367.59 16.58 282.98 1350.31 89.94 -44.12 -135.90 1.33 1463.98 16.33 279.76 1442.76 115.32 -38.73 -162.65 0.98 1559.91 16.36 280.27 1534.81 140.17 -34.04 -189.24 0.15 1655.71 17.64 280.55 1626.42 166.03 -28.98 -216.79 1.34 1750.55 16.92 281.25 1716.98 192.13 -23.65 -244.45 0.79 1846.84 18.53 282.09 1808.70 219.44 -17.71 -273.15 1.69 1941.46 23.02 285.87 1897.15 251.18 -9.50 -305.67 4.95 2037.51 26.62 286.39 1984.31 289.76 1.71 -344.39 3.75 2133.58 28.87 288.26 2069.33 332.82 15.05 -387.07 2.51 2182.50 29.12 288.91 2112.12 355.79 22.61 -409.55 0.82 2307.81 32.32 290.29 2219.83 418.06 44.11 -469.83 2.61 2404.06 36.70 291.47 2299.13 471.36 63.57 -520.75 4.60 2499.82 40.74 294.90 2373.83 530.37 87.22 -575.75 4.78 2594.64 44.31 294.62 2443.70 593.78 114.05 -633.94 3.77 2689.55 48.89 293.85 2508.90 661.92 142.33 -696.81 4.86 2786.19 52.58 292.74 2570.05 735.65 171.90 -765.53 3.92 2881.84 56.00 292.80 2625.87 812.07 201.95 -837.13 3.58 2976.87 59.97 292.25 2676.24 891.29 232.81 -911.55 4.21 3072.94 64.72 290.24 2720.82 974.56 263.60 -990.84 5.28 3168.70 68.77 289.48 2758.62 1060.21 293.47 -1073.58 4.29 3264.27 73.00 290.31 2789.91 1148.14 324.20 -1158.47 4.50 3359.68 77.25 290.43 2814.40 1238.11 356.29 -1244.89 4.46 3454.41 79.73 291.78 2833.30 1328.93 389.72 -1331.48 2.97 Surveys(continued) Measured Inclination I Azimuth True Vertical Latitude Departure Dogleg 68 CANRIG IX pili Eni Petroleum OP 17-02 and OP 17-02-PB1 Depth Vertical Section (ft) (ft) Rate _ (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 3551.06 80.57 291.06 2849.84 1422.21 424.49 -1420.13 1.14 3648.00 80.77 289.84 2865.55 1515.58 457.92 -1509.75 1.26 3746.20 80.74 289.77 2881.33 1609.95 490.76 -1600.94 0.08 3845.59 80.97 288.69 _2897.13 1705.25 523.07 -1693.60 1.10 3943.45 80.92 287.97 2912.53 1798.74 553.47 -1785.33 0.73 4042.41 80.88 287.72 2928.18 1893.06 583.41 -1878.34 0.25 4140.40 80.86 287.51 2943.73 1986.34 612.69 -1970.56 0.21 4238.60 80.89 289.05 2959.30 2080.11 643.10 -2062.62 1.55 4337.50 80.57 288.80 2975.23 2174.79 674.76 -2154.95 0.41 4435.78 80.86 290.29 2991.09 2269.12 707.20 -2246.35 1.53 4535.87 80.83 291.22 3007.02 2365.68 742.22 -2338.75 0.92 4633.91 80.83 291.89 3022.64 2460.55 777.78 -2428.77 0.67 4731.92 80.98 291.82 3038.13 2555.50 813.81 -2518.59 0.17 4829.53 80.86 291.79 3053.54 2650.05 849.61 -2608.08 0.13 4927.98 81.00 292.96 3069.06 2745.60 886.62 -2697.98 1.18 5026.66 81.09 293.68 3084.42 2841.69 925.20 -2787.49 0.73 5126.15 81.00 293.22 3099.91 2938.61 964.31 -2877.65 0.47 5224.16 80.89 292.75 3115.33 3033.92 1002.11 -2966.76 0.49 5322.20 81.25 296.31 3130.55 3129.70 1042.31 -3054.85 3.61 5420.44 77.72 297.67 3148.48 3225.74 1086.13 -3140.91 3.84 5518.60 77.44 292.95 _ 3169.60 3320.71 1127.11 -3227.54 4.70 5617.59 81.05 296.50 3188.08 3416.92 1167.79 -3315.84 5.07 5715.66 79.42 294.40 3204.71 3512.72 1209.32 -3403.10 2.69 5813.89 80.12 293.86 3222.16 3608.23 1248.84 -3491.32 0.89 5910.98 81.16 295.85 3237.95 3703.06 1289.10 -3578.24 2.29 6008.45 81.02 295.16 3253.05 3798.53 1330.56 -3665.15 0.71 6107.91 81.10 295.20 3268.50 3895.87 1372.37 -3754.06 0.09 6212.32 80.67 295.38 3285.04 3998.03 1416.41 -3847.27 0.45 6305.21 79.51 295.84 3301.03 4088.77 1455.96 -3929.79 1.34 6410.60 80.09 296.56 3319.69 4191.76 1501.75 -4022.85 0.87 6503.51 80.61 295.51 3335.27 4282.68 1541.96 -4105.15 1.25 6607.42 80.56 296.33 3352.27 4384.41 1586.76 -4197.35 0.78 6699.56 80.70 293.85 3367.27 4474.45 1625.31 -4279.68 2.66 6798.95 80.50 293.90 3383.50 4571.26 1665.00 -4369.34 0.21 6897.56 79.83 295.13 3400.35 4667.36 1705.31 -4457.74 1.40 6995.40 80.30 296.94 3417.23 4763.01 1747.61 -4544.33 1.88 7094.56 80.38 298.75 3433.87 4860.37 1793.27 -4630.76 1.80 7192.10 80.15 302.16 3450.37 4956.39 1841.99 -4713.62 3.45 7290.57 81.60 308.60 3466.00 5053.48 1898.25 -4792.84 6.62 7388.45 83.76 310.72 3478.47 5149.89 1960.21 -4867.57 3.08 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg 69 CANRIG lik Leni Eni Petroleum OP 17-02 and OP 17-02-PB1 Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 7487.63 85.31 312.58 3487.92 5247.49 2025.82 -4941.33 2.43 7584.15 85.62 313.96 3495.55 5342.16 2091.77 -5011.39 1.46 7684.48 85.53 315.06 3503.29 5440.18 2161.89 -5082.72 1.10 7782.13 85.59 316.58 3510.85 5535.11 2231.71 -5150.57 1.55 7879.35 85.77 316.60 3518.17 5629.34 2302.14 -5217.19 0.19 7977.67 85.68 316.11 3525.50 5724.73 2373.09 -5284.86 0.51 8077.20 85.54 315.85 3533.12 5821.44 2444.45 -5353.82 0.30 8174.73 85.94 316.09 3540.37 5916.21 2514.38 -5421.42 0.48 8272.63 87.05 317.17 3546.35 6011.18 2585.41 -5488.52 1.58 8369.56 87.22 317.54 3551.20 6104.96 2656.62 -5554.11 0.42 8441.65 87.23 316.92 3554.69 6174.76 2709.48 -5603.00 0.86 8547.30 87.60 318.41 3559.45 6276.86 2787.49 -5674.08 1.45 8645.87 89.97 318.79 3561.54 6371.77 2861.41 -5739.24 2.44 8744.45 91.77 316.37 3560.04 6467.15 2934.17 -5805.73 3.06 8842.54 91.23 315.76 3557.48 6562.67 3004.78 -5873.76 0.83 8941.44 89.42 313.57 3556.92 6659.52 3074.29 -5944.09 2.87 9040.37 89.83 311.99 3557.56 _ 6757.00 3141.48 -6016.70 1.65 9138.50 91.34 316.51 3556.56 6853.21 3209.93 -6086.97 4.86 9237.43 90.60 315.87 3554.89 6949.52 3281.31 -6155.44 0.99 9336.13 89.91 316.98 3554.45 7045.52 3352.82 -6223.48 1.32 9433.93 90.40 316.06 3554.18 7140.61 3423.78 -6290.77 1.07 9532.54 90.80 316.68 3553.15 7236.54 3495.15 -6358.81 0.75 9631.22 91.85 317.58 3550.87 7332.21 3567.45 -6425.92 1.40 9729.65 92.31 318.59 3547.29 7427.18 3640.65 -6491.63 1.13 9827.62 91.05 315.33 3544.42 7522.20 3712.21 -6558.46 3.57 9925.82 91.54 314.80 3542.20 7618.21 3781.71 -6627.80 0.73 10024.41 90.45 314.92 3540.49 7714.68 3851.24 -6697.67 1.11 10122.57 91.79 316.03 3538.57 7810.50 3921.20 -6766.49 1.77 10220.43 87.77 315.58 3538.95 7905.90 3991.35 -6834.69 4.13 10319.56 88.05 318.80 3542.56 8001.93 4064.02 -6902.00 3.26 10418.14 89.71 319.82 3544.49 8096.52 4138.75 -6966.26 1.98 10516.48 89.88 320.50 3544.84 8190.48 4214.26 -7029.26 0.71 10614.48 88.20 322.00 3546.48 8283.53 4290.67 -7090.59 2.30 10713.41 87.94 321.04 3549.82 8377.29 4368.07 -7152.11 1.00 10811.60 91.62 325.41 3550.19 8469.38 4446.69 -7210.87 5.82 10907.51 90.63 325.54 3548.31 8557.99 4525.69 -7265.22 1.04 11006.72 90.83 323.26 3547.05 8650.35 4606.34 -7322.96 2.31 11102.32 89.91 321.63 3546.43 8740.49 4682.13 -7381.23 1.96 11207.51 93.17 320.45 3543.60 8840.45 4763.88 -7447.33 3.30 11304.05 95.43 319.91 3536.36 8932.42 4837.81 -7508.98 2.41 Surveys (continued) 70 CANRIG itik ,cni Eni Petroleum OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 11401.83 95.23 320.83 3527.28 9025.34 4912.80 -7571.07 0.96 11500.91 94.00 320.71 3519.31 9119.38 4989.29 -7633.53 1.25 11597.91 92.25 320.25 3514.02 9211.76 5064.01 -7695.16 1.87 11695.58 91.57 318.88 3510.77 9305.32 5138.30 -7758.47 1.57 11794.50 89.23 318.56 3510.08 9400.53 5212.63 -7823.73 2.39 11892.67 88.31 318.85 3512.18 9495.02 5286.37 -7888.50 0.98 11991.18 85.68 317.88 3517.35 9589.87 5359.89 -7953.85 2.85 12088.78 88.85 318.02 3522.00 9684.04 5432.27 -8019.14 3.25 12186.88 90.20 319.91 3522.82 9778.35 5506.26 -8083.54 2.37 12286.42 90.34 319.85 3522.35 9873.60 5582.38 -8147.68 0.15 12383.23 90.63 320.55 3521.53 9966.08 5656.75 -8209.64 0.78 12481.92 90.54 321.29 3520.52 10059.97 5733.36 -8271.85 0.76 12580.09 90.63 322.88 3519.52 10152.74 5810.80 -8332.17 1.62 12678.26 91.48 322.40 3517.71 10245.18 5888.82 -8391.73 0.99 12775.47 88.00 322.33 3518.15 10336.88 5965.79 -8451.08 3.58 12874.08 84.50 322.28 3524.60 10429.73 6043.64 -8511.24 3.55 12972.19 83.87 322.08 3534.54 10521.91 6120.74 -8571.09 0.67 13069.55 87.54 324.28 3541.83 10613.02 6198.44 -8629.26 4.39 13169.17 86.17 321.08 3547.30 10706.66 6277.54 -8689.55 3.49 13266.39 85.56 319.33 3554.31 10799.29 6352.04 -8751.61 1.90 13365.82 88.05 320.60 3559.85 10894.23 6428.04 -8815.46 2.81 13464.35 89.17 319.54 3562.24 10988.39 6503.57 -8878.69 1.56 13562.33 90.14 319.57 3562.83 11082.31 6578.13 -8942.25 0.99 13661.68 90.03 318.81 3562.68 11177.72 6653.33 -9007.18 0.77 13760.10 89.37 313.82 3563.20 11273.46 6724.48 -9075.13 5.11 13858.85 90.63 314.38 3563.20 11370.36 6793.20 -9146.04 1.40 13957.18 90.71 314.19 3562.05 11466.78 6861.85 -9216.43 0.21 14055.84 91.51 315.72 3560.14 11563.28 6931.54 -9286.23 1.75 14154.60 92.23 314.88 3556.91 11659.72 7001.70 -9355.66 1.12 14253.28 93.06 311.50 3552.36 11756.72 7069.16 -9427.52 3.52 14352.09 94.16 309.99 3546.14 11854.43 7133.52 -9502.23 1.89 14450.45 92.80 307.78 3540.17 11952.09 7195.15 -9578.65 2.63 14548.99 92.74 300.81 3535.40 12050.43 7250.57 -9659.91 7.07 14648.17 91.00 299.98 3532.16 12149.45 7300.72 -9745.41 1.94 14746.53 91.20 297.63 3530.27 12247.52 7348.10 -9831.58 2.40 14845.73 91.54 297.63 3527.90 12346.25 7394.10 -9919.44 0.34 14943.04 91.28 297.53 3525.51 12443.10 7439.14 -10005.66 0.29 15041.82 91.00 297.81 3523.54 12541.43 7485.00 -10093.13 0.40 15140.99 89.63 297.86 3523.00 12640.20 7531.30 -10180.82 1.38 15239.73 89.80 296.93 3523.49 12738.46 7576.73 -10268.49 0.96 Surveys(continued) 71 CANRIG iiiits eni Eni Petroleum OP 17-02 and OP 17-02-PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 15338.06 90.94 298.51 3522.85 12836.37 7622.47 -10355.52 1.98 15436.91 91.00 297.50 3521.18 12934.83 7668.87 -10442.79 1.02_ 15535.29 89.97 293.99 3520.35 13032.40 7711.60 -10531.38 3.72_ 15632.99 88.00 294.27 3522.08 13128.91 7751.53 -10620.53 2.04 15731.42 88.05 293.40 3525.47 13226.02 7791.28 -10710.51 0.88 15829.54 89.65 292.46 3527.44 13322.61 7829.50 -10800.85 1.89_ 15928.49 89.68 289.83 3528.02 13419.44 7865.19 -10893.13 2.66_ 16026.71 89.68 289.79 3528.57 13515.07 7898.48 -10985.54 0.04 16125.71 89.68 293.45 3529.12 13612.10 7934.95 -11077.55 3.70 16224.41 88.68 294.22 3530.53 13709.53 7974.83 -11167.83 1.28- 16321.75 88.83 293.40 3532.65 13805.60 8014.12 -11256.86 0.86_ 16420.10 91.11 294.17 3532.70 13902.67 8053.78 -11346.85 2.45 16519.16 92.11 295.56 3529.91 14000.69 8095.41 -11436.69 1.73 16617.85 95.05 296.19 3523.75 14098.42 8138.39 -11525.30 3.05_ 16714.72 93.83 295.61 3516.25 14194.25 8180.58 -11612.18 1.39_ 16812.65 94.00 297.70 3509.57 14291.35 8224.40 -11699.49 2.14 16912.08 95.96 297.96 3500.94 14390.00 8270.65 -11787.08 1.99 17010.78 94.32 295.99 3492.09 14487.75 8315.23 -11874.69 2.59_ 17108.37 92.08 294.36 3486.65 14584.27 8356.67 -11962.86 2.84_ 17207.48 90.37 292.24 3484.53 14681.93 8395.86 -12053.86 2.75 17305.43 87.20 288.77 3486.60 14777.51 8430.16 -12145.56 4.80 17403.70 89.48 291.22 3489.45 14873.21 8463.74 -12237.85 3.40_ 17502.38 89.50 293.49 3490.33 14970.18 8501.27 -12329.10 2.30_ 17600.62 87.36 293.09 3493.02 15066.97 8540.10 -12419.30 2.22 17696.36 83.79 291.47 3500.41 15160.74 8576.28 -12507.61 4.09 17793.43 85.97 292.62 3509.07 15255.66 8612.57 -12597.22 2.54_ 17895.32 86.02 290.50 3516.19 15355.27 8649.92 -12691.74 2.08_ 17993.85 86.28 290.04 3522.80 15451.16 8683.98 -12783.96 0.54 18092.06 92.53 292.32 3523.82 15547.23 8719.44 -12875.48 6.77 18190.64 94.77 293.37 3517.55 15644.06 8757.63 -12966.14 2.51_ 18288.47 98.03 293.76 3506.64 15739.95 8796.49 -13055.24 3.36_ 18383.97 97.26 292.37 3493.94 15833.18 8833.57 -13142.32 1.65 18486.04 92.97 291.28 3484.84 15932.89 8871.35 -13236.67 4.34_ 18583.18 89.91 291.14 3482.40 16027.94 8906.48 -13327.19 3.15_ 18681.25 88.63 296.23 3483.65 16124.68 8945.86 -13416.96 5.35 18780.17 86.80 296.97 3487.59 16222.90 8990.11 -13505.34 2.00 18877.74 87.88 296.19 3492.12 16319.75 9033.72 -13592.50 1.36 72 CANRIG co L Q O , a O Q 0 Q 0 FT (nOCQ � H ca , H ,-3 ) ZO I- F I- E' H a) H Z m U m m , 0 N - M N N N N CD 1:1- 00 O N- Ma L Ot = N CO N- > Ot CS) Q /X w 0) ,- Q Ce w CO y 00 NO uj CO 2 N Nf-ci co `n 2 N- m to O LO oN Ya) O d .� N 0 .- fcrO N . LLQ N CO CO LLQ 00 .0 into co co t co) Q, 7 a+ co to N Q 7 ON 0 N to CO Q O CO 7- Lo LO FO Q C ++ CO LO NN Q C ++ CO m y — g 0 N CO to Q. 0 N to CO 0 00) N = O N. r O Ctt�� d Q - N Q - a CO -p 0 co rn �� y N co (0 N ILI N8'.- X 7 Mcu N.. Ft.E O 0 CL y co i N 0 N ,- .,MS ,Q L O O Cc?) CO ja CO uCh N ) 7 cn N N 7 N Z LL N N Z N 0 CO CO CO LL LL Y cu C. fx 0 to 0 0 O 2 Y Q O O 0 2 Cl) (i) CC N _ to to C (O N N LO N C t!) �. N cNi 00 N O L L d a, r E m D N CO �t m a E D m = 1 m m m m z > CC m -0 a Z a 6 Z Z Z Z Z , N z }' Z 2' V O m Z N IQI, G m: I I I I CO [ m LL CI. ZZ � a Q E O 0 ori NI- r- + w coo o ' 0000 coo o 00 CO CO 000v aoo I I 1 1 .ii;0 r r r C N Q O E I 0 o co O 00000000 cm wLoo0o0o ca 0 O O U) o ' ' O O Tr Cf) CO Nr- ' ' al 3 O N M �Y 00 6) r r r r r r -511- m1.7, L � L 3 = O O r M r M- N V' U) U) Co CO V U fl. c5666 " 66666666 w 6 IL N Q O 1- c _ J Ea▪ aI 00 U) I- , , 00OO U) 1"- CO , i , i WZQLI N N r r r 0 CO r r r r 11 II II 1- N- N- N- 1- U) 0 V M- CO V M WW Z 0 CA O Cn CA i i O O O O 6) O O 6) i i i i O r r r r - - - - N M N- r r r r r r r N N r r O N NNNLO N r N ',-- = I E CO _ 0 0 0 000 • 000 = U m o (0 0 ~ c vi 1 0 M M N N N V U) CO u"mo 0000 6 ' ' 0 c m U) 032 -O 0 sc 4) -0 m C > ID 2 (.0 J O 0 r O• N• M'• CO• LC)• M• 00• U) L C - + G. LL ~ O O CO U) U) U) U) U) U) ..-',„ 0c-' (6 N 0 - . OLU Li. Lm p M o r CA N 00 r 1- 0 M U) M M M ICl. C R N (n N CO 'Cr cI , M CO N N M N M N N r r r F- 11 11 W N UO0 J I U) 0 4 N in W M CO O in V O8- 4„. 9W r N M •1 -. r N N N N r r r r r = COm = ! > N r 0 0 O U V M N N N CO N- MU r N- a. r r r r r 01"-- '1' M- M- N- 1- 0 LO 0 M M N M N- C() - M M O CO U) N N N M d) N >- r N N N N- N r N N N N N r r r r r r O 0 Z > M N r W r OO 0 r N M U) r N CT O C)) COO J M = c- NN- Na- 0 r r r r r r r - C 03 O _ O II N > a C7 U) 0�0 1 1 I i 1 1 1 1 1 1 1 1 1 1 `' N WN > V W O U) C 00 J13. 2 ✓ COp Q 1` o N M M N O O O r N M N 11 C II m , 20. co O O O O O OO O O 66666666 W to LL N _ ca a E O O W O 0 W M N O O U) UUC) UU ,.. O 6) r N V- O U) U) U) U) U) U) C 0-7:3 _ ~ NNNNNNMMMMMMMMMM O '00 (6 I- C (0 L 0 _0 W 0 0 U) U) U) M O U) O M O O O O o O O It% O O O r U) O M N N N N N N N > T .) N N N .Tr U N V N N N N co00 ) U) U) UU) U ) CC) ) _ (CO N N V U) U) I,- CO 00 CO CO CO IX) 0O V) •N t 2 -- • O O W 000000000000000000 c a� > -o W c' c) 41pc - 6 , c1c) 4L, o5a� oa .� F- O r N M V U) CO W O O r N M U7 Q N MM M 0 0 0 0 0 0 0 0 0 \ \ \ lC = C N -0 O 0 000 . . . . . 0 0 = M0 0 O r r r N-r r r r r r r r r r r r r r •� LL a } Ce IT II II II II 7 Q 2 > d >- 2 in ui Ln N- O ,^7.-„, - U0, N CO 4 CO 6) r N N N N N N N W Q O O O O O O ,- (5) O 6) 6) 6) O 6) c a) (1 0 E a) W .0N r r CO (- Ln r (0 M co 4 CO N V C -O H 2 _a r 6) r V r co 6) V O ,-- r N O J r O T r 1- O O r r r r c- 1-- r 5 LL C --- O O O O O O O O O 0 0 0 0 CD .ill . 1 .. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) 0 c LL U- O O O L() 0 0 0 0 0 0 0 0 0 0 O V V N (0 CO CO N- Ln Ln CO N V CO O- II Ln V CO CO CO Ln Ln 6) 6) 6) 6) 6) O 07 ) Q 0 H r r r r r — J _ w ° pLL Z J E CO N co r O CO l'-_. r D. 0 00 co O) LO I I �I I I Q da O 0 r o0rrro000 0u_ w ZO O - O O O r - - 0) 6) 0) N N N N N N N LO Ln Ln Ln 4 V O 6) 0) O O) O O O 6) 0) 6) 0) r r N- (` CO (` CO 00 CO V V V Cr Ln Ln Ln E No i i , . i I I I i I I I I I U N C O a) O 0 J CO CO Ln (0 Ln Ln (fl H — N O c 07 CO CO r •I• • CaI N- N N- N. N N- N- 0 a) a) ✓ r r r r r r = O) C m 00 O '6 Na) (6 N 111111 C > 48 P CO CO Ln Ln V >,.-, a) I I ® `- _C O :0 + 0 Ln in M (0 CO co8: O 2 O 0 �/ `SY (n N N N N N N N L co co L co r co O VL J N N (`0 N N N N LO L() tn O CO LO I I W 0 c al {U N 0 ,r N N N V 4 4 V 4 LO LO 1.-- II I' AVE 9 2 Q0 a. a_ 0) CO 6) O) CO 00 O CO V ' V CO V Ln 0 C a) > N O O 6) O O O CO (o (0 (0 N N r C 0 N N N r N N N N N N N N N N o O U O -a N C C CO N6 r a CO 0 0 CO00 00 CO r i i i i i O > v N- N- CO CO CO CO N C O II _ p (n O � � J _ CO 4 CO N N CV CO (`O N N N N N N N N '''" -0 O (n C 6) 2 Q O 0) 6) 6) 6) O O) 6) O) O) 6) O) 0) 6) O '5 U) N. J o) LL wd O r OV co O CO V O) O) 6) 6) O) O 61 O 00 0 LL (/ O - 0) 7r - r C7 ('7 (') (`0 07 M M (h M a) (0 — > Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln O M Co LA) CO CO M CO CO CO (`) CO CO CO CO a) _ c O � d O O O O O O O O O O O O O OO '- p 2 Lo N CD COCO CO '7 CO N N 0 N N N 0N N N � >+ V /^ U_ O O N v CO CO CO 00 CO CO CO CO CO CO .N ,r U) Q r r r r r r r r T T r r r N 7:1O � z 00 O L (�._ , n' O O O O O O O O O O O O O O N N > W r r r r r r r r \ r \ r r r O > 2 0- ti H CO V" Ln CO N- 00 6) O r N CO Ln CO ;r -o C . o 4 0 0 0 O O O O r r \ \ \ \ \ (a C 0) - () 0 N N N N N N N N N N N N N N '� 2 n CO N a) r r r r E CL i II II II II -a _ co > a. = Q > a. >- to Lei (0 N LO LO O 0) M c0 N- CO LO N- LU Cfl N- T U Q V V 0) m O M O V ti ti O Cfl CO O O CO (0 W Q W M of 6j 0 0 0 0 0 0 0 0 0 0 0 0 0 C r ,- = = = = = .- a) Q . 0 E 0) a) E 4 O O (f) N M N = = = = O O O) O 0 O) 'C o () J iE0 0 — - - -- 00000 . = L 20 '- L 03 =-, • ..--. 00000000000000000 U O O 1 -=- 00000000000000000 ; 0 >ME 0 0 (n (.h (f) O (f) 0 0 0 0 0 0 0 0 0 II O E N N N M Cfl LU M 0 0 0 0 20 0 00 (A 0) N N V V V V LU LO LU LU LU (n (.C) d- 0 Q, Q H C _ -1 L L O O- LL Z E . . O) O O) 00 M 0) C0 ti N- N- I` r Or 0)0 II II II J O � 0 0 0 0 0 0 0 0 0 0 0 0 Q d � LL W Z O N- N N O O O O O O) 0) O) O) O N N N N N N N N N N N = r = = N N 0 0 — — — — 0 0) O CO M CO N O O O O O m m oo co O CA N- N- N- I` I- I- 00 00 00 00 00 00 00 00 00 00 N E • o , , i i , , , , , , I I , , , i U (6 N 0 co J Lo CO M co M M M M M L O H O— N O O O M N 0O (() (f) I- CO (0 0) CO a) C W IIII 0 Cfl Cfl (fl Cfl O O O O O N- M 00 6 06 a) C cm C n m O 12 N Ji i 1 i C >+ _ �7 n LL >,= N 11 r ® L C + �_ O) M - M M N O) CT 00 6) 0O N O O 0 t▪ O C/) \ \ N N N N N N N N N N N N N N .--- W -C J ,� OO DO CO O CO DO O 0 0 I"- CO N II O 0 W .- N N N N N N N N N N N N W N Ur M M N LO N M V M M N ,- I- ti I` 00 N- N m =II I' 8. u ^ QU d d 00 00 V CO O 0 0 co O CO 0 O r r r = = = = = ' a) > c0 M - M 00) 00) 0) 0 N- tLv (0L - 0 d ' = N N N ,- N = = N = N N N N N N O O O V -0 0) - C CO _ (6 a , , M (D M N N OO OO M N M CO LO M M O > v co CO N- N- N- N- CO O CO CO CO CO CO CO N- O II •a- 22 N m ON - _17 7 n. L C5. d- LOLOLOM L0 I� 00 I- CO CO CO M CO N O (n N m Q 00 00 00 00 00 00 00 OO 0 ()00 00 0 6) 0) 00 6) 6) 7 (1) au) HIH J N , 2 a) -J -6 CLEL 0 CO CO M 0 CO LO LO O) LU LU (f) LO C W (n Q LO L CO V LO N O) 0) O) C)) 0) C7) 0) O (.() Liz Lf) (0 - LO dM coM coM coM cocM co coM coM coM coM COM M M M M _ > -0 H >= O C IZ CO V N- I- O O O O O O O 0 E W O 0 0 0 O O . . N Ln N V O y (6 O N N N O (.h M CO O) CA 0) CO = ..j LL (7) :'-' Z 2 ":E. 00 N o Fcl_ o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 � > > �o H CC) I� M 0) O N M to CO 0 ,- N L aD C . - Q ' .- N- \ NNNNNNNN N N M O O 0CC N U = DMO 0 = - ' ,- NN _ 2 Ct III H II II E r-- 6 6 CANRIG SHOW REPORT NO. 1 D.,.,Trc vs I:rir. ENI Petroleum 0P17-02 Nikaitchuq,Oliktok Point,Alaska DEPTH INTERVAL: 6880 TO 6940 (MD) TOTAL FTG: 60 3396.31 TO 3406.56 {TVD) BIT INFORMATION: BIT TYPE- Hycalog MSF619M AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 72.3 103 110.11 80.6 WOB 15.4 5.24 13.97 11.66 RPM 116.42 115.85 118.33 111.89 MUD WT 9.2 9.2 9.2 9.2 CHLORIDE 1400 1400 1400 1400 TOTAL GAS 32.3 225.9 382.4 100.9 Cl (ppm) 4948.4 65390.2 109736.3 42437.9 C2(ppm) 55.7 896.3 1541.3 574.3 C3(ppm) 12.5 218.9 378.1 148.4 C4(12Pm) 23.9 427.5 728.9 294.3 C5(ppm) 14.7 268.9 455.7 186.3 RATIO ROP INCREASE TO GAS INCREASE: 38/350 SAMPLE CUTTINGS FLUORESENCE%80 to 100%EVEN COLOR YELLOW-GREEN INTENSITY: DULL-MILKY CUT: STRAW-WHITE MUD FLUORESCENCE BRIGHT YELLOW FORMATION DESCRIPTION: Sand/Sandstone(6880-6950)=clear to translucent, with some white, light gray,pale green,pale blue,moderate yellowish brown, and dusky brown hues; predominantly quartz grain sand matrix; upper very fine to upper medium, fair to poorly sorted; very angular to sub-angular,with some slightly sub-rounded,moderate sphericity; 85%-95% bright yellow sample fluorescence;instantaneous milky white solvent cut; some free oil in sample; strong petroleum odor;abundant pyrite crystals. SHOW RATING:(T,P,F,G) POOR-FAIR LOGGING GEOLOGIST(S): Steven Pike;Jeffrey McBeth Page 1 CANRIG SHOW REPORT NO. 2 D.,I I,TE,vvui K;r Liu. ENI Petroleum OP17-02 Nikaitchuq,Oliktok Point,Alaska DEPTH INTERVAL: 8080 TO 8520 (MD) TOTAL FTG: 440 3530 TO 3555 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSF619M AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 98.1 135.1 201.95 130.1 WOB 13.5 10.7 39.59 13.07 RPM 121.5 119.2 125.48 119.5 MUD WT 9.3 9.3 9.3 9.3 CHLORIDE 1700 1700 1700 1700 TOTAL GAS 43.9 465.5 924.7 300.6 Cl (ppm) 12674.979 111276.87 223477.64 72501.677 C2(ppm) 95.801 2171.3383 5402.4062 1276.3926 C3(ppm) 154.400 3051.1578 6727.7109 1928.7116 C4(ppm) 99.206 1730.0906 3676.7168 1121.2543 C5(ppm) 33.693 1484.8812 3620.6151 985.78558 RATIO ROP INCREASE TO GAS INCREASE: 104/881 SAMPLE CUTTINGS FLUORESENCE%: 80 to 100%EVEN COLOR YELLOW-GREEN INTENSITY: DULL-MILKY CUT: STRAW-WHITE MUD FLUORESCENCE: BRIGHT YELLOW FORMATION DESCRIPTION: Sand/Sandstone(8080-8475)=Medium light gray to medium gray with some light bluish gray and translucents; loose disaggregated sand;Lower fine to upper very fine grained;Very well to well sorted; Sub-angular to sub-rounded;Moderate sphericity; Sparse amounts of pyrite and jasper;Abundant amounts of free oil on shakers; Strong petroleum odor; 100%Even greenish yellow sample fluorescence; 80-100%Medium to dark visible staining; Straw to amber visible cut;Instant moderately strong to strong intensity yellow to bright milky white sample cut fluorescence;Bright milky white sample cut fluorescence;Moderate to dark straw visible residual cut ring. SHOW RATING:(T,P,F,G) GOOD LOGGING GEOLOGIST(S): Jeffrey McBeth;Steven Pike Page 1 CANRIG SHOW REPORT NO. 3 DRILLNG Tec HNuI_ .y L I,. ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point,Alaska DEPTH INTERVAL: 8520 TO 11070 (MD) TOTAL FTG 2550 3557 TO 3546 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 135 236 385 331 WOB 10.7 5.7 29 8.5 RPM 119.2 111 123 115 MUD WT 9.3 8.5 8.5 8.5 CHLORIDE 1700 42500 44000 44000 TOTAL GAS 466 325 930 40 Cl (ppm) 111277 51919 153792 6911 C2(ppm) 2171 505 1430 89 C3(ppm) 3051 368 2517 105 C4(ppm) 1730 438 3943 137 C5(ppm) 1484 357 2561 149 RATIO ROP INCREASE TO GAS INCREASE: (250/464) SAMPLE CUTTINGS FLUORESENCE%: 40-100% COLOR YELLOW INTENSITY: MODERATE CUT: WHITE MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sand/Sandstone=Very light gray to translucent to medium gray to occasional clear grains; Individual sand grains are unconsolidated; Sandstone cuttings are easily fraible to firmly friable; Upper very fine to upper fine; Very well sorted; Sub-angular to angular to sub- rounded; Moderate sphericity; Approximately 10%fine grained black lithics; 5%moderate green to brilliant green fine grained lithics; Moderate orange pink to pale yellowish orange shell fragments. SHOW RATING: (T,P,F,G) Good LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz CANRIG SHOW REPORT NO 4 L)ILI.IN;THF NOl trtn Lri,. ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 11400 TO 11650 (MD) TOTAL FTG 250 3527 TO 3512 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE r DURING AFTER Average Maximum ROP(fph) 239 265 408 261 WOB 9.3 6.6 33 12.7 RPM 120 119 125 121 MUD WT 8.5 8.5 8.5 8.5 CHLORIDE 42500 43500 44000 44000 TOTAL GAS 151 243 377 41 Cl (ppm) 34387 55056 99559 8137 C2(ppm) 348 580 1063 84 C3(ppm) 347 419 742 64 C4(ppm) 623 528 929 79 C5(ppm) 1070 627 1522 98 RATIO ROP INCREASE TO GAS INCREASE: (169/226) SAMPLE CUTTINGS FLUORESENCE%: 30-50% COLOR YELLOW INTENSITY: DULL CUT: WHITE MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sand/Sandstone=Clear to translucent to very light gray with black to grayish to brownish to greenish hues; Sandstone is easily friable to firmly friable; Upper very fine to upper fine; Very well sorted; Sub-angular to angular; Poor to moderate sphericity. SHOW RATING: (T,P,F,G) Poor to Fair LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz CANRIG SHOW REPORT NO. 5 D)h11.1.IN,Tt.cHN ii,,y Li u. ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 11975 TO 12660 (MD) TOTAL FTG 685 3517 TO 3517 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 185 283 399 202 WOB 6.8 4.9 35 7.2 RPM 119 121 122 118 MUD WT 8.5 8.5 8.5 8.5 CHLORIDE 42500 43500 45000 4500 TOTAL GAS 30 389 610 27 Cl (ppm) 6019 75127 113792 5439 C2(ppm) 76 828 1221 80 C3(ppm) 75 593 962 138 C4(ppm) 105 700 1229 225 C5(ppm) 162 680 1603 305 RATIO ROP INCREASE TO GAS INCREASE: (214/580) SAMPLE CUTTINGS FLUORESENCE%: 5-10% COLOR INTENSITY: DULL CUT: MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sandstone/Sand =White, light gray, pale green, dusky red,with blackish red, dark gray,and black hues along with predominantly translucent to clear sand grains; Predominantly quartz grain sand matrix throughout; Lower very fine to upper fine with very little lower medium grain sand; Poorly sorted; Very angular to sub-angular,with some sub-rounded to rounded; Moderate sphericity. SHOW RATING: (T,P,F,G) Fair LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz CANRIG SHOW REPORT NO. 6 Mil LI..\(:TL(:HNOLMY Lii,. ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point,Alaska DEPTH INTERVAL: 13165 TO 14530 (MD) TOTAL FTG 1365 3547 TO 3537 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 283 251 396 244 WOB 7.9 7 30 13.4 RPM 120 116 123 120 MUD WT 8.5 8.5 8.5 8.5 CHLORIDE 43500 44000 48000 48000 TOTAL GAS 45 231 562 50 Cl (ppm) 8698 42240 11977 9761 C2(ppm) 55 401 1075 67 C3(ppm) 90 240 1140 54 C4(ppm) 91 288 2054 87 C5(ppm) 166 224 2363 72 RATIO ROP INCREASE TO GAS INCREASE: (113/517) SAMPLE CUTTINGS FLUORESENCE%: 40-100% COLOR YELLOW INTENSITY: MODERATE TO BRIGHT CUT: WHITE MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sand/Sandstone=Very light gray to clear to milky white to translucent to light gray quartz grains; Black to brownish to reddish to greenish hues; Upper very fine to upper fine; Very well sorted; Sub-angular to angular with moderate to low sphericity; Sandstone cuttings are easily friable to firmly friable; 10-15%fine grained black lithics; 5-7%moderate green to brilliant green to light bluish green fine grained lithics. SHOW RATING: (T,P,F,G) Fair LOGGING GEOLOGIST(S): Steve Pike & Emil Opitz CANRIG SHOW REPORT NO 7 DbIll.i,(;Tu.f:Hx01.,1 Ll I,. - ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 15050 TO 16180 (MD) TOTAL FTG 1130 3523 TO 3530 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 318 259 379 322 WOB 4.2 8.6 25 5.3 RPM 120 116 122 122 MUD WT 8.5 8.5 8.5 8.5 CHLORIDE 42500 43000 45000 45000 TOTAL GAS 233 227 446 251 Cl (ppm) 45045 39936 84448 46455 C2(ppm) 358 331 898 481 C3(ppm) 186 196 955 286 C4(ppm) 167 213 1452 272 C5(ppm) 89 133 1097 147 RATIO ROP INCREASE TO GAS INCREASE: (59/213) SAMPLE CUTTINGS FLUORESENCE%: 30-100% COLOR YELLOW INTENSITY: MODERATE TO BRIGHT CUT: WHITE MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sandstone/Sand =Clear to translucent with some milky white, light gray, pale green, pale blue,yellowish brown,dusky red, and black hues; Upper very fine to upper fine, with some lower medium grain sand; Moderate to poorly sorted; Very angular to sub-angular,with some sub-rounded; Moderate sphericity, Increasingly thicker beds of loose unconsolidated fine grain quartz sand. SHOW RATING: (T,P,F,G) Fair to Good LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz CANRIG SHOW REPORT NO. 8 llrarmc TeCHNOI_( L'ri,. ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 16725 TO 16875 (MD) TOTAL FTG 150 3515 TO 3503 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 198 281 398 262 WOB 7.9 7.1 19 5.4 RPM 119 115 121 117 MUD WT 8.5 8.5 8.5 8.5 CHLORIDE 44000 44000 44000 44000 TOTAL GAS 229 313 536 15 Cl (ppm) 41199 50601 86659 2203 C2(ppm) 280 565 1095 21 C3(ppm) 157 313 589 20 C4(ppm) 178 293 520 22 C5(ppm) 94 144 239 16 RATIO ROP INCREASE TO GAS INCREASE: (200/307) SAMPLE CUTTINGS FLUORESENCE%: 40-50% COLOR YELLOW INTENSITY: BRIGHT CUT: WHITE MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sandstone/Sand = Mostly translucent to clear,with light gray, green, pale blue, pale green, moderate yellowish brown, dusky red,and black hues; Upper very fine to upper fine with some lower medium sand grains; Moderate to poorly sorted;Very angular with sub-rounded; Moderate sphericity;Thicker beds of loose uncemented quartz sand,and very friable siliceous cemented sandstone, interbedded with very thin beds of sandy siltstones. SHOW RATING: (T,P,F,G) Fair LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz GANRIG SHOW REPORT NO 9 DHI.I.I\t:Tt.CHNOl M1 Ll I. ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 17300 TO 18060 (MD) TOTAL FTG 760 3486 TO 3523 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 225 259 384 263 WOB 11 7.9 18 8.2 RPM 120 119 123 120 MUD WT 8.5 8.5 8.5 8.5 CHLORIDE 44000 44000 45000 44000 TOTAL GAS 20 141 440 12 Cl (ppm) 3511 25444 80378 2463 C2(ppm) 25 258 890 30 C3(ppm) 39 176 1056 23 C4(ppm) 27 167 1137 33 C5(ppm) 10 103 1142 30 RATIO ROP INCREASE TO GAS INCREASE: (159/420) SAMPLE CUTTINGS FLUORESENCE%: 80-100% COLOR YELLOW INTENSITY: MODERATE TO BRIGHT CUT: WHITE MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sand/Sandstone=Clear to light gray to translucent to milky white with dusky reddish to light greenish to dusky yellowish hues; Predominantly upper very fine to lower fine with occasional upper fine to medium sized grains; Very well sorted; Sub-angular to angular with moderate sphericity; Fine to coarse grain sized pyrite scattered throughout interval, <1%; Fine grained black lithics, 8-10%; Approximately 5%light bluish green to brilliant green to moderate green fine grained lithics; Pale yellowish orange to moderate orange pink shell fragments; Sandstone cuttings are calcareously cemented. SHOW RATING: (T,P,F,G) Fair to Good LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz CANRIG SHOW REPORT NO. 10 0,1111M,TECHN,I_, Y L i i, ENI Petroleum OP17-02-PB1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 18500 TO 18940 (MD) TOTAL FTG 440 3484 TO 3494 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSR616M-F8 PDC bit AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 224 231 379 N/A WOB 8.5 7.4 22 N/A RPM 115 113 122 N/A MUD WT 8.5 8.5 8.5 N/A CHLORIDE 44000 44000 50000 N/A TOTAL GAS 10 109 513 N/A Cl (ppm) 2324 21193 123726 N/A C2(ppm) 51 200 924 N/A C3(ppm) 32 136 559 N/A C4(ppm) 36 140 593 N/A C5(ppm) 20 90 430 N/A RATIO ROP INCREASE TO GAS INCREASE: (155/503) SAMPLE CUTTINGS FLUORESENCE%: 100% COLOR Yellow INTENSITY: Moderate CUT: Dull white Flourescence MUD FLUORESCENCE (none) FORMATION DESCRIPTION: Sand/Sandstone= Light gray to clear to milky white to medium gray with light greenish to light bluish to reddish hues; Predominantly upper very fine to lower fine with some upper fine to medium sized grains throughout sample interval; Angular to sub-angular with moderate sphericity; Sandstone cuttings are easily friable to firmly friable; Sandstone is calcareously cemented; Fine to medium sized pyrite in samples; Very fine to fine grained black lithics. SHOW RATING: (T,P,F,G) Fair LOGGING GEOLOGIST(S): Steve Pike& Emil Opitz Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT PI EPOCH O P 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Oct 29,2010 DEPTH 0' PRESENT OPERATION Slip and cut drill line TIME 24:00:00 YESTERDAY 0' 24 HOUR FOOTAGE 0' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 0' MW 8.7 VIS 57 PV 13 YP 13 FL 15.5 Gels 10/17/23 CL- 200 FC -/3 SOL 3.0 SD - OIL 1/97 MBL 20 pH 10.0 Ca+ 80 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG - PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Work on CD unit and plumbing for CD unit.Calibrate block height,fill hole and slip and cut drill line as of midnight. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT PI EPOCH O P 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 07,2010 DEPTH 5800' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 5355' 24 HOUR FOOTAGE 445' CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5813.89 80.16 293.89 3222.13 SURVEY DATA 5715.66 79.47 293.90 3204.76 5617.59 80.94 296.01 3188.07 5518.60 77.48 292.42 3169.54 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' - 445' 7 - - 2 12 1/4" Hughes QD505XX 7131957 8x14 2265' 5355' 3090' 25.7 2-4-BT-S-X-I-CT-RP Bit Trip DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 292.6 @ 5692.0 3.3 @ 5355.0 157.0 61.17 FT/HR SURFACE TORQUE 15820 @ 5365.0 4296 @ 5441.0 9304.7 11048.32 AMPS WEIGHT ON BIT 50 @ 5356.0 0 @ 5651.0 5.7 14.99 KLBS ROTARY RPM 118 @ 5798.0 63 @ 5355.0 103.9 73.92 RPM PUMP PRESSURE 2129 @ 5671.0 1358 @ 5356.0 2033.2 2113.35 PSI DRILLING MUD REPORT DEPTH 5829' MW 9.1 VIS - PV 12 YP 26 FL 5.8 Gels 18/26/31 CL- 1500 FC 1/- SOL 4.5 SD 0.2 OIL 1/95 MBL 16 pH 9.4 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2265'TO 5800' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 24 @ 5588.0 2 @ 5375.0 10.1 TRIP GAS 55 CUTTING GAS 0 @ 5800.0 0 @ 5800.0 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 5378 @ 5624.0 579 @ 5375.0 2139.7 CONNECTION GAS HIGH - ETHANE(C-2) 0 @ 5800.0 0 @ 5800.0 0.0 AVG - PROPANE(C-3) 0 @ 5800.0 0 @ 5800.0 0.0 CURRENT- BUTANE(C-4) 0 @ 5800.0 0 @ 5800.0 0.0 CURRENT BACKGROUND/AVG 4/15 PENTANE(C-5) 0 @ 5800.0 0 @ 5800.0 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Conglomerate Sand,Siltstone PRESENT LITHOLOGY Sand 60%,Conglomerate Sand 20%,Siltstone 20% DAILY ACTIVITY Lay down BHA.Monitor the well.Pick up and make up the new BHA.Clear derrick of ice.Run in hole to bottom.Drill on hard spot at SUMMARY 5355'to 5380'.Continue drilling from 5380'to 5800'md with no issues. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 08,2010 DEPTH 7325.00000 PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 5800.00000 24 HOUR FOOTAGE 1525 CASING INFORMATION 20"@ 160' 13 3/8"@ 2249 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7290.29 81.79 302.46 3464.38 SURVEY DATA 7192.1 80.19 301.97 3449.01 7094.56 80.42 298.37 3432.58 6995.4 80.34 296.51 3416 6897.56 79.87 294.7 3399.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' - 1970' 31 - 2 12 1/4" Hughes QD505XX 7131957 8x14 2265' 5355' 3090' 25.7 2-4-BT-S-X-I-CT-RP Bit Trip DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1710.4 @ 6479.00000 13.0 @ 7253.00000 126.4 146.57 FT/HR SURFACE TORQUE 17764 @ 6468.00000 6456 @ 6172.00000 10608.0 11135.07 AMPS WEIGHT ON BIT 26 @ 6773.00000 0 @ 6990.00000 9.4 10.21 KLBS ROTARY RPM 123 @ 6419.00000 46 @ 6448.00000 112.5 116.46 RPM PUMP PRESSURE 2453 @ 7161.00000 1101 @ 6487.00000 2234.3 0.00000 PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 13 YP 23 FL 5.5 Gels 11/24/27 CL- 1300 FC 1/- SOL 5.0 SD 0.1 OIL 2/94 MBL 14 pH 9.5 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2265'TO 7325 TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 383 @ 6986.00000 1 @ 5844.00000 53.1 TRIP GAS - CUTTING GAS 0 @ 7263.00000 0 @ 7263.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY - METHANE(C-1) 223421 @ 6986.00000 352 @ 5844.00000 23604.4 CONNECTION GAS HIGH- ETHANE(C-2) 2888 @ 6986.00000 0 @ 6684.00000 269.5 AVG- PROPANE(C-3) 781 @ 6986.00000 0 @ 6811.00000 79.0 CURRENT- BUTANE(C-4) 1913 @ 6986.00000 0 @ 6811.00000 177.6 CURRENT BACKGROUND/AVG 54/172 PENTANE(C-5) 1044 @ 6986.00000 0 @ 6811.00000 103.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 80%,Sandstone 20% DAILY ACTIVITY SUMMARY Drilling ahead from 5800'-7290'MD with no issues/no losses to formation. EPOCH PERSONNEL ON BOARD 4 DAILY COST$4430; Rigwatch -$1450 REPORT BY J. McBeth file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nov09,2010 DAILY WELLSITE REPORT PI EPOCH OP17-02 REPORT FOR DATE Nov 10,2010 DEPTH 8520.00000 PRESENT OPERATION Circulating TIME 24:00:00 YESTERDAY 7325.00000 24 HOUR FOOTAGE 1195 CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8441.65 87.26 316.84 3552.53 SURVEY DATA 8369.56 87.26 317.16 3549.09 8272.63 87.09 316.61 3544.31 8174.73 85.97 315.48 3538.38 8077.2 85.57 315.22 3531.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' - 3165' 34.07 - 2 12 1/4" Hughs QD505XX 7131957 8x14 2265' 5355' 3090' 25.7 2-4-BT-S-X-I-CT-RP Bit Trip DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 202.0 @ 8451.00000 2.5 @ 8124.00000 109.9 166.83492 FT/HR SURFACE TORQUE 18899 @ 8488.00000 8839 @ 7498.00000 12680.3 15157.25098 AMPS WEIGHT ON BIT 50 @ 8051.00000 1 @ 8116.00000 12.2 5.99420 KLBS ROTARY RPM 125 @ 8308.00000 55 @ 8127.00000 119.1 122.60217 RPM PUMP PRESSURE 2919 @ 8365.00000 1775 @ 7524.00000 2637.8 2830.27148 PSI DRILLING MUD REPORT DEPTH MW 9.3 VIS - PV 15 YP 20 FL 5.3 Gels 13/25/30 CL- 1700 FC 1/- SOL 6 SD .2 OIL 2/93 MBL 15 pH 9.5 Ca+ 80 CCI - MWD SUMMARY INTERVAL 7325 TO 8520 TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 924 @ 8409.00000 13 @ 7822.00000 209.8 TRIP GAS - CUTTING GAS 0 @ 8520.00000 0 @ 8520.00000 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 223477 @ 8412.00000 3979 @ 7562.00000 51344.1 CONNECTION GAS HIGH - ETHANE(C-2) 5402 @ 8397.00000 0 @ 7679.00000 941.3 AVG - PROPANE(C-3) 6727 @ 8402.00000 0 @ 7679.00000 1306.4 CURRENT- BUTANE(C-4) 8906 @ 8499.00000 0 @ 7679.00000 1812.6 CURRENT BACKGROUND/AVG 80/200 PENTANE(C-5) 6379 @ 8504.00000 2 @ 7681.00000 1086.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone,Sand,Siltstone PRESENT LITHOLOGY Sandstone 70%,Sand 30%,Siltstone 10% DAILY ACTIVITY SUMMARY Drilled ahead to 8520'MD with no losses and no issues.Circulating 5X BU @ TD. EPOCH PERSONNEL ON BOARD 4 DAILY COST$4430; Rigwatch -$1450 REPORT BY J. McBeth file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 10,2010 DEPTH 8520' PRESENT OPERATION Laying down BHA TIME 24:00:00 YESTERDAY 8520' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2249 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8441.65 87.26 316.84 3552.53 SURVEY DATA 8369.56 87.26 317.16 3549.09 8272.693 87.09 316.61 3544.312 8174.73 85.97 315.48 3538.38 8077.2 85.57 315.22 3531.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' - 3165' 34.07 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ 1775 @ PSI DRILLING MUD REPORT DEPTH 8520 MW 9.2 VIS - PV 11 YP 16 FL 5.8 Gels 6/15/23 CL- 1200 FC 1/- SOL 5 SD .1 OIL 1/94 MBL 17 pH 9.6 Ca+ 40 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) / @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone,Sand,Siltstone PRESENT LITHOLOGY Sandstone 70%,Sand 30%,Siltstone 10% DAILY ACTIVITY Circulate and condition 5X BU.Backream from 8051-shoe @ 2249'.Circulate and condition 2.5X BU @900 gpm.1300 psi.POOH on SUMMARY elevators.LD BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY J. McBeth file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH O P 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 11,2010 DEPTH 8520' PRESENT OPERATION RIH Casing TIME 24:00:00 YESTERDAY 8520' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2249 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8441.65 87.26 316.84 3552.53 SURVEY DATA 8369.56 87.26 317.16 3549.09 8272.693 87.09 316.61 3544.312 8174.73 85.97 315.48 3538.38 8077.2 85.57 315.22 3531.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' 8520' 3165' 34.07 2-4-CT-A-X-I-BT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ 1775 @ PSI DRILLING MUD REPORT DEPTH 8520 MW 9.1 VIS - PV 12 YP 15 FL 5.5 Gels 7/14/25 CL- 1700 FC 1/- SOL 5.5 SD .1 OIL 1/93 MBL 16 pH 9.6 Ca+ 80 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) / @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone,Sand,Siltstone PRESENT LITHOLOGY Sandstone 70%,Sand 30%,Siltstone 10% DAILY ACTIVITY LD BHA.PU test tools.Test BOPS's.10.74"rams failed.Installed new rubbers and retest 250/3500 for 5 mins ea.LD test tools.RU to run SUMMARY casing.Run 9.625"casing as per running order to shoe.Circulate 5X BU @5 bpm/150 psi. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY J. McBeth file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\OP17-0... Daily Report ENI Petroleum DAILY WELLSITE REPORT PI EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 12,2010 DEPTH 8520' PRESENT OPERATION RIH Casing TIME 24:00:00 YESTERDAY 8520' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2249 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8441.65 87.26 316.84 3552.53 SURVEY DATA 8369.56 87.26 317.16 3549.09 8272.693 87.09 316.61 3544.312 8174.73 85.97 315.48 3538.38 8077.2 85.57 315.22 3531.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8520 MW 9.1 VIS - PV 9 VP 12 FL - Gels 4/11/13 CL- - FC - SOL - SD - OIL - MBL - pH 7.4 Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 123 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) / @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone,Sand,Siltstone PRESENT LITHOLOGY Sandstone 70%,Sand 30%,Siltstone 10% DAILY ACTIVITY Run casing break circulation every 200'.LD Franks tool and MU cement head.Test lines to 3000 psi.Pump 70 bbls/10.5 ppg mud push.Drop SUMMARY plug.Pump 300 bbls 12.5 ppg cement.Drop plug and displace with rig pumps @ 330 gpm/650 psi.Bumped plug at 6150 stx.RD cement and csg equip.Set and test Pack Off to 5000 psi.Freeze protect 150 bbls @ 2 bbls/min 1350 psi. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY J. McBeth file://C:\Documents and Settings\EpochAdmin\Desktop\20101112.htm Daily Report ENI Petroleum DAILY WELLSITE REPORT El I EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 13,2010 DEPTH 8520 PRESENT OPERATION P/U Pipe TIME 24:00:00 YESTERDAY 8520 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8441.65 87.26 316.84 3552.53 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' 8520' 3165' 34 2-4-CT-A-X-I-BT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.1 VIS - PV 9 YP 12 FL - Gels 4/11/13 CL- - FC -/- SOL - SD - OIL - MBL - pH 7.4 Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Change top RAM's to 7".Test BOP's to 3500 psi for 5 min.Good.Install wear ring.L/D drill pipe sucking each joint out before laying SUMMARY down.Pick up D/P. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT Li EPOCIEII OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Nov 14,2010 DEPTH 8520 PRESENT OPERATION P/U Pipe TIME 24:00:00 YESTERDAY 8520 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8441.65 87.26 316.84 3552.53 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 227102 6x16 5355' 8520' 3165' 34 2-4-CT-A-X-I-BT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.1 VIS - PV 9 YP 12 FL - Gels 4/11/13 CL- - FC -/- SOL - SD - OIL - MBL - pH 7.4 Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Cut&Slip drilling line.Service Top Drive,drawworks,crown.BOP testing.P/U drill pipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El I EPOCH O P 17-02 REPORT FOR Keener/Smith/Buchanan DATE Nov 15,2010 DEPTH 8520 PRESENT OPERATION Work on Elmago brake TIME 24:00:00 YESTERDAY 8520 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.1 VIS - PV 8 YP 13 FL - Gels 4/10/- CL- - FC -/- SOL - SD - OIL - MBL - pH - Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY P/U DP singles and stand back.Drawworks elmago brake broke down.Waiting on replacement from Deadhorse to arrive. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML- $2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT 11 EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Nov 16,2010 DEPTH 8520 PRESENT OPERATION Replace/Repair Elmago Brake TIME 24:00:00 YESTERDAY 8520 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.4 VIS - PV 16 YP 8 FL - Gels 3/8/- CL- 22000 FC - SOL 9 SD - OIL 72 MBL - pH - Ca+ .65 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue replacing/repairing Elmago brake. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Oct 30,2010 DEPTH 747' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 0' 24 HOUR FOOTAGE 747' CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 732.25 6.73 230.05 730.72 SURVEY DATA 698.9 6.07 223.69 697.58 635.2 5.61 212.12 634.21 543.0 4.22 188.83 542.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Smith XR+6C PS3158 1x16,3x20 0 - 747' 12.1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 236.5 @ 270.00000 17.8 @ 614.00000 70.2 84.55580 FT/HR SURFACE TORQUE 13962 @ 511.00000 0 @ 597.00000 427.7 0.00000 AMPS WEIGHT ON BIT 25 @ 680.00000 -11 @ 275.00000 7.5 20.35096 KLBS ROTARY RPM 43 @ 666.00000 0 @ 616.00000 7.9 0.00039 RPM PUMP PRESSURE 994 @ 712.00000 428 @ 215.00000 487.6 836.63898 PSI DRILLING MUD REPORT DEPTH 747' MW 9.0 VIS 55 PV 17 YP 22 FL 13.5 Gels 15/26/30 CL- 400 FC 3/- SOL 3.0 SD 0.2 OIL 1/97 MBL 20 pH 9.0 Ca+ 160 CCI - MWD SUMMARY INTERVAL 0'TO 747' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1 @ 497.00000 0 @ 717.00000 0.4 TRIP GAS- CUTTING GAS 0 @ 747.00000 0 @ 747.00000 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 0 @ 747.00000 0 @ 747.00000 0.0 CONNECTION GAS HIGH - ETHANE(C-2) 0 @ 747.00000 0 @ 747.00000 0.0 AVG - PROPANE(C-3) 0 @ 747.00000 0 @ 747.00000 0.0 CURRENT - BUTANE(C-4) 0 @ 747.00000 0 @ 747.00000 0.0 CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) 0 @ 747.00000 0 @ 747.00000 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Pick up 5"HWDP and stand back in derrick.Pick up BHA for cleaning out the conductor and rat hole for drilling BHA.Pick up drilling SUMMARY BHA and drill from 160'to 747'as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH O P 17-02 REPORT FOR Keener/Smith/Buchanan DATE Nov 17,2010 DEPTH 8520 PRESENT OPERATION RIH TIME 24:00:00 YESTERDAY 8520 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.4 VIS - PV 16 YP 8 FL - Gels 3/8/- CL- 22000 FC - SOL 9 SD - OIL 72 MBL - pH - Ca+ 0.65 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Finish testing Elmago brake.Calibrate Blocks.P/U and M/U BHA,RIH.Test MWD tools.Pressure test casing.Waiting on weather SUMMARY conditions;currently Phase III. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT E I EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Nov 18,2010 DEPTH 9080 PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 8520 24 HOUR FOOTAGE 560 CASING INFORMATION 13 3/8"@ 2249'9 5/8"g 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 311.9 @ 9013.00000 10.1 @ 8539.00000 213.3 220.49022 FT/HR SURFACE TORQUE 15157 @ 8520.00000 4671 @ 8537.00000 6545.1 6780.58789 AMPS WEIGHT ON BIT 23 @ 9006.00000 0 @ 9027.00000 5.6 1.60843 KLBS ROTARY RPM 122 @ 8520.00000 48 @ 8522.00000 87.4 119.47724 RPM PUMP PRESSURE 2830 @ 8520.00000 1732 @ 8541.00000 2500.1 2717.46484 PSI DRILLING MUD REPORT DEPTH 8720 MW 8.5 VIS 83 PV 24 YP 14 FL - Gels 12/16/19 CL- 42500 FC - SOL 6.35 SD - OIL 76/24 MBL - pH - Ca+ 1.5 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 455 @ 8658.00000 1 @ 8540.00000 244.4 TRIP GAS CUTTING GAS 0 @ 9080.00000 0 @ 9080.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 94658 @ 8658.00000 37 @ 8540.00000 47682.9 CONNECTION GAS HIGH ETHANE(C-2) 1286 @ 8520.00000 0 @ 8540.00000 373.3 AVG PROPANE(C-3) 2517 @ 8520.00000 0 @ 8537.00000 209.7 CURRENT BUTANE(C-4) 3943 @ 8520.00000 0 @ 8537.00000 183.2 CURRENT BACKGROUND/AVG 36 PENTANE(C-5) 2561 @ 8520.00000 0 @ 8537.00000 71.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone,Siltstone,Shell Fragments,Shale PRESENT LITHOLOGY 70%Sand;20%Sandstone;10%Siltstone DAILY ACTIVITY Displace to OBM.Drill out cement to 8550'.Prepare for and conduct LOT.LOT performed to 12.8 ppg.Service Top Drive.RIH and SUMMARY Drill ahead. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 19,2010 DEPTH 11420 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 9080 24 HOUR FOOTAGE 2340 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11695.58 91.63 320.08 3507.99 11597.91 92.32 320.76 3511.35 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 408.4 @ 11410.00000 15.3 @ 9506.00000 248.5 325.07236 FT/HR SURFACE TORQUE 11991 @ 10893.00000 6159 @ 9124.00000 8577.2 9911.17090 AMPS WEIGHT ON BIT 29 @ 9299.00000 0 @ 10899.00000 6.3 9.38374 KLBS ROTARY RPM 123 @ 9302.00000 67 @ 9547.00000 117.8 117.60076 RPM PUMP PRESSURE 3177 @ 11412.00000 2138 @ 9439.00000 2834.3 3167.25024 PSI DRILLING MUD REPORT DEPTH MW 8.5 VIS 86 PV 23 YP 13 FL 7.5 Gels 15/20/23 CL- 43500 FC NA/2 SOL 6.28 SD - OIL 78/22 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 9080 TO 11420 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 930 @ 9929.00000 11 @ 11196.00000 306.7 TRIP GAS CUTTING GAS 0 @ 11420.00000 0 @ 11420.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 153792 @ 9587.00000 1839 @ 10876.00000 48620.0 CONNECTION GAS HIGH ETHANE(C-2) 1430 @ 9587.00000 19 @ 10871.00000 500.5 AVG PROPANE(C-3) 1411 @ 10349.00000 12 @ 10871.00000 397.6 CURRENT BUTANE(C-4) 2200 @ 10348.00000 12 @ 10871.00000 505.2 CURRENT BACKGROUND/AVG 14 PENTANE(C-5) 2841 @ 11326.00000 10 @ 10871.00000 474.4 HYDROCARBON SHOWS 2 zones INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9080-11060;11400-11650 Primarily Sand and Sandstone,occasionally Siltstone and Shale laminations Max 930u @ 9929' LITHOLOGY Sand,Sandstone,Shale,Siltstone PRESENT LITHOLOGY 30%Sand,20%Sandstone,30%Shale,20%Siltstone DAILY ACTIVITY SUMMARY Continue drilling ahead from 9080 to 11420. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\IVIY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT PI EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 20,2010 DEPTH 13824 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 11420 24 HOUR FOOTAGE 2404 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13760.10 89.42 315.46 3558.77 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 387.4 @ 13144.00000 23.8 @ 13784.00000 252.5 310.37265 FT/HR SURFACE TORQUE 15020 @ 12626.00000 8342 @ 11661.00000 10968.4 11352.25586 AMPS WEIGHT ON BIT 35 @ 12249.00000 0 @ 13431.00000 6.9 6.68101 KLBS ROTARY RPM 125 @ 11564.00000 80 @ 13481.00000 118.6 120.50219 RPM PUMP PRESSURE 3463 @ 12751.00000 2198 @ 11617.00000 3187.7 3082.40454 PSI DRILLING MUD REPORT DEPTH 11098 MW 8.5 VIS 73 PV 20 YP 11 FL 6.8 Gels 12/16/21 CL- 46500 FC -/2 SOL 6.14 SD - OIL 78/22 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 11420 TO 13824 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 610 @ 12607.00000 4 @ 13628.00000 218.2 TRIP GAS CUTTING GAS 0 @ 13824.00000 0 @ 13824.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 113792 @ 12606.00000 969 @ 13628.00000 43022.1 CONNECTION GAS HIGH ETHANE(C-2) 1221 @ 12607.00000 9 @ 13628.00000 461.7 AVG PROPANE(C-3) 1140 @ 13777.00000 4 @ 13628.00000 334.6 CURRENT BUTANE(C-4) 2054 @ 13778.00000 4 @ 13628.00000 409.8 CURRENT BACKGROUND/AVG 21 PENTANE(C-5) 2363 @ 13778.00000 2 @ 13628.00000 424.7 HYDROCARBON SHOWS 3 zones INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11420-11660;11975-12660;13165- Primarily disaggregated Sands and Sandstone cuttings.Sandstone cuttings often Max 610u @ 13824 grade to Siltstone. 12607' LITHOLOGY Sand,Sandstone,Siltstone,Shale PRESENT LITHOLOGY 60%Sand;20%Sandstone;20%Siltstone DAILY ACTIVITY SUMMARY Drilled ahead from 11420'to 13824'.Re-Calibrated gas detection equipment. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT Ell EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 21,2010 DEPTH 15910 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 13824 24 HOUR FOOTAGE 2086 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 16026.71 89.74 291.82 3529.93 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 373.0 @ 15013.00000 8.4 @ 15794.00000 254.3 265.04941 FT/HR SURFACE TORQUE 18557 @ 15874.00000 9675 @ 14289.00000 13165.8 14575.71387 AMPS WEIGHT ON BIT 30 @ 13923.00000 0 @ 14725.00000 7.8 2.35415 KLBS ROTARY RPM 122 @ 14888.00000 61 @ 13827.00000 116.0 121.26177 RPM PUMP PRESSURE 3449 @ 15811.00000 1985 @ 14718.00000 3175.2 3407.39697 PSI DRILLING MUD REPORT DEPTH MW 8.5 VIS 72 PV 19 YP 10 FL - Gels 13/18/21 CL- 45000 FC -/- SOL 6.83 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 13824 TO 15910 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 562 @ 13824.00000 0 @ 14081.00000 218.3 TRIP GAS CUTTING GAS 0 @ 15910.00000 0 @ 15910.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 85584 @ 13824.00000 74 @ 14081.00000 37733.1 CONNECTION GAS HIGH ETHANE(C-2) 777 @ 13824.00000 0 @ 14080.00000 305.9 AVG PROPANE(C-3) 389 @ 13824.00000 0 @ 14080.00000 165.5 CURRENT BUTANE(C-4) 427 @ 15639.00000 0 @ 14080.00000 181.3 CURRENT BACKGROUND/AVG 8 PENTANE(C-5) 335 @ 14648.00000 0 @ 14080.00000 104.8 HYDROCARBON SHOWS 2 zones INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 13824-14520;15050-15790 Primarily disaggregated Sands,as well as Sandstone that grades to Silty Sandstone and Sandy Siltstone. Max 562 LITHOLOGY Sand,Sandstone,Siltstone PRESENT LITHOLOGY 50%Sand;30%Sandstone;20%Siltstone DAILY ACTIVITY SUMMARY Drilling Ahead from 13824.Issues with pump pressure,cleaned suction screens to pumps @ 14138'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\IVIY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 22,2010 DEPTH 17760 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 15910 24 HOUR FOOTAGE 1850 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 17696.36 83.85 293.37 3510.93 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 397.9 @ 16827.00000 13.8 @ 16103.00000 261.7 26.30568 FT/HR SURFACE TORQUE 23601 @ 16782.00000 13557 @ 16362.00000 16605.2 22684.36914 AMPS WEIGHT ON BIT 25 @ 16090.00000 0 @ 17369.00000 8.1 17.77280 KLBS ROTARY RPM 123 @ 17484.00000 80 @ 17009.00000 118.2 83.68187 RPM PUMP PRESSURE 3624 @ 16100.00000 2223 @ 17007.00000 3189.4 3425.72046 PSI DRILLING MUD REPORT DEPTH 17607 MW 8.5 VIS 71 PV 20 YP 11 FL - Gels 14/20/24 CL- 43500 FC -/- SOL 6.56 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 15910 TO 17760 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 536 @ 16798.00000 1 @ 17618.00000 160.3 TRIP GAS CUTTING GAS 0 @ 17760.00000 0 @ 17760.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 86659 @ 16744.00000 332 @ 17618.00000 27714.3 CONNECTION GAS HIGH ETHANE(C-2) 1095 @ 16798.00000 3 @ 17617.00000 281.4 AVG PROPANE(C-3) 1056 @ 17744.00000 1 @ 17617.00000 175.6 CURRENT BUTANE(C-4) 1452 @ 16177.00000 1 @ 17617.00000 175.5 CURRENT BACKGROUND/AVG 14 PENTANE(C-5) 1142 @ 17744.00000 0 @ 17617.00000 104.7 HYDROCARBON SHOWS 4 zones INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 15900-16080;16720-16880:17300-17475; Primarily disaggregated Sands and Sandstone.Sandstone grades to Silty Sandstone Max 17670-17745 and Sandy Siltstone. 536u LITHOLOGY Sand,Sandstone,Siltstone PRESENT LITHOLOGY 80%Sand;10%Sandstone;10%Siltstone;scattered Shell Fragments DAILY ACTIVITY SUMMARY Drill ahead from 15910'.Work on cable for survey tools @ 17664'.Resume drilling. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2980; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum (� DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 23,2010 DEPTH 18940 PRESENT OPERATION Circulate and Condition TIME 24:00:00 YESTERDAY 17760 24 HOUR FOOTAGE 1180 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 384.2 @ 17827.00000 18.8 @ 18708.00000 249.2 260.91547 FT/HR SURFACE TORQUE 26696 @ 17804.00000 16615 @ 18406.00000 19882.9 18529.51172 AMPS WEIGHT ON BIT 22 @ 18908.00000 0 @ 17850.00000 8.2 2.16638 KLBS ROTARY RPM 122 @ 17782.00000 79 @ 18600.00000 116.4 119.56830 RPM PUMP PRESSURE 3564 @ 18287.00000 2786 @ 18634.00000 3193.6 3130.87939 PSI DRILLING MUD REPORT DEPTH 18940 MW 8.5 VIS 72 PV 19 YP 10 FL - Gels 13/20/24 CL- 50000 FC -/- SOL 8.3 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 17760 TO 18940 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 514 @ 18829.00000 4 @ 18374.00000 81.5 TRIP GAS CUTTING GAS 0 @ 18939.00000 0 @ 18939.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 123726 @ 18543.00000 526 @ 18376.00000 15469.3 CONNECTION GAS HIGH ETHANE(C-2) 3219 @ 18406.00000 9 @ 18309.00000 206.3 AVG PROPANE(C-3) 2048 @ 18406.00000 11 @ 18270.00000 141.3 CURRENT BUTANE(C-4) 2324 @ 18406.00000 14 @ 18846.00000 156.9 CURRENT BACKGROUND/AVG 10 PENTANE(C-5) 1335 @ 18406.00000 0 @ 18310.00000 101.2 HYDROCARBON SHOWS 3 zones INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 17820-18050;18490-18590;18680- Primarily disaggregated Sands and Sandstone/Sandstone continually grades into Silty Max 18940 Sandstone and Sandy Siltstone. 514u LITHOLOGY Sand,Sandstone,Siltstone PRESENT LITHOLOGY 40%Sand;30%Sandstone;20%Siltstone DAILY ACTIVITY SUMMARY Drill ahead to TD of 18940',Circulate and condition mud. EPOCH PERSONNEL ON BOARD 5 DAILY COST DML-$3080; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El I EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 24,2010 DEPTH 18940 PRESENT OPERATION Backreaming TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.7 VIS 68 PV 19 YP 9 FL - Gels 13/21/23 CL- 50000 FC -/- SOL 6.73 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 6 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Circulate 7x botoms up to clean hole.Weight up mud to 8.7 to stop flow.Backreaming to 15760'as of midnight. EPOCH PERSONNEL ON BOARD 5 DAILY COST DML-$3080; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 25,2010 DEPTH 18940 PRESENT OPERATION Backreaming TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.8 VIS 68 PV 20 YP 8 FL 7.1 Gels 12/21/23 CL- 50000 FC -/2 SOL 6.64 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue backreaming out of hole to intermediate casing shoe.Tight spots @ 13215,12835,and 12780-12650. EPOCH PERSONNEL ON BOARD 5 DAILY COST DML-$3080; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPcCIH OP 17-02 REPORT FOR Keener/Goerlich/Buchanan DATE Nov 26,2010 DEPTH 18940 PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.7 VIS 67 PV 17 YP 9 FL - Gels 11/20/22 CL- 50000 FC -/- SOL 6.64 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continued backreaming out of hole to casing shoe©8500'.RIH and hit hard spot @ 11180'.Tried to pump and rotate through,orient SUMMARY directional tools high side per DD.Didn't work.Drill ahead from 11175'to 11269'trying to get back to old hole.Didn't work.Resume backreaming out of hole. EPOCH PERSONNEL ON BOARD 5 DAILY COST DML-$3080; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Oct 31,2010 DEPTH 2240' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 747' 24 HOUR FOOTAGE 1493' CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2182.5 29.12 288.91 2112.12 SURVEY DATA 2133.58 28.87 288.26 2069.33 2037.51 26.62 286.39 1984.31 1941.46 23.02 285.87 1897.15 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16' Smith XR+6C PS3158 1x16,3x20 0' - 2240' 24.9 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 557.4 @ 1283.00000 23.4 @ 923.00000 128.7 79.71857 FT/HR SURFACE TORQUE 14027 @ 1941.00000 0 @ 1900.00000 1787.9 1.36487 AMPS WEIGHT ON BIT 44 @ 2214.00000 0 @ 1341.00000 15.7 16.96365 KLBS ROTARY RPM 44 @ 841.00000 0 @ 798.00000 22.4 0.00000 RPM PUMP PRESSURE 1574 @ 2038.00000 729 @ 749.00000 1146.9 1413.45618 PSI DRILLING MUD REPORT DEPTH 2240' MW 9.2 VIS 84 PV 21 YP 23 FL 7 Gels 14/30/41 CL- 350 FC 2/- SOL 2.5 SD 0.2 OIL 1/97 MBL 15 pH 9.1 Ca+ 100 CCI - MWD SUMMARY INTERVAL 0'TO 2240' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 170 @ 1520.00000 0 @ 980.00000 37.3 TRIP GAS - CUTTING GAS 0 @ 2240.00000 0 @ 2240.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 39469 @ 1520.00000 26 @ 1061.00000 8805.7 CONNECTION GAS HIGH - ETHANE(C-2) 14 @ 1750.00000 0 @ 1201.00000 3.4 AVG - PROPANE(C-3) 18 @ 1750.00000 0 @ 1301.00000 1.0 CURRENT- BUTANE(C-4) 8 @ 1506.00000 0 @ 1547.00000 0.1 CURRENT BACKGROUND/AVG 0/60 PENTANE(C-5) 0 @ 2240.00000 0 @ 2240.00000 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Conglomeratic Sand,Claystone PRESENT LITHOLOGY Sand 60%,Conglomeratic Sand 20%,Claystone 20% DAILY ACTIVITY SUMMARY Continue drilling ahead from 747'to 2240'MD with no issues.High gas for the day was 170u. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch - $1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT E I EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 27,2010 DEPTH 18940 PRESENT OPERATION Lay down BHA TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.6 VIS 83 PV 24 YP 13 FL - Gels 17/27/29 CL- 50500 FC -1- SOL 7.3 SD - OIL 81/19 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to POOH,laying down bad joints. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El I EPOCIE[ OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 28,2010 DEPTH 18940 PRESENT OPERATION Service Top Drive TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 18940 10420 59.11 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.6 VIS 82 PV 25 YP 12 FL - Gels 17/26/29 CL- 50000 FC -/- SOL 8.3 SD - OIL 81/19 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY UD BHA.Rig up for BOP tests.Blind RAMs failed.Replace rubbers on blind RAMs and reinstall.BOP test OK.Work on Saver Sub SUMMARY and Wash Pipe on Top Drive. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT I EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 29,2010 DEPTH 18940 PRESENT OPERATION P/U 4.5"DP TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 18940 10420 59.11 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.6 VIS 83 PV 24 YP 13 FL - Gels 17/25/28 CL- 50000 FC -/- SOL 8.3 SD - OIL 81/19 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY LD bad 5"joints.Change out swivel packing.Trip in hole and POOH LD DP removing CD valves. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 30,2010 DEPTH 18940 PRESENT OPERATION Rack back DP TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 18940 10420 59.11 2-2-WT-A-X-I-BT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.9 VIS 86 PV 26 YP 12 FL - Gels 18/25/29 CL- 48000 FC -/- SOL 6.91 SD - OIL 81/19 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY P/U and L/D DP flagging bad joints.Install CD subs. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Dec 1,2010 DEPTH 18940 PRESENT OPERATION PU 4.5"DP TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 Hycalog RSR616M-F8 227030 6x14 8520 18940 10420 59.11 2-2-WT-A-X-I-BT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.6 VIS 85 PV 25 YP 12 FL - Gels 17/25/28 CL- 49000 FC -/- SOL 8.35 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PU 51 joints of 5"DP.Test BOP's.PU 4.5"DP. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT 1E1 EPOCH OP 17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Dec 2,2010 DEPTH 18940 PRESENT OPERATION Calibrate blocks TIME 24:00:00 YESTERDAY 18940 24 HOUR FOOTAGE 0 CASING INFORMATION 13/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8000 MW 9.2 VIS 73 PV 21 YP 9 FL 6.8 Gels 12/22/24 CL- 49000 FC -/2 SOL 11.93 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Finish picking up 4.5"DP.Circulate and condition mud up to 9.2ppg as per mud engineer.POOH.Make up BHA and run in hole.Cut SUMMARY and slip drill line.Calibrate blocks. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El I EPOCH O P 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 3,2010 DEPTH 9502 PRESENT OPERATION Service Top Drive TIME 24:00:00 YESTERDAY 9502 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.3 VIS 73 PV 22 YP 9 FL 6.6 Gels 14/22/24 CL- 50000 FC -/1 SOL 11.93 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Service Top Drive.RIH on elevators to 9448'.Attempt open hole sidetrack beginning @ 9475'.POOH to shoe to fix Top Drive. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 04,2010 DEPTH 10145 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 9502 24 HOUR FOOTAGE 643 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10173.07 90.23 321.31 3553.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 356.9 @ 10137.00000 1.7 @ 9507.00000 268.6 219.38936 FT/HR SURFACE TORQUE 11268 @ 10099.00000 5757 @ 9505.00000 7517.9 9292.07617 AMPS WEIGHT ON BIT 38 @ 9841.00000 0 @ 9504.00000 5.3 9.83943 KLBS ROTARY RPM 122 @ 10039.00000 80 @ 9725.00000 119.4 118.47707 RPM PUMP PRESSURE 3504 @ 9504.00000 2551 @ 9905.00000 3242.5 3339.14551 PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS 70 PV 20 YP 8 FL 6.2 Gels 15/24/25 CL- 44000 FC -/1 SOL 11.88 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 582 @ 9816.00000 2 @ 9502.00000 316.1 TRIP GAS CUTTING GAS 0 @ 10145.00000 0 @ 10145.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 93806 @ 9816.00000 558 @ 9502.00000 51014.9 CONNECTION GAS HIGH ETHANE(C-2) 1039 @ 10068.00000 4 @ 9502.00000 539.7 AVG PROPANE(C-3) 618 @ 10068.00000 2 @ 9502.00000 304.1 CURRENT BUTANE(C-4) 509 @ 10068.00000 2 @ 9502.00000 236.7 CURRENT BACKGROUND/AVG 26 PENTANE(C-5) 223 @ 10068.00000 0 @ 9645.00000 96.0 HYDROCARBON SHOWS OA Sand INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9502-10145 Sand and Sandstone with Sandstone occasionally grading to Silty Sandstone and Sandy Siltstone. Max 582u LITHOLOGY Sand,Sandstone,Siltstone,Shale PRESENT LITHOLOGY 80%Sand;10%Sandstone;10%Siltstone DAILY ACTIVITY SUMMARY Repair Top Drive.Replace encoder.Remove wash pipe and bounce bearing,then replace.Trip in hole and drill ahead. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch - $1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Ell DAILY WELLSITE REPORT EPOCIE[ OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 07,2010 DEPTH 12401 PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 10145 24 HOUR FOOTAGE 2256 CASING INFORMATION 9 5/8"@ 2249' 13 3/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12337.61 89.18 320.89 3540.0 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 353.9 @ 10637.00000 16.3 @ 11486.00000 209.0 37.88192 FT/HR SURFACE TORQUE 14909 @ 12400.00000 6606 @ 10262.00000 8606.3 14909.85840 AMPS WEIGHT ON BIT 35 @ 11712.00000 0 @ 12130.00000 4.9 14.12531 KLBS ROTARY RPM 123 @ 11376.00000 68 @ 10519.00000 118.8 82.77962 RPM PUMP PRESSURE 3852 @ 12171.00000 2638 @ 10488.00000 3513.5 3654.71582 PSI DRILLING MUD REPORT DEPTH 12300 MW 9.2 VIS 69 PV 20 YP 9 FL - Gels 15/23/25 CL- 64000 FC -/- SOL 11.65 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 10145 TO 12401 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 553 @ 10664.00000 0 @ 10740.00000 210.5 TRIP GAS CUTTING GAS 0 @ 12400.00000 0 @ 12400.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 114704 @ 10845.00000 37 @ 10740.00000 41174.6 CONNECTION GAS HIGH ETHANE(C-2) 1187 @ 10845.00000 0 @ 10740.00000 448.7 AVG PROPANE(C-3) 930 @ 11539.00000 0 @ 10740.00000 318.3 CURRENT BUTANE(C-4) 1150 @ 11774.00000 0 @ 10740.00000 322.6 CURRENT BACKGROUND/AVG 15 PENTANE(C-5) 872 @ 11774.00000 0 @ 10740.00000 174.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10145-12401 Primarily Sandstone and Unconsolidated Sands.Sandstone occasionally grades to Silty Sandstone and Max Sandy Siltstone. 553u LITHOLOGY Sand,Sandstone,Siltstone,Shale PRESENT LITHOLOGY 50%Sand;20%Sandstone;30%Siltstone DAILY ACTIVITY SUMMARY Change out bad sub.Changed out SLB sensor.Drilling ahead. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML- $3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT Li EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 06,2010 DEPTH 14631 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 12401 24 HOUR FOOTAGE 2230 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 14600.17 91.15 306.65 3541.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 414.5 @ 14476.00000 7.6 @ 13103.00000 272.1 340.78772 FT/HR SURFACE TORQUE 18849 @ 14063.00000 41 @ 12930.00000 11231.8 12189.35156 AMPS WEIGHT ON BIT 21 @ 13189.00000 0 @ 13922.00000 6.2 3.70890 KLBS ROTARY RPM 122 @ 14599.00000 60 @ 13009.00000 117.6 121.48465 RPM PUMP PRESSURE 3824 @ 13727.00000 2813 @ 13002.00000 3588.6 3750.73315 PSI DRILLING MUD REPORT DEPTH 14480 MW 9.2 VIS 68 PV 19 YP 9 FL - Gels 12/22/23 CL- 62500 FC -/- SOL 11.3 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 12401 TO 14631 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 572 @ 14128.00000 8 @ 14368.00000 298.0 TRIP GAS CUTTING GAS 0 @ 14631.00000 0 @ 14631.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 117671 @ 14129.00000 1164 @ 13007.00000 54039.2 CONNECTION GAS HIGH ETHANE(C-2) 1300 @ 14129.00000 15 @ 14368.00000 544.8 AVG PROPANE(C-3) 822 @ 14110.00000 8 @ 14368.00000 348.7 CURRENT BUTANE(C-4) 1017 @ 14091.00000 8 @ 14368.00000 368.0 CURRENT BACKGROUND/AVG 18 PENTANE(C-5) 716 @ 12985.00000 4 @ 13101.00000 208.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 12401-14631 Primarily unconsolidated Sands and Sandstone.Sandstone grades to Silty Sandstone and Sandy Siltstone Max throughout the interval. 572u LITHOLOGY Sand,Sandstone,Siltstone,Shale PRESENT LITHOLOGY 80%Sand;20%Sandstone DAILY ACTIVITY SUMMARY Drilling ahead.Problem with Top Drive.Fix and resume drilling. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT Ell EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 01,2010 DEPTH 2265' PRESENT OPERATION Rig up for cement TIME 24:00:00 YESTERDAY 2240' 24 HOUR FOOTAGE 25' CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2182.5 29.12 288.91 2112.12 SURVEY DATA 2133.58 28.87 288.26 2069.33 2037.51 26.62 286.39 1984.31 1941.46 23.02 285.87 1897.15 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Smith XR+6C PS3158 1x16,3x20 0' 2265' 2265' 24.9 1-1-WT-A-E-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 89.5 @ 2257.0 50.6 @ 2254.0 74.9 63.91 FT/HR SURFACE TORQUE 5 @ 2256.0 0 @ 2252.0 1.0 0.00 AMPS WEIGHT ON BIT 22 @ 2256.0 7 @ 2254.0 19.3 18.62 KLBS ROTARY RPM 0 @ 2243.0 0 @ 2261.0 0.0 0.00434 RPM PUMP PRESSURE 1517 @ 2257.0 1388 @ 2247.0 1506.9 1433.89 PSI DRILLING MUD REPORT DEPTH 2265' MW 9.3 VIS - PV 16 YP 24 FL 6.1 Gels 18/44/49 CL- 400 FC 2/- SOL 2.5 SD 0.15 OIL 1/97 MBL 17 pH 9.3 Ca+ 80 CCI - MWD SUMMARY INTERVAL 0'TO 2265' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 21 @ 2264.0 11 @ 2242.0 16.4 TRIP GAS- CUTTING GAS 0 @ 2264.0 0 @ 2264.0 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 4634 @ 2263.0 2629 @ 2242.0 3751.6 CONNECTION GAS HIGH - ETHANE(C-2) 0 @ 2264.0 0 @ 2264.0 0.0 AVG - PROPANE(C-3) 0 @ 2264.0 0 @ 2264.0 0.0 CURRENT- BUTANE(C-4) 0 @ 2264.0 0 @ 2264.0 0.0 CURRENT BACKGROUND/AVG 0/15 PENTANE(C-5) 0 @ 2264.0 0 @ 2264.0 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Conglomeratic Sand,Claystone PRESENT LITHOLOGY Sand 60%,Conglomeratic Sand 20%,Claystone 20% DAILY ACTIVITY Continue drilling ahead from 2240'to TD at 2265'md.Circulate 3+bottoms up.Backream from 2265'to 630'with no tight spots.Circulate until SUMMARY shackers clean.Trip in hole on elevators to 2265'.Circulate and condition hole.Pull out of hole and lay down BHA.Rig up and run 13 3/8" casing.Verify landing at depth of 2249'.Rigging up for cement as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z, Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El I EPOCIE[ OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 7,2010 DEPTH 16893 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 14631 24 HOUR FOOTAGE 2262 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 16865.01 88.35 296.61 3509.87 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 404.5 @ 16353.00000 3.9 @ 15138.00000 288.3 313.25751 FT/HR SURFACE TORQUE 23837 @ 16853.00000 4105 @ 15091.00000 14467.8 15802.06543 AMPS WEIGHT ON BIT 21 @ 16042.00000 0 @ 15451.00000 6.7 3.24311 KLBS ROTARY RPM 122 @ 16353.00000 62 @ 15086.00000 116.0 117.53564 RPM PUMP PRESSURE 3767 @ 15127.00000 2632 @ 16893.00000 3570.8 2632.14087 PSI DRILLING MUD REPORT DEPTH 16660 MW 9.3 VIS 68 PV 20 YP 8 FL 5.0 Gels 12/22/23 CL- 63000 FC -/1 SOL 11.75 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 14631 TO 16893 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 911 @ 16002.00000 1 @ 15111.00000 267.6 TRIP GAS CUTTING GAS 0 @ 16893.00000 0 @ 16893.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 163385 @ 16002.00000 252 @ 15111.00000 49508.8 CONNECTION GAS HIGH ETHANE(C-2) 2397 @ 16002.00000 6 @ 15111.00000 547.8 AVG PROPANE(C-3) 1306 @ 14888.00000 5 @ 15111.00000 383.8 CURRENT BUTANE(C-4) 2020 @ 14888.00000 9 @ 14934.00000 437.9 CURRENT BACKGROUND/AVG 48 PENTANE(C-5) 1547 @ 14888.00000 6 @ 14934.00000 246.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 14631-16893 Primarily disaggregated Sands and Sandstone.Sandstone is cemented calcareously and occasionally grades Max to Silty Sandstone and Sandy Siltstone. 911u LITHOLOGY Sand,Sandstone,Siltstone PRESENT LITHOLOGY 80%Sand;10%Sandstone;10%Siltstone DAILY ACTIVITY SUMMARY Drill from 14631'to 16893'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 08,2010 DEPTH 18200 PRESENT OPERATION Circulate hole clean TIME 24:00:00 YESTERDAY 16893 24 HOUR FOOTAGE 1307 CASING INFORMATION 13 3/8"@ 2249' 13 3/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 18130.54 89.03 282.5 3521.61 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 394.4 @ 17112.00000 4.4 @ 17151.00000 267.4 104.72956 FT/HR SURFACE TORQUE 27406 @ 17289.00000 13088 @ 17160.00000 17598.5 17137.62109 AMPS WEIGHT ON BIT 16 @ 16910.00000 0 @ 17097.00000 6.8 3.04287 KLBS ROTARY RPM 123 @ 16958.00000 51 @ 17185.00000 115.5 119.55819 RPM PUMP PRESSURE 4010 @ 17358.00000 2632 @ 16893.00000 3877.0 3831.14502 PSI DRILLING MUD REPORT DEPTH 18200 MW 9.3 VIS 68 PV 20 YP 8 FL 5.0 Gels 12/22/23 CL- 58000 FC -/1 SOL 11.75 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 16893 TO 18200 TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 749 @ 17297.00000 2 @ 17211.00000 311.9 TRIP GAS CUTTING GAS 0 @ 18200.00000 0 @ 18200.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 157129 @ 16967.00000 347 @ 17211.00000 48767.0 CONNECTION GAS HIGH ETHANE(C-2) 1667 @ 17479.00000 1 @ 17211.00000 545.2 AVG PROPANE(C-3) 994 @ 16967.00000 4 @ 17211.00000 365.0 CURRENT BUTANE(C-4) 2534 @ 17056.00000 7 @ 17211.00000 343.1 CURRENT BACKGROUND/AVG 8 PENTANE(C-5) 1332 @ 17056.00000 4 @ 16893.00000 172.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 16893-18050 Primarily unconsolidated Sands and calcareously cemented Sandstone. Max 749u LITHOLOGY Sand,Sandstone,Siltstone,Shale PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill ahead from 16893'to TD of 18200'MD. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT Ell EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Dec 09,2010 DEPTH 18200 PRESENT OPERATION Backream TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 18200 MW 9.2 VIS 71 PV 20 YP 10 FL 4.4 Gels 8/22/23 CL- 56000 FC -/2 SOL 12.6 SD - OIL 80/20 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Circulate and condition mud;8x BU.Pull 1 stand every BU.Backream to shoe. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\DESKTOP\OP17-02 DM... Daily Report ENI Petroleum DAILY WELLSITE REPORT EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 10,2010 DEPTH 18200 PRESENT OPERATION Prepare to POOH and LD 4.5"DP TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS Xceed,Periscope,Telescope,LWD GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continue backreaming out of hole.Tightspot encountered @ 10983'.RIH to 11318'and CBU 3x.Continue backreaming to shoe.Cut SUMMARY and slip.Bring on 9.4ppg mud. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3060; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT [1 I EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 11,2010 DEPTH 18200 PRESENT OPERATION Test BOP's TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog R5616M-F8 227031 6x14 9460 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 23 YP 4 FL - Gels 4/5/6 CL- 195000 FC -/- SOL 7 SD - OIL 51/49 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Cut new mud weight to 9.2ppg from 9.4ppg and then displace.POOH on elevators.LD BHA.Test BOP's EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT tillEPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 12,2010 DEPTH 18200 PRESENT OPERATION RIH w/Liner TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Hycalog RSR616M-F8 227031 6x14 9460 18200 8740 63 2-3-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish BOP testing.R/U to run liner.RIH with liner,currently at 5500' EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT Li EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 13,2010 DEPTH 18200 PRESENT OPERATION RIH w/casing TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505" DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 23 YP 4 FL - Gels 4/5/5 CL- 196000 FC -/- SOL 7 SD - OIL 51/49 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIH with liner.Currently TIH with 5"DP.Tight spot encountered @ 13280'. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT PI EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 14,2010 DEPTH 18200 PRESENT OPERATION Set Hanger TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 22 YP 6 FL - Gels 4/6/6 CL- 192000 FC -/- SOL 7 SD - OIL 51/49 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continue RIH tubing.Drop and pump ball to set hanger.Didn't work.Pump 20bbI sweep to get ball to bottom.Didn't work.Drop wiper SUMMARY ball to try to get ball to set. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch - $1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT Pll EPOCH OP17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 15,2010 DEPTH 18200 PRESENT OPERATION VD Pipe TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505 5 1/2"@ 18030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 22 YP 4 FL - Gels 5/6/7 CL- 194000 FC - SOL 7 SD - OIL 51/49 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished setting hangar.POOH and lay down 5"DP. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT PI EPOCH OP 17-02 REPORT FOR Keener/Smith/Buchanan DATE Dec 16,2010 DEPTH 18200 PRESENT OPERATION R/U for tubing TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505'5 1/2"@ 18030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 21 YP 5 FL - Gels 5/5/6 CL- 193000 FC - SOL 7 SD - OIL 51/49 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish UD 5"DP.Remove wear ring.R/U for tubing.Work on pump assembly. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT Ul EPOCIEI O P 17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 02,2010 DEPTH 2265' PRESENT OPERATION Picking up drill pipe TIME 24:00:00 YESTERDAY 2265' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2182.5 29.12 288.91 2112.12 SURVEY DATA 2133.58 28.87 288.26 2069.33 2037.51 26.62 286.39 1984.31 1941.46 23.02 285.87 1897.15 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2265' MW 9.3 VIS - PV 21 YP 7 FL - Gels 3/4/- CL- - FC -/- SOL - SD - OIL -/- MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG- PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Conglomeratic Sand,Claystone PRESENT LITHOLOGY Sand 60%,Conglomeratic Sand 20%,Claystone 20% DAILY ACTIVITY Rig up cementers.Perform cement job.Test lines to 3000 psi and drop plug.Clean all pits.Nipple down riser and nipple up BOP. SUMMARY Start making up pipe as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\IVIY ... Daily Report ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP17-02 REPORT FOR Keener/Beauchamp/Buchanan DATE Dec 17,2010 DEPTH 18200 PRESENT OPERATION RIH w/Tubing TIME 24:00:00 YESTERDAY 18200 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2249'9 5/8"@ 8505'5 1/2"@ 18030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS - PV 23 YP 3 FL - Gels 4/5/5 CL- 192000 FC - SOL 7 SD - OIL 51/49 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Work on down hole pump.RIH w/4.5"tubing EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2285; Rigwatch -$1450 REPORT BY E. Opitz file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 3,2010 DEPTH 2265' PRESENT OPERATION Testing BOPS TIME 24:00:00 YESTERDAY 2265' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2182.5 29.12 288.91 2112.12 SURVEY DATA 2133.58 28.87 288.26 2069.33 2037.51 26.62 286.39 1984.31 1941.46 23.02 285.87 1897.15 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2265' MW 9.2 VIS - PV 19 YP 7 FL - Gels 2/2/3 CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG - PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Conglomeratic Sand,Claystone PRESENT LITHOLOGY Sand 60%,Conglomeratic Sand 20%,Claystone 20% DAILY ACTIVITY Pick up drill pipe and install CD valves on stand 38-92.Test choke manifold.Test CD manifold.Pick up test tools and install wear ring. SUMMARY Make up test joint and set test plug. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT LI EPOCH OP17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 4,2010 DEPTH 2379' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 2265' 24 HOUR FOOTAGE 114' CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2404.06 36.67 291.76 2299.17 SURVEY DATA 2307.81 32.29 290.66 2219.85 2182.5 29.12 288.91 2112.12 2133.58 28.87 288.26 2069.33 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hughes QD505XX 7131957 8x14 2265' - 114' 1.5 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 686.7 @ 2267.00000 76.9 @ 2290.00000 238.1 242.76790 FT/HR SURFACE TORQUE 6649 @ 2379.00000 3950 @ 2303.00000 4779.3 6649.74707 AMPS WEIGHT ON BIT 62 @ 2265.00000 -47 @ 2284.00000 4.6 2.83027 KLBS ROTARY RPM 73 @ 2343.00000 60 @ 2379.00000 72.4 60.87970 RPM PUMP PRESSURE 1189 @ 2270.00000 730 @ 2284.00000 857.7 806.64703 PSI DRILLING MUD REPORT DEPTH 2443' MW 8.8 VIS 40 PV 6 YP 14 FL 9.0 Gels 5/5/6 CL- 800 FC 2/- SOL 2.0 SD - OIL 1/97 MBL 1.0 pH 9.1 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2265'TO 2379' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 60 @ 2345.00000 0 @ 2273.00000 31.9 TRIP GAS- CUTTING GAS 0 @ 2379.00000 0 @ 2379.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 12512 @ 2345.00000 4 @ 2273.00000 6626.1 CONNECTION GAS HIGH - ETHANE(C-2) 0 @ 2379.00000 0 @ 2379.00000 0.0 AVG - PROPANE(C-3) 0 @ 2379.00000 0 @ 2379.00000 0.0 CURRENT- BUTANE(C-4) 0 @ 2379.00000 0 @ 2379.00000 0.0 CURRENT BACKGROUND/AVG 4/28 PENTANE(C-5) 0 @ 2379.00000 0 @ 2379.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 90%,Sandstone 10% DAILY ACTIVITY Test BOPs.Remove and install wear ring.Lay down test tools and equipment.Pick up BHA#3.Trip in hole to 2145'and tag cement.Circulate SUMMARY and test casing to 2500psi for 30 minutes.Drill out cement,plugs,float,and new hole to 2284'.Circulate and condition mud to 9.2ppg. Perfoem FIT test to 12ppg EMW.Displace to new 8.8ppg LSND mud.Clean pit 7,shakers,and possum belly. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML- $4430; RigWatch - $1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El I EPOCH OP 17-02 REPORT FOR Cormier/Goerlich/Buchanan DATE Nov 5,2010 DEPTH 4420' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 2379' 24 HOUR FOOTAGE 2041' CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4337.50 80.57 289.83 2975.49 SURVEY DATA 4238.60 80.89 290.01 2959.56 4140.40 80.85 288.48 2943.98 4042.41 80.88 288.76 2928.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hughes QD505XX 7131957 8x14 2265' - 2155' 18.25 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 686.7 @ 2267.0 11.0 @ 2442.0 168.3 163.19 FT/HR SURFACE TORQUE 15922 @ 4222.0 3255 @ 2512.0 6984.2 8421.50 AMPS WEIGHT ON BIT 62 @ 2265.0 -47 @ 2284.0 8.8 1.14 KLBS ROTARY RPM 131 @ 3587.0 57 @ 2508.0 112.7 119.51 RPM PUMP PRESSURE 1782 @ 4229.0 426 @ 2472.0 1161.1 1477.13 PSI DRILLING MUD REPORT DEPTH 4410' MW 9.0 VIS - PV 10 YP 25 FL 6.2 Gels 12/18/22 CL- 900 FC 1/- SOL 4.0 SD 0.2 OIL 1/95 MBL 9.0 pH 9.4 Ca+ 60 CCI - MWD SUMMARY INTERVAL 2265'TO 4420' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 125 @ 2606.0 0 @ 2273.0 27.1 TRIP GAS- CUTTING GAS 0 @ 4420.0 0 @ 4420.0 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 24974 @ 2606.0 4 @ 2273.0 5453.0 CONNECTION GAS HIGH - ETHANE(C-2) 29 @ 3168.0 0 @ 3001.0 1.8 AVG - PROPANE(C-3) 0 @ 4420.0 0 @ 4420.0 0.0 CURRENT - BUTANE(C-4) 0 @ 4420.0 0 @ 4420.0 0.0 CURRENT BACKGROUND/AVG 5/32 PENTANE(C-5) 0 @ 4420.0 0 @ 4420.0 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Siltstone PRESENT LITHOLOGY Sand 80%,Siltstone 20% DAILY ACTIVITY Continue drilling ahead from 2379'to current depth as of midnight without any issues.Checking flow every connection.High gas for SUMMARY the day was 125u. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... Daily Report ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT I EPOCH OP 17-02 REPORT FOR Cormier/Smith/Buchanan DATE Nov 6,2010 DEPTH 5355' PRESENT OPERATION Bit trip TIME 24:00:00 YESTERDAY 4420' 24 HOUR FOOTAGE 935' CASING INFORMATION 20"@ 160' 13 3/8"@ 2249' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5224.16 80.89 292.75 3115.33 SURVEY DATA 5126.15 81.0 293.22 3099.91 5026.66 81.09 293.68 3084.42 4927.98 81.0 292.96 3069.06 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hughes QD505XX 7131957 8x14 2265' 5355' 3090' 30.6 - Bit Trip DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 266.6 @ 5306.0 3.2 @ 5354.0 137.8 3.28 FT/HR SURFACE TORQUE 17486 @ 5339.0 4435 @ 5344.0 9463.9 14125.42 AMPS WEIGHT ON BIT 32 @ 4703.0 0 @ 4453.0 7.9 21.73 KLBS ROTARY RPM 122 @ 4573.0 60 @ 5336.0 104.2 63.49 RPM PUMP PRESSURE 2018 @ 5306.0 1239 @ 4650.0 1826.0 1621.58 PSI DRILLING MUD REPORT DEPTH 5355' MW 9.0 VIS - PV 11 YP 24 FL 5.4 Gels 12/23/28 CL- 1450 FC 1/- SOL 4.0 SD 0.2 OIL 1/95 MBL 15.0 pH 9.2 Ca+ 100 CCI - MWD SUMMARY INTERVAL 2265'TO 5355' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 74 @ 5129.0 0 @ 4482.0 13.3 TRIP GAS- CUTTING GAS 0 @ 5355.0 0 @ 5355.0 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 16581 @ 5129.0 108 @ 5259.0 2905.9 CONNECTION GAS HIGH - ETHANE(C-2) 0 @ 5355.0 0 @ 5355.0 0.0 AVG- PROPANE(C-3) 0 @ 5355.0 0 @ 5355.0 0.0 CURRENT- BUTANE(C-4) 0 @ 5355.0 0 @ 5355.0 0.0 CURRENT BACKGROUND/AVG 2/16 PENTANE(C-5) 0 @ 5355.0 0 @ 5355.0 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone,Siltstone PRESENT LITHOLOGY Sand 70%,Sandstone 20%,Siltstone 10% DAILY ACTIVITY Continued drilling from 4410'to 5330'with no issues.From 5330'to 5355',drilling was hard and ROP dropped off.Circulated 1.5 SUMMARY bottoms up then decision was made to pull out of hole for bit. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$4430; RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY ... 0 -n3 o' r 0 co OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.