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210-041
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251113 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# OP08-04 50029234247000 210041 06/12/2013 SCHLUMBERGER USIT OP14-S03 50029234470000 211052 09/26/2013 SCHLUMBERGER CBL/USIT SI29-S02 50629234640000 213006 02/29/2012 SCHLUMBERGER SONIC VISION - TOC SP24-SE1 50629235100000 214011 03/19/2014 HALLIBURTON CAST-M/CBL-M/ACE Please include current contact information if different from above. T41096 T41097 T41098 T41099 212-006 OP08-04 50029234247000 210041 06/12/2013 SCHLUMBERGER USIT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.13 13:15:44 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ OP08-04 JBR 07/18/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 4-1/2" & 2-7/8" test joints, F/P on manual Kill F/P on Annular with 2-7/8" Test joint. N2 Precharge 18@ 996 psi. This test was a 5K test due to swapping the double gates and and a new Annular element, most of the BOP stack had been taken apart with replacement parts added after the rig had been down for a month. Good test over all. Test Results TEST DATA Rig Rep:John Kelly/ Sean StuckaOperator:Hilcorp Alaska, LLC Operator Rep:Dave Smith/ Craig Smith Rig Owner/Rig No.:Nordic 4 PTD#:2100410 DATE:5/11/2025 Type Operation:WRKOV Annular: 250/5000Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopJDH250513073605 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 11.5 MASP: 739 Sundry No: 325-244 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" 5K FP #1 Rams 1 Blinds P #2 Rams 1 2-7/8"x5-1/2" P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 1 3-1/8"FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3025 Pressure After Closure P2100 200 PSI Attained P26 Full Pressure Attained P68 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2800 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P10 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9 9 9 9 FP FP This test was a 5K test due to swapping the double gates and and a new Annular element F/P on manual Kill F/P on Annular 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 Swap and Clean-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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,344 NA Casing Collapse Conductor NA Surface 2,260psi Production Intermediate 4,760psi Liner Motherbore Liner Lateral L1 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Ryan Rupert Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Slotted liner Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355024, ADL0373301, ADL0390616 210-041 NIKAITCHUQ OP08-04 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23424-00-00 NIKAITCHUQ Hilcorp Alaska, LLC Length Size Proposed Pools: 3,745 11,338 3,743 739 SCHRADER BLUFF OIL Same 154 154 12.6# / L-80 TVD Burst 3,984 Slotted liner MD NA 6,870psi 5,020psi2,151 3,629 2,334 See Schematic 3,7265-1/2" 160 20" 13-3/8"2,334 9-5/8"4,999 See Schematic 907-777-8503 ryan.rupert@hilcorp.com Operations Manager May 7, 2025 11,3387,189 4-1/2" 3,743 Perforation Depth MD (ft): C.O. 639 NA and NA NA 11,113 4,999 6,321 5-1/2" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:10 am, Apr 22, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.04.21 15:53:33 - 08'00' Sara Hannegan (2519) 325-244 10-404 11,113 SFD MGR22APR25 SFD SFD 4/24/2025 11,240 DSR-4/24/25 3,706 3,727 * BOPE test to 2000 psi. 48 hour notice to AOGCC. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.24 16:01:35 -08'00'04/24/25 RBDMS JSB 042525 ESP Swap RWO Well: OP08 Well Name:OP08 API Number:50-029-23424-00-00 Current Status:Offline ESP producer Permit to Drill Number:210-041 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Maximum Expected BHP:1080 psi @ 3,402’ TVD (6.2ppg) Projected static from 4/21/25 buildup (10 days) Max. Potential Surface Pressure: 739 psi Using 0.1 psi/ft Brief Well Summary OP08 is a dual lateral OA sand producer. It’s ESP failed in April-2025, and is ready for an ESP swap. It passed a casing MIT in 2019, but has never had a liner cleanout. The goal of this project is install a new ESP and return the well to production Pertinent wellbore information: - Deviation: Goes >70 degrees at 4382’ MD -DLS: o Gets up to 5.3 degree / 100’ between surface and set depth o DLS range from the 4.6϶ -3.4϶ in the deepest 700’ MD above top liner at 4179’ MD o Previous ESP was set from 3984 – 4059’ MD and had good run lifes -Last casing test: MIT of 9-5/8” casing PASSED to 1500psi from 4100’ MD and above (3/15/19) - Pertinent History: o 2010: Drill and complete as single horizontal in OA sand o 2013: Upper lateral added in OA sand o Dec-2018: WL diagnostics find tubing hole at 275’ MD o 2019 ESP Swap RWO: 8.5” Mill + casing scraper to 4106’ MD Casing MIT per above Ran new 4-1/2” non-coated tubing o 4/10/25: ESP dies after 6+ year run life ESP Swap RWO Well: OP08 RWO Procedure 1. MIRU Nordic #4 2. Circulate / kill well: a. Work over fluid will be injection water (8.33ppg or heavier) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 62bbls d. IA to top liner = 223bbls 3. Set BPV/TWC, ND tree, NU BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH laying down 4-1/2” ESP completion 7. Pickout cleanout run 8. Cleanout casing and liner as deep as practical 9. Pickup and RIH with ESP completion a. Bottom ESP to be set at same location ±4,049’ MD b. New tubing will be ran (likely 3-1/2”) 10. Land ESP completion 11. Set BPV/TWC, ND BOP 12. NU tree and test, pull BPV/TWC 13. RDMO RWO crew and equipment Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. BOP schematic Nikaitchuq Field Well: OP08-04/04L1 Last Completed: 3/18/2019 210-041 (Mainbore) / 213-061 (Lateral) API #: 50-029-23424-00-00 (Mainbore)/60-00 (Lateral) Casing 20” 20" 9-5/8" Size ID Top Btm 20"N/A Surface 154' 13-3/8"12.415" Surface 2,334' 13-3/8" 9-5/8"8.681" Surface 4,999' 5-1/2”4.892” 4,792' 11,113' 5-12"4.950” 4,149' 11,338' 4-1/2"3.958” Surface 3,984' No Top MD TVD Inc ID OD 1 3,984' 3,378' 64 NA 7.625" 2 4,149' 3,444' 68 4.950" 5.5" 3 4,792' 3,620' 84 4.950" 5.5" Volumetric Top of Cement in 9-5/8" @ 3,619' MD / 3,124' TVD Item JEWELRY DETAIL ESP Components, bottom of motor @ 4,052 MD w/ 7- 5/8" shroud Lateral L1 Baker SLXP Liner Hanger/Packer 13-3/8" 30" hole, cement to surface Mainbore Baker SLXP Liner Hanger/Packer Schematic Dual Lateral Producer with ESP Lift 15.5#, L-80, Hyd 521 17#, L-80, DWC/C 16" hole, Stg 1 – 352 bbls 10.7# ASL, Stg 2 – 72 bbls 12# DeepCrete 12-1/4" hole, 103 bbls 12.5# DeepCrete CASING DETAIL 47#, L-80, BTC-MIntermediate Surface Conductor Type 68#, L-80, ABTR 179#, X-65 1 Wt/ Grade/ Conn Tubing Production (OP08-04L1) Production (OP08-04) TUBING DETAIL 12.6#, L80 CEMENT DETAIL Cement Details Hole MD 154' 2,334' 4,999' Casing exit window @ 4,351' - 4,368' MD 2 HAL 5-1/2" Oil Swell Packers OA Sand 3 Lateral L1 5-1/2" Slotted liner to 11,338' MD / 3,745' TVD, hole TD 11,340' MD 9-5/8" OA Sand Mainbore 5-1/2" Slotted liner to 11,113' MD / 3,726' TVD, hole TD 11,240' MD00070 degree inclination @ ~4,286' Last edited by: DH 4/16/2025 Nikaitchuq Field Well: OP08-04/04L1 Last Completed: 3/18/2019 210-041 (Mainbore) / 213-061 (Lateral) API #: 50-029-23424-00-00 (Mainbore)/60-00 (Lateral) Casing 20” 20" 9-5/8" Size ID Top Btm 20"N/A Surface 154' 13-3/8"12.415" Surface 2,334' 13-3/8" 9-5/8"8.681" Surface 4,999' 5-1/2”4.892” 4,792' 11,113' 5-12"4.950” 4,149' 11,338' 3-1/2"2.992” Surface ~3984 No Top MD TVD Inc ID OD 1 3,984' 3,378' 64 NA 7.625" 2 4,149' 3,444' 68 4.950" 5.5" 3 4,792' 3,620' 84 4.950" 5.5" Volumetric Top of Cement in 9-5/8" @ 3,619' MD / 3,124' TVD Item JEWELRY DETAIL ESP Components, bottom of motor @ ~4,052 MD w/ 7- 5/8" shroud Lateral L1 Baker SLXP Liner Hanger/Packer 30" hole, cement to surface Mainbore Baker SLXP Liner Hanger/Packer Proposed Dual Lateral Producer with ESP Lift 15.5#, L-80, Hyd 521 17#, L-80, DWC/C 16" hole, Stg 1 – 352 bbls 10.7# ASL, Stg 2 – 72 bbls 12# DeepCrete 12-1/4" hole, 103 bbls 12.5# DeepCrete CASING DETAIL 47#, L-80, BTC-MIntermediate Surface Conductor Type 68#, L-80, ABTR 179#, X-65 13-3/8" 1 Wt/ Grade/ Conn Tubing Production (OP08-04L1) Production (OP08-04) TUBING DETAIL 9.2#, 13Cr CEMENT DETAIL Cement Details Hole MD 154' 2,334' 4,999' Casing exit window @ 4,351' - 4,368' MD 2 HAL 5-1/2" Oil Swell Packers OA Sand 3 Lateral L1 5-1/2" Slotted liner to 11,338' MD / 3,745' TVD, hole TD 11,340' MD 9-5/8" OA Sand Mainbore 5-1/2" Slotted liner to 11,113' MD / 3,726' TVD, hole TD 11,240' MD00070 degree inclination @ ~4,286' Last edited by: DH 4/16/2025 Nordic Rig 4 ARRS 5M Nordic Calista 02.24.2025 All Components 5,000 psi BLIND/SHEAR RAMS VBR RAMS CHOKE HCR MANUAL CHOKE 3" 5,000 PSI WP CHOKE LINEKILL HCR INSIDE KILL3" 5,000 PSI WP KILL LINE Annular 2 7/8” x 5” VBR New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PM 21Qe4(c, Regg, James B (DOA) From: Regg, James B (DOA) 'g Sent: Tuesday, March 19, 2019 10:20 AM 6 To: O'neal Robert; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: Mallano Tommaso; Lawrence Steve Subject: RE: MIT form, Eni OP08-04 Additional clarification highlighted Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.ree¢Calalaska.¢ov. From: O'neal Robert <RObert.ONeal@external.eni.com> Sent: Monday, March 18, 2019 4:47 PM To: Regg, James B (DOA) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Mallano Tommaso <Tommaso.Mallano@eni.com>; Lawrence Steve <Steve.Lawrence@external.eni.com> Subject: RE: MIT form, Eni OP08-04 Thank you for the comments Jim. This was my first (and apparently horrible) attempt at this form with no guidance other than your website. I will re -do and send for further review. I placed comments below and any clarification would be really appreciated. I will compile an "instruction sheet" for anyone completing this in the future. From: Regg, James B (DOA) rmailto:Jim.regg(@alaska.gov] Sent: Monday, March 18, 2019 4:33 PM To: O'neal Robert; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: Mallano Tommaso; Billington Mitchell; Rigmanager.Rig4(&nordic-calista.com; Enipetroleum AKRigClerksDoyon15 Subject: RE: MIT form, Eni OP08-04 Report has numerous errors: • PTD p is missing —should be 210410 That is my error; since we were working under the Sundry I did not place the PTD Remarks call this a 9 5/8" casing test; was tubing run in the well making this a test of the inner annulus (tubing - casing annulus)? The tubing had been pulled and then the team ran in on drill pipe so it was 5" DP in the well so does this make it technically an IA test since the DP was then pulled? This is the problem with using a form designed for wells completed for injection service; it would be better to just provide a copy of the test chart with the required 30-404 (subsequent report of sundry operations. Test pressure results do not make sense for a supposed 1500 psi test. I am unclear on this one. We took the pressure up to 500 psi, checked for leaks, all good so we took it up to 1560 psi to stabilize and then recorded a final pressure of 1510 psi. I am unsure how else to record it. See above regarding the appropriateness of using the MIT form. Missing pressures at 0, 15min, and 30 min for the tubing and outer annulus (casing -casing annulus) assuming you are referencing a tubing -casing pressure test. A valid MIT requires pressures to be monitored and documented in the annular space (and tubing) adjacent to the tested annulus. We did monitor the OOA (13- 5/8" by 9-5/8") over the test period. [OA not OOA] Was there a supplementary form I am supposed to submit along with the submitted form? Already answered If this test was required by an AOGCC approved sundry please include the sundry # in the remarks (Sundry 319- 048?) 1 will correct Test interval should be "0" for Other since this is presumably a required MIT per the sundry approval I will correct Please correct and resend. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or pr ileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended r pient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it toyou ontact Jim Regg at 907- 793-1236 or iim.rege@alaska.aov. From: O'neal Robert <RObert.ONeal@external.eni.com> Sent: Friday, March 15, 2019 2:16 PM To: Regg, James B (DOA) <lim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Wallace, Chris D (D( Cc: Mallano Tommaso <Tommaso.Mallano@eni.com>; Billington Mitchell < Rigmanager.Rig4@nordic-calista.com; Enipetroleum AKRigClerksDoyonl < Subject: MITform, Eni OP08-04 W Please forgive me if I sent this to the wrong distribution. I ve had the help of the engineers in the past so this is my first time... Attached is the completed MIT record for the curre well being worked on, OP08-04, for Eni drilling at Oliktok Point. The test was on the 9-5/8" casing. Rob O'Neal (AES) Eni Company Rep on Nordic Rig 4 Office: 907-685-0710 Mobile: 907-232-4429 Message for the recipient only, jYreceived in error, please notify the sender and read htto://www.eni.com/disclaimer/ James B From: Sent: O'neal Robert <RObert.ONeal@external.eni.com> To: Monday, March 18, 2019 6:19 PM / Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); 31 Lij(f y Subject: Mallano Tommaso ) Wallace,�/✓allaChris D (�OA) Attachments: Re -submittal Of MIT form, Eni OP08-04 OP08-04 9.625 csg PT, 3-15-2019jpg; Form 10-426, 9.675 csg PT, OP08-04.xlsx Jim, Again, I apologize for the errors. I have completed the form let me know if I can do anything else to ensure completeness. Thank you again for the remarks. ��part. please per your instruction and also included the test ch Rob O'Neal From: Regg, James B (DOA) [mailto:jim.regg@alaska.govj Sent: Monday, March 18, 2019 4:33 PM To: O'neal Robert; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: Mallano Tommaso; Billington Mitchell; Rigmanager.Rig4@nordic-ca' Enipetroleum AKRi9ClerksDoyon15 Subject: RE: MIT form, Eni OP08-04 Report has numerous errors: PTD # is missing — should be 210410 • Remarks call this a 9 5/8" casing test; was tubing run in the well making this a test of the inner annulus (tubing - casing annulus)? • Test pressure results do not make sense for a supposed 1500 psi test. • Missing pressures at 0, 15min, and 30 min for the tubing and outer annulus (casing -casing annulus) assuming You are referencing a tubing -casing pressure test. A valid MIT requires pressures to be monitored and documented in the annular space (and tubing) adjacent to the tested annulus. • If this test was required by an AOGCC a 048?) Pproved sundry please include the sundry # in the remarks (Sund • Test interval should be "0" for Other since this is presumably a required MIT per the sund rY 319 Please correct and resend. rY approval Jim Regg Supervisor, Inspections AOGCC 333 W.7'hAve, Suite 100 Anchorage, AK 99501 907-7931236 CONFIDENT/AL/Ty NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, Please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, V contain confidential and/or privileged information. 793-1236 or i'mit, without a ;irst s oy Y contact Jim Regg at 907- From: O'neal Robert <Robert.ONeal@external.eni.com> Sent: Friday, March 15, 2019 2:16 PM To: Regg, James B (DOA) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Wallace, Chris D (DOA) <chris.waIlace@alaska.gov> Cc: Mallano Tommaso <Tommaso.Mallano@eni.com>; Billington Mitchell <Mitchell.Billington@external.eni.com>; Rigmanager.Rig4@nordic-calista.com; Enipetroleum AKRigClerksDoyon15 <AKRigClerksDoyonl5@eni.com> Subject: MIT form, Eni OP08-04 All, Please forgive me if I sent this to the wrong distribution. I have had the help of the engineers in the past so this is my first time... Attached is the completed MIT record for the current well being worked on, OP08-04, for Eni drilling at Oliktok Point. The test was on the 9-5/8" casing. Rob O'Neal (AES) Eni Company Rep on Nordic Rig 4 Office: 907-685-0710 Mobile: 907-232-4429 Message for the recipient only, if received in error, please notify the sender and read htto://www.eni.com/disclaimer/ r'f OPo6-o4 P, t� -LA C)04to a S�Ly C'as ' i esr - 3Jts-/jj S100ACO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test fJla rte, 2�I T Submit to lim regpSialaska.0ov: AOGCC Inspect ors®alaska.0ov: phcebe.bmokstffialaska.cov Chris wallaceigalaska.0ov OPERATOR: Ent n q FIELD/UNIT/PAD: Nioetchup Oliktok Point OPD8-09 DATE: 0115/1P OPERATOR REP: Robert O'Neal AOGCC REP: N/A Well OPOS44 Pressures. Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD 10 Type Inj N Tubing NA NA NA NA NA NA Type Tesl O Packer ND 3368 ' BBL Pump 1 2 IA 0 1560 ' 1590 - 1510 - NA NA Interval 4 Test psi 1500 ' BBL Retum 1.2 OA 150 260 1 180 1 150 NA NA I Result P Notes: Teslrequiredby, Sundry, pennitk319-048. This test fulfilled MIT requirement for production casing annulus (9-W- tested Win packer RIH and set on Y drill pipe. Tested to 1560 psi Win 50 psi bleed over 35 minutes. Well Pressures. Protest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Tesl Packer ND BBLPump 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 BBLPump IA In 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 BBLPump IA Interval Test psi BBL Return OA Result Neta.: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer ND BEL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Nob.: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Type Int Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Note.: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Int Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Netes: TYPE INJ Codes W=Water G=Ga. a=Slurry = Industrial Wastewater N =Not Inleeling Form 10-026 (Revised 01/2017) TYPE TEST Codes INTERVPL Codes P = o,asams Teal I =Initial Test O= Other (describe In Nalm) 4=Four Year Cycle V = Requimd ey Variance O = Other (desMes In notes) Form 10-0269.6]5 use PT OP09A1(002) Reeult Cod. P = Pam F = Fall 1=lncancluvve Submit to: "m reaanalaska.aov: OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOGCC Insoectors®alaska.aoe Phoebe brookslibalaska aov N'ka'tchug Ofktok Point OP08-04 Oda Wallacenalaska gov �' Aeif '�SAA-f Well Opoi Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj N Tubing NA NA NA NA NA NA Type Test P Packer NO 3368 BBL Pump 1.2 IA NA NA NA NA NA NA Interval 4 Test psi 1500 BBL ReWm 1.2 1 OA 150 260 180 150 NA NA Result P Notes: This test fulfilled MIT requirement for production casing (990'). Tested to 1560 psi min 50 psi bleed over 36 minutes. Well Pressures Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test PackerND BBL Pump IA Interval Test psi RBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnl I Tubing I Type Test PackerND BBL Pump IA Interval Test psi BBL Ratum OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Men. PTD Type lnj Tubing Type Tesl Packer NO BBL Pump IA Interval Test psi RBL Relum OA Result Notes: Well Pressures'. Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer NO 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 Int Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result NNS: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. W Min, PTD Type lnj Tubing Type Test PackerND BBL Pump IA Interval Test psi BBL Return OR Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Type lnj Tubing Type Test PackerND BBL Pump IA Interval Test psi BBL Retum OA Result Dohs: TYPE INJ Go4es W=Wale, G = Gas S=starry I = Industrial Watlewate, N=NM Inlsol TYPE TEST Coon INTERVAL Codes P= Previous Tat 1=Wiest Test O= Omer(descrbe in Notea) 4=Four Year Cyde V =Required try Vannce 0=Corer (dVivia in nota) Form 10426 (Revised 01/2017) Form 10-0269. 675 csg PT CP06 04 (002) Result Codes P=Pass F a Fell 1=lnconduslve THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Operations Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP08-04 Permit to Drill Number: 210-041 Sundry Number: 319-048 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 w .aogcc.aloska.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, Daniel T. Seamount, Jr. Commissioner DATED this S day of February, 2019. SCANNED FEB 0 6 2019 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 e i APPLICATION FOR SUNDRY APPROVALS AA �. 20 AAC 25.280 J -A n C C. 1 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: Eni US Operating Co. Inc. Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 210-0410 - 3. Address: 6. API Number: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23424-00-00 ' 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 OP08-04 9. Property Designation (Lease Number): 10. Field/Pool(s): 0373301',0355024,'0390616* 1 Nikaitchug Schrader Bluff Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total De th TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): /frL10 1 3/ 11,340' 3,743 840 Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 154 154 Surface 2334 13.375 2334 2151 5210 2480 Intermediate 4999 9.625 4999 1 3629 6890 1 4790 Production Liner 6114 5.5 11113 3727 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,999'-11,344' 3,629-3,744 4-1 /2" L-80 4052' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary L.rj Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory ❑ Stratigraphic ❑ Development 2 Service ❑ 14. Estimated Date for 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 Pro ct Manager Contact Email: am*ad.chaudh eni.conn Contact Phone: 907-865-3379 Authorized Signature: Date: ) GO( COMMISSION USE ONLY Conditions of approval: Notify Commission a representative may witness Sundry Number: ,soo,that Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: /� [� T` GLS(, ruz....,.t.,.� ,11,tS1l_ 4b ,05 Z ��jPG- j -to 3.�oo "os �s Post Initial Injection IT Req'd? Yes No ❑ Spacing Exception Required? Yes 1:1 No Subsequent Form Required: L G -- l 0 c/ J APPROVED BY L J Approved by: COMMISSIONER THE COMMISSION Date: h S 'is �� RBDMSL" FEB 0 51019 Submit Form and Form 10-403 Revised 4!2017 Approved applicatio s a d o 2 n fr ¢date Of approval. Attachments in Duplicate Cinii foetirolleu n� 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.Pierfelici@eni.com February 151, 2019 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP08-04 Rig Workover Dear Commissioners, / J01^t11 c RE `tom "nE 6 tl9 FEB 0 1 2010 L( ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP08-04. OP08-04 was originally completed on OPP on July, 2010 with a through -tubing conveyed electric submersible pump (TTC-ESP).in April 2014 a workover was done on the well and completed with TTC-ESP. Since December 19", 2018 well is shut down because of a suspected tubi eak. Plan is to pull out TTC-ESP completion and complete it with new tubing and conventional ESP system. The estimated date for beginning this work is February 15th, 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, Stefano Pierfelici Well Operations Project Manager OP08-04 Workover — Summary Page OP08-04 Rig Workover PTD#:210-041 Current Status Well OP08-04 is currently shut due to a tubing leak, 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 conventional ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 11, 113'MD/3,726'TVD. This well is expected to have a static max bottom hole pressure of approximately 1,250 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/Blind/VBR/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 in July 2010. Well type: Producer Estimated start date: February 15`h, 2019 Drilling rig: Nordic 4 Completion Engineer Tommaso Mallano: tommaso.mallanogeni.com Sr. Drilling Engineer: Amjad Chaudhry: amiad.chaudhrygeni.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. Tubing has a suspected leak (if leak in tubing confirmed circulate 9.3 ppg 3 % KCl/NaCl 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. PU test packer and RIH to 4100' c s 8. Pressure test casing to 1500 psi, POOH and LD the test packer. 9. MU new ESP assembly and RIH to setting depth. - 10. Land hanger, and test it. 11. Install BPV and nipple down BOP. 12. NU tubing adapter and tree. 13. Pull BPV, install test plug and test tree.( 5000 psi test) 14. Circulate Freeze protect through tree down IA. 15. Shut in well. 16. RDMO. Relnw the current schematic of the well: Surf. Casing 13.3/8", 68 # 4' MD, 2,151' TVD 34- Inc. 4,149' MD — Lt - Baker SLXP Llner Hanger/Packer 4,792' MD, Baker SLXI Liner Hanger/Packer Nikaitchuq Field. Oliklok Pant 4-1/V 12.6 ppf Production Tubing 2,116' MD, 1,989' TVD 33° Inc - GLM, KBMG, 4-%a" x 1", with 2,000 psi STS -1 SOV installed 4-'h' x-cplg cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line 3,846' MD, 3,310' TVD, 59° Inc - GLM, KBMG. 4-'h" x 1", with 3,100 psi STS -1 SOV installed o r0roleum O P08-04 Dual Lateral Producer with ESP Lift April 18 2014 3,950' MD, 3,361' TVD - Discharge Gauge Sub 4,052' MD, 3,405' TVD, 660 Inc— Bottom of Motor Centralizer Centrili8, TTC-ESP, 116+80 -stage 38OP18SXD pump, 513 GS83 seals, 150 HP MSP1 motor 4,067' MO Shroud Assembly with cable and / chemical injection line feed-thrus, Pert. Dip Tube Slotted Liner, 5-tfi" Silver Bullet Ecc 5-14" 15.5 ppf 4,351.4,368' MD, HAL 5-'h' Oil Swell Now Guide Shoe with 11,338' MD, 3,743' Planned Casing Exit Packer Bent Joint TVD / Window \ 9V Inc. Interm. Casing 9-618". 47# 4,999' MD, 3.629' TVD 85- Inc. 5-1/V Silver Bullet Ecc Slotted Liner, HAL 5-Yf Oil Swell Nose Guide Shoe 5=6' 17 ppf Packer 11,113' MD, 3,726' TVD 98° Inc. Ve?tcoGray Me -247 SURFACE COMPLETION SYSTEM PRP 10161, NC 0 G= umagnal,cn v:::•�i4 10 OF 10 23 JANUARY 2008 -1 Rig Nordic #4 Well OP -18 Stack measurements Rntary TahlP Note: To be confirmed when rigged up 2-7/8" x 5" VBR rams MSIDE KILL KILL 4-1/2" pipe rams 'moo �— CHOKE LINE k, 1312" 3" 29.5" KILL LINE ECHO EL CHOKE HCR 85 TOP OF WELL HOUSE Top Flange RISER 13'10"to GL Upper Lock Down Screws 16' 4" Projected 911 25' 3" 34' to GL (Nordic Rig 4 RKB 33.5' + 6" mats) Draft 09-28-18 • • ill O CO N n O M W <° N N b CO O p O W C0 �' W .- W r0 n N N 8- m h .- n is! .- W r n m odi m W .) 0 U2 0 M .- OOM W CD Is N Is Q N T N A N M N N O N N M .78 O< M N M �O M CO < N t�ry C..4 0 I 0 r 9Z. 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E — j d t CO ° O O O aa O M O O 0 W W Z A N W z N LLzwz _3 3 ! ,. 2 ID Q zmmz a a a a au) a sq1= VlL Naz vz n a3 a5 $ d 0 C) d N a td rm CO _ d US Co 8 N d m N } n000mI0.a a a 0. a a 0. a a a n. 0co 0coNaaNaHNNNNo2 (0y . az w 0 0 0 0 0 0 0 0 0 0 0 0 ( co to (0 co fn N ten to t (0 Q cN STATE OF ALASKA 2 5 i ALASKA OIL AND GAS CONSERVATION COMMISSION �� REPORT OF SUNDRY WELL OPERATIONS OGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other a ESP Change Out Performed: Alter Casing ❑ Pull Tubing Q Stimulate-Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well ❑ 2.Operator Eni US Operating Co.Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Q Exploratory ❑ 210-0410 ' 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-23424-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: 0373301,0355024,0390616 - OP08-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Nikaitchuq/Schrader Bluff Oil Pool 11.Present Well Condition Summary: Total Depth measured 4 11,240 feet Plugs measured feet true vertical 3,706 feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 154 154 Surface 2,334 13 2,334 2,151 5,210 2,480 Intermediate 4,999 10 4,999 3,629 6,890 4,790 Production Liner 6,114 6 11,113 3,727 slotted slotted Perforation depth Measured depth 4999-11113 feet SCANNED JUL 2014 True Vertical depth 3629-3727 feet Tubing(size,grade,measured and true vertical depth) 4.5" 12.6 ppf L80 4,067'MD 3,409'TVD Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: "^v Intervals treated(measured): RBDMS f 6 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 347 37.7 3.5 0 207 Subsequent to operation: 270 0 30 0 208 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil - A Gas U WDSPL L GSTOR ❑ WINJ ❑ WAG ❑ GINJ El 3USP ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-229 Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc KuckTitle Production Optimization Coordinator fit.,....LSignature /i 12 Phone (907)865-3328 Date 4/24/2014 M er • d 1:-.1. � H L c 0-M J � � O C d "a EA C.) ,- 2 > o c_ a 1• d V z ' I— C _- J ti M c O O M r_ — N M d : go pa o E � M 000 � � � a I14 .. R11 � co L W i I I 6 �, a a� � 8 Wo O _ = w �, 1.E ,„:, MO MY a) —. ow I 1 1 1 co- ii5 7 4E' : I ICI, ce mco N (n 0 � Z I co" I I li) L Y _x i 0 E = N sa 00 czo oY I I ° Y rn pw � d o_ a rr � � co Ea I I - J O 00 _ vi J Q II -J CD - ao = Q w I i OM � '- I J co U' -0 N m 4) >, I C UCU U � fa I i. C 0 '0 W C C it') L C N O O � °' of �— - N0 oo U) (1, I I .. i o C C7 N vi _ � O i � � Q •c = • cm F— O co C U > co o 0 .- Opc.� W ,I I +I I .N ti N U f6 00 ,' ,✓ •2 i c4 er co U D FO oM H � H Ha -c a0 2 c U _ . ci c O H — t 3 0 0_ CO r - ' M CO 0 LLJ C CO co co Q ,- � ss�� M Q M (Y) I— - U IU c w, �► c07 � o N Q� � o o � coin = 5 + I "x' oX N CO 01 O CV •L U ,- o -N to rn in a / / / o a) I I O M 4 N N 4 § M t U ' \\ i. L. \,8 % . dctI m to ct o CI I ii 3 i d a i . LI: ro:1_ 401 N to ci 0 L 2 _ z ca Nc 2 ciN it ii MN Z N . if, Eni US Operatin... Well Name:0P08-04 OR ENI Petroleum Co.Inc. Daily Report Well Code:23950 Field Name:Nikaitchuq • API/UWI:50-029-23424-00-00 2^ii Date:4/13/2014 - Report#: 1 II IIpage 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-0410 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) I DFS(days) Original Hole WORKOVER 1393.67 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 68.0 13.0 CLEAR WC 7 SW @ 4 MPH Daily summary operation 24h Summary CLEAN/DRAIN PITS. PREP TO SPLIT MODULES. SET HERCULITE AND MAT BOARDS. MOB UTILITY MODULE. MOB/SPOT DRILLING MODULE OVER OP-08,MARRY UTILITY MODULE. RIG ON DOWNTIME FOR OBM CLEANUP OF HERCULITE AND MATTING BOARDS AT OP-18. Operation at 07.00 -- - --- _ INSTALL BERMING AROUND RIG,CLEANUP COMPLETE 0300. 24h Forecast FINISH CLEANUP. RESUME BERMING,PREP RIG FOR OPERATIONS ON OP-08. TAKE ON PRODUCED WATER. KILL WELL. N/D TREE,N/U BOP STACK AND TEST. 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. 0000 15.00 15.00 15.00 MOB A2P MOB RIG F/OP18-08 L1 TIOPO8-04 L7 RWO. CLEAN AND PATCH HERCULITE. SET MAT BOARDS. CLEAN/DRAIN PITS. PREPARE DICONNECTS,LINES.CABLES. MOVE UTILITY MODULE. MOVE/SPOT DRILLING MODULE OVER OP08,JACK AND SHIM. SPOT UTILITY MODULE,SHIM AS NEEDED. HOOK UP LINES AND ELECTRICS. 15.00 00.00 9.00 24.00 MOB A '20 •P CLEAN UP OF OBM SPILLED AT OP-08 DURING LAST WELL ACTIVITY. OIL ON HERCULITE AND MATTING BOARDS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-0710 Eni representative Craig Rammer Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Wade Thomas Eni Petroleum Rig Clerk 907-670-8537 907-232-8631 Eni representative Vance Dale Eni Petroleum Materials Coordinate 907-685-0718 Eni representative Jeremy Decker Eni Petroleum Expediter 907-980-7545 Eni representative Bill Petty Eni Petroleum HSE 907-670-8602 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher 907-670-8603 Tool Push Mike Rees Nabors Alaska Drilling Tool Pusher 907-670-8603 Eni representative Davide Simeone Eni Petroleum Dolling Manager Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4,892 L80 -1,361.2 11,113.0 8/27/2010 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) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 Eni US Operatin... . Well Name:0P08-04 OR PIA ENI Petroleum Co.Inc. Daily Report` Well Code:23950 Field Name: Nikaitchuq • API/UW:50-029-23424-00-00 2 n ii Date:4/14/2014 - Report#: 2 I� II page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-0410 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) Original Hole WORKOVER 1394.67 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 68.0 23.0 OVERCAST WC 16 SW @ 6 MPH Daily summary operation 24h Summary CLEAN UP OF OBM SPILLED AT OP-08 DURING LAST WELL ACTIVITY. OIL ON HERCULITE AND MATTING BOARDS. COMPLETE BERMING AROUND RIG. TAKE ON FLUIDS. CLEAN MATS IN PIPE SHED. PREP OP08 FOR KILL OPS,STAGE FITTINGS AND HOSES. ASSIST ACS PREP PAD AREA FOR CUTTINGS BOXES. CLEAN UP LAST DIRTY MAT BOARDS. HOOK UP TO TREE. MISC RIG MAINTENANCE. LAY DOWN HERCULITE,SET MATS.BUILD BERMING FOR CUTTINGS BOXES. Operation at 07.00 TAKE ON WATER FROM PRODUCTION. 24h Forecast TAKE ON PRODUCTION/INJECTION WATER TO CUTTINGS BOXES,TRANSFER TO RIG WHEN COOLED TO 140F. PUMP DOWN/KILL OP08. N/D TREE,N/U BOP STACK,TEST. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 0000 03.00 3.00' 3.00 MOB A 20 P CLEAN UP OF OBM SPILLED AT OP-08 DURING LAST WELL ACTIVITY. OIL ON HERCULITE AND MATTING BOARDS. 03.00 1200 9.00 12.00 PREP 'A 1 P COMPLETE BERMING AROUND RIG. TAKE ON FLUIDS. CLEAN MATS IN PIPE SHED. PREP WELL FOR KILL OPS, STAGE FITTINGS AND HOSES. 12.00 00'00 12.00 24.00 PREP 'A 1 P ASSIST ACS PREP PAD AREA FOR CUTTINGS BOXES. CLEAN UP LAST DIRTY MAT BOARDS. HOOK UP TO TREE. MISC RIG MAINTENANCE. LAY DOWN HERCULITE,SET MATS,BUILD BERMING FOR CUTTINGS BOXES. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Wade Thomas Em Petroleum Rig Clerk 907-670-8537 907-232-8631 Eni representative Vance Dale Eni Petroleum Materials Coordinato 907-685-0718 Eni representative Jeremy Decker Eni Petroleum Expediter 907-980-7545 Em representative Bill Petty Eni Petroleum HSE 907-670-8602 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher 907-670-8603 Tool Push Mike Rees Nabors Alaska Dolling Tool Pusher 907-670-8603 Eni representative Davide Simeone Eni Petroleum Orilling Manager Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.892 L80 -1,361.2 11,113.0 8/27/2010 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) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 • fo tEni US Operatin... .} [Well Name:OP08-04 OR I • ENI Petroleum Co.Inc. Daily Report Well Code:23950 Field Name:Nikaitchuq • API/UW1: 50-029-23424-00-00 2^ Date:4/15/2014 - Report#: 3 II II page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 210-0410 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) Original Hole WORKOVER 1395.67 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 71.0 15.0 CLOUDY WC 2 WNW @ 10 MPH Daily summary operation 24h Summary FINISH BERMING CUTTINGS BOXES. TAKE ON PRODUCTION/INJECTION WATER, ALLOW TO COOL,TRANSFER TO RIG PITS. PUMP 65 BBLS WATER DOWN TUBING,230 BBLS TO IA. BLEED-OFF GAS. SET BPV. N/D SWAB VALVE AND TREE. N/U BOP'S. Operation at 07.00 INSTALL TEST DART 8 LJ/FILL STACK 8 PREP FOR BOPE TEST 24h Forecast FINISH N/U BOP'S. TEST ON 4.5"TEST JT. R/U BCL AND GBR EQ,BEGIN DECOMPLETION. PULL HANGER,PULL 4.5"12.69 L-80 IBTM TUBING AND ESP ASSY. 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 12.00 12.00 12.00 PREP A 1 P FINISH BERMING CUTTINGS BOXES. R/U LINES TO OP13 INJ MANIFOLD,LEVEL SENSOR. PJSM,TAKE PRODUTION/INJECTION WATER TO CUTTINGS TANKS,COOL TI140F,TRANSFER TO RIG PITS WNAC TRUCK. 1200 14.00 2.00 14.00 PREP A 1 P CONTINUE TAKE PRODUTION/INJECTION WATER TO RIG PITS. 14.00 14.30 0.50- 14.50 W.O. M 1 P CONTACT PRODUCTION TO UNLOCK OP06. 14:30 17.30 3.00 17.50 W.O. M 7 P PJSM,OPEN TUBING VALVE,28 PSI,PUMP 65 BBLS,8 BPM,250 PSI,SHUT IN. OPEN IA VALVE,270 PSI,PUMP 230 BBLS,8 BPM.530 PSI,SHUT DOWN. MONITOR WELL-TUBING 11 PSI,IA 182 PSI. BLEED OFF GAS. 17:30 00.00 6.50 24.00-W.O. C 5 P SET BPV. N/D SWAB VALVE AND TREE. N/U RISER AND SPACER SPOOL. SET BOP STACK ON RISER.N/U. PREP FOR BCL-HANG ELEPHANT TRUNK FROM DERRICK TO SPOOLING UNIT. Daily Contacts Position Contact Name Company Title E-mail Office _ Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dnlling Supv. 907-685-0710 Eni representative Wade Thomas Eni Petroleum Rig Clerk 907-670-8537 907-232-8631 Eni representative Vance Dale Eni Petroleum Materials Coordinato 907-685-0718 Eni representative Jeremy Decker Eni Petroleum Expediter 907-980-7545 Eni representative Troy England Eni Petroleum HSE 907-670-8602 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher 907-670-8603 Tool Push Mike Rees Nabors Alaska Drilling Tool Pusher 907-670-8603 Eni representative Davide Simeone Eni Petroleum Drilling Manager Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.892 L80 -1,361.2 11,113.0 8/27/2010 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 11111* Eni US Operatin... I Well Name:0P08-04 OR ENI Petroleum Co.Inc. Daily Report Well Code:23950 Field Name:Nikaitchuq • API/UWI:50-029-23424-00-00 2^ Date:4/16/2014 - Report#: 4 II II page 1 of 1 Wellbore name: Original Hole Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 210-0410 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) Original Hole WORKOVER 1396.67 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 74.0 17.0 OVERCAST WC 6 N @ 9 MPH Daily summary operation 24h Summary FINISH N/U BOP STACK,FLOW NIPPLE AND FLOWLINE. INSTALL KATCH KAN AND CURTAIN. TEST BOPS ON 4.5"TEST JT. R/U BCL AND GBR EQ. PULL TUBING HANGER,UD. P01-I,L/D 4.5"12.60 L-80 IBTM TUBING T/140'. BCL WORK ON ESP ASSY. Operation at 07.00 R/U TO RIH W/ESP ASSY 24h Forecast FINISH POH 4.5"12.60 L-80 IBTM TUBING AND ESP ASSY. UD ESP MOTOR ASSY. P/U NEW ESP MOTOR AND PUMP ASSY,RIH. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.50 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 W.O. C 5 P N/U BOP STACK ON RISER,N/U FLOW NIPPLE.FLOW LINE. INSTALL KATCH KAN AND CURTAIN. M/U BLEEDER LINE TO RISER. 05.00 10:30 5.50 10.50 W.O. C 12 P M/U 4.5"TEST JT AND VG TEST PLUG. FILL STACK AND MANIFOLD. TEST BOPS,RAMS L 250 PSI/H 3500 PSI ANNULAR L 250 PSI/H 2500 PSI. KOOMEY TEST 3000 PSI SYSTEM, 1800 PSI AFTER CLOSURE,200 PSI/42 SEC, FULL P/163 SEC. AVG CHG P 2200 PSI. AOGCC WITNESS WAIVED BY BOB NOBLE 10:40 4/14/14. 10:30 12:00 1.50 12.00 W.O. C 12 P L/D TEST TOOLS. BLOW DOWN CHOKE AND KILL MANIFOLDS. SECURE WELL,PULL BPV PER VG REP. 12.00 13:00 1.00 13.00 W.O. L 2 P R/U BCL AND GBR EQ ON RIG FLOOR. 13.00 00:00 11.00 24.00 W.O. L 4 P M/U LANDING JT,SAFETY VALVE. BO LDSS,PULL HANGER FREE AT 105 K,PU 95 K. BCL AND VG PREP HANGER,ESP CABLE AND LINE. UD HANGER. ADD 20 BBLS WATER TO IA. PULL 2 4.5"VIT JTS,L/D. PULL 4.5" 12.6#L-80 IBTM TUBING,L/D T/140'. BCL CUT AND SECURE ESP CABLE AND CAP TUBE TO ROPE. REMOVE CLAMPS AND PUPS FROM RIG FLOOR. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spin. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Wade Thomas Eni Petroleum Rig Clerk 907-670-8537 907-232-8631 Eni representative Greg Parker Eni Petroleum Matenals Coordinato 907-685-0718 Eni representative Jeremy Decker Eni Petroleum Expediter 907-980-7545 Eni representative Troy England Eni Petroleum HSE 907-670-8602 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher 907-670-8603 Tool Push Mike Rees Nabors Alaska Drilling Tool Pusher 907-670-8603 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 51/2 4.892 L80 -1,361.2 11,113.0 8/27/2010 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) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 fol ' Z Eni US Operatin... Well Name:OP08-04 OR ENI Petroleum Co.Inc. Daily Report Well Code:23950 Field Name:Nikaitchuq • APIIUWI:50-029-23424-00-00 2^ Date:4/17/2014 - Report#: 5 If �I page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share("A) Well Configuration type 210-0410 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) Original Hole WORKOVER 1397.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather NAM 0.0 71.0 16.0 LT SNOW WC 9° N @ 5 MPH Daily summary operation 24h Summary FINISH POH 4.5"12.6*L-80 IBTM TUBING AND ESP ASSY. UD ESP MOTOR ASSY. R/U GBR VOLANT TOOL. P/U M/U NEW ESP MOTOR ASSY. R/U HES SLICKLINE. RUN PUMP ASSY AND PACK-OFF,TEST. SET TUBING STOP. R/D HES SLICKLINE. M/U ESP MOTOR AND PUMP ASSY,BCL SERVICE MOTOR AND SEAL ASSYS. PULL ESP CABLE AND CAP LINE TO RIG FLOOR FROM SPOOLING UNIT. ATTACH,BCL PERFORM SPLICES,E-TESTS,ROT CHECKS. INSTALL CANNON CLAMPS. RIH ESP ASSY ON 4.5"12.6*L-80 IBTM TUBING T/311'. DGU INSTALLED AT 115',LOWER GLM AT 208'. Operation at 07.00 RIH ESP ASSY ON 4.5"12.6#L-80 IBTM TUBING AT/1,400'MD 24h Forecast FINISH RIH 4.5"12,6*L-80 IBTM TUBING AND ESP ASSY.F/311'T/4071'. P/U M/U TUBING HANGER AND LANDING JT. SET HANGER. 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.Dscr. 00:00 04:30 4.50 4.50 W.O. L 5 P UD ESP MOTOR ASSY TO PIPE SHED. POH 7"SHROUD,STRAP,RACK BACK TO SIDE IN DERRICK. LOWER ESP CABLE AND CAP LINE TO SPOOLING UNIT W/ROPE.ADD 10 BBLS/HR WATER TO IA. 04:30 09:30 5.00 9.50 W.O. 'K 5 P C/O ELEVATORS TO SIDE-DOOR. R/U GBR VOLANT TOOL. C/O ESP SPOOL. RIH 7"SHROUD. P/U M/U ESP MOTOR ASSY.ADD 10 BBLS/HR WATER TO IA. 09:30 14:30 ' 5.00 14.50 W.O. K 5 P PJSM,SPOT AND RN HES SLICKLINE UNIT. P/U TOOLS FROM PIPE SHED.RUN PUMP ASSY,PACKOFF. TEST/CHART 1000 PSI/15 MIN-GOOD TEST. SET TUBING STOP. ADD 10 BBLS/HR WATER TO IA. 14:30 00:00 9.50 24.00 W.O. v 5 P M/U PUMP ASSY TO ESP MOTOR ASSY. BCL SERVICE MOTOR AND SEALS. BCL ATTACH CAP LINE AND ESP CABLE/PIGTAIL. PULL ESP CABLE AND CAP LINE OVER SHEAVES FROM SPOOLING UNIT. BCL PERFORM SPLICES,E-TEST,AND ROT CHECKS. INSTALL CANNON CLAMPS. RIH ESP ASSY ON 4.5"12.6*L-80 IBTM TUBING T/311'. DGU INSTALLED AT 115',LOWER GLM AT 208'.ADD 10 BBLS WATER TO IA. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dug.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dnlling Supv. 907-685-0710 Eni representative Steve Abbott Eni Petroleum Rig Clerk 907-670-8537 Eni representative Greg Parker Eni Petroleum Materials Coordinato 907-685-0718 Eni representative Jeremy Decker Eni Petroleum Expediter 907-980-7545 Eni representative Troy England Eni Petroleum HSE 907-670-8602 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher 907-670-8603 Tool Push Thomas Brandenburg Nabors Alaska Drilling Tour Pusher 907-670-8603 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(f1KB) Run Date LINER 51/2 4.892 L80 -1,361.2 11.113.0 8/27/2010 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) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 Eni US Operatin... Well Name:0P08-04 OR 0191* ENI Petroleum Co.Inc. Daily Report Well Code:23950 Field Name:Nikaitchuq • APIIUWI:50-029-23424-00-00 2^n II Date:4/18/2014 - Report#: 6 II II page 1 of 1 Wellbore name: Original Hole Well Header PermiUConcession N° Operator ENI Share(16) Well Configuration type 210-0410 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) Original Hole WORKOVER 1398.67 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 71.0 -5.0 LT SNOW WC-22° N @ 9 MPH Daily summary operation 24h Summary RIH ESP ASSY ON 4.5"12.68 L-80 IBTM TUBING F/311'T/4070'. UPPER GLM INSTALLED AT 2116'. M/U TUBING HANGER AND LANDING JT. BCL AND VG INSTALL PENETRATORS. LAND HANGER.TEST U/L HANGER SEALS. SET BPV. N/U BOP STACK. N/U TUBING ADAPTER AND TREE,TEST HANGER VOID AND TREE. SECURE WELL. RELEASE RIG AT 0000 4/18/14 Operation at 07.00 MOB RIG TO OP16-03 Li.FINAL REPORT. 24h Forecast RIG RELEASED AT 00:00 408/14,MOB RIG TO OP16-03 L1. 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 .10:00 10.00 10.00 W.O. K 4 •P 'RIH ESP ASSY ON 4.5"12.66 L-80 IBTM TUBING F/311'T/4070'.BCL PERFORM E-TEST/1000'. INSTALL CANNON CLAMPS. UPPER GLM INSTALLED AT 2116'. CIO CAP LINE SPOOL. ADD 10 BBLS WATER TO IA. 1000 12:00 - 2.00 12.00 W.O. K 4 •P •R/D UD GBR VOLANT TOOL. C/O ELEVATORS. P/U LANDING JT.M/U TUBING HANGER. BCL AND VG INSTALL PENETRATORS,PERFORM SPLICES 12.00 '15,30 3.50 15.50 W.O. K 4 •P 'BCL AND VG FINISH PENETRATORS/SPLICES. LAND HANGER IN WELLHEAD.PU 95 K,SO 84 K. VG R/I LDS'S. BCL CECK CONT. TEST HANGER U/L BODY SEALS T/5000 PSI/10 MINED BCL EO FROM RIG FLOOR. LOWER ESP CABLE AND CAP LINE TO SPOOLING UNIT. L/D LANDING JT. INSTALL BPV. 15.30 '20:00 4.50 20.00 W.O. C 5 •P •N/D BOPS. REMOVE CURTAIN.KATCH KAN,BLEEDER LINE. N/D FLOW LINE AND NIPPLE. N/D RISER. RELEASE TURNBUCKLES. N/D CHOKE AND KILL LINES. PULL BOP STACK AND SET ON STUMP,SECURE. N/D RISER. 20.00 '00.00 4.00 24.00 W.O. C 5 -P N/U TUBING ADAPTER AND TREE. PULL BPV,INSTALL TEST PLUG. TEST HANGER VOID AND TREE T/5000 PSI/10 MIN. Daily Contacts Position _ Contact Name Company • Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.DrIg.Spvr. -907-685-0710 Eni representative Craig Rummer Eni Petroleum Dulling Supv. 907-685-0710 Eni representative Steve Abbott Eni Petroleum Rig Clerk 907-670-8537 Eni representative Greg Parker Eni Petroleum Materials Coordinato 907-685-0718 Eni representative Ken Bogner Eni Petroleum Materials Coordinato 907-980-7545 Eni representative Troy England Eni Petroleum HSE 907-670-8602 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher 907-670-8603 Tool Push Thomas Brandenburg Nabors Alaska Drilling Tour Pusher 907-670-8603 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom)ftKB) Run Date LINER 51/2 4.892 L80 -1,361.2 11,113.0 8/27/2010 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) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 OP05-06 Workover— Summary Page OP05-06 Rig Workover PTD#:210-080 Current Status Well OP05-06 is currently in production. Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and run in with a new conventional ESP system and packer. General Well info Reservoir Pressure/TVD: The ESP downhole gauge is reading 995 psi at 8,049'MD/3,724'TVD on April 24 , with ESP in running. Reservoir depth is 8,709'MD/3830'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 2010. Well type: Producer Estimated start date: May 7st 2014 Drilling rig: Nabors 245 RWO Engineer: Marc Kuck: Marc.Kuck@enipetroleum.corn Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. Shear lower GLM valve and circulate 9.1 ppg hot water with 3 %KC1 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. Set packer. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree.( 5000 psi test) 12. Circulate Freeze protect through tree down IA. 13. Shut in well. 14. RDMO. Current schematic of the well: 4-W 12.6 ppf Production Tubing I 2.168'MD,2,021'TVD 42°Inc-GLM.KBMG. 4-W x 1",with en i e't roleum 2.000 psi STS-1 SOV installed P /4-14"x-cplg cable clamps,for ESP OP05-06 'PIMPower Cable,(1)3/8"Chem Inj Line Dual Lateral Producer 7,947'MD,3700'ND 77°Inc-GLM,KBMG. 4-14'x 1",with with ESP Lift r 3,100 psi STS-1 SOV installed As Completed r 8,049'MD,3,724'TVD-Discharge Gauge Sub 11/15/2013 8,151'MD,3,747'TVD,77°Inc-Bottom of Motor Centralizer Centrilift,TTC-ESP,116-stage 380P18SXD pump.513 GSB3 seals,150 HP MSP325 motor Surf.Casco, 4 � 8,166'MD 32#Shroud Assembly with cable and 13-3i8".68 /� ,� chemical injection line feed-thrll5 Slotted Liner, 2.416'M D.2.189' ' 5-W Silver Bullet Ecc. 5-':"15.5 ppf TVD 8.387-8,404'MD, HAL 5-14 Oil Swell �/ Nose Guide Shoe with 17.015'M D.4.053' CasingExit Window Packer 518.20 \ / \� gent Joint - TVD 8.206'MD.3.159' / 89' Inc. TVD-L1-Baker . _ SLXP Liner - ♦ __ittlttlittf Hanger/Packer 1 - ' Silver Bullet Ecc. ti'Llu..L-.''1:1r ® Nose Guide Shoe S 1/2"Oil Swell Pck 42=Ma - - - - - 1 8.494'MD. / EVEIMMITI ORM Baker TVD• 11 Il ,/ L 2"Od Swell Pck p4� Baker SLXP E172:371MEEltitl' _ Liner Hanger fir Swell Pck#6ltiti I Packer .-w- -- -- Slotted Liner. Item(Lower Lateral) MD lht Interco.Casing Resman Tracer Sub 41 R05 20/RWS 158 8739.6 item(Lower Lateral) MD(h) S-'4"17 ppf Resman Tracer Sub R2 ROS 148/RWS 160 ll75B.3 9.5,8".47# 51/2"Oil Swell Pck#1 8709.$ HAL 5-Y:" 16,920'MD.4,001'TVD Resman Tracer Sub#3 ROS 149/RWS 159 13666.8 8,684'MD. 51/2"Oil Swell Pck 112 11772,9 ON Swell Packer 92°Inc. Resman Tracer Sub#4 ROS 147/RWS 157 15111.8 3,831'TVD 51/2"Oil Swell Pck 43 13640.8 Resman ON/Water - _ 4.-1 ,-,/ 90`Inc. 51/2"Oil Swell Pck 44 15085.7 Tracer Sub Planned schematic of the well: ___._----3-W 9.2 ppf Production Tubing,IBTM 3'W x-cplg cable damps,for ESP Power Cable,3/8"Chem ern l Inj Line,'/.'hyd.Control line fi i lH<1fIT11 TR-SCSV,2.81"'X'Profile,W SS hyd.Control line OP05-06 Dual Lateral Producer 4"- � — +1-2013'MD,1900'ND 35°Inc.Twine Seal Packer with 3 '/2" Completion i — PGV Gas Vent Flapper Valve,W SS hyd.Control line X-nipple As Plane v2 ,.+ -- 3-'/?x-cplg cable clamps,for ESP Power Cable,(1)3/8"Chem lnj Line 2 7/8"ADV Valve +1-8,155'MD,3748'ND,77°Inc.,Bottom of Conventional ESP \'\ �.\ Slotted Liner. /. 8.387-8.404'M D. HAL 5'h"Oil Swell 5- °Silver Bullet Ecc 5-'�"15.5 ppf .,\ "%/2-• Nose Guide Shoe with 17,015'MD.4.053' ��� \ Casing Exit Window Packer'''',..,,,,,, gent Joint TVD 89°Inc. 8.206'MD.3.759' 'r TVD-L1-Baker — — — — - — — — SLXP Liner ' M a — AIM= Hanger/Packer _ - - - - _ _- - -� - ___ - 5-1/2"Silver Bullet Ecc _ _Nose_Guide Shoe 8.494'MD. 3.816'TVD. Baker I I Illillill if Baker SLXP Liner Hanger/ , Packer —-_ �~ .......--e• - Slotted Liner, Interm.Casing 5-'i"17 ppf 9-5/8".47# HAL 5-W 16.920'MD,4.001'ND 8.684'MD. Oil Swell Packer 92°Inc. 3.831'TVD Resman Oil/Water 90°Inc. Tracer Sub Nikadchuq Field-Ohktok Pant a b g§i �� r411 §11 ; aN W P I g I! frIIIHUII_I.he WNo III I= �l � 7 n in a ii W'W $ WZz LC zIR li ' _ Z Hd I I lkI Z�W N - II•• teCt a ® Io• 01' - I ��0- 12j r �I [IL1 III= ^ :_;,._`.__ — Z o re P- �o'z % •. :i...... ooZw m<0 • N a g 'Wfk8 OM z$g �R�3 her , g il P; a g 5 i „ 1 Irl' NN\ za I,,1_XyN K O V 2 I x U a III, z Y a V o ''3 ct --] AL ] L_ g __ .....-JZ • V n �� aUHlh I 1 Q o ■ u_ I a ix*g., o w h t , = N a VetcoGray MB-247 SURFACE COMPLETION SYSTEM �iINN/CL f-- 6330 ,/" --I5 37.19 1 His 1. o II a. Z1 t �' , T.0 S. EL 26' 5-3/4" ia. ' 1.062 OFFSET C/L I B.O.S. EL 25' 7-1/4" © TOP OF WELLHEAD 5.O0' EL 25' 2-1/4- 01 p (I CI PFT ELECTRICAL Ili_ FEEDTHRU 21.81 Y or• J7 13-5/8' 5000 PSI .. VG 5137 CLAMP „MINIM ii- 5000 PSI �I] 'I IIrC i_ __ CLD - J-- ___ !EiJ1j,(!M 3.437 OFFSET 106.0 6.50'- Ill In _.:i..;. 2-1 PSI I 1'Y�1- 5000 631 ,.I T.• _ _1/16. —e ® yt. �_� — 5500 I -:1C_ .. __ I '- 66.71 PosmON .�I I. 13'5000 PSI 52.96' •wail' ' ib w VG 134 MOO. 26.5. ■U i f —:' `' SI, silk ?I:• � 34.00' •I . 11_: . :,11._ 2_1,16' 1 5000 PSI 24.2 -- - '', I:' 15.25' OUT Or POSITION B=.1111yam. i _ TOG I TOP OF GRADING I.- - EL 16' 1-1/4' • 1.00 PROPRETAR1 NOTICE 450' 20' OD 133 K-55 r Err'!-E'a.-- ����r�- 13-3/8' OD 68# L-BO A, .! J. WACO ENI ALASKA 9-5/8 00 53.5 L-80 MI=Pn HORIZONTAL MULTI-BOWL SYSTEM 4-1/2' 00 WITH 6-5/B VT I' 20 X 13-3/8 X 9-5/B X "O.1' X 4-1/2 WITH 6-5/8 MT E BORAk AND ESP FLAT CABLE 23 Arid m "....:24,V(i)-(} tti r H173370-1 �.a.. r4 wr...c t.....0a.® .O WIN 868!. 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Li O °o o`n o o 0 O C%. jl W = V N N > U J M• M_ CU W d N N Z v C) h I� X re a Q a Z' o N y O J _ .� 0 _ V U N I CL E N o jO U U m `o • N a) j 0 a • er E ,N N N N N Jo U H Q 0 0 1 ii a v A N 0 O O �- C�_ o E.:. 16 W �,I ��0. — 0 CO m CO a c C/) 0 N O N V, ~_H N co '', o O Q _ Z Qo ° w .> .> 4' w Z EO ! > > .> .> .> W O I N y N N N co 0 CU CU 0 CD Z w tx ce cc w C C C C C O) O O O O O 0) 0 > 7 > > > O M C c c C c to Z O pp Q T r O) . � I m C ` 0 a) d Q CL d N m d d C C u- P d Z CV 0 d Z C O C O v is O ._ N G)r 1 i N 0 N) a I I O d O O O I J J J W O O d J J t c N O Q 0 Q R I O O I O j t s j - MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg zj�,f DATE: March 24, 2011 P. I. Supervisor ( ( 1 FROM: Lou Grimaldi SUBJECT: No Flow Verification Petroleum Inspector ENI Petroleum OP08-PO4 PTD # 210-041 Nikaitchuq Field Thursday, March 24, 2011; I witnessed the No-Flow test on ENI Petroleum's well OP08-PO4 in the Nikaitchuq Field. I had been in contact with the operator Delton Carrol about equipment and procedure. When I arrived he was very prepared for the test. I arrived at the facility to find the well open to atmosphere. The tubing and annulus were tied together with a "C" section used to vent free gas on the backside to the flowline. This well is a packer-less completion. After verifying the position of the pertinent valves The Flow (if any) would be measured by an Erdco "Armor flo" gas meter capable of measuring 150-1500 scf/hour of gas flow. There also was a calibrated 30 psi "Test" gauge (0.1 psi increment) used to monitor the tubing/annulus pressure. A % turn block valve downstream of the gauge was used to close the flow from the tubing/annulus to atmosphere/tankage. I required 2 equal-time tests, both involving shut-in and flowing intervals. During the 2 tests, tubing pressure never rose above 11.3 psi and sustained gas flow was well below the measurable capacity of the flow meter (150 scf). There was no fluid produced to surface during the entire no flow test I monitored. The following table describes the details of the test: 2011-0324_No-Flow_NikaitchugOP08-PO4_1g.doc 1 of 2 r Nikaitchuq OP08-PO4 No Flow Test Time Pressure Flow Notes 1100 0 Bare Whisper Start of test, well lined up to open top tank 1100 0 Shut in well at wellhead 1115 1.9 Shut in. 1130 5.3 Shut in. 1145 7.7 Shut in. 1200 9.8 Shut in. 1215 11.3 1500SCF/hour Open well to open top tank, press dropped to 8 psi and fell off to 0 Pressure/Flow quickly. 1230 0 Whisper Flow thru flow-meter to bleed trailer 1245 0 Whisper Flow thru flow-meter to bleed trailer 1300 0 Whisper Flow thru flow-meter to bleed trailer 1315 0 Shut in. 1330 2.1 Shut in. 1345 4.3 Shut in. 1400 5.8 Shut in. 1415 6.9 1600SCF/hour Open well to open top tank, press dropped to 4.5 psi and fell off to 0 Pressure/Flow quickly.Flow thru flow-meter to bleed trailer 1430 .1 <150 SCF/hour Flow thru flow-meter to bleed trailer 1445 0 Bare whisper Flow thru flow-meter to bleed trailer 1430 0 Bare whisper Flow thru flow-meter to bleed trailer 1445 0 Bare whisper Flow thru flow-meter to bleed trailer 1515 0 Bare whisper Flow thru flow-meter to bleed trailer The test was concluded at this point. I observed less buildup in the second shut-in test and quicker bleed down in the second flow test. This well appears to meet the criteria set forth in 20 AAC 25.265 for No-Flow status. Attachments: None Non-Confidential 2011-0324 No-Flow Nikaitchuq OP08-PO4_lg.doc — 2of2 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Mahnken Well No OP08-04/0P08-04PB1 Date Dispatched: 2-Jul-10 Installation/Rig Nabors 245E Dispatched By: Paul Wyman Data No Of Prints No of CDs OP08-04-Logs: 1 2 in MD 1 2inTVD 1 OP08-04PB1 -Logs: 1 2 in MD 1 2 in TVD 1 /C � ' +.3'-� E oLu to' 1l I,v� 2010 Alaska C z Avichornce Received By: Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 pvvvman@slb.com Paul Wyman Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El . Gas❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC25.105 20AAC25.110 Development El • Exploratory GINJ❑ WINJ❑ WDSPL❑ 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.: 7/13/2010 • 210-0410 . 3.Address: 6.Date Spudded: ,. jO r 03.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 -.§-1-171-16.'1° (e'I1i i`;l 50-029-23424-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: ` 14.Well Name and Number: Surface: 3197 FSL 1576 FEL S5 T13N R9E UM 7/8/2010 • OP08-04 • Top of Productive Horizon: 8.KB(ft above MSL): 53.2 • 15.Field/Pool(s): 709'FSL, 1672'FEL,S32 T14N R9E UM Ground(ft MSL): 12 • Nikaitchuq . Total Depth: 9.Plug Back Depth(MD+TVD): 274'FSL,4513'FEL,S29 T14N R9E UM 11,113 MD/3727 ND 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: . Surface: x- 516703.74 • y-6036550.67 • Zone- 4 • 11,240 MD/3706 ND • 0373301,0355024,0390616 TPI: x- 516593.3448 y-6039340.247 Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 513726.79 y-6044180.37 Zone- 4 none ADL 417493 18.Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost(ND): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) _ 1874' 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 ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 178.89 X-65 SURFACE 154 SURFACE 154 30 Cement to Surface 13-3/8" 68 L-80 • SURFACE 2334 SURFACE 2151 16 352 bbls 10.7#ASL,72 bbls 12#Crete 9-5/8" 47 L-80 SURFACE 4999 SURFACE 3629 12.25 103 bbls 12.5#Litecrete I 5.5" 17 L-80 4814 11113 3616 3727 8.5 slotted liner 23.Open to production or injection? Yes Ei No❑ If Yes,list each 24. TUBING RECORD interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) slotted liner 4.5 4417 NA/ESP completion -. 25. ACID,FRACTURE,CEMENT SQUEEZE,ETC. C(fSCP14111/y » DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): NA(to be Jan 1,2011) ESP Completi n 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 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+ND 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 MC 25.071. +RFC VED At)t'i 0 9 ?01t RBQMS AUG 10 10i Alaska!' a Ge»Germ•Commission Form 10-407 Revised 2/2007 CONTINUED ON REVERSE 74- (.57// tiachelr ge ,,'Y a../ /i' 6 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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 1874 1765 Nr ? OA sand top 4976 3628 Formation at total depth: OA sand 11240 3706 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: (U_'( Phone: Date: / 61 2 i INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole Item la: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for I njection,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 illytii J Eni E&P Division Daily Report Well Name: OP08-04 ENI Petroleum Well code: 23950 • CO. Inc. Field Name: Nikaitchuq • Date:6/17/2010 - Report#: 1 APUUWI: 50-029-23424-00-00 page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM ■ 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 I 12.20 Rig Information Contractor [Rig Name Rig Type NABORS ALASKA ! NABORS 245 E .LAND RIG Job Information Wellbore Job Phase I Spud Date Target Depth(ftKB)'Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 1 6/20/2010 10,927.0 I 3,758.9 11,810.00 158.27 74.6 -2.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB 'Temperature(°F) Weather Wind 77.0 32.9 Cloudy,Fog,WC 21°NNE @ 15.2 22.3° mph Daily summary operation 24h Summary Move in/Rig up Nabors 245 on OP08-04 Operation at 07.00 Rig move 24h Forecast Move in/Rig up Nabors 245 on OP08-04 Lithology Shows JMAASP Pressure(psi) !Mud Weight(lb/gal) Time Log Cum Start End Dur Our Time Time (hrs) (mss) Phase Opr. Act Plan Opsr.Dew. _ 08:00 00:00 16.00 16.00 MOB A 2 P PJSM,commence rig down Nabors rig 245,move to OP08-04 RIG UP/DOWN-MOBILIZATION PREP FOR RIG MOVE.SECURE BOPS/IRON RUFFNECK,RAISE CELLAR BOX,R/D DE-GASSER LINE,FLOWLINES.INNER CONNECT LINES. R/D BERMING AROUND RIG,ROLL UP LAMBSON CURTAINS RIG UP/DOWN-MOBILIZATION REPAIR DERRICK CAMERA. RE-WORK BOLTS ON BOP'S.REMOVE RENTAL HYDRAULIC UNIT.PREP BIG CRIB BLOCKS F/INSTALLATION.START COLD START GENERATOR AND SPLIT MODULE POWER.PREP LAMPSONS F/RIG MOVE RIG UP/DOWN-MOBILIZATION MOVE SUB MODULE T/EAST, UTILITY MODULE T/WEST.REMOVE RIG MATS AND HERCULITE F/PAD GRADING. Daily Contacts Position ! Contact Name Company I Title E until I Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative I Dave Morris ENI Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com ,907-670-8607 907-229-6100 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) 1 Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type :Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) to* Eni E&P Division Well Name: OP08-04 ENI Petroleum Daily Report well Code: 23950 Field Name: Nikaitchuq •n Co. Inc. Date:6/18/2010 - Report#: 2 API/UWI: 50-029-23424-00-00 111 fl Wellbore name: Original Hole page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 1ENI PETROLEUM 100.00 1DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB•Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG 1 Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(R/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 -1.94 Daily Information Depth End(ftKB) Depth End(TVD)(...'Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB (Temperature(°F) Weather Wind 80.0 30.9 Cloudy.WC 20.7 5N @ 14 mph Daily summary operation 24h Summary Remove ice from old location.Survey to+2"grade in front on WCS.Spread gravel and level.Spot Herculite and mats,Move rig sub over conductor. Operation at 07.00 Rig up and install well head 24h Forecast Finish rig move 8 R/U Nabors 245-Prep for spud. Lithology chows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 MOB A 2 P Remove mats and clear Herculite from where old rig location,ice built up under same and attempt to remove with both loaders. 04:00 11:00 7.00 11.00 MOB A 1 P Remove ice and clear form pad,mobilizated AIC grader to rip/blade same,prep location for gravel to belayed.Lounsbury 1 survey grade+2"and stack out pad.Work in pits,change out 8 clean out desilter cones,replace equalizer gaskets.Prep diverter line for remove w/crane from on top of WCS.Change out saver sub on top drive. 11:00 19:00 8.00 19.00 MOB A 1 P Rig loaders haul and spread gravel to a grade+2"in front of WC for rig sub and utility module-AIC road grader put final grade and leveled location.Continue working in pits to changing out gaskets in equilizers,also remove two section of diverter line,change out steel WCS hatch cover for aluminum cover,prep surface annular preventer for storage/shippment to town. 19:00 20:00 1.00 20.00 MOB A 1 P Lay out Herculite liner and spot rig mats for rig sub on Well OP08-04. 20:00 00:00 4.00 24.00 MOB A 2 P Move rig sub in and center over conductor and confirmed level,all load bearing surface were in contact with rig mats.Set mats for utility module. Daily Contacts Position -Contact Name Company MN E-mail 7_------Offer Mobile Eni representative '.Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 1907-670-8623 907-841-8759 Eni representative Alvin Criswell ENI :I Expediter Alvin.Criswell @enipetroleum.com 1 907-980-7545 Eni representative 'Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative David Smith ENI 1Drilling Spvr. 907-670-8623 1907-632-3085 Last Casing seat Cas.Type OD(In) I ID(In) Grade Top(RKB) I Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) ND(ftKB) I Fluid Type Fluid Density(lb/gal) P(Surf)(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) ifiltios Eni E&P Division Report Well Name: OP08-04 Daily Repot L Well Code: 23950 ENI Petroleum Field Name: Nikaitchuq n• CO. Inc. Date:6/19/2010 - Report#: 3 API/UWI: 50-029-23424-00-00 11 Wellbore name: Original Hole page 1 of 1 Well Header PermltConcesslon N° Operator ENI Share(%) Well Configuration type 402100 IENI PETROLEUM 100.00 'DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor 1 Rig Name Rig Type NABORS ALASKA 1 NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 -0.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB 'Temperature("F) Weather Wind 86.0 30.0 Cloudy.Fog. WC 30 NNE @ 14 mph 19.8 Daily summary operation 24h Summary Finish rig move and R/U of equipment. Install starting head and adapter. Mix spud mud. Work on rig fabrication work. Load drill pipe and BHA in shed. Operation at 07.00 Picking-up 5"drill pipe 24h Forecast Install flow nipple-P/U DP and BHA. Replace 4"HP valve in mud line.Conduct pre-spud meeting.Spud well Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Cum Start End Dur Dur Time Time (hrs) Mrs) Phase Opr. Act. Plan Opsr.Descr. 00:00 04:30 • 4.50 4.50 MOB A 2 P Spot Utility Module in place against rig sub,check all alignment of service connect between unit. 04:30 06:30 2.00 6.50 MOB A 2 P Hook-up interconnect's between modules-flow line area,charge pump room,plug electrical plugs into sub and berm rig. 06:30 08:00 1.50 8.00 MOB A 2 P Nipple-up starting head w/VG landing ring and adapter flange on conductor,test to 500 psi for 5 mins with Vetco Gray hand. 08:00 16:00 8.00 16.00 MOB A 2 P Welders-Nabors fabricated new conductor/flow nipple riser and GBR installing equalizer line/valve in suction line in pit #4.Calibrate and test all gas detectors.Service Top Drive(change oil&repair torque booster)&inspect same-OK. Remove ESP sheave from derrick.Load 132 jts.5"drill pipe in shed,Strap pipe.MI Swaco&CH2M loader operator build containemnt for CCB ISO pumps,R-Valve conex,&slop tank-berm in same.MI R/U COB hoses,lines&etc.Starting mixing spud mud @ 1400 hrs.as per MI mud egineer. 16:00 00:00 8.00 24.00 MOB A 1 P Conitune mixing spud mud as per MI mud engineer.Mixed a total of 600 bbls.8.8 ppg&120 vis.Gyro data build tools& test,Install in DC-retest. M/U back tools string.Load BHA in pipe shed.Continue working on welding on flow nipple riser &suction line in pit#4.After repair of 4"OTECO high pressure valve on#3 mud pump,tested&leaked @ 1000 psi. Remove same and Nabors will replace with new demco valve,(required welding).Go through pre-spud check list. Daily Contacts Position _ Contact Name Company use E-mail 1 Office Mobile , Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative ;Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 1907-670-8607 Eni representative ,Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative 'Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) I ID(In) Grade Top((RCS) I Bottom(15KB) Run Date Last Leakoff Test Depth(5KB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) 'P(Surf)(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) siyokt Eni E&P Division Well Name: OP08-04 ENI Petroleum Daily Report Well Code: 23950 -Field Name: Nikaitchuq • CO. Inc. Date:6/20/2010 - Report#: 4 API/UWI: 50-029-23424-00-00 2nopage 1 of I Wellbore name: Original Hole Well Header Permit/Concession N° Operator L ENI Share(%) Well Configuration type 402100 IENI PETROLEUM J 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 1 12.20 Rig Information Contractor Rig Name [Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information --,, Wellbore Job Phase Spud Date Target Depth(ftKB)',Target Depth(TV... Depth Dr.(MD)(ft) Drifting Hours(hrs) Average ROP(ftlhr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 1 3,758.9 11,810.00 158.27 74.6 0.06 Daily Information Depth End(ftKB) Depth End(TVD)(... a t ress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 165.0 165.0 35.00 0.50 70.0 89.0 30.9 Cloudy.Fog. WC 24 NNE @ 14.5 mph 20.3 Daily summary operation 24h Summary N/U flow riser and spill prevention,and flow line. Modification to#4 pit suction line and replace 4"high pressure valve on#1 mud pump line. P/U 5"DP,HWDP and clean out assembly. Conduct Pre- Spud meeting. clean out conductor and drill new hole to 165' POOH to P/U Schlumberger/Gyro Data directional tools. Operation at 07.00 - - - Drilling ahead to kick-off point. 24h Forecast -- -- ------- ----. _____ P/U Schlumberger/Gyro Data directional assembly. Drill ahead from 165'. P/U remainder of non-mag drill collars while drilling hole and follow well directional program as per Sdumberger DD to total depth of surface hole. Lithology _ -- Shows I MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log cum Start End Dur Dur Time lime (bra) (MS) Phase Opr. Act Plan ;,I Oper.Deaar. 00:00 08:00 8.00 8.00 MOB A 1 P P/U and N/U flow riser from adapter flange on starting head;install turn buckles and flow line.Install Katch-Kan&skirt around same,put liner between Dixie cup&well bay.GBR Welders-finished suction line,re-installed line with new valve -cut off OTECO valve from#1 mud pump high pressure line,dress and weld out 4"1002 union,install 1002 unions on new 4"Demco valve to replace Oteco valve. 08:00 19:00 11.00 19.00 DRILL E 4 P P/U 132 joints of 5"drill pipe and stand back in derrick,(new pipe required to make&break connection).Continue to P/U 14 jts.of 5"HWDP with jars&stand back in derrick.Tag BTM @ 130'in conductor. 19:00 21:00 2.00 21.00 DRILL E 5 P Install new 4"Demco valve on#1 mud pump line-finished spill containment In cellar area-fill hole/flow riser with mud;no leaks-Pressure test HP mud lines and new valve to 2500 psi for 5 mins;good. 21:00 22:00 1.00 22.00 DRILL E 4 P P/U clean out assembly as per Schlumberger to tag CO 130'ready to spud. 22:00 22:30 0.50 22.50 DRILL E 20 P Held pre-spud meeting with all personnel on tour-over reviewed well program and discussed safety aspects and spill prevention,main focus is good communication between crews. 22:30 23:00 0.50 23.00 DRILL E 3 P Rotary drill-clean out f/130'-t/165'-pump rate @ 550 gpm with 450 psi.-40 RPM @ 900-1000 ff/Ibs torque-WOB - 4-5K-Up wt 55K-Dn wL 55K-Rot wt.55K. 23:00 23:30 0.50 23.50 DRILL E 4 P POOH f/165'to mud motor,L/D XO. 23:30 00:00 0.50 24.00 DRILL E 14 P Calibrate block height with Schlumberger MWD.Load floor with remainder of BHA(stab&XO). Daily Contacts Position I Contact Name Company I Title E knail I Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith EM Drilling Spvr. 907-670-8623 907-632-3085 Eni representative :,Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative l Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative [Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) I ID(In) Grads i Tap( ) Bottom(MD) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) j I loll Eni E&P Division Well Name: OP08-04 ENI Petroleum Daily Report Well Code: 23950 Co. Inc. IFieldName: Nikaitchuq enti Date:6/21/2010 - Report#: 5 API/UWI: 50-029-23424-00-00 page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 (ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E BLAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB)'Target Depth(TV... Depth Dr.(MD)(ft) T Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 1 3,758.9 11,810.00 158.27 74.6 _ 1.06 Daily Information Depth End(ftKB) Depth End(ND)(... Depth Progress(ft) Drilling Hours(hrs) (Average ROP(ft/hr) POB Temperature(°F) Weather Wind 1,125.0 1,108.9 960.00 17.50 54.9 87.0 29.3 Cloudy.Fog.WC 45 NE @ 13 mph 19.0 Daily summary operation 24h Summary P/U Schlumberger/Gryodata directional drilling assembly.Drilling surface hole.Check shot Gyro Pulse tool on Schlumberger E-line survey tool @ 788'MD-good survey. Continue to drill ahead per well plan. Operation at 07.00 Drilling 16"surface as per Schlumberger directional driller. 24h Forecast Drill to Surface Casing TD per directional plan. Lithology Shows MAASP Pressure(psi) 1Mud Weight(lb/gal) I 1 9.00 Time Log Cum Start End Dur Dur 'rims Thee (hrs) Mrs) Phase Opr. Act Plan Oper.Descr. 00:00 03:30 3.50 3.501 DRILL E 4 -P Held PJSM for BHA#2-P/U directional assembly as per Schlumberger/Gyro Data U 157'. 03:30 04:00 0.50 4.00'DRILL E '7 P Break circulation and obtain directional survey data from gyro pulse tool,pre-formed check shot. 04:00 07:30 3.50 7.50 DRILL E 3 P Rotary%slide drill 6165'-t/249'-start KOP @ 180'-pump rate @ 400-525 gpm with 420-620 psi.-40 RPM @ 2K ft/lbs torque-WOB 15-20K-Up wt 65K-Dn wt.65K-Rot wt.65K. 07:30 08:30 1.00 8.50 DRILL E 4 P POOH-stand back 5"HWDP-P/U two NMDC,stab and XO to complete BHA. - '. 08:30 12:00 3.50 12.00 DRILL E 3 P Drill slide/rotary:f/249'-U 502'with 550 gpm @ 810 psi.-40 rpm @ 1-2K torque-WOB 20-30K-(ART=1.18 hrs./ AST=2.56 hrs./Jars hrs.=3.70).Up wt.=85/On wt.=85K/Rot wt.=85K. 12:00 16:30 4.50 16.50 DRILL E 3 P Drill slide/rotary as required for well plan f/502'-t/788'-pump rate 470 gpm @ 765 psi-pumped 25 bbl weight sweep @ 755'-40 rpm @ 2K torque-WOB 20-25K.Up wt=90K/Dn wt.=90k/Rot wt.=90K. 16:30 18:00 1.50 18.00 DRILL E 19 P Schlumberger/Gyro Data-RIH with e-line gyro survey tool for check shot of Gyro Pulse tool,good-also preform several check shots while POOH.RN Schlumberger E-line equipment. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill slide/rotary:f/788'-U 1,125'with 470 gpm @ 765 psi.-40 rpm @ 1-2K torque-WOB 20-25K-(ART=1.42 hrs./ AST=5.22 hrs./Jars hrs.=11.1).Up wt.=102/Dn wt.=95K/Rot=97K. Dal Contacts '" -w` .; a ,,i, me Company T Title E-mail 1 Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 i Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) ID(M) Grads Top(ftK8) Bottom MKS) Run Date Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(1b/gal) !Leak Off Pressure(psi) ilioil i 1 Eni E&P Division Well Name: OP08 0a Daily Report ort ENI Petroleum Well Code: 23950 • Field Name: Nikaitchuq (� Co. Inc. Date:6/22/2010 - Report#: 6 API/UWI: 50-029-23424-00-00 •�- J page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) iWater Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) 'Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 2.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) i Average ROP(ft/hr) P08 Temperature(°F) Weather Wind 2,344.0 2,159.4 i 1,219.00 16.00 i 76.2 91.0 31.8 Cloudy,Fog WC 24 NNE @ 9 mph i j 24.1 Daily summary operation 24h Summary Drill slide/rotate from 1,125'to 1,266'.Ream and wash out 6.70 dogleg from 1,140'-1,266'. Drill slide and rotate from 1,266'to 2,344'. TD surface hole at 2,344'. Circulate and condition hole. Made wiper trip to 600'on elevators. Monitor well. RIH to 2,344'. Circulate and condition hole for 13-3/8"casing run. Operation at 07.00 UD Schlumberger BHA 24h Forecast Circulate and condition hole. POOH and UD-Dummy hanger run.R/U GBR casing equipment.Run 13 3/8"casing.Circulate and condition hole for cement job while R/U Schlumberger lines.Pump cement. Lithology --_-- J(Shows --- IMAASPPressure(pal) Mud Weight(lb/gal) 9.40 Time Log Cum Start End f Our Dur Time Time (hrs) (ys) Phase Opr. Act. Plan Opar.Dena. 00:00 03:00 3.00 3.00 DRILL E 3 P Drill Slide/Rotate f/1125'-111266'-pump rate 520 gpm with 950 psi.-40 RPM @ 4-5K ft/lbs torque-WOB 20-30K-Up wt 100K-Dn wt.95K-Rot wt.95K. 03:00 05:00 2.00 5.00 DRILL E 6 U Reaming/washing out 6+degree dogleg f/1140'-t/1266'-pump rate @ 600 gpm @ 950 psi.-40 RPM @ 2K torque-Up wt 100K-Dn wt.95K-Rot wt.95K. 05:00 12:00 7.00 12.00 DRILL E 3 P Drill Slide/Rotate f/1266'-1/1757'-pump rate 610 gpm @ 1170 psi.-40 RPM @ 3-4K ft/lbs torque-WOB 25K-Up wt 115K -Dn wt.100K-Rot wL 110K. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Slide/Rotate 1/1757'-t/2344'(TD surface)-pump rate 754 gpm @ 1650 psi.-40 RPM @ 4-6K fl/Ibs torque-WOB 15-25K-Up wt 140K-Dn wt.105K-Rot wt.112K. 18:00 20:30 2.50 20.50 DRILL E 7 P Circulate&reciprocated string with pump rate @ 800 gpm with 1650 psi.&65 RPM @ 4k torque-pumped 35 bbls. weighted sweep-circulate 3 1/2 bottoms-up until clean.Flow check for 5 mins. 20:30 22:30 2.00 22.50 DRILL E 4 P POOH on elevators to HWDP @ 630'-tight spot f/1180'-1/1260'-pulled 25K over @ 1200'-worked twice-pass through free.Proper hole fill&monitor well 5 mins. 22:30 23:30 1.00 23.50 DRILL E 4 P RIH f/630'-1/2256'-good hole condition-wash down from f/2256'-1/2344'.Up wt 135K-Dn wt.105K-Rot wt.112K. 23:30 00:00 0.50 24.00 DRILL E 7 P Circulate&reciprocated string with pump rate @ 800 gpm with 1650 psi.&65 RPM @ 4k torque-pumped 25 bbls. i ' weighted sweep-After breaking circulation and inital bottoms-up cuttings returns increase by 300%&weight sweep cuttings increased by 100%of clay&little sand. I NOTE: Total Rotating Hours for 16"Surface Hole: 6.60 Total Rotating Footage for 16"Surface Hole: 976' Total Sliding Hours for 16"Surface Hole: 14.60 Total Sliding Footage for 16"Surface Hole: 1,208' Daily Contacts Position I Contact Name Company Title E-nafi , Office Mobile Eni representative Scott Beauchamp (ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative :Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com ,907-670-8607 Eni representative ,Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative iAlvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative jMichael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) t ID(n) Grade 1 Top lam) i Bottom(RKB) Run Date CASING 133/8, 12.415 L80 0.0 2,333.6.6/23/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) P(Surf)(psi) !Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 1 os Eni E&P Division Well Name: oPOa-04 Daily Report _ ENI Petroleum Well Code: 23950 • CO. Inc. Field Name: Nikaitchuq • Date:6/23/2010 - Report#: 7 APIIUWI: 50-029-23424-00-00 page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 1DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 1 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 'LAND RIG Job information Wellbore Job Phase Spud Date Target Depth(RKB);Target Depth(TV... Depth Dr.(MD)(ft) IDrilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 1 3,758.9 11,810.00 158.27 74.6 3.06 Daily Information Depth End(ftKB) Depth End(ND)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind _. ._2,344.0 2,159.4 0.00 92.0 32.4 Clear,WC 23.4 1N @ 11.6 mph Daily summary operation 24h Summary Circulate weighted sweep and four bottoms-up. Hole clean. POOH and L/D Schlumberger/Gyrodata Directional BHA. Repair pipe skate.Make a Vetco Gray dummy run on hanger.R/U GBR casing tools. R/U/P/U and ran 13 3/8"casing.Circulate and reciprocate casing while condition mud.PJSM w/Schlumberoer. R/U lines and oumo cement. Operation at 07.00 Cementing 13-3/8"casing. 24h Forecast Cement 13-3/8"casing. Nipple down diverter. Nipple up and test BOPE. Pick up BHA. Prepare to drill ahead with 12-1/4"hole. Lithology Shows MAASP Pressure(psi) IMud Weight(lb/gal) --- _ I 9.40 Time Log Cum Start End Dur Dun Time Time (has) (his) Phase Opr. Act. Plan Opsr.Descr. 00:00 01:30 1.50 1.50 DRILL E 7 ,P Circulate and reciprocate drill string with pump rate @ 800 gpm with 1760 psi.and 65 RPM @ 4k torque.Weighted sweep , increased returns 100%.Circulated plus three bottoms-up.Hole clean.Up Wt 135K-Dn Wt.105K-Rot wt.112K. Monitor well 10 minutes. 01:30 03:30 2.00 3.50 DRILL 'E 4 P Trip out of hole from 2,344'to 692'. Pulled wet. Pulled 25K over at 2,060'. 03:30 09:00 5.50 9.00 DRILL E 4 P Lay down BHA. Stand back HWDP and drill collars. Lay down ARC,stabilizers,crossover and bit. 09:00 09:30 0.50 9.50 DRILL E 4 I P Safety stand down. Remove ice from derrick. 09:30 10:00 0.50 10.00 DRILL E 20 CP Perform rig service. Service drawworks,top drive and iron roughneck. 10:00 12:00 2.00 12.00 DRILL E 13 TR99 Pipe skate machine blew a hydraulic hose. Down time to repair skate. 12:00 12:30 0.50 12.50 DRILL E 13 P Perform rig service. Service crown sheaves and tugger sheaves. 12:30 15:30 3.00 15.50 DRILL E 13 TR99 Continue to repair pipe skate machine. 15:30 16:30 1.00 16.50 DRILL E 4 P Lay down remaining BHA. 16:30 17:30 1.00 17.50 DRILL E 20 P Rig up to run 13-3/8"casing. Pick up hanger and perform dummy run. OK. 17:30 18:00 0.50 18.00 DRILL G 4 P Hold safety meeting with rig crew and company rep.to run 13-3/8"casing. 18:00 19:00 1.00 19.00 DRILL G 4 P Rig up to run 13-3/8"casing. 19:00 00:00 5.00 24.00 DRILL G 4 P Run 68 lbs/ft.L-80 BTC 13-3/8"casing.Average torque 7,850 ft.lbs. Run casing per tally. Fill casing on the fly.Top off every 10 stands. Tight hole from 1,860'to 1,950'. Break circulation at 5 BPM at 300 PSI.Wash down through tight spot- OK. Run 13-3/8"casing to 2,166'. Up Wt=195 Dn Wt=130. Daily Contacts Position I Contact Name Company I Title E-mail Office Mobile Eni representative !Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative 'David Smith ENI Dulling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI 'Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI ,Project Advisor 907-865-3337 907-952-7880 Last Casing seat. Ca..Type OD(In) I ID(In) Grade Top( ) I Bottom(1 ) Run Date CASING 133/8 12.415 L80 0.0 2,333.6 6/23/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) ..... _.._._._. __ tfookt Eni E&P Division �} Well Name: OP08-04 Daily Report Well Code:23950 EN!Petroleum Field Name: Nikaitchuq • Co. Inc. , Date:6/24/2010 - Report#: 8 APIIUWI: 50-029-23424-00-00 npage 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° ,Operator ENI Share(%) Well Configuration type 402100 jENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 . 1 12.20 ■ Rig Information Contractor ,Rig Name !Rig Type NABORS ALASKA I NABORS 245 E ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 4.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB !Temperature(°F) Weather Wind 2,344.0 2,159.4 0.00 89.0 28.2 Mostly Clear.Patchy 355 N @ 11 mph I Fog. WC 18.5 Daily summary operation 24h Summary P/U&ran 13 3/8"csg U 2333'-circulate&reciprocate csg while condition mud-UD Franks&R/U cement head&lines-PJSM w/Schlumberger and performed surface cement Job,note 109 bbls mud push&172 bbls.cement back to surface-N/D riser&N/U 13 3/8"stack-Test BOPE witnessed by AODCC Rep.Bob Noble. Operation at 07.00 P/U BHA#3 as per Schlumberger DD/MWD 24h Forecast Finish test BOPE.P/U BHA#3 per SLB.RIH&test 13 3/8"csg..Drill out&circulate clean.Displace to LSND new mud.Perform LOT/FIT to 12 ppg EMW.Establish SCR'S,Base line ECD-Drill ahead. Lithology -_-- [Shows -_-- -- IMAASP Pressure(psi) Mud Weight(lb/gal) _L. 9.60 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00'DRILL G 4 P RIH-P/U 13 3/8 -68#csg.surface casing f/2166'-t/2291'-P/U landing joint&hanger-Up wt.195K/Dn wt.130K. 01:00 02:30 1.50 2.50 DRILL G 7 P Circulate&condition mud-stage pump rate up to 340 gpm @ 530 psi.-redprocate string-Up wt.185K Dn wt.140K. 02:30 03:00 0.50 3.00 DRILL H 1 P Shut down-R/D GBR Franks tool-P/U cement head and lines. 03:00 04:30 1.50 4.50 DRILL H 7 P Condition mud for cemnet job pumping through cement head.Pump rate 357 gpm @ 540 psi.-reciprocating 13 3/8"csg: Up wt.205K-Dn wt.145K. 04:30 08:00 3.50 8.00 DRILL H 7 P Hold PJSM w/all personnel involved for cement job.SLB pump 5 bbls H2O&test lines to 3000/psi-OK,SLB pump 109 ( bbls mud-push II 10.2 ppg @ 5.4 bpm w/260 psi,shut-down drop bottom plug.SLB mix&pump lead slurry 352 bbls 10.7 f' ppg,435 sks,4.52 Yield,mix water at 21.38 gal/sk @ 4.9 bpm w/345 psl,SLB mix and pump tail slurry 72 bbls,12 ppg, sµ' 243 sks,1.62 Yield,mix H2O at 5.403 gal/sk.at 2.8 bpm w/412 psi,shut down&drop top plug,SLB pump 10 bbls H2O G'f ° and wash up.Displace with 326 bbls 9.5 ppg mud with rig pump at 8.5 bpm w/730 psi,at 311 bbls away slow pump to 3 1/ bpm with 380/psi FCP,bump plug to 500/psi,over FCP to 880/psi,hold for 2 minutes and bleed off,check floats are holding,OK,floats hold good.Rig down SLB,lay down landing joint and flush out riser with Johnny whacker with black-water pill. 08:00 11:00 3.00 11.00 DRILL H 5 P Rig down SLB cement head and GBR equipment,lay down landing joint and flush out riser with Johnny whacker with black-water pill.Clean surface equipment&transferring active pit system to the WIF. 11:00 20:30 9.50 20.50 DRILL C 5 P Nipple down surface riser,starting head and adapter flange-Nipple up Vetco Gray wellhead and test to 5000 psi for 10 mins.-ENI Rep witnessed same-OK.Nipple-up 13 5/8"BOPE stack,flow line,ketch can and spill containment.Charge accumulator&function test stack.Clean pits&prep for new LSND mud. 20:30 00:00 3.50 24.00 DRILL C 12 !P P/U&M/U test joint,set plug purge,BOP stack with w/H2O.Test BOP 250/2500 psi.on annular-250/3500 psi.on remaining equipment.Chart record test-held 5 minutes each.Witness by AOGCC Rep Bob Noble.Schlumberger ' directional tools on location @ 2230 hrs. --- ---------- ------ Daily Contacts Position I Contact Name Company Title E-mall 1 Office Mobile Eni representative Scott Beauchamp ENI ,Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI !Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing -- T ) - -- --I 1 Bottom MKS) Run Date Type OD(in) --_ (+n) TOp(ftK6) 2,333.6 6/23/2010 CASING 133/8 12.415 L80 0.0�, Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type !Fluid Density(lb/gal) !P(Surf)(psi) Eq.Mud Weight(lb/gal) !Leak Off Pressure(psi) I I 141 Eni E&P Division Well Name: OP08-04 EN!Petroleum Daily Report Well Code: 23950 • CO. Inc. Field Name: Nikaitchuq enDate:6/25/2010 - Report#: 9 API/UWI: 50-029-23424-00-00 11 page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) !Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) !Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 5.06 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) !Average ROP(ft/hr) POB Temperature(°F) Weather Wind 2,370.0 2,181.0 26.00 1.00 1 26.0 92.0 34.9 Overcast.Patchy 265W @ 5.4 mph Fog.WC 30.2 Daily summary operation 24h Summary Finish BOP-P/U BHA#3 per SLB-RIH&test 13 3/8"casing-Cut drilling line-Drill out&circulate clean shoe track and new hole for LOT/FIT-displace hole to LSD new mud-perform LOT/FIT to 12 ppg.EMW. Operation at 07.00 Drilling ahead with Rotary Steerable. 24h Forecast Continue to drill ahead to T/D-as per well plan-prep for 9 5/8"csg job. Lithology __-- ------- _-- Shows - - _ -------- - MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Dur Dur Time Time (hrs) (hr•) Phase Opr. Act. Plan Oper.Deser. 00:00 02:00 2.00 2.00,DRILL E 12 P Finished testing BOPE 250/3500 psi with 5 min time frame/accumulator system with AOGCC witness Bob Noble. 02:00 03:00 ' 1.00 3.00 DRILL E 12 P LD test joint&plug-set wear ring with Vetco Gray rep.-OD 13.438"/ID 12.31" 03:00 08:00 5.00 8.00 DRILL E 4 P P/U 12 1/4"BHA#3 Rotary steerable as per Schlumberger and preformed test on MWD tool @ 1000'-P/U ghost reamer. 08:00 09:00 1.00 9.00 DRILL E 4 P RIH f/1000'-U 2150'-circulate bottoms for casing test. 09:00 10:00 1.00 10.00 DRILL E 12 P Test 133/8"/68#csg.to 2500 psi for 30 mins.-chart record. 10:00 11:30 1.50 11.50 DRILL E 1 P Held PJSM-Cut&slip drilling line 11:30 13:00 1.50 13.00 DRILL E 3 P Service rig&recalibrate Schlumberger lock measurement. 13:00 20:00 7.00 20.00 DRILL E 3 P Ream/wash down f/2150'-U 2242'tag-Rotary drill shoe track f/2242'-1/2333'pump rate 500 gpm C 600 psi./50-60 rpm @ 4-5k torque/WOB 4-18K/Up wt.120K,Dn wt.95K,Rot wt.105K 20:00 21:00 1.00 21.00 DRILL E 3 P Rotary drill f/2333'-U 2370'(26'feet new hole)pump rate 600 gpm @ 800 psi./60 rpm C 5k torque/WOB 5K/Up wt. 120K,Dn wt.95K,Rot wt.105K/Drilled 26'new for LOT/FIT. 21:00 23:00 2.00 23.00 DRILL E 7 P Circulate/displace-pump 20 bbls.Hi-vis spacer sweep followed with new LSND mud-pump rate 600 gpm @ 600 psi.- circulate weights 8.9 ppg in&out. 23:00 00:00 1.00 24.00 DRILL E 12 P Perform LOT on 13 3/8"shoe-broke down @ 623 psi.-mud wt.8.9 ppg.Calculated from data enters into test form EMW I =13.8 ppg.Bleed back 3.2 bbls.and pump 3.7 bbls. Daily Contacts _ Position Tme E-mail 1 Office Mobile Eni representative Jack Keener Name ENI Company �Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas@enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD " ID(in) Grade Top(RKB) I Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,333.6 6/23/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type !Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(1b/gal) 1 Leak Off Pressure(psi) 2,333.0 2,150.24 LSND Mud ! 8.90 267.0 11.29 I 1,261.1 ifoitil Eni E&P Division Well Name: OP08-04 Daily Report EN!Petroleum Well Code: 23950 • Field Name: Nikaitchuq n Co. Inc. Date:6/26/2010 - Report#: 10 API/UWI: 50-029-23424-00-00 2n II Wellbore name: Original Hole page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 6.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB ITemperature(°F) Weather Wind 3,865.0 3,319.4 1,495.00 23.50 63.6 95.0 32.5 Mostly Clear.WC 259W @ 6 mph 26.8 Daily summary operation 24h Summary Performed PWD baseline,tool orientation-Drill ahead f/2370'-U 3850'. Operation at 07.00 Drill Rotary Steerable on hard stringer-varying parameters. 24h Forecast Drill Rotary Steerable ahead to TD-circulate/sweep hole-short trip/back ream to shoe-circulate/sweep for 9 5/8"csg.-POOH-UD BHA Lithology i Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) --- -__ _---- 9.00 Time Log Cum Start End Dur Dur Time Time tore) (ore) Phase Opr. Act. Plan Oper.Dam. 00:00 00:30 0.50 0.50 DRILL E 7 P Preformed PWD baseline test-EST ECD's=600 gpm w/600 psi.@ 9.17 ppg-700 gpm w/740 psi.@ 9.18 ppg-800 w/ 970 psi.@ 9.17 ppg-900 gpm w/1180 psi.@ 9.19 ppg.Up wt.125K/Dn wt.100K/Rot wt.110K./Rotating 80 rpm with 3K torque/900 gpm-ECD @ 9.2 ppg. 00:30 12:00 11.50 12.00 DRILL E 3 P Drill Rotary Steerable f/2370'-U 3107'(TVD 2760)/pump rate 900 gpm @ 1400 psi./80 rpm with 4-5K troque/WOB 5-8K/SPR 1&2=20/30 spm @ 60/80 psi.(MD 3011'-TVD 2663')/ADT=8.10/Jar hrs.29.7.MWT 9.1 ppg. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable f/3107'-U 3620'/pump rate 900 gpm @ 1400 psi./80 rpm with 4-5K troque/WOB 5-8K/MWT 9.1 ppg. 18:00 20:30 2.50 20.50 DRILL E 3 P Drill Rotary Steerable f/3620'-U 3635'(hard string @ lower Ugnu with ROP reduction to 4-10 ft/hr.)-pump rate 900 gpm @ 1520 psi.-80 rpm @ 5.4-7.2K torque-WOB 5-20K-Up wt.138K/Dn wt.118K/Rot wt.128K-Mud wt.9.1 ppg. 20:30 00:00 3.50 24.00 DRILL E 3 P Drill Rotary Steerable f/3635'-U 3865'-pump rate 900 gpm©1520 psi.-80-120 rpm @ 5.7-6.3K torque-WOB 5-20K- Up wt.140K/Dn wt.115K/Rot wt.130K-Mud wt.9.1 ppg.-SPR @(3640'MD/3140'TVD)-#1=20 spm-86 psi; 30spm-104 psi/#2 20 spm-90 psi;30 spm-110 psi.Slight losses started @ 3670'MD 3290'TVD with 5-10 bph/Total 40 bbls to well bore.No static losses.ADT=8.91/Jar hrs.38.6 Rotating Footage: 1,238' Rotating Hours: 14.04 Sliding Footage: 283' Sliding Hours: 3.28 1 Daily Contacts Position I Contact Name Company ) Title E4111111 L Office Mobile Eni representative Jack Keener ENI ',Sr.Drilling Spur. Jack.Keener @enipetroleum.com ';907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI I HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI IExpediter AMn.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI IProject Advisor 1907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) 1 ID(in) Grade Top(MKS) _.,, ,.._,__ :1-..,:. u.. Run Date CASING 13 3/8 12.415 L80 0.0 2,333.6 6/23/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,333.0 2,150.24 LSND Mud 8.90 267.0 11.29 1,261.1 . .- ,.'.. 1- z r fit irpoihl Eni E&P Division �} Well Name: OP08-04 Daily Repol {, 'Well Code: 23950 EN!Petroleum Field Name: Nikaitchuq i Co. Inc. Date:6/27/2010 - Report#: 11 API/UWI: 50-029-23424-00-00 enI ! _ page lofl Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM I 100.00 DIRECTIONAL Rotary Table Elevation(ft) 'Ground Level(ft) `Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING i 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 7.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) /Average ROP(ft/hr) POB !,Temperature(°F) Weather Wind _ 5,020.0 3,630.6 1,155.00 22.50 i 51.3 92.0 i 36.9 Clear. WC 33.6 69 NNE @ 3.8 mph Dally summary operation 24h Summary nrill Rotary Steerable from 3865'to 5 070"-Circulate hole dean-threw bottoms-un POOH on elevators tom sing.shoe. RIH back to TD. Operation at 07.00 RIH f/13 3/8"csg shoe-back to TD @ 5020'. 24h Forecast - - Finish short trip to 13 3/8"shoe. RIH to TD. Circulate clean. POOH/SLM-UD BHA 3#. Change rams to 9 5/8"-Vetco Gray perform dummy run with hanger. R/U GBR and run 95/8"casing.. Circulate and condtion at shoe and TD Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Cum Start End Dur Dur Time Time (hrs) (hre) Phase Opr. Act. Plan Oper.Oescr. 00:00 12:00 12.00 12.00 DRILL E 3 ,P Drill Rotary Steerable from 3656'to 4514'(3549'TVD)-pump rate 900 gpm @ 1730 psi.-120 rpm @ 5-7K torque WOB 8-10K-Up wt.135K/Dn wt.115K/Rot wt.125K-MW=9.1 ppg.&ECD=9.77 ppg-SPR @(4159'MD/3425'TVD)- #1=20/30 spm @ 85/110-#2=20/30 spm @ 80/110 psi.-Total loss=70 bbls.ADT=8.71 Hrs./Jar Hrs.47.38 12:00 22:30 10.50 22.50 DRILL E 3 P Drill Rotary Steerable from 4514'to 5020'(EST.3630'ND)-pump rate 900 gpm @ 1830 psi.-120 rpm @ 5-7K torque- WOB 5-20K-Up wt.132K/Dn w.112K/Rot wt.125K-MW=9.3 ppg.&ECD=9.8 ppg-SPR @(4830'MD/3602' ND)-#1=20/30 spm= 85/110 psi/#2 20/30 spm=90/115 psi;Total loss 30 bbls.No static losses.ADT=7..62 Hrs./ Jar Hrs.=5p.Too of OA sand 1W 4976'MD/3677'Nn , Rotating Footage: 1,438' Rotating Hours: 16.33 22:30 00:00 1.50 24.00 DRILL E 7 P Circulate/condition&reciprocate pipe-pump rate 900 gpm @ 1800 psi.-12orpm @ 5K troque-2 1/2 bottoms-up until - _ clean-Peak gas 700 units @ bottom-up/backgound 50 units.Flow check-static. Daily Contacts Position Name Company T Emma - 1 glace Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com x907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670.8623 907-632-3085 Eni representative 'Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Alvin Criswell ENI !iExpediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) 7 Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,333.6 6/23/2010 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 2,333.0 2,150.24 LSND Mud 8.90 267.0 1 11.29 j 1,261.1 $00 Eni E&P Division Well Name: OP08-04 Daily Report Well Code 23950 ENI Petroleum ,... Field Name: Nikaitchuq • • Co. Inc. Date:6/28/2010 - Report#: 12 API/UWI: 50-029-23424-00-00 eno Pagel oft Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM J 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 8.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) ''Average ROP(ft/hr) POB !Temperature(°F) Weather Wind 5,020.0 3,630.6 0.00 I 94.0 34.5 Overcast.Foggy. 41 NE©10.2 mph WC 26.8 Daily summary operation 24h Summary --- POOH(short trip to 13 3/8"shoe)on elevators-RIH to TD-Circulate,weight sweep&CBU until clean-POOH on elevators,SLM pipe -L/D BHA#3-Pull wear bushing-Vetco Gray perform dummy on 9 5/8"hanger-Chanaa rams&test-R/U GBR tools&Franks tool-Hold PSM.P/U 9 5/8"can. Operation at 07.00 - - ---- -- - --. - -- - P/U 9 5/8"csg.@ 3,136'. 24h Forecast Continue P/U 9 5/8"47#csg-circulate for cement job-R/U SLB&cement,R/D-freeze protect annulus-change rams-P/U drip pipe. Lithology - _-- Shows --- MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Cum Start End Dur Dur Thne Time (hrs) ( ) Phase Opr. Act. Plan Oper.Dena. 00:00 00:30 0.50 0.50 DRILL E 17 P Circulate&reciprocate @ 5020'TD-pump rate 900 gpm 1800 psi-120 rpm @ SK torque-Up wt.130K-Dn wt.105K- Rot wt.115K.MW=9.3 ppg,ECD=9.8 ppg. 00:30 03:30 3.00 3.50 DRILL E 6 P POOH f/5020'-t/2245'no problems&proper hole fill. 03:30 04:00 0.50 4.00 DRILL E 25 P Service Rig-Top drive,block&crown sheaves,draw-works. 04:00 05:30 1.50 5.50 DRILL E 6 P RIH f/2245'-t/5020'-hole in good condition. 05:30 08:00 2.50 8.00 DRILL E 7 P Circulate&condition hole-Reciprocatinfg&rotating @ 120 rpm w/4k torque&pump rate 800 gpm @ 1610 psi.Pumped 40 bbls.@ 11 ppg weight sweep+2 bottoms-up/clean. i 08:00 10:30 2.50 10.50 DRILL E 4 P POOH f/5020'-V 250'-L/D ghost reamer&stand back HWDP-SLM with no correction. 10:30 14:30 4.00 14.50 DRILL E 4 P UD BHA#3 per Schlumberger DD/MWD-no excessive wear noticed on tool string. 14:30 16:30 2.00 16.50 DRILL E 29 P Pull wear bushing-change top BOP rams to 9 5/8"csg. 16:30 17:30 1.00 17.50 DRILL G 1 P Preformed dummy run with 9 5/8"csg hanger per Vetco Gray Rep. 17:30 19:30 2.00 19.50 DRILL E 12 P P/U test equipment&set plug-test 9 5/8"csg rams to 250/3500 psi.for 5 mins each,chart record-L/D test equipment. 19:30 21:00 1.50 21.00 DRILL G 1 P R/U GBR csg.equipment&Franks fill-up tool-Held PJSM for 9 5/8"casing job. 21:00 00:00 3.00 24.00 DRILL G 4 P P/U 95/8"csg.to 1196'-check float equipment-record torque&weight parameters-fill every joint-Install centralizers as required. Daily Contacts Position i Contact Name Company d Title E-maIl t Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams©enipetroleum.com Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Cris.Type OD(in) 1 ID(In) Grade Top MB) 1 Bottom(MB) Run Date CASING 9 5/8 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(pal) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,333.0 2,150.24 LSND Mud 8.90 267.0 11.29 1,261.1 Well Name: OPOB-04 Daily Report n► Division ENI Petroleum Weil Code: 23950 Field Name: Nikailchuq (�n• CO. Inc. Date:6/29/2010 - Report#: 13 API/UWI: 50-029-23424-00-00 ( II ►I o page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 jENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 g 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 9.06 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 5,020.0 3,630.6 0.00 94.0 37.2 Fog.WC 30 9 N @ 10 mph Daily summary operation 24h Summary __--- Run 9 5/8"L-80 47#-fill pipe with Franks tool-Circulate @ 2333'(13 3/8"shoe)&3517'-RIH to 4.999'-circulate&condition for Gementina-Hold PJSM with Schlumberger-R/U SLB cement head- circulate-test lines to 4000 psi-Mix&pump 103 bbls.Lite CRETE cement slurry-bump plugs&test @ 1250 psi,checks floats,OK-R/D Schlumberger/GBR equipment.Install pack off with Vetco Gray Rep&test to 5000 psi./10 mins.-change top rams&test-install wear ring-change over mud system-P/U 5"drill pipe. Operation at 07.00 P/U 5"drill pipe-clean pits&change over to OBM. 24h Forecast P/U 5"drill pipe-clean pits&change over OBM mud- P/U BHA#4 as per Schlumberger- RIH above float collar&test csg V 3000 psi.-Drill out float equipment&new hole-Preform LOT/FIT-Drill ahead. Lithology Shows -_- MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Cwn start End our Our Tbrw Time (hre) ( ) Phase Opr. Act. Plan Oper.Dew. 00:00 01:30 1.50 1.50 DRILL G i4 P Run 9 5/8"47#L-80 BTCM casing f/1196'-t/2316'-average makeup torque 8000 ft lbs.Monitor drag and surge and losses. 01:30 02:00 0.50 2.00 DRILL G 7 P Circulate bottom-up @ shoe with conditioned mud.pump rate @ 235 gpm with 230 psi. 02:00 06:30 4.50 6.50 DRILL G 4 P Continue P/U 9 5/8"csg.47#BTCM-f/2316'-V 4999'-break circulation r 3517'and landing joint with pump rate 235 gpm @ 330 psi.Monitor drag and surge and losses. 06:30 10:00 3.50 10.00 DRILL G 7 P Circulate&treat mud for cement job-stage rate up to 530 gpm @ 1000 psi-continuous pipe reciprocation.Circulate 2 bosom-up while R/U.Held PJSM with Schlumberger cementers&rig personnel.Land out to load shoulder,L/D GBR L Franks tool and P/U cement head.Continue to circulate with#3 mud pump while priming#1&2 mud pumps with OBM. j r. 10:00 12:00 2.00 12.00 DRILL H 7 P Pump 5 bbls.of water,test cement lines to 4000 psi,SLB pump 50 bbls.Mud Push II C 11 ppg.-shut down and drop ( . bottom plug SIB mixed&pump 103 bbls./345 sacks of Lite CRETE,12.5 ppg.1.54 ft3/sk/5.091 gal/sk.@ 5 bpm.Drop the top plug&pumped 3 bbls.of water.Switched to rig pumps&displace with 355 bbls.of 8.9 ppg OBM©6 bpm with 500 psi.Continuous pipe reciprocation until the lowing pump rate down to 3 bpm©750 psi.the last 15 bbls.-,Plug land on calculated strokes.Held 500 psi.over FCP of 750 psi.-bleed off&check floats-Good. r, L - _ 12:00 13:30 1.50 13.50 DRILL G 5 P R/D Schlumberger Cement head&GBR equipment L/D landino Joint . 13:30 14:30 1.00 14.50 DRILL G 12 P Vetco Gray Rep-set pack-off&test well head to 5000 psi for 10 mins. 14:30 15:30 1.00 15.50 DRILL G 5 P Charles.nut Inn rams f/Q 5/A"to 4 1/2"x 7"variables 15:30 18:00 2.50 18.00 DRILL E 12 P P/U test joint and set plug-test 4"x&"rams 250/3500 psi for 5 each-chart record.-1/D test equipment.Install wear 4./ bushing w/9"ID. /sap 18:00 23:00 5.00 23.00 DRILL E ;1 P Changed over mud systems from LSND to OMB(VersaPro)-Clean pits-Preload Pipe shed with 5"drill pipe-Clean rig i floor-Freeze protect 13 3/8"x 9 5/8"annulus with diesel-pumped 154 bbls.CO 2 bpm with final rate 1 bpm @ 1100 psi.- shut in pressure©800 psi.Held PJSM for P/U drill pipe. 23:00 00:00 1 1.00 24.00 DRILL E 14 P P/U 5"drill pipe&continue clean pits and change over to VersaPro OBM. Daily Contacts Position Contact Name Company I Title E-mail Office Mobile Eni representative Jack Keener ENI ''Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams©enipetroleum.com Eni representative Alvin Criswell ENI ,Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(m) ID On) Grade Top(NCB) 1 Bottom(RKB) Run Date J CASING 9 5/8 8.681 L80 0.4 4,999.2.6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,333.0 2,150.24 LSND Mud 8.90 267.0 11.29 1,261.1 silyi Eni E&P Division Well Name: OP08-04 Daily Report ENI Petroleum weu Code: 23950 CO. Inc. Field Name: Nikaitchuq 2 a Date:6/30/2010 - Report#: 14 API/UWI: 50-029-23424-00-00 page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 402100 jENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 10.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) IAverage ROP(ft/hr) POB Temperature(°F) Weather Wind 5,020.0 3,630.6 0.00 94.0 37.2 Fog.WC 30 9 N @ 10.1 mph Daily summary operation 24h Summary P/U 5"drill pipe for production section-dean pits&change over to OBM-Wait on tools&prep same to P/U-P/U BHA#4 as per Schlumberger-RIH-test 9 5/8"cs./47#to 3000•si.-chart record. Operation at 07.00 --- -___-- -_--- Drilling out 9 5/8"float equipment. 24h Forecast Drill out 9 5/8"float track&20'new hole-circulate clean with equal mud weights-Perform LOT/FIT-Drill ahead to TO @ 10,927'as per Schlumberger Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Ctrs Start End Dur Our Time Time (hrs) ( 'e) ;phase Opr. Act Plan Oper.Dem. 00:00 03:30 3.50 3.50 DRILL E '4 U P/U 5"drill pipe,RIH V 2986'-continue cleaning pits&off load OBM(VersaPro)into same. 03:30 05:30 2.00 5.50 DRILL E 4 'P POOH f/2986'-V to surface-31 stands. 05:30 10:30 5.00 10.50 DRILL E 4 P P/U jars&5"HWDP&continue P/U 5"DP V 3472'. 10:30 13:00 2.50 13.00 DRILL E 4 P POOH f/3472'-V surface UD mule. 13:00 14:00 1.00 14.00 DRILL E 24 U Wait on third party tools to arrive&prep to be P/U. 14:00 20:30 6.50 20.50 DRILL E 4 P P/U BHA#4 as per Schlumberger DD-Held PJSM-Test Power Drive w/450 gpm @ 430 psi.Continue P/U BHA-load sources in tools-RIH to 1200'&perform swallow test,good. 20:30 22:00 1.50 22.00 DRILL E 4 P RIH f/1200'-t/4861'-fill&break circulation @ 3242'-pump rate 252 gpm @ 300 psi. 22:00 23:30 1.50 23.50 DRILL E 7 P Wash&ream f/4861'-t/4900'-tag with 10K-circulate bottoms-up-pump rate 425 gpm @ 1000 psi;with 135 bbls. pumped returns became containment for 56 bbls and leaned up with Mud weight 8.8 in&8.9 out. 23:30 00:00 � 0.50 24.00DRILL E 12 •P Test ---_ _-_ csg.to 3000 psi.with 1/2 bpm rate-5.1 bbls.pumped-chart record. Daily Contacts Position I Contact Name Company i Title Email I Office Mobile Eni representative 'Jack Keener ENI 'Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com '. Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative ,Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type _ OD(in) I ID(in) Grade Top(ftKB) 1 Bottom(K03) Run Date CASING 9 5/8 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type I Fluid Density(lb/gal) I P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM j 8.80 j 629.0 12.14 2,287.9 , '"" Eni E&P Division Well Name: OP08-04 � ENI Petroleum Daily Report Well Code: 23950 • Field Name: Nikaitchuq n CO. Inc. Date:7/1/2010 - Report#: 15 API/UWI: 50-029-23424-00-00 efl fi Wellbore name: Original Hole page Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type 402100 i ENI PETROLEUM i 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E :LAND RIG _ Job Information Wellbore Job Phase 1Spud Date Target Depth(ftKB)'Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 11.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 5,750.0 3,639.9 730.00 5.84 125.0 93.0 37.8 Overcast.Fog.WC 10 N @ 8 mph 28.7 Daily summary operation 24h Summary Complete 9 5/8"csg test to 3000 psi.-Down time due to electrical problems with breaker in SCR module-Drill out float equipment(shoe @ 4999')&new hole to 5040'-Circulate/clean and equal mud weight A 8.8 ppg.-Perform LOT-EMW_B 12.4_Don-Preformed PWD base line parameters-Drill rotary steerable f/5040'-U 5800'. Operation at 07.00 Drill ahead Rotary Steerable 24h Forecast Drill Rotary Steerable to TD-as per well plan,Schlumberger DD/Geologist.Prep 4 1/2"production string&5 1/2"liner in pipe shed. Lithology ------ --- Shows -_----- --- MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Cum Start End Dur Dur Time Time (hrs) Owe) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 12 P Complete 9 5/8"csg.test to 3000 psi.for 30 minutes-chart record-pumped 5.1 bbls.&bled back 5.0 bbls. 00:30 02:00 1.50 2.00 DRILL E 125 P Service rig-drawworks,top drive,grease top drive rails.Electrical problems with re-setting breaker for the Top Drive SCR, after bringing other generator on line. 02:00 10:00 8.00 10.00 DRILL E 3 P Ream/wash down f/4861'-U 4910'tag-Rotary drill shoe track&cement f/4910'-U 4999'pump rate 360 gpm @ 1000 psi./30-60 rpm @ 3-4.5K torque/WOB 6-12K/Up wt.125K,Dn wt.95K,Rot wt.115K.Varying parameters to optimize ROP. 10:00 10:30 0.50 10.50 DRILL E 3 P Rotary drill f/5020'-t/5040'(20'new hole)pump rate 500 gpm @ 1460 psi./80 rpm @ 3-4k torque/WOB 4K/Up wt. 130K,Dn wt.100K,Rot wt.115K/Drilled 20'new for LOT/FIT. ADT=.33 hr.Jar hrs.=44.43. 10:30 11:00 0.50 11.00 DRILL E 7 P Circulate&condition mud for LOT/FIT-ricprocate pipe-pump rate 500 gpm @ 1460 psi.-circulate weights 8.8 ppg in& out 11:00 13:00 2.00 13.00 DRILL E 7 P R/U Perform LOT on 95/8"shoe @ 4999'-test mud wt.8.8 ppg.-fluid away @ 650 psi-EMW=12.4 ppg. _ 13:00 14:00 1.00 14.00 DRILL E 7 P Preformed PWD baseline parameters.Pump rates as follows:575 gpm @ 1907 psi./600 gpm @ 2070 psi./625 gpm @ 2190 psi./650 gpm t 2340 psi. 14:00 00:00 10.00 24.00 DRILL E 3 P Drill Rotary Steerable f/5040'-t/5750'(3638'TVD)-pump rate 630 gpm @ 2340 psi./ECD @ 10.33 ppg./80-120 rpm 3.8K off&4.8K on bottom torques/WOB 5-12K/Up wt.138K,Dn wt.95K,Rot wt.108K.ADT=5.51 hrs./Jar hrs.= 49.91. Rotary Steerable footage=730' Rotating hrs.=5.84 Daily Contacts Position I Contact Name Company ;,-^; „_ This E-mail Office Mobil. Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670.8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative ,Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(In) I ID(In) Grade Top MO) 1 Bottom(ftKB) Run Date CASING 95/8, 8.681 L80 0.41 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 i 12.14 2,287.9 Eni E&P Division Well Name: OP08-04 EN!Petroleum Daily Report Well Code: 23950 Field Name: Nikaitchuq •/�11 11�n Co. Inc. Date:7/2/2010 - Report#: 16 API/UWI: 50-029-23424-00-00 t II page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concesslon N° Operator ENI Share(%) !Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E I LAND RIG _ Job Information Wellbore Job Phase Spud Date Target Depth(RKB)!Target Depth(TV... Depth Dr.(MD)(ft) 'Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 1 3,758.9 11,810.00 158.27 74.6 12.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB !Temperature(°F) Weather Wind 7,140.0 3,735.3 1,390.00 21.00 66.2 _ 93.0 1 37.2 Clear,WC 29.1° 1°N @ 12.4 mph Daily summary operation 24h Summary Drill 5750-5886,Repair Rig Watch instrumentation,drill 5886-6680.Wiper trip to 6200.Drill 6680-7140 ft. Operation at 07.00 Drill ahead 8-1/2 hole drctnl. Depth @ 0345 7540'MD 24h Forecast --- _--- - - Drill ahead 8-1/2 hole drctnl towards TD Lithology Shows _-_- MAASP Pressure(psi) Mud Weight(11b/gal) 8.90 Time Lod__ Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00.DRILL E 13 i P Drill ahead 8-1/2 hole drctnl 5750-5886 ft. Connections free,normal drag/torque.No gain/loss. Up 135, Dn 95, Rot 105, WOB 5/12K, RPM 120, SPP 2310 psi,GPM 630 04:00 05:30 1.50 5.50 DRILL E 25 U Repair Rig Watch instrumentation,total loss,no data. 05:30 17:00 11.50 17.00 DRILL E 3 P Drill ahead 8-1/2 hole drctnl 5886-6680 ft Connections free,normal drag/torque.No gain/loss. Up 135, Dn 95, Rot 105, WOB 5/12K, RPM 120, SPP 2430 psi,GPM 630 Units gas 250-780 ave. 17:00 18:30 1.50 18.50 DRILL E 6 P PJSM,Flow check,Wiper trip to6200 ft.backreaming out.Wellbore excellent condition.Normal drag,no gain/losses.Precaution ream 30 ft to btm.No fill. 18:30 00:00 5.50 24.00-DRILL 1E 3 P Drill ahead 8-1/2 hole drctnl 6680-7140 ft. Connections free,normal drag/torque.No gain/loss. Up 135, Dn 95, Rot 105, WOB 5/12K, RPM 120, SPP 2430 psi,GPM 630 Units gas 250-780 ave. Daily Contacts Position I . .Contact Name Company... I Title E-rnail Office Mobile..... Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Dave Morris ENI ,Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig EN1 Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI ,Expediter Greg.Parker @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(in) I ID(in) Grade Top MKS) I Bottom(ftKB) Run Date CASING 9 5/8'. 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test --- 629.0 12.14 'Leak Off Pressure(psi) Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I,p(Surf)(psi) Eq.Mud Weight(lb/gal) 4,999.0 3,628.87 VersaPro OBM 8.80 1. 2,287.9 1 Voikt Eni E&P Division Well Name: 0P08-04 ENI Petroleum Daily Report Well Code: 23950 Co. Inc. Date:7/3/2010 Report#: 17 Field Wl: 50-029-23424-00-00 0i9-2342q eni - p API/UWI: 50-029-23424-00-00 ' page 1 of 1"'"'Wellbore name: Original Hole Well Header Permit/Concession N° Operas- for ENI Share(%) Well Configuration type 402100 IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) 'Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 I 3,758.9 11,810.00 I 158.27 74.6 13.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) lAverage ROP(ft/hr) POB Temperature(°F) Weather Wind 7,925.0 3,754.2 785.00 7.00 I 112.1 87.0 35.8 Fog,WC 34.3° 76°ENE©2.5 mph Daily summary operation 24h Summary Drill 7140-7925 ft.Ciro/cond fluids,POH for BHA change.MU BHA#5,RIH 4770 ft. Operation at 07.00 RIH BHA#5,Depth @ 0345 4725'MD 24h Forecast RIH BHA#5,drill ahead 8-1/2 hole towards TD Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Our Dur Time Time (hrs) (hre) Phase. Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E i3 P Drill ahead 8-1/2 hole drctnl 7140-7925 ft. Connections free,normal drag/torque.No gain/loss. Up 150, Dn 91, Rot 116, WOB 5/12K, RPM 120, SPP 2530 psi,GPM 630 Units gas 250-465 ave.ECD 10.5, ADT=4.02 hrs. 07:00 09:00 2.00 9.00 DRILL E 7 P Ciro/cond fluids,POH to 7730,circ clean,no gain/losses.Pump sweep. 09:00 14:00 5.00 14.00 DRILL E 4 P PJSM,flow check,POH 5"DP on elevators to BHA.15K overpull at 6510 ft.Remainder wellbore exc condition.No swab/ gain/loss.140-165K up.Correct hole fill. 14:00 17:30 3.50 17.50 DRILL E 4 P Flow check,PJSM,Handle BHA#4,lay dn drctnl assy. 17:30 21:30 4.00 21.50 DRILL E I4 P PJSM,MU BHA#5 with Xceed drctnl assy,load source,RIH 1033 ft.Shallow test tools.510 gpm/900 psi. 21:30 00:00 2.50 24.00 DRILL E 4 I P _ _Flow check,PJSM,follow BHA with 5"DP to 4770 ft.Normal dn drag.No gain/loss. Daily Contacts Position L Contact Name Company E mall l_.. Office Mobile Eni representative Jack Keener ENI 'Sr.Drilling Spvr. Jack.Keener @enipetroleum.com '907-670-8623 907-715-6434 Eni representative Dave Morris ENI Drilling Spvr. Dave.Morris @enipetroleum.com ,907-670-8623 Eni representative Tom Norvig ENI 'Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI 1 HSE Jack.Potter©enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 -''Eni representative Greg Parker ENI Expediter Greg.Parker©Jenipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(in) I ID(In) Grade Top(ftKB) I Bottom((KB) Run Date CASING 9 5/8, 8.681 L80 0.41 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB)3,628.87 FersaTye Fluid Density 8.80 1P(Surf)(psi) Eq.Mud Weight(lb/gal) '.,Leak Off Pressure(psi) 2,287.9 Eni E&P Division Well Name: OP08-04 04041 ENI Petroleum Daily Report Well Code:23950 Field Name: Nikaitchuq (�• Co. Inc. Date:7/4/2010 - Report#: 18 API/UWI: 50-029-23424-00-00 en n.n page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) 1Weil Configuration type 402100 ENI PETROLEUM I 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 14.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 8,840.0 1 3,749.2 915.00 13.50 67.8 87.0 37.6 Clear,WC 32.2° 307°NW @ 7.6 mph Daily summary operation 24h Summary -_.-- ---_-- Slip/cut drlg line,RIH,drill 7925-8840 ft.C&C fluids,POH for Xceed tool failure. Operation at 07.00 - - - __-. . -- - -- -- - ------------ ----- Drill ahead 8-1/2 hole drctnl. Depth @0345 8150'MD 24h Forecast -. -- --- ---------- POH,sidetrack well+-8150 ft.Drill ahead 8-1/2 hole towards TD. Uthology Shows MAASP Pressure(psl) Mud Weight(lb/gal) 8.95 Time Log Cum Start End Our Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 25 P PJSM,flow check,slip/cut drag line. 03:00 04:00 1.00 4.00 DRILL E 17. P Circ/cond fluids,circ csg clean. 04:00 06:00 2.00 6.00 DRILL E 4 P Flow check,RIH 5"DP to 7700 ft.Slight excess do drag 3/4K.No gain/loss.Correct displacement. 06:00 06:30 0.50 6.50 DRILL E 6 P Precaution wash/ream 7700-btm at 7925 ft.No fill. __ 06:30 15:30 9.00 15.50 DRILL E 3 P Drill ahead 8-1/2 hole drctnl,7925-8598 ft WOB 6/12K, RPM 140, SPP 2700, SPM 155, GPM 650 Up 155, Dn 85, Rot 102, Tork on 8000,Tort off 6500 ECD 10.88, Gas 45-465 units, Adt=6.4 hrs. Connections free,normal drag/torque,No gain/loss. Cuttings return normal quantity/quality. 15:30 17:30 2.00 17.50 DRILL E 16 P Difficulty with wellbore trajectory,backream 8598-8408 ft.No increase cuttings at shaker.Wash?ream to btm at 8598 ft._. 17:30 22:00 4.50 22.00 DRILL E 3 P Resume Drill ahead 8-1/2 hole dretnl,8598 ft.-8840ft/ f WOB 6/12K, RPM 140, SPP 2700, SPM 155, GPM 650 y1"0 Up 155, Dn 85, Rot 102, Tork on 8000, Tork off 6500 r Q� t i 6 o . ��i�v ECD 10.88, Gas 45-465 units, Adt=6.4 hrs. v Connections free,normal drag/torque,No gain/loss. Cuttings return normal quantity/quality. 22:00 23:00 1.00 23.00 DRILL F 7 U PJSM,flow check,decision made for sidetrck at+-8150 ft.as per ENI Geo Dept.C&C fluids for POH. 23:00 00:00 1.00 24.00 DRILL F 4 U PJSM,flow check,POH for sidetrack wellbore.8130 ft end of tour. Daily Contacts Position j Contact Name Company 1 Title Email I Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Dave Morris ENI Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative 'Jack Potter ENI HSE Jack.Potter©enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Last Casing _Cas.Type OD(in) ID(in) Grade Top(RKB) _ Bottom(ftKB) Run Date CASING 9 5/81 8.681 L80 0.41 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 1 Fluid Density(lb/gal) 'I P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 1041 Eni E&P Division Well Name: OP08-04 ENI Petroleum Daily Report Well Code: 23950 Field Name: Nikaitchuq • Co. Inc. Date:7/5/2010 - Report#: 19 API/UWI: 50-029-23424-00-00 2n e page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 iENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 15.06 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft)'Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 8,840.0 3,749.2 0.00 1 89.0 33.4 OC,Fog,WC 27.7° 279°W @ 6.7 mph Daily summary operation 2411 Summary Attempt sidetrack,POH for SLB Xceed tool failure.Test BOPE. Operation at 07.00 MU BHA#6 24h Forecast Test BOP,MU BHA#6,RIH,sidetrack well,drill ahead 8-1/2 hole. Lithology I Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.95 Time Log Cum Start End Dur Our Time Time (hrs) (hr•) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL F 3 'P PJSM,flow check,attempt open hole sidetrack 8123-8160 ft.SLB"Xceed"tool failure.Prepare POH for BHA. 08:30 14:00 5.50 14.00 DRILL F 4 P PJSM,flow check,POH 5"DP to BHA.Normal drag,no swab/gain/loss. Correct displacement. 14:00 17:00 3.00 17.00 DRILL F 4 P Flow check,lay dn BHA#5,inspect/grade bit(As new condition).Lay dn all Xceed components. 17:00 00:00 7.00 24.00 DRILL F 12 P PJSM,flow check,prepare test BOPE.Pull wear ring,set test plug. Test BOPE/all components 250/3500 psi.Test annular 250/2500 psi. M7/„, Perform time/volume/press test at accumulator system.Test all floor valves, all valving/plumbing to mud pumps.Test successful,no re-tests. Witness waived,Mr Jeff Jones AOGCC. Daily Contacts Position I Contact Name Company I TNN E-mall : Office Mobile Eni representative Jack Keener ENI :Sr.Drilling Slaw. Jack.Keener @enipetroleum.com :907-670-8623 907-715-6434 Eni representative Dave Moms ENI Drilling Spvr. Dave.Moms @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig©enipetroleum.com 907-670-8607 907-229-6100 !, Eni representative Jack Potter ENI HSE Jack.Potter@enipetroleum.com Eni representative ',Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI ',Expediter Greg.Parker©enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L80 ------- 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VereaPro OBM 8.80 629.0 12.14 2,287.9 sr Eni E&P Division Name: OP08-04 094 1 ENI Petroleum Daily Report Well Code: 23950 •n C.O. Inc. Field Name: Nikaitchuq II Date:7/6/2010 - Report#: 20 API/UWI: 50-029-23424-00-00 page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) ,Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(N... Depth Dr.(MD)(ft) 'Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 16.06 Daily Information Depth End(ftKB) Depth End(ND)(...j Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 8,990.0 3,754.9 850.00 8.41 101.1 91.0 46.5 OC,WC 40.3° 200°SSW @ 13 i mph Daily summary operation 24h Summary Complete test BOPE,MU BHA#6,RIH test same.RIH 5"DP,complete sidetrack,commence drill ahead 8-1/2 hole drctnl 8140-8990 ft. Operation at 07.00 Drilling ahead 8-1/2"hole as per SLB,Depth at 0400 9300'MD 24h Forecast Drill ahead 8-1/2 hole towards TD Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Dew. 00:00 01:00 1.00 1.00,DRILL F 12 P Remove test plug,set wear ring.Blow do lines.Clear floor. -�- - 01:00 03:30 2.50 3.50 DRILL F 4 P PJSM,MU BHA#6,"Xceed"drctnl assy.Flow check,RIH same. 03:30 04:30 1.00 4.50 DRILL F 12 P Shallow test drctnl assy at 950 ft.Test successful. 04:30 09:00 4.50 9.00 DRILL F 4 P PJSM,flow check,follow BHA with 5"DP to 7900 ft.Work tight hole at 6324 ft.Take approx 5-7K wt.No gain/loss. Correct displacement. 09:00 10:30 1.50 10.50 DRILL F 19 P Precaution wash 7900-8123 ft.Wellbore good cond.no fill. / ,I - 10:30 11:00 0.50 11.00 DRILL F 19 P Flow check,Resume open hole sidetrack cut trough 8123-8140 f1. ✓ 650 gpm,2800 psi,80 rpm,5500-8000 torque.Confirm sidetracked. 11:00 00:00 13.00 24.00 DRILL E 3 P Resume Drill ahead 8-1/2 hole drctnl,8140 ft.-8990ft WOB 6/12K, RPM 120, SPP 2700, SPM 155, GPM 650 I ! Up 158, Dn 87, Rot 103, Torque on 8900, Torque off 6500 ECD 10.59, Gas 45-461 units, Adt=8.41 hrs. Connections free,normal drag/torque,No gain/loss. Cuttings retum normal quantity/quality. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com ,907-670-8623 907-715-6434 , Eni representative Dave Morris ENI Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig@enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter@enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Last Casing seat _ Cas.Type OD(In) I ID(in) Grade Top(RKB) I Bottom(RKB) Run Date CASING 95/8 8.681 L80 0.41 -- --- 4,999.2 6/28/2010-__-- Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 I 2,287.9 I I Vois Eni E&P Division Well Name: OP08-04 -_-- Daily Report Well Code: 23950_---- ENI Petroleum • Field Name: Nikaitchuq /g� n Co. Inc. Date:7/7/2010 - Report#: 21 API/UWI: 50-029-23424-00-00 en n. Wellbore name: Original Hole page 1 of l Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) I Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase ',Spud Date Target Depth(ftKB)'Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING I 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 17.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(R) Drilling Hours(hrs) Average ROP(ft/hr) POB (Temperature(°F) Weather Wind 10,490.0 3,748.9 1,500.00 16.15 92.9 89.0 46.6 Clear,WC 40.8° 220°SW @ 11.4 mph Daily summary operation 24h Summary Drill 8-1/2 hole 8990-10490 ft Operation at 07.00 Drilling ahead 8-1/T hole as per SLB,Depth at 0400 hours,-10,750'MD 24h Forecast TD well,circ,wiper trip,POH for liner. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Our Our Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 3 P Resume Drill ahead 8-1/2 hole drctnl,8990-9300 ft. WOB 6K, RPM 120, SPP 2800, SPM 155, GPM 663 Up 166, Dn 83, Rot 107, Torque on 9000, Torque off 7000 ECD 10.8, Gas 55-580 units, Connections free,normal drag/torque,No gain/loss. 'Cuttings return normal quantity/quality. 04:00 05:00 1.00 5.00 DRILL E 21 P Circ/cond fluids while wait on orders Geo Dept ENI Anchorage. 05:00 12:00 7.00 12.00 DRILL E 3 P Flow check,Resume Drill ahead 8-1/2 hole drctnl,9300 ft.-9830 ft WOB 6K, RPM 120, SPP 2800, SPM 155, GPM 663 Up 166, Dn 83, Rot 107, Torque on 9000, Torque off 7000 ECD 10.8, Gas 55-580 units,Adt=6.65 hrs. Connections free,normal drag/torque,No gain/loss. Cuttings return normal quantity/quality. 12:00 00:00 12.00 24.00 DRILL E 3 P Flow check,Resume Drill ahead 8-1/2 hole drctnl,9830-10490 ft WOB 7K, RPM 120, SPP 2800, SPM 155, GPM 663 Up 160, Dn 80, Rot 102, Torque on 10000, Torque off 8000 ECD 11.09, Gas 60-590 units,Mt=16.15 hrs. Connections free,normal drag/torque,No gain/loss. Cuttings return normal quantity/quality. Daily Contacts Position I Contact Name I Company ; This E-mail I Office Mobile Eni representative Jack Keener ENI '.Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Dave Morris ENI Drilling Spvr. Dave.Moris @enipetroleum.com ,907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907.670.8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(In) ID(M) Grade Top(RKB) f Bottom(RKB) Run Date CASING 9 5/81 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 I 2,287.9 ico Eni E&P Division Well Name: OP08-04 ENI Petroleum Daily Report Well Code: 23950 Field Name Nikaitchuq j n CO. Inc Date:7/8/2010 - Report#: 22 API/UWI: 50-029-23424-00-00 lC II - Wellbore name: Original Hole page 1 of 1 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB)(Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING I 6/20/2010 10,927.0 I 3,758.9 11,810.00 158.27 74.6 18.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 11,240.0 3,707.3 750.00 5.37 139.7 89.0 55.9 Clear,WC 55.9° 221°SSW @ 6.8 mph Daily summary operation 24h Summary Drill ahead 10490-11240 fTDI.C&C fluids,POH wiper hip to 8600 ft. Well OP08-04 TD(MD 11240 ft TVD 3706 ft),this date at 0930 hrs. Operation at 07.00 ----- Backreaming out of hole 24h Forecast Badcream out of hole to 9-5/8 csg shoe.C&C fluids,RIH for fluid displacement. Llthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Dur Dur Time Time (his) ( ) Phase Opr. Act _ Plan Oper.Darer. 00:00 09:30 9.50 9.50 DRILL E 3 P Flow check,Resume Drill ahead 8-1/2 hole drctnl,10490-11240 ft(TD) WOB 7K, RPM 120, SPP 2990, SPM 155, GPM 663 Up 160, Dn 80, Rot 100, Torque on 11000, Torque off 10000 ECD 11.3, Gas 60-785 units, Adt=5.37 hrs. Connections free,normal drag/torque,No gain/loss. Cuttings return normal quantity/quality. Well OP08-04 TD(MD 11240 ft TVD 3706 ft),this date at 0930 hrs. 09:30 12:30 3.00 12.50 DRILL E 7 P Clrc/cond fluids,660 gpm/2990 psi,no gain/loss. Shakers clean. 12:30 15:00 2.50 15.00 DRILL E 6 TP04 PJSM,flow check,POH 5"DP wiper trip to 10550 ft Tight hole with swabbing.Wash to brim at 11240 ft. 15:00 18:00 3.00 18.00 DRILL E 7 TP04 Circ/cond fluids,660 gpm/2990 psi,no gain/loss. Pump weighted sweep.10%addtnl sand with sweep.Continue circ shakers clean. 18:00 20:30 2.50 20.50 DRILL E 6 P PJSM,flow check,P01-15"DP to 9275 ft on elevators.Tight hole,no swabbing. Stuck pipe.Regain rotation/reciprocation.Work/ream free and clean with top drive. 20:30 00:00 3.50 24.00 DRILL E 6 TP04 Commence backream towards 9-5/8 csg shoe.9275-8600 ft. No abnormal torque/drag.No gain/loss.Correct displacement. Daily Contacts _ Position I Contact Name Company 7 Title ' E-mall 0111q Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Dave Moms ENI Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907.670-8607 907-229-6100 Eni representative Jack Potter ENI HSE Jadc.Potter@enipetroleum.com Eni representative 'Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(In) j ID(in) Grade Top(RKB) I Bottom(RKB) Run Date CASING 9 5/8I 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P(Surf)(psi) [Eq.Mud Weight(1b/gal) Leak Off Pressure(psl) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 it Eni E&P Division Well Name: 0P08-04 Daily Report ENI Petroleum Well Code: 23950 Field Name: Nikaitchuq • Co. Inc. Date:7/9/2010 - Report#: 23 APUUWI: 50-029-23424-00-00 en Wellbore name: Original Hole page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type 402100 IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) I Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 I 12.20 Rig information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 19.06 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) 'Average ROP(ft/hr) POB Temperature(°F) Weather Wind 11,240.0 3,707.3 0.00 88.0 I 35.4 OC,FOG,WC 25.2° 41°NE @ 17.4 mph Daily summary operation 24h Summary Complete backream 8450-4070 ft.Slip/cut dug line,service rig,RIH,complete wiper trip to btm.C/C fluids,displace well to completion fluids,prepare POH. Operation at 07.00 POH and laying down 5"DP 24h Forecast P01-1 laying dn Excess 5"DP,Lay dn BHA,RU for liner run, Lithology Shows __--- .-- ---- MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log cum Start End Dur Dur Time Time (hrs) (hrs) Phase O_p r. Act Plan Oper.Dears. 00:00 06:30 6.50 6.50'DRILL E -- 6 P Complete wiper trip out of hole,backream out to csg shoe at 4970 ft. No abnormal torque/drag.No gain/loss.Correct displacement. 06:30 09:00 2.50 9.00 DRILL E 25 P PJSM,flow check,slip/cut drig line,service rig. 09:00 13:30 4.50 13.50 DRILL E 6 P PJSM,flow check,complete wiper trip in hole to 11100 ft.Work tight hole at 9590-9720 ft.No pump/rot.Correct displacement.No gain/losses. 13:30 14:00 0.50 14.00 DRILL E 6 P Flow check,precaution wash/ream 11100-11240 ft.No fill. 14:00 19:30 5.50 19.50 DRILL E 7 P Circ/cond fluids,pump weighted sweep.3-4%increased cuttings retums to shaker. 19:30 23:30 4.00 23.50 DRILL E 7 P PJSM,displace well to completion fluids(Versa Pro SF). 23:30 00:00 0.50 24.00 DRILL E 4 P Flow check,well static,pump wt pill,prepare POH for liner. Daily Contacts Position I Contact Name Company I Title E-mail Office Mobile Eni representative ,Jack Keener ENI ''Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Dave Morris ENI Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI ;Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative I Nelson Carballo ENI Drig Superintendent Nelson.Carballo @enipetroleum.com 907-865-3325 Last Casing seat Cas.Type OD(In) J ID(in) Grade Top(RKB) I Bottom(RKB) Rum Date CASING 9 5/8. 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM I 8.80 629.0 12.14 2,287.9 101 Eni E&P Division } Well Name: OP08-04 Daily Report` WellCode: 23950 ENI Petroleum • CO. Inc. Field Name: Nikaitchuq Date:7/10/2010 - Report#: 24 API/UWI: 50-029-23424-00-00 page 1 of 1 Wellbore name: Original Hole Well Header -_ Permit/Concession N° Operator ENI Share(%) I Well Configuration type 402100 'ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date Target Depth(RKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 20.06 Daily information Depth End(RKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) IAverage ROP(ft/hr) POB Temperature(°F) Weather Wind 11,240.0 3,707.3 0.00 1 89.0 38.5 OC,FOG,WC 30.2° 62°ENE @ 13.1 1 mph 1 Daily summary operation 24h Summary -s. : 'r.., -..- •- - dn BHA RU/RUN 5-1/2 liner to 4899 ft. Operation at 07.00 Running 5-1/2"liner,depth at 0345 hours 6740'MD 24h Forecast Complete run 5-1/2 liner,suspend and test hanger/pkr.POH laying dn DP. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 1 9.30 Time Log Cum I Start End Dur Dur Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 14 P Resume POH 5"DP standing back in mast for liner run. No swab.No abnormal drag.Correct hole fill. 03:00 13:00 10.00 13.00 DRILL E 4 P PJSM,flow check.Rig up for POH 5"DP in singles laying dn to pipe I shed.100 jts set aside with wom hard band. No correction SLM to Logger depth. 13:00 15:00 2.00 15.00 DRILL E 4 P Flow check at BHA,trip losses approx.5 bph.Lay do dretnl BHA. 15:00 16:00 1.00 16.00 DRILL E 20 P Remove BHA from pipe shed.Clear rig floor,prep to handle HWDP. 16:00 17:30 1.50 17.50 DRILL E 4 P PU/stand back 7 stds 5'HWDP in mast.Strap/drift same. ' 17:30 19:00 1.50 19.00 DRILL E 20 P PJSM,RU liner running equipment,MU safety jt. 19:00 00:00 5.00 24.00 DRILL E 4 P Commence RIH 5-1/2 liner assy.MU guide shoe,follow with slotted liner with blanks at specified intervals.Turbo - centralizers at all jts.4800 ft at shift change.Up 102, Dn 85. I LESSON LEARNED:THE SFOBM WAS PUT INTO DIFFERENT RIG PITS THAN NORMAL FOR DISPLACEMENT,WHEN WE WENT TO START ON THE DISPL. WE WERE NOT ABLE TO PUMP,DISPLACE,AND RETURN INTO THE PLANNED MUD PITS,DUE TO THE PIT WOULD NOT EQUALIZE.THE MUD WAS THEN TRANSFERRED AROUND,AND DISPLACEMENT WAS COMPLETED.THE SOLUTION WAS DETERMINED THAT A PROCEDURE TO BE WROTE UP FOR DISPLACEMENTS,AND BE USED THE SAME ON ALL DISPLACEMENT JOBS,FOR ALL CREWS&MUD ENGINEERS.TO PREVENT THIS FROM HAPPENING AGAIN. Daily Contacts Position I Contact Name Company I_ Title E-mail Office 1 Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Dave Morris ENI Drilling Spvr. Dave.Monis @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com '907-670-8607 907-229-6100 I Eni representative !Jack Potter ENI HSE Jack.Potter@enipetroleum.com I Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 I Eni representative ,Greg Parker ENI 'Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative i Nelson Carballo ENI I Ddg Superintendent Nelson.Carballo @enipetroleum.com 907-865-3325 Last Casing seat s,"'Cas.Type OD(In) I ID(in) Grade Top(RKB) I Bott ' . .. r"';;Sun Date CASING 9 5/8, 8.681 L80 0.411 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 i 01 Eni E&P Division Well Name: OP08-04 Daily Report ENI Petroleum Well Code: 23950 Field Name: Nikaitchuq • Co. Inc. Date:7/11/2010 - Report#: 25 API/UWI: 50-029-23424-00-00 fpage 1 of I Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole DRILLING 6/20/2010 10,927.0 3,758.9 11,810.00 158.27 74.6 21.77 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB 'Temperature(°F) Weather Wind 11,240.0 3,707.3 0.00 89.0 38.8 OC,WC 29.8° 292°WNW @19.9 mph Daily summary operation 24h Summary Run/suspend/test 5-1/2 liner assy.POH laying dn 5"DP.Lay liner run equip. Note:Last DRILLING report.Continued on COMPLETION Reports. Operation at 07.00 MU/RIH ESP completion 24h Forecast Complete MU/RIH ESP completion. Lithology Shows MAASP Pressure(psi) 'Mud Weight(Ib/gal) 9.30 Time Log / Cum I - - _-. Start End Dur Dur Time Time (hrs) (hr.) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 4 IP Continue RIH 5-1/2 liner assy. 02:00 03:00 1.00 3.00 DRILL E 5 P PJSM,MU Baker SLZXP liner hgr/packer.Mix/pour"Pal"mix. Wait on Pal mix set up 30 min.Inspect Liner hanger for proper specs. 03:00 06:30 3.50 6.50 DRILL E 4 P PJSM,flow check,follow liner hanger with 5"DP to setting depth. Excellent casing/open hole running conditions.Normal dn drag/rotating torques/correct displacement.No gain/losses. 06:30 09:00 2.50 9.00 DRILL E 19 P 5.5"DWC SLOTTED LINER ON DEPTH @11113'MD,M/U TOPDRIVE AND BREAK CIRCULATION,CIRC.DP+HWDP CAPACITY+200 STKS @5 BPM PSI=411,PU WT=180K,SO WT=80K,ROT.WT=123K,RPM=15,TQ=8K. DROP BALL&PUMP DOWN BALL 1/2 OF STRING CAPACITY AT 4 BPM WITH 230 PSI,SLOW PUMP TO 2 BPM AT 440 STKS AWAY WITH 85 PSI, LAND BALL&PT UP TO 3000/PSI-OK,HOLD 10 MINUTES,BLEED OFF. S/O TO 75K,PT DP UP TO 4000 PSI,BLEED OFF,PU TO 110K.PT ANNULUS TEST PACKER TO 1500 PSI F/10 MINUTES-OK,BLEED OFF,PU TO 153K& RELEASE FROM LINER-OK.BREAK OFF STAND DP&RACK BACK SAME. Final Setting Depths=Liner shoe at 11,113 ft, Top Liner Hgr at 4,792.40 ft 09:00 10:00 1.00 10.00'DRILL E 4 P Flow check,PJSM,POH laying do 5"DP to 4223 ft. 10:00 10:30 0.50 10.50 DRILL E 25 P Service rig. 10:30 16:00 5.50 16.00 DRILL E 4 P PJSM,flow check,resume POH laying dn 5"DP to liner run tool. 16:00 17:00 1.00 17.00 DRILL E 5 P Lay do liner run equip.Clear floor all liner/drig related equip. Note:Last DRILLING report.Continued on COMPLETION Reports. Daily Contacts Position I Contact Name Company I Title Email Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative Dave Morris ENI Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI ''HSE Jack.Potter @enipetroleum.com Eni representative '.Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker©enipetroleum.com 907-980-7545 Eni representative Nelson Carballo ENI Drig Superintendent Nelson.Carballo @ enipetroleum.com 907-865-3325 Eni representative 'Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) ID(in) Grade Top MKS) I Bottom(ftKB) Run Date CASING 9 5/8 8.681 L80 0.4: 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) !Leak Off Pressure(pal) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 1 2,287.9 "�" Eni E&P Division Report Well Name: OP08-04 Daily Repot ` WellCode: 23950 ENI Petroleum Field Name: Nikaitchuq Co. Inc. Date:7/11/2010 - Report#: 1 API/UWI: 50-029-23424-00-00•f Wellbore name: Original Hole page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name •Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase ISpud Date Target Depth(RKB)'Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole COMPLETION 10,927.0 3,758.9 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) I Average ROP(ft/hr) POE Temperature(°F) Weather Wind 89.0 37.2 OC,WC 27.7° 265°W @ 19 mph Daily summary operation 24h Summary RU/Run 4-1/2 ESP comoletion MU/test ell FSP aimnnnentc Set ninon/test t Operation at 07.00 Run 4-1/2 ESP completion. 24h Forecast RU/Run 4-1/2 ESP completion. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Cum Start End Dur Dur Time Time (hrs) (ha) Phase Opr. Aet. Plan Dew. 17:00 20:00 3.00 3.00 DRILL K 5 i P PJSM,rig up for ESP completion.Place all equip to rig floor.Arrange pipe shed,RU slick line sheaves/unit.RU tbg tongs. 20:00 23:00 3.00 6.00 DRILL K 5 __ P PJSM,PU tbg Intake,/t tbg, PU pump assy,set in tbg. 23:00 00:00 1.00 7.00 DRILL K 5 P Commence slickline work.Set tbg padcoff,confirm seated. Daily Contacts Position 7 Contact Name , Company I Tide EarW l — y ,, 011166 Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative Dave Moms ENI Sr.Drilling Spvr. Dave.Moms @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI •HSE Jack.Potter©enipetroleum.com 907-685-1227 907-032-2236 Eni representative Joe Longo ENI 'Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker@enipetroleum.com 907-980-7545 Eni representative Nelson Carballo ENI .DrIg Superintendent Nelson.Carballo(genipetroleum.com 907-865-3325 Eni representative Michael Seward ENI i Project Advisor Michael.Seward @enipetroleum.com ,907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) I ID(it) — Grade Top(RKB) 1 Bottom(ig0B) 1 Run Dab CASING 9 5/8 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) ND(RKB) Fluid Type Fluid Density(11)/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM i 8.80 I 629.0 I 12.14 2,287.9 I • It Viiiii Eni E&P Division Well Name: OP08-04 EN!Petroleum Daily Report Well Code: 23950 • CO- inc. '.. Field Name: Nikaitchuq Date:7/12/2010 - Report#: 2 API/UWI: 50-029-23424-00-00 rri page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type ' 402100 L PETROLEUM I 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole COMPLETION 10,927.0 3,758.9 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) (Average ROP(ft/hr)IPOB Temperature(°F) Weather Wind 11 -- 88.0 36.7 Clear,WC 31.6° 132°SE @ 6 mph Daily summary operation 24h Summary -- --- --- --Run ESP completion,PU VIT jts. Operation at 07.00 Terminating ESP connections 24h Forecast Complete ESP completion,land hgr,terminate lines,test Lithology _----Shows - --- MAASP Pressure(psi) Mud Weight(Ib/gal) i__ 9.30 Time Log Cum Start End Dur Dur ', Time Time (hrs) (hrs) Phase Opr. Act. � Plan Oper.Descr.00:00 01:30 1.50 1.50 DRILL K 5 P Continue MU pump assy 4-1/2 ESP completion.Test pkf to 1000 psi with slickline.Test successful.RD Howco slickline,release unit. 01:30 10:00 8.50 10.00 DRILL K 5 I P MU remainder ESP um p p assy.Service motor/seal assy,Make control line connections.Secure lines with Cannon clamps.Re-confirm/meg/press test all connections. 10:00 18:00 8.00 18.00'(DRILL K 4 P Follow ESP BHA with 4-1/2,12.6#,L80 tbg to VIT jts at 4287 ft. 18:00 22:00 4.00 22.00 DRILL K 5 U Multiple attempts to MU 4-1/2 X 5-1/2 VIT jts.Pins will not shoulder up at makeup.Connections destroyed at breakout. Cease attempt at MU VIT jts.Confir with Mr Marc Kuck ENI Anchorage.Decision made to forego run VIT jts,replace with tbg jts. 22:00 23:30 1.50 23.50 DRILL K 25 TS03 GBR tbg tongs malfunction/broken parts.Cannot remove from VIT jt.Partial disassemble in place.Remove/replace tbg tongs. 23:30 00:00 0.50 24.00 i DRILL K 15 --j UU- Break out VIT jts/XOs. Daily Contacts Position I Contact Name Congany Title Small I Office Mobile Eni representative 'Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 1907-670-8623 907-841-8759 Eni representative ;Dave Morris ENI Sr.Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670.8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 907-632-2236 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor Michael.Seward @enipetroleum.com 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) I ID(In) Grade Top(ftKB) I Bottom(RKB) Run Date CASING 9 5/81 8.681 L80 0.4, 4,999.2 6/28/2010 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) !Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 mss. Well Name: OP08-04 itt o Eni E&P Division f71J2 } ENI Petroleum Daily Report Well Code: 23950 'Field Name: Nikaitchuq • �• Co. Inc. Date:7/13/2010 - Report#: 3 API/UWI: 50-029-23424-00-00 Wellbore name: Original Hole page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type 402100 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 , 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(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole COMPLETION 10,927.0 3,758.9 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB i Temperature(°F) Weather Wind 82.0 I 43.0 Partly Cloudy,WC 208°SSW©5.1 39.6° mph Daily summary operation 24h Summary Freeze protect and secure well Operation at 07.00 _- Rigging dwn/moving rig 24h Forecast Move/spot rig to OP12-01 location Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL K 5 P Continue change out VIT jts to tbg jts(2),clamp lines to tbg hgr area.Make up tbg hgr,orient alignment slots.Make elect connections,install penetrator.Meg out electrical.Test press gauge tbg.line.Tests succesful. 05:00 06:30 1.50 6.50 DRILL K 12 P PJSM,drain BOP stack,land tbg hgr.test hgr seals 5000 psi/10 min.Test successful.No re-tests.Set two way check. 06:30 11:00 4.50 11.00 DRILL K 5 P PJSM,ND ROPE,all related equipment.Set back BOP stack,secure on pedestal. 11:00 13:30 2.50 13.50 DRILL K 5 P Install prod tree,connect all peripherals. 13:30 14:00 0.50 14.00 DRILL K 12 P PJSM,test against TWC/primary-secondary seals/flange gasket,penetrator seals and prod tree(5000 psi/10 min) test successful,no re-tests. 14:00 16:30 2.50 16.50 DRILL K 5 P Install lubricator,pull TWC,dose master valve.Install wing valve,actuator valve on prod tree. 16:30 21:00 4.50 21.00 DRILL K 9 P PJSM.commence freeze well(4-1/2 tbg&9-5/8 X 4-1/2 annulus) Test lines 3000 psi.Test good.Open lines to well,annulus on vacuum.Begin pumping.ICP 0 psi due to vacuum.Pump 2.5 bbls build to 800 psi/5 bpm.Lose approx 50%returns as diesel turns corner to tbg.Reduce rate to 2 bpm.Continue pump total 320 bbls diesel.87 bbls returned to surface.FCP remaining at 800 psi. Confir with Mr Joe Longo and Marc Kuck.Decision to let job stand,proceed to next phase.Rig dn LRS,release unit. Note:Tbg=600 psi Annulus=850 psi. 21:00 22:30 1.50 22.50 DRILL K 5 P PJSM,lubricate in BPV,secure well.Rig dn lubricator. 22:30 00:00 1.50 24.00 DRILL K 5 P PJSM,install choke valve on prod tree.Install ported flange/gauge on Inner annulus. . Note: Nabors rig 245e released this date 00:00 hrs. Daily Contacts Position i Contact Name Company I Title Ell I Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative Dave Morris ENI Sr.Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 907-632-2236 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 1 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor Michael.Seward @enipetroleum.com 907-865-3337 907-952-7880 Last Casing seat Cas.Type __-_--_-.00(in) I ID(in) Grade Top(ftKB)---- I--"-Bottom(MB) Run Date CASING 95/8 8.681 L80 0.4 - - --- 4,999.26/28/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 629.0 12.14 2,287.9 Toil Eni E&P Division Well Name: OP08-04 ENI Petroleum Daily Report Well Code:23950 • Field Name: Nikaitchuq Co. Inc. Date:7/14/2010 - Report#: 4 API/UWI: 50-029-23424-00-00 en n• page 1 of 1 Wellbore name: Original Hole Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM J 100.00 DIRECTIONAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.20 12.20 Rig Information Contractor Rig Name !Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 1Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) Original Hole COMPLETION i 10,927.0 3,758.9 Daily Information Depth End(ftKB) Depth End(TVD)(...!Depth Progress(ft) Drilling Hours(hrs) !Average ROP(ft/hr) POB Temperature(°F) (Weather (Wind i 82.0 1 L--- Daily summary operation 24h Summary Rig dn,split rig modules,prep gravel for mats,set mats,spot derrick module. Operation at 07.00 Move In/rig upon OP12-01 24h Forecast Move in/rig up on OP12-01 Llthology _..- _.._ .... 'Shows -.._--- MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Cunt Start End Dur Dur ! Time Time (his) (his) ; Phase Opr. Act Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL A 2 P PJSM,commence rig dn/prep for rig move.R/D de-gasser,roll up curtains,hang cellar box,remove shaker screens, secure BOP stack.Blow dn steam/water lines,Disconnect elect to modules,remove all connecting plumbing to modules. Jack up modules,set on crib blocks.Warm up Lampsons.Remove cuttings tank.Remove berm surrounding rig. 12:00 00:00 12.00 24.00 DRILL A 2 P PJSM,Split modules.Transport sub to east,utility to west.Remove rig mats.Dispose old berm.Surveyors shoot/grade/ stake pad.Take load gravel,spread to new drill site.Grader/loader/compactor level pad.Raise BOP scaffolding in cellar.Roll out herculite over new pad.Set mats for sub,and plywood for"stomper".Spot derrick module. Daily Contacts Position Contact Name :Company --. 'ftl I Email •! Office -..Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Dave Morris ENI Sr.Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Jack Potter ENI HSE Jack.Potter©enipetroleum.com 907-685-1227 907-632-2236 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 1907-865-3323 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker©enipetroleum.com 907-980-7545 Eni representative IMichaelSeward ENI Project Advisor Michael.Seward @enipetroleum.com 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) ID(in) Grade 1 Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L80 0.4 4,999.2 6/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) l P(Surf)(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 4,999.0 3,628.87 VersaPro OBM 8.80 j 629.0 12.14 2,287.9 0r-0., ., .O O,M .1.-0..t 0.A .-,00.- M O O O M N O O N, N M A N O O M N M. NO N M MOOT, .T r M N 1r,-_g22 a0N _ npMNN N Y N N'4 C T V NO ND D 00 0N 10OM. 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LL J M O O m O W n LL 0 Z' U T. a O �p p� W CMN • LL . - i E ��ppOMOIA�O NmNN{A3 Omi3O C'l7aA t'��Op:28 p<M<S g gpN §E§ i6ii C N M V N �O�pp rp0 OA1 O m 0)M N1�m O O e^.-�OIA�N f thm N N O 03 m CI 00000 O�0 0 0 0 00000 000 0007 `� 000001 .0 O N O m` O O a TO O O q y E Co 0 0 0 o E p E e`8N.29 m 2eLL o0m00 m q G r 2 • m N Y M E g 0J 0 d a> E m V! U ws N N li °iPeloton Wellhiew(OPT, )4) - File Tools Help Well: 0P08-04 . "Close d Edit Data... 0 Sync Data... Add-Ins, Q Help... Reports Schematic I Wellbore Job Date I Original Hole zi I DRILLING,6/17/2010 8:00:00 AM 2:118/27/2010 J ► Well ftKB ftKB (MD) (TVD) Inc! Schematic-Actual 0 0 0.0 - 32 32 on ® 7 36 36 0.0 gir : m. 37 37 0.0 IL 2/1.t111-1/ /' : 1101/ ,/ll/ll,//l/„1//■l/lull!,!,//1/,/fl„Il, 42 42 0.0 46 46 0.0 130 130 0.3 -` 135 135 0.4 2,205 2,044 33.5 2,248 2,080 33.6 I 2,332 2,149 34.0 2,334 2,151 34.0 ilk■ CASING,13 3B,0,2,333.6 3,619 3,180 51.4 r 4,213 3,467 68.7 4,226 3,471 68.9 4,317 3,503 70.0 4,325 3506 70.1 4,378 3,524 70.6 1 II 4,395 3,530 70.9 4,413 3,535 71.2 4,417 3,536 71.3 4,814 3,616 85.9 I 1 4,819 3,616 86.0 1 1I 4,876 3,620 86.6 4,914 3,623 86.2 4,991 3,628 85.0 4,999 3,629 84.9 t 1 CASING,9 518,8.681,0,4,998.1 5,020 3,631 55.1 5,655 3,638 90.3 HMI 6,272 3,675 85.9 6,731 3,715 84.2 7,604 3,749 90.8 MI M 8,514 3,743 89.3 1111 ill 9,418 3,770 87.6 : : 9,709 3,765 93.5 10,413 3,749 89.6 1111 ill. 11,113 3,727 98.3 I I LINER,8,4.780,4,792,6,320.6 El File Tools Help Well: OP08-04 'Close ri Edit Data... 0 Sync Data.,. Add-Ins.. Q Help.., Reports Schematic 1 Wellbore Job Date Original Hole J I DRILLING,6/1 7/201 0 8:00.00 AM J q 8/27/2010 .._! / 141 11 t., >11 Well type:DIRECTIONAL-Original Hole,8127/2010 ftKB(MD) Schematic-Actual 0 1-1,R.K.B..4 1/2,3.958,0,31.9 4 , P 1-2,VD TBG.HANGER,32,1.9 2-1,CSG•LANDING JOINT,9 5/8.8.681,0.35.5 8 1-1,RKB,13 3/8,0,38.8 1-2,VD HANGER.13 3/8.37.0.4 32 n MI 1-3.CROSS OVER PUP JT.,41/2,3.968,34,9.1 .,r 2-2,CSG•NOR PUP,9 518,8.681.36,4.4 37 ,t L QuT•1 P I$ 1 '1§•.4�x_r,_i/r l t 46 _ _ < 1.3,CSG PUP JT,13 3B,37,4.4 x 134 a ■ 1-5,TUBING JOINT,4 1/2,3.068,46,84.0 1-6,CSG w/cemralizer,13 3/8,12.415,42.83.8 165 1.8.TUBING JOINT,4 1/2,3.958,130,4,077.6 1.6,CSG,13 3/8,12.416,125,2,079.5 2,118 1-7,CSO/contr.10'above FC,13 3/8,12.415,2,205.41.9 2,175 1-8,FLOAT COLLAR,13 3/8,2,247,1.6 1-9,CSG,13 318,12.416,2,248,41.7 2 228 1-10,CSG/2-centr.5'&8'above FS,13 3/8,12.415.2,290,41.7 1-11,FLOAT SHOE,13 3/8,2,332,1.9 2,252 1-7,TUBING PUP JT.,41/2,3.958,4.207,6.7 1-8,GLM-KBMG-STS-1 SV2000,41/2,3.968,4,213,7.2 2,316 1-1-9, -10.TUBING JOINT.41/2.3.068,4,226,84.6 2,343 1-11,CROSS OVER PUP JT.,4 112,3.958,4.311,8.1 f�l�1-12,DISCHARGE SUB,4 12,4.317.2.4 4'207 ��"/ 1-13,CROSS OVER PUP JT.,4 1/2.3.058,4,319,8.1 4,311 a 1-14,TUBING JOINT.41/2.3.958,4.325,42.3 1-15,CROSS OVER PUP JT.,412,3.958,4.368,9.9 4,368 1-16,TTC X-0 W/SCREEN INTAKE,4,378,10.5 1-17,UPPER TANDEM SEAL,4,388,6.9 4,402 1-18,LOWER TANDBat SEAL,4,395,6.9 4,417 1-19,MOTOR-126 HP,MS P1-250,4,402,11.1 7,7 1-2D,GAUGE HOUSING,4,413.1.8 451 9 1-21,MOTOR CENTRALIZER,4,415,2.0 3-1,SLZXP Liner Hgr/Pkr,7,7.500,4,792,21.1 4,876 : 3.2,1(0,7"298 VamTop HT Box x 5-12"Hydra 563 Pin,7,6.140,4,814,1.4 4,91 3 3.3,Seal Bore,5 12,4.780,4,815.4-.4 3-4,X0,5-12"Hydril 563 Box x DWC Pin,5 12,4.892,4,819,3.9 4,971 2-3,CSG,9 518.8.681,40,4,836.1 2.4,CSG-CENT10'UP,95/8,8.681,4,876,36.6 4 999 C C 2.5,FLOAT COLLAR,9 5/8,8.681,4,913,1.5 C c �24,CSG,95/8,8.681,4,915,41.6 5,613 . \ 3.5,5-1/2"Blank Liner,5 12,4.892,4,823,168.1 I Im • 2.7,CSG-CENT 5'&8',9 618,8.681,4,956,41.2 6,689 amori 2-8.FLOAT SHOE,9 518,8.681,4,997,1.9 E .,. 33.6,5-12"Slotted Liner,5 12,4.892,4,991,621.9 7,604 � 3-7,Easy Well Swell Packer,8,4.892,5,613,41.6 7,775 3-8,5-12"Slotted L ner,5 12,4.892,5,855,574.7 [ r 3-9,EasyWell Swell Packer.8.4.892,6,230,41.9 7,885 [ C 3-10,5-1/2"Blank Liner,5 1/2,4.892,6,272,417.5 7,925 [ [ 1 3.11,EasyWell Swell Packer,8,4.892,6,689,42.0 3-12,5-1/2 Slotted Liner,5 12,4.892,6,731,831.4 ' 3-13,EasyWell Swell Packer,8,4.892,7,562,41.9 8,448 1 I- r 3-14,5-12"Slotted Liner,5 12,4.892.7,604.868.7 $,514 7�c "U 3-15,EasyWell Swell Packer.8,4.892.8.473.41.5 I c c 3-16,5-12"Slotted Liner,5 12,4.892,8,514,861.1 8,685 1 C c 3-17,EasyWell Swell Packer,8,4.892,9,376,42.0 r 3.18,5.12"Blank Liner,5 12,4.892,9,418,249.8 9,418 3.19,6syWe11 Swell Packer,8,4.892,9,667,43.0 � 3.20,5.12"Slotted Liner,5 12,4.892,9,709.662.3 1 0,41 3 C 3-21,EasyWell Swell Packer,8,4.892,10,372,41.6 10,848 E C 10,961 I L 1 3-22.5-12"Slotted Liner,5 12,4.892,10,413,697.8 11,113 3-23,Silver Bullet Guide Shoe,5 718,4.892,11,111,1.9 I Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 29, 2010 10:02 AM To: 'Quay Walter Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: RE: OP08-04- Permit 210-0410 Walter, After review of the last state witnessed BOP test the request to extend the testing frequency to 14 days is granted for Nabors 245. Please be very diligent in your operations scheduling that you adhere to this 14 day limit. Extensions to this time limit will not be granted unless there are very extenuating circumstances. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Quay Walter [mailto:Walter.Quay @enipetroleum.com] Sent: Tuesday, June 29, 2010 9:45 AM To: Schwartz, Guy L(DOA) Subject: OP08-04 - Permit 210-0410 Guy, With the witness of the BOP test on Nabors 245, June 25, 2010, by Bob Noble of the AOGCC, as per the attached note, please review for consideration the 14 day BOP Test frequency for the ENI drilling operation. Walter Quay Drilling Superintendent Walter.Quay@enipetroleum.com Office: 907-865-3324 Cell: 907-230-3961 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. 6/29/2010 sifollE 6 a 0 {F SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Undefined Oil Pool, OP08-04 ENI US Operating Co. Inc. Permit No: 210-041 Surface Location: 3197' FSL, 1576' FEL, S5, T13N, R9E, UM Bottomhole Location: 106' FSL, 4267' FEL, S29, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. 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 thisZ Y day of April, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) EGE VEC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 4 ,M O PERMIT TO DRILL 20 MC 25.005 i, : ,1 ,,,■;t1;.,:100 la.Type of Work: lb.Proposed Well Class: Development-Oil El • Service- Winj ❑ Single Zone . pe '4I"'~ :; osed for Drill IS • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed `• as Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 ' OP08-04 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 10926 ' TVD: 3759 Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3197 FSL 1576 FEL S5 T13N R9E UM ADL 0373301,ADL 0355024,ADL 0390616 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1066 FSL 1663 FEL S32 T14N R9E UM ADL 417493 6/26/2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 106 FSL 4267 FEL S29 T14N R9E UM 1280 617' ri-c) `"L�t I.•Li`', 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 52.2 - 15.Distance to Nearest Well Open Surface:x- 516704 • y- 6036551 ' Zone- 4 GL Elevation above MSL: 12.2 ' to Same Pool: 2579' 4.7 0PO 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) i° ' Maximum Hole Angle: 90.79° degrees Downhole: 1620.72 • Surface: 1227.69 • 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 154 Surface Surface 154 154 pre-installed 674 TOTAL sx - 16" 13-3/8" 68 L-80 BTC 2309 Surface Surface 2349 + 2152 LEAD:443 sx 10.7 ppg ASL TAIL:231 sx 12.0 ppg DeepCrete 12.25" 9-5/8" 47 L-80 BTCM 4868 Surface Surface 4908 - 3625 ' 325 TOTAL sx 325 sx 12.5 ppg DeepCrete 8.5" 5.5" 17 L-80 DWC 6218 4708 3603 10926 - 3759 - 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 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ig Diverter Sketch 15I Seabed Report ❑ Drilling Fluid Program isi 20 AAC 25.050 requirements el 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Joseph Longo @ 907-865-3323 Printed Name Maurizio Grandi ' Title Well Operation Project Manager Signature A JAMA/WAP is.tAA/ Phone Date j q J I. O Commission Use Only Permit to Drill API Number: Permit A p See cover letter for other Number: �Lt q/C. 50-02'i._f.3(1241(Ye.-(-7 Date: � I� requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce oalbed methane,•=s hydrates,or gas contained in shales: Other: _)(3500 Sc, goO TS.7 ` Samples req'd: Yes❑ No Is Mud log req'd: Yes ❑ No 2 50 o p 5•:. A K h,�.. -5 f CAw.,J H2S measures: Yes❑ No[ Directional svy req'd: Yes Q No ❑ O APPROVED BY THE COMMISSION _a 1I Q DATE: y' ' ,COMMISSIONER Forrri 10-401 fl?,..' vise 7/2009) This permit is valid fo 74 months from the date of approval(20 AAC 25.005(g L(�S Ic,Submit in Dupli O • O RECEIVED STATE OF ALASKA APR 0 8 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Oil&Gas Cons.Conunission 20 AAC 25.005 Anchorage la.Type of Work: lb.Current Well Class: Exploratory ❑ Development Oil 0, 1c.Specify if well is proposed for: Drill 1151 ' Re-drill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates❑ Re-entry❑ Multiple Zone❑ Single Zone ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ENI US Operating Co Inc. Bond No. RLB0008627 OP08-04 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD:10,926' , ND:3,759' Nikaitchuq ' 4a. Location of Well(Governmental Section): 7.Property Designation: SHL:3197 FSL 1576 FEL S5 T13N R9E UM • ADL 0373301,ADL 0355024,ADL 0390. • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1066 FSL 1663 FEL S32 T14N R9E UM �S Acres in Proprty' e 417493 14.Distance to Nearest y: 7493 6/26/2010 Total Depth: BHL:106 FSL 4267 FEL S29 T14N R9E UM 280' 617 4b.Location of Well(State Base Plane CoNdiesl .=..Y =.�, _r- -„;,r, „?0,aQf . •'o• • 15.Distance to Nearest 12.2'MSL&52.2'RKB Surface: x-516704• y-6036550.67 • Zone-4 (Height ab••e GL): Well within Pool: 2579' 16.Deviated wells: Kickoff depth: 300 ft. . 17.M mum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90.79° deg aownhole:752 psi Surface:569 psi 18.Casing Program Specifications I Setting Depth Quantity of Cement Size t ts i' Top Bottom c.f.or sacks Hole Casing Weight Grade Coupling Lenkh - MD ND MD ND (including stage data) Driven 20" 178.89 X-65 Welded ( 1 ��Surface Surface 154 154 pre-installed lr /- ' 674 TOTAL sx 16" 13-3/8" 68 L-80 BT( / 214 Surface Surface 2349 • 2152 LEAD:443 sx 10.7 ppg ASL TAIL:231 sx 12.0 ppg DeepCrete 12.25" 9-5/8" 47 L-80 T 4868 Surface Surface 4908 3625 325 TOTAL sx •�� 325 sx 12.5 ppg DeepCrete 8.5" 5.5" 17 L;i DW 6218 4708 3603 10926 3759 Slotted Liner in Open Hole Y ,N / 1. 19. / -E- NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): C •al Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structur Surface Intermed to Produ on Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: Filing Fee ❑ BOP Sketcl❑✓ Drilling Program Time v.Depth PI❑ Shallow Hazard Analysis 0 Property Plat 0 Diverter SketcJ Seabed Repo Drilling Fluid ProgrL 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of mknowledge. Contact Joseph Longo @ 907-865-3323 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature ittb- ^i7 6414-,JIA&A" Phon 907-865-3320 Date 41 �l 4'D Commission Use Only 1 I Permit to Drill API Number:: Permit Approval See cover letter Number: 2"C(‘)(-77C, 50-(7261-2 .2V Zi- -0C'?'C Date: for other requirements �/ Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: LD Samples req'd: Yes r(110 � Mud log req'd: Yes ❑ No ❑ lYJ Other: H2S measures: Yes ❑Jo Directional svy req'd: Yes Ig No ❑ DATE: ORIGIN ARP i VED BY THE COMMISSION CO MISS aNER Form 1U-4U1 Kevlsed 1Z/2UUb !H\ L Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 eni petroleum Application for Permit to Drill Document Producer Well OP08-04 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(0 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Requirements of 20 MC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 MC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 MC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 MC 25.005(c)(5) 3 6. Casing and Cementing Program 3 Requirements of 20 MC 25.005(c)(6) 3 7. Diverter System Information 3 Requirements of 20 AAC 25.005(c)(7) 3 8. Drilling Fluid Program 3 Requirements of 20 MC 25.005(c)(8) 3 Surface Hole Mud Program(extended bentonite) 3 Intermediate Hole Mud Program(LSND) 3 Lateral Mud Program(MI VersaPro LS Mineral Oil Base) 3 9. Abnormally Pressured Formation Information 3 Requirements of 20 MC 25.005(c)(9) 3 10.Seismic Analysis 3 Requirements of 20 MC 25.005(c)(10) 3 11.Seabed Condition Analysis 3 Requirements of 20 AAC 25.005(c)(11) 3 12.Evidence of Bonding 3 Requirements of 20 MC 25.005(c)(12) 3 OP08-04 PERMIT Page 1 of 8 Printed:20-Apr-10 rot Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 em petroleum 13.Proposed Drilling Program 3 Requirements of 20 MC 25.005(c)(13) 3 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 3 Requirements of 20 MC 25.005(c)(14) 3 15.Attachments 3 Attachment 1 Directional Plan 3 Attachment 2 Drilling Hazards Summary 3 Attachment 3 BOP and Diverter Configuration 3 Attachment 4 Cement Loads and CemCADE Summary 3 Attachment 5 Well Schematic 3 Attachment 6 Formation Integrity And Leak Off Test Procedure 3 Attachment 7 Surface Platt 3 OP08-04 PERMIT Page 2 of 8 Printed:20-Apr-10 Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 em petroleum 1. Well Name Requirements of 20 MC 25.005(0 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. The well for which this Application is submitted will be designated as OP08-04. 2. Location Summary Requirements of 20 MC 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: Surface 3197 FSL 1576 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 52.2'AMSL Northings:6,036,551' Eastings: 516,704' Pad Elevation 12.2'AMSL Location: Top of Productive Interval "OA" Sand 1066 FSL 1663 FEL S32 T14N R9E UM Measured Depth, RKB: 4,918' ASP Zone 4 NAD 27 Coordinates Total Vertical Depth, RKB: 3,625' Northings:6,039,699' Eastings:516,600' Total Vertical Depth, SS: 3,573' Location: Total Depth 106 FSL 4267 FEL S29 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10,926' Northings:6,044,013' Eastings:513,974' Total Vertical Depth, RKB: 3,759' Total Vertical Depth, SS: 3,707' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(6); Requirements of 20 MC 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 we//bores 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. OP08-04 PERMIT Page 3 of 8 Printed:20-Apr-10 Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 eni petroleums 3. Blowout Prevention Equipment Information Requirements of 20 MC 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(POPE)as required by 20 MC 25.035,20 MC 25.036, or 10 AAC 25.037,as applicable,' Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 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; /62...o _ 'i SSx 3S 73'T✓t, The expected reservoir pressure in the Schrader Bluff sand is,,Z.5215-si, assuming a 0.455 psi/ft oil _/ 1.Zo•'o gradient. T" 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 1228 psi: MPSP = (3,573'TVD)(0.455 - 0.11 psi/ft) = 1228 psi - (B)data on potential gas zones; 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 MC 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(f) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 MC 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 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; OP08-04 PERMIT Page 4 of 8 Printed:20-Apr-10 ri* Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 • eni petroleum Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/7VD MD/TVD OD(in) (in) (lb/tt) Grade Connection (It) (ft) (ft) Cement Program 20 N/A 178.89 X-65 Welded 154 Surface 154'/ 154' pre-installed Surface/ 674 TOTAL sx 13-3/8 16" 68 L-80 BTC 2309' Surface 2349'/ 2152' LEAD:443 sx 10.7 ppg ASL TAIL:231 sx 12.0 ppg DeepCrete 9-5/8 12-1/4" 47 L-80 BTC-M 4868' Surface/ 4908'/ 3625' 325 TOTAL sx Surface 325 sx 12.5 ppg DeepCrete 5-1/2 8-1/2" 17 L-80 DWC 6218' 4708'/ 3603' 10926'/ 3759' Slotted Liner in Open Hole 7. Diverter System Information Requirements of 20 MC 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 10 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 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 MC 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 (seconds) 150 250 200 300 Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy(CP) 30 55 15 20 pH 9 9.5 9 9.5 API Filtrate NC 8 8 8 (cc/30 min)) OP08-04 PERMIT Page 5 of 8 Printed:20-Apr-10 VIE* Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 em petroleum Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 13-3/8" Csg Shoe to 9-5/8" Csg Point Value Value Density(ppg) 8.8 - 9.5 Density(ppq) 9.0 -9.3 Funnel Viscosity Plastic Viscostiy(CP) 15 -25 45 (seconds) - 60 Yield Point (lb/100 sf) 15 -20 Plastic Viscostiy 12 -18 (CP) HTHP Fluid loss (ml/30 min @ 200psi & 100°F <5.0 Yield Point 18-24 (lb/100 sf) Oil/Water Ratio 75/25 API Filtrate 4 - 6 Electrical Stability >600 (cc/30 min)) Chlorides(mg/I) <500 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 MC 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),' Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 MC 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 MC 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 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 MC 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 app//cation.• (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. OP08-04 PERMIT Page 6 of 8 Printed:20-Apr-10 Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 em petroleum 13.Proposed Drilling Program Requirements of 20 MC 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. 1. Move in/ rig up Nabors 245E. Install 21-1/4"Annular with 16"diverter line and function test. • 2. Spud and directionally drill 16"hole to casing point at +/- 2,349' MD/2,152'ND 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. Displace cement with mud. Perform top job • if required. 4. Remove diverter system, 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 8"directional drilling assembly with MWD, LWD and PWD. . 8. Drill out cement and 20'to 50' of new hole. Perform formation integrity test to leak off, recording . results. 9. Directionally drill to 9-5/8"casing point at 4,908' MD/3,625'ND. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams. Run and cement 9-5/8", 47# L80, BTC Mod casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 11. Install 9-5/8"packoff and test to 5000 psi. 12. Flush 13-3/8"x 9-5/8"annulus with water, followed by diesel. ' 13. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 14. 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. 15. Drill out cement and between 20'and 50' of new hole. Displace hole to lateral drilling OBM muds Perform formation integrity test, recording results. . 16. Directionally drill 8-1/2"hole to TD at +/- 10,926' MD/ 3,759'ND as per directional plan. Pull out of hole backreaming to the intermediate casing shoe. 17. PU and run 5-1/2"slotted liner to TD. 18. Land liner, set liner hanger with 200'Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 19. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 20. Nipple down BOP, nipple up tree and test. Pull BPV. ' 21. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 22. Set BPV and move rig off. OP08-04 PERMIT Page 7 of 8 Printed:20-Apr-10 VAIS Application for Permit to Drill,Well OP08-04 Revision No.0 Saved:20-Apr-10 t1' petroleum 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 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 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down our 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 in the OP26-DSPO2 Class 1 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 OP08-04 PERMIT Page 8 of 8 Printed:20-Apr-10 ve} M r 0p W W O) C`7OO W COIOMaT W r r ^ r r Cfl R N N O CO O Q 7 r r 010M ,70). M ^00000 M 0000 0 0 O p O O O 00) 0) 0) 0) CO E (0 r ^ r r N r r N r r r r r r r r W W W W co y 2 . . . . . . . . . .W W W CO CO W CO W W W CO CO W W Co _W _W CO CO_ CO R W "-',1, 10 ,n101.0 If) Cf) C C() Cn Cn C j M) LO C j L00004, In w o N C. 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O U) 0 h h N W h 0 _0 0) N v v 0 0) 0) a) = Co .- - O W W 0) 0) 0) 0) U) U) N N v O CD N N U) U) U) h W W 0) 0) O . M U) U) h M O O E.'.3 O .� W 0 0 0 W W W W W W W W W W 0 N v v v v v v v Ni v Ni U U) U D W h h CD D CD CD 0) o h h h h h h h h h h h h h h h o W W W W W W W W W W W W W W W W W W W W W W c aN6 v U) ,- N U) U) W W N M U) W W W 0 M CO 0) 0) 0 N M CD Cn 0) M CD W W 0) 0) 0 v U) U) U) O m Co W 0) 0) 0) 0) 0) 0) O O poop ,- ‘- ,- '- .- N N N N N N M M M M M (') C') v v v v v U) YG d 66666 66666 66666 66666 W (D W W W 66666 CD W W W (D 666 83 c 00000 00000 00000 00000 00000 00000 00000 000 00000 00000 00000 00000 00000 00000 00000 000 Co °o v v O v v 44464 v v v O v 44444 O v v v v v v v v O v v v (6 v 4406 J o p) N a w J J J J J J J J J J J J J J J J J J J J J _1 _1 _11 _1 J J Q' Q' w y C) i v O h U) i D) W N O ow h - . co Co U) 0) v U) M N- . 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Icy 1 1 11 1 1.V y Iy I; a i i 4 1 x I j♦Yi 1 1 1 1 1 W 6 m I W I I m 1 1 11 1 4 1 1 11 1 K Y I i ■ 1 ;1.C., 1l 1 1 II 1 0 4 1 ly ;I p IV 1 1 1 1 1 0. e 1 1 1 ;II 1g 1 1 11 1 0 €i O ii 1 4 a ♦ I 4..14.4 O C'i I 4 IN I ii 1 1 1 1 1 1 E IN iN 1 1 i 1 1 1 11 1 €- g W P; 1 1 1 j i ! i j !! 1 i i 1 1 i 1 1 1 II 1 ■ i i ■ :1 ■ I ■ i i i 1 i i i :j 1 i i ij i 0 0 0 0 0 o o O O o 0 0 0 N CO Nr (4)000I.:(ui)I.=eleoS aAl E Enii P e troIleum Schiumberger WELL I FIELD STRl1CTURE OP08-04 (P2b) Nikaitchuq Oliktok Point Magnetic Parameters Surface Location NAD27 Alaska Stale Planes.Zone 04.US Feel MiscelPneow Model 6000 2009 Dip 60955 Data: Jona30,2010 Lek 04703039.762 N+U0g. 6036550 67 MIS Grit Cony+012885603' I Slot OP08 ND Ref Rotary Table 152.208 above MSL Mag Dec +21650' FS: 57878.1 nT Lon W1495(47925 Pasting. 51670374(WS Scale Fact.0.9909003169 Plan. 0170844(P2b) Spry Date -4000 -3000 -2000 -1000 0 1000 Illemeellinrep83T58g5 EN!Lease Line pGA}g ••.8-04(P2b) TO/5-1/2r"Lnr End Cry OP PO4 Tgt 10 End Cry Cry 4/100 7000 •- ` OP PO4 Tgt 11 7000 Cry 4/100 End Cry OP PO4 Tgt 8 Cry 4/100 End Cry End Cry OP PO4 Tgt 9 • Cry 4/100 OP PO4 Tgt 7 • 6000 coo 4/10. 6000 End ere OP 1404 Tgt Cry 4/100 . End Cry OP PO4 Tgt 5 • - Cry 4/100 5000 5000 End Cry • A A . ', OP PO4 Tgt 4 Z '111, �, Cry 4/100' End Cry OP PO4 Tgt 3 ° 4000 -C1rv4/100 4000 End Cry • OP PO4 Tgt 2 I I 02 Cry 6/100 co U (n End Cry OP PO4 Tgt 1 v 3000 Cn/4/100 - 3000 v V Cry 4/100 95/8"Cs. rR End Cry PO4 Heel .,1 End Cry NI`ea�e0Line 6//814 2000 •l4e$.§.' i i i i LU Cry 4/100 1000 1000 • 13-3/8"Csg • r End Cry Bld 3.25/100 Bld 3.25/100 0 RTE Bld 2/100 0 KOP Bid 1.5/100 -4000 -3000 -2000 -1000 0 1000 «< W Scale= 1(in):1000(ft) E >>> Schlumberger TRAVELING CYLINDFR PLO T Client: ENI NoGo Region EOU's based on: Well: OP08-04 Oriented EOU Dimension Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule Date: March 11,2010 used:Minor Risk-Separation Factor North 350 0 10 340 20 330 .03(P1) .-• P07(30) 140 320 i ASO 0100.4740- � 40 .-.� 120 ► 310. �4 4 � � 50 4,,,T` V�I�ATP/ 100 (��i 300 691,04: ' ' 80 t$14.V 60 mow' ■ ►4 290 .0.,�� �•a. 60 r�'_+ 70 NitdiwkwEso,„:11.-.:Nr■*1'OP/ Igivike."...ttt -a;:—.. fir,44 , �.� � `fir Olikto Point llP # ■�4 i;v6. ■ 270 '�Y t, *. �,l •, �.- �4 ,'-"'Akil 1 ■, ' .;0741''' `q'��Y 4 •liktok Point 1-1A-106 F X44•$ 260 � • !`i i 1 `>te'/ ' ,• 100 • I ; I ..1c.'_r, , ��'.„.„._.441,00.0:P0036:105, _ (P3) •P mr ��-�• - ,'"y�� . , . PPOSPB2 250 �� I 4', 1.�\ ,\ 110 �° �. ��: /,� \ OP07-104(P1) zao :,.4. ,:C3S �� 1 / 120 �! N.`r`� OP05-P06(P3) %v�WW02R63)(P1) 4111� 230 , 130 220 � � , 140 210 �� 150 200 - 60P 3-VWV02FTB5)(P1) 190 180 170 Well Ticks Type: MD on OP08-04(P2b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP08-04 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule Date: March 11,2010 used:Minor Risk-Separation Factor North 350 0 10 340 30 20 330 30 320 ,9 P09-S 0 `. 25 40 15 1 310 ' TAt 50 300 , /E:Iti -- 11 60 ■ 300`\ ` 290 , ‘440,1k 4�00 .*ii 70 �'�:-P09(P1) �� -�► •P06-105(P3) 280 ItirgallillP. �, �1� 80 �,, .270 / M., �_ ` 190 260 • �, o 4100 250 - ,�1 �� � 0 \ 0 300 ,� i \L.. , gP07-104(P1) 240 ' Apiroo ow 12 0 ►� 23°\11-101 (P�1 130 I 220 140 210 150 200 160 190 180 170 Well Ticks Type: MD on OP08-04(P2b) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=10.00 ft ANTICOLLISION SUMMARY REPORT Client: ENI Slot: OP08 Field: Nikaitchuq Well: OP08-PO4 Structure: Oliktok Point Borehole: OP08-PO4 Subject Trajectory:OP08-PO4(P2b)(DEF PLN) Rpt Date: March 11,2010 Analysis Method: Normal Plane Depth Interval: Every 5.00ft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Mag Model: BGGM 2009 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct-Ct(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major Nikaitchuq 1(DEF SW) PASS 18547.12 18544.611 N/A1 16.26 16.26 MinPt-O-SF 18549.86 18544.76 10686.21 374.98 374.97 MinPt-O-SF Nikaitchuq 2(DEF SVY) PASS 19044.64 19042.13 N/A 12.25 12.25 Surface 15199.00 15114.47 277.87 8382.95 3724.87 MinPt-C1Ct 15199.00 15114.47 277.87 8382.99 3724.87 MinPt-O-ADP 15222.63 15137.901 277.66 8391.66 3725.01 MinPt-O-SF 15709.38 15623.051 281.031 8445.34 3726.04 MinPt-O-SF 15985.22 15898.531 284.771 8471.13 3726.63 MinPt-O-SF 16063.37 15976.221 284.611 8478.47 3726.80 MinPI-O-SF 19588.2511 19423.71) 181.31 8671.50 3733.26 MinPts Nikaitchuq 3(DEF SW PASS 18474.9011 18472.36 660171.34 50.80 50.80 MinPt-CtCt 18475.7511 18471.1711 13330.95 255.80 255.80 MinPt-O-ADP 18476.27 18471.2311 10899.5211 301.12 301.12 MinPt-O-SF 18475.6711 18470.7511 11469.57 321.01 321.00 MinPt-O-ADP 18475.6611 18470.76 11513.44 323.66 323.66 MinPt-CtCt 13997.0911 13877.6811 179.56 9380.15 3750.32 MinPts 13914.40 13791.551 173.391 9860.80 3768.44 MinPt-O-SF 13715.92 13592.821 170.561 10420.04 3763.94 MinPt-O-SF 1 13581.121 13450.8914611 10926.15 3759.01 MinPts Nikaitchuq 3PB1(DEF SVY PASS 18474.90 18472.36 660171.34 50.80 50.80 MinPt-CtCt 18475.751 18471.1711 13330.95 255.80 255.80 MinPt-O-ADP 18476.27 18471.231 10899.5211 301.12 301.12 MinPt-O-SF 18475.67 18470.75 11469.57 321.01 321.00 MinPt-O-ADP 11 18475.661 18470.76 11513.44 323.66 323.66 MinPt-CtCt 18477.57 18472.47 Er= 374.04 374.04 MinPt-O-SF Nikaitchuq 3PB2(DEF SVY) PASS 11 18474.9011 18472.36 660171.34 50.80 50.80 MinPt-CtCt 18475.7511 18471.1711 13330.95 255.80 255.80 MinPt-O-ADP 18476.27 18471.2311 10899.5211 301.12 301.12 MinPt-O-SF 18475.6711 18470.7511 11469.57 321.01 321.00 MinPt-O-ADP II 18475.661 18470.76 11513.44 323.66 323.66 MinPt-CtCt 13392.05 13264.89 161.11 10926.15 3759.01 MinPts 13392.05 13264.89 161.11 10926.15 3759.01 MinPt-O-SF Nikaitchuq 3PB3(DEF SVY PASS 18474.90 18472.36 660171.34 50.80 50.80 MinPt-CtCt 18475.751 18471.1711 13330.95 255.80 255.80 MinPt-O-ADP 18476.27 18471.231 10899.5211 301.12 301.12 MinPt-O-SE 18475.67 18470.75 11469.57 321.01 321.00 MinPt-O-ADP 11 18475.661 18470.76 11513.44 323.66 323.66 MinPt-CtCt 18477.57 18472.47 374.04 374.04 MinPt-O-SF Nikaitchuq 4(DEF SVY) PASS 18514.42 18511.911 N/A1 20.94 20.94 MinPt-O-SF 18514.42 18511.87 652389.38 50.94 50.94 MinPt-CtCt 18515.051 18511.4411 25108.58 175.91 175.91 MinPt-O-ADP 11 18515.561 18510.72 11866.13 335.57 335.57 MinPt-CtCt 18515.57 18510.72 11816.05 338.22 338.22 MinPt-O-ADP 18517.08 18511.98 10706.68 374.02 374.02 MinPt-O-SF Nikaitchuq 4PB1(DEF SVY) PASS 18514.42 18511.911 N/A1 20.94 20.94 MinPt-O-SF 18514.42 18511.87 652389.38 50.94 50.94 MinPt-CtCt 18515.051 18511.4411 25108.62 175.91 175.91 MinPt-O-ADP 11 18515.561 18510.72 11866.13 335.57 335.57 MinPt-CtCt 18515.57 18510.72 11816.05 338.22 338.22 MinPt-O-ADP 18517.08 18511.98 10706.68 374.02 374.02 MinPt-O-SF Version DO 4.0(doc40x_100)SP 2.1 -ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 1 of 9 Offset Trajectory Sep. Blow Sep. Subject Trajectory Separation F Alert Status Ct-Ct(ft)I Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor 1 Major Kigun 1(DEF SW) PASS 17140.14 17137.631 N/A1 17.17 17.17 MinPt-O-SF 17140.09 17136.79 32365.38 159.93 159.93 MinPt-CtCt 17140.241 17136.6611 23843.06 197.17 197.17 MinPt-0-ADP 11 17140.661 17136.00 11933.20 336.67 336.67 MinPt-CtCt 17140.67 17135.99 11785.50 340.23 340.23 MinPt-O-ADP 17143.31 17138.17 9768.26 400.57 400.56 MinPt-O-SF Kigun 1 PB1(DEF SW) PASS 17140.14 17137.631 N/A1 17.17 17.17 MinPt-O-SF 17140.09 17136.79 32365.38 159.93 159.93 MinPt-CtCt 17140.241 17136.6611 23843.06 197.17 197.17 MinPt-O-ADP 11 17140.661 17136.00 11933.20 336.67 336.67 MinPt-CtCt 17140.6 17135.99 11785.50 340.23 340.23 MinPt-O-ADP 17143.31 17138.17 9768.26 400.57 400.56 MinPt-O-SF Tuvaaq ST 1(DEF SW) PASS 17140.14 17137.631 N/A1 17.17 17.17 MinPt-O-SF 17140.09 17136.79 32365.39 159.93 159.93 MinPt-CtCt 17140.241 17136.66i1 23843.06 197.17 197.17 MinPt-O-ADP 1 17140.661 17136.00 11933.20 336.67 336.67 MinPt-CtCt 17140.67' 17135.99 11785.50 340.23 340.23 MinPt-O-ADP 17143.31 17138.17 9768.26 400.57 400.56 MinPt-O-SF Oliktok Point I-1(DEF SW PASS 64.7 62.23 13414.63 39.20 39.20 MinPt-CtCt 65.0 62.0 168.81 119.20 119.20 MinPt-O-ADP 144.53 134.10 26.841 849.44 846.46 MinPt-O-SF 166.26 154.661 27.021 914.91 910.46 MinPt-O-SF 6286.03 6179.001 90.171 5386.15 3623.09 MinPt-O-SF 6301.6111 6154.6111 65.391 5492.97 3621.62 MinPts Oliktok Point I-1A-106(P3 DEF PLN) PASS 64.7 62.23 13414.63 39.20 39.20 MinPt-CtCt 65.0 62.02 MinPt-O-SF 119.20 119.20 MinPt-O-ADP 144.53 134.10 26.841 849.44 846.46 MinPt-OF 166.26 154.671 27.021 914.91 910.46 MinPt-O-SF 6303.6511 6201.0411 94.421 4933.83 3626.09 MinPts 1 6303.651 6201.04 94.42 4934.81 3626.14 MinPt-CtCt 1 6304.851 6184.93 80.51 6377.55 3644.91 MinPt-CtCt 1 6304.491 6174.33 74.05 6783.06 3662.54 MinPt-CtCt 6305.0111 6173.8611 73.49 6799.76 3663.27 MinPt-O-ADP 6328.02 6190.531 70.291 6895.64 3667.98 MinPt-O-SF 6357.19 6217.301 69.381 6950.77 3670.95 MinPt-O-SF 6446.79 6294.611 64.581 7301.70 3690.91 MinPt-O-SF 6835.05 6654.191 57.461 7618.98 3713.52 MinPt-O-SF 7940.86 7712.101 52.631 8179.00 3722.92 MinPt-O-SF 8060.37 7829.341 52.891 8207.25 3723.02 MinPt-O-SF 8674.70 8428.41 53.36 8331.95 3724.12 TD Oliktok Point 1-2(DEF SW) PASS 56.70 54.20 11682.38 38.55 38.55 MinPt-CtCt 39.3 30.34 8.51 703.88 702.77 MinPt-CtCt 39.40 30.28 8.36 714.69 713.49 MinPt-O-ADP 40.37 30.93 8.181 744.26 742.76 MinPt-O-SF 3912.62 3799.521 53.031 4907.27 3624.62 MinPt-O-SF 4947.87 4810.931 55.181 5852.44 3616.65 MinPt-O-SF 5336.11 5186.051 54.221 6381.15 3645.10 MinPt-O-SF II 5255.6611 5087.6711 47.61 7003.99 3673.93 MinPts 4886.28 4699.501E1111I 8249.55 3723.28 MinPt-O-SF 4732.9011 4565.0211 42.90 8716.56 3735.25 MinPt-O-ADP 4736.33 4564.1111 41.84i1 8857.66 3741.83 MinPt-O-SF 1 4735.011 4565.28 42.45 8902.74 3743.56 MinPt-CtCt 4735.43 4567.0111 42.791 8924.38 3744.14 MinPt-O-SF 1 4594.1011 4379.2611 32.441 10419.37 3763.94 MinPts 1 4447.5411 4216.7011 29.201 10926.15 3759.01 MinPts 4447.55 4216.70 29.20 10926.15 3759.01 TD OP03-P05(DEF SW) PASS 48.10 45.51 698.89 65.88 65.88 MinPt-CtCt 1 48.211 44.46 54.85 244.00 244.00 MinPt-CtCt 48.5.=mg 38.47 324.13 324.13 MinPt-O-ADP 98.28 84.231 12.441 1089.43 1078.09 MinPt-O-SE 103.09 88.45 12.44 1113.64 1100.94 MinPt-O-SF II 2579.8211 2492.14 45.39 4958.81 3627.17 MinPt-CtCt 2579.8511 2492.10i1 45.35 4970.74 3627.53 MinPI-0-ADP II 2517.9911 2418.8911 39.06 6428.21 3647.18 MinPt-O-ADP 2560.88 2454.651 37.001 6840.95 3665.20 MinPt-O-SF 2698.17 2583.631 36.091 7306.04 3691.17 MinPt-O-SF Version DO 4.0(doc40x_100)SP 2.1 -ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 2 of 9 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation i Jr Alert Status Ct-Ct(ft)I Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor I Major 2811.07 2694.39 36.90 7521.17 3706.65 MinPt-O-SF 3444.70 3319.581 42.111 8161.25 3722.88 MinPt-O-SF 4307.5211 4133.2311 37.591 8462.52 3726.42 MinPts OP03-P05PB1(DEF SW PASS 48.10 45.51 698.89 65.88 65.88 MinPt-CtCt 1 48.211 44.46 54.85 244.00 244.00 MinPt-CtCt 48.5 MIIMFEJ 38.47 324.13 324.13 MinPt-O-ADP 98.28 84.23 1089.43 1078.09 MinPt-O-SF 103.09 88.45 12.44 1113.64 1100.94 MinPt-O-SF 2645.6711 2419.431 17.721 4937.91 3626.30 MinPts OP03-P05PB2(DEF SVY PASS 48.10 45.51 698.89 65.88 65.88 MinPt-CtCt 1 48.211 44.46 54.85 244.00 244.00 MinPt-CtCt 48.52 MUM 38.47 324.13 324.13 MinPt-O-ADP 98.28 84.231 12.441 1089.43 1078.09 MinPt-O-SF 103.09 88.45 12.44 1113.64 1100.94 MinPt-O-SF 11 2579.8211 2492.14 45.39 4958.81 3627.17 MinPt-CtCt 2579.8511 2492.1011 45.35 4970.74 3627.53 MinPt-O-ADP 11 2517.8111 2419.04 39.19 6407.50 3646.28 MinPt-CtCt 2517.9911 2418.8911 39.06 6428.21 3647.18 MinPt-O-ADP 2560.88 2454.651 37.001 6840.95 3665.20 MinPt-O-SF 2698.17 2583.631 36.091 7306.04 3691.17 MinPt-O-SF 2811.07 2694.401 36.901 7521.17 3706.65 MinPt-O-SF 3001.6611 2812.8211 24.141 7740.64 3719.36 MinPts OPO4-P07(P8)(DEF PLN PASS 40.19 35.49 25.69 299.00 299.00 MinPt-CtCt 40.64 34.1511 14.32 479.98 479.90 MinPt-O-ADP 54.22 42.78 8.68 812.46 810.11 MinPt-O-SF 1089.85 1050.64 44.421 4926.95 3625.72 MinPt-O-SF 11 465.3111 348.23 6.06 7387.21 3696.36 MinPt-CtCt 467.8511 345.391 5.82 7450.51 3701.01 MinPt-O-ADP 494.79 358.01 5.50 7631.46 3714.26 MinPt-O-SF 3561.30 3404.701 34.641 10066.80 3767.90 MinPt-O-SF 3591.98 3434.091 34.651 10112.42 3767.39 MinPt-O-SF 3731.47 3567.361 34.611 10319.78 3765.06 MinPt-O-SF 3898.35 3727.781 34.771 10561.99 3762.55 MinPt-O-SF OP05 PO6(P3)(DEF PLN PASS 31.9 26.26 13.90 401.51 401.50 MinPt-CtCt 32.0 26.16 13.12 440.49 440.46 MinPt-0-ADP 34.55 28.1 12.241 535.47 535.28 MinPt-O-SF 4198.66 4135.191 103.231 3446.41 3055.30 MinPt-O-SF 1 5103.061 5001.561 77.281 4930.80 3625.93 MinPts 1 5104.2611 4986.03 66.13 6377.79 3644.93 MinPt-CtCt 1 5103.891 4975.66 60.86 6783.07 3662.54 MinPt-CtCt 5104.2111 4975.331 60.55 6797.32 3663.16 MinPt-0-ADP 5106.93 4976.75 59.971 6827.16 3664.54 MinPt-O-SF 5152.65 5017.10 58.061 6958.48 3671.37 MinPt-O-SF 5770.27 5591.94 49.211 7728.51 3718.92 MinPt-O-SF 6021.91 5835.30 49.041 7833.68 3721.78 MinPt-O-SF 6206.18 6015.70 49.501 7898.57 3722.42 MinPt-O-SF 6461.10 6259.151 48.571 8161.79 3722.88 MinPt-O-SF 7592.76 7367.40 51.09 8419.68 3725.51 TD OP06-105(P3)(DEF PLN PASS ® 16.42 7.06 525.76 525.60 MinPt-CtCt 24.36 15.30 5.00 711.12 709.95 5.00 Enter Alert 26.38 14.90 3.99 856.62 853.50 MinPt-O-ADP 29.28 16.21 3.80 936.92 931.86 MinPt-O-SF 60.55 40.50 4.96 1174.60 1157.97 5.00 Exit Alert 3706.15 3608.6211 3854.4311 3745.2511 54.161 SSF 61 5872.94 3616.50 MinPts 1 3854.631 3740.56 51.79 6376.53 3644.86 MinPt-CtCt 1 3854.261 3732.53 48.46 6783.62 3662.56 MinPt-CtCt 3854.2811 3732.5111 48.44 6787.58 3662.73 MinPt-O-ADP 3902.88 3778.351 47.941 6978.49 3672.49 MinPt-O-SE 4327.47 4180.801 45.001 7681.49 3716.90 MinPt-O-SF 4992.91 4825.351 45.351 8162.03 3722.88 MinPt-O-SF 6112.20 5927.51 50.30 8461.41 3726.40 TD OP07-104(P1)(DEF PLN) PASS 8.20 3.98 4.97 250.00 250.00 5.00 Enter Alert 118 1.84 2.35 433.10 433.07 MinPt-CtCt 7.6 1.76 2.28 455.07 455.03 MinPt-O-ADP 7.78 1.78 2.26 470.07 470.00 MinPt-O-SF 25.55 16.13 4.99 758.74 757.09 5.00 Exit Alert 1306.711 1215.801 22.13 4917.42 3625.19 MinPt-O-ADP Version DO 4.0(doc40x_100)SP 2.1-ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 3 of 9 Offset Trajectory Sep. Blow Sep. Subject Trajectory Separation I. Alert Status Ct-Ct(ft) Dev.(ft) Fact. MD(ft) I ND(ft) Alert I Minor I Major 1306.75 1215.82 22.13 4922.41 3625.47 MinPt-O-SF 1310.11 1213.121 20.76 5733.08 3618.30 MinPt-O-ADP 1310.64 1212.071 20.42 5874.13 3616.50 MinPt-O-ADP 11 1310.571 1204.13 18.88 6367.46 3644.34 MinPt-CtCt 1311.13 1195.9511 17.42i1 6781.16 3662.45 MinPts 1311.38 1196.0711 17.40 6797.23 3663.16 MinPt-O-ADP 1328.22 1210.181 17.211 6938.19 3670.26 MinPt-O-SF 1392.64 1270.451 17.421 7295.45 3690.55 MinPt-O-SF 1482.97 1356.561 17.921 7521.09 3706.65 MinPt-O-SF 3980.02 3836.78 42.39 8906.39 3743.67 TD OP09-S03(P1)(DEF PLN) PASS 7.81 3.67 4.85 240.00 240.00 5.00 Enter Alert i 7.811 3.09 3.59 300.00 300.00 MinPt-CtCt 7.7 1.12 1.91 524.75 524.59 MinPt-CtCt 7.89 1.0 1.85 564.71 564.43 MinPt-O-ADP 7.98 1.03 1.8 574.70 574.38 MinPt-O-SF 30.77 19.72 4.96 900.32 896.24 5.00 Exit Alert 1016.04 984.38[ 52.131 3030.79 2717.85 MinPt-O-SF 127628 1233.99[ 48.02) 4934.34 3626.12 MinPt-O-SF 11 323.5311- 237.56 5.77 8935.68 3744.39 MinPt-CtCt 329.921 IMMO I 5.10 8990.98 3745.19 MinPt-O-ADP 333.25 231.52 5.00 9003.84 3745.36 5.00 Enter Alert 366.31 248.79[-mow 9080.97 3746.38 MinPt-O-SF 427.22 297.01 4.99 9170.96 3747.56 5.00 Exit Alert 1690.97 1499.00®] 10926.15 3759.01 MinPt-O-SF OP1 O-P09(P1)(DEF PLN PASS 10.92 8.55 316.85 316.85 MinPt-CtCt 16.021 10.561 6.85 394.83 394.82 MinPt-O-ADP 16.10 10.56 6.71 404.81 404.79 MinPt-O-ADP 20.71 13.401 5.68) 574.44 574.12 MinPt-O-SF 23.20 15.231 5.681 619.35 618.83 MinPt-O-SF 1584.3111 1523.290 40.54 4917.45 3625.19 MinPt-O-ADP 11 1578.3811 1509.24 35.47 5356.42 3623.50 MinPt-CtCt 1581.761 1506.261 32.45 5605.14 3620.07 MinPt-O-ADP 1729.13 L 1614.181 23.03 7004.90 3673.98 MinPt-O-ADP 1681.75 1552.85111 8158.49 3722.87 MinPt-O-SF 326.66 226.72 4.99 10805.68 3760.18 5.00 Enter Alert 11 303.301 190.65 MME 10926.15 3759.01 MinPts OP11-101(P1)(DEF PLN PASS 23.80 19.09 14.45 300.00 300.00 MinPt-CtCt 24.24 18.68 10.64 384.74 384.74 MinPt-O-ADP 30.71 23.101 8.27 583.55 583.20 MinPt-O-SF 32.75 24.761 8.27 618.25 617.74 MinPt-O-SF 60.56 48.491 9.10 908.31 904.04 MinPt-O-SF 110.13 90.071 9.19 1201.32 1182.73 MinPt-O-SF 1339.71 1234.421 19.51 5357.37 3623.48 MinPt-O-SF 1600.80 1485.211 21.20 6374.98 3644.77 MinPt-0-SF 1912.37 1778.901 21.87 7709.24 3718.14 MinPt-O-SF 1921.24 1785.041 21.531 8165.14 3722.88 MinPt-O-SF 1920.501 1784.81 21.60 8195.62 3722.97 MinPt-O-ADP 1 1919.5411 1785.87 21.92 8287.46 3723.61 MinPt-CtCt 1 1343.5911 1169.6411 11.731 10926.15 3759.01 MinPts OP12-P01(P1)(DEF PLN PASS 31.80 27.09 19.89 300.00 300.00 MinPt-CtCt 31.9 26.9 17.29 339.85 339.85 MinPt-O-ADP 43.23 35.90 12.651 593.20 592.81 MinPt-O-SF 49.43 41.30 12.491 657.48 656.73 MinPt-O-SF 59.64 50.28 12.501 74125 739.78 MinPt-O-SF 72.24 61.40 12.551 824.50 821.96 MinPt-O-SF 95.74 82.18 12.641 945.42 940.10 MinPt-O-SF 125.22 108.14 12.631 1064.73 1054.67 MinPt-O-SF 152.94 132.45 12.541 1158.83 1143.28 MinPt-O-SF 2419.34 2317.82 36.611 4905.97 3624.55 MinPt-O-SF 3618.73 3498.05 45.901 6381.29 3645.11 MinPt-O-SF 3583.43 3441.00 38.391 7897.17 3722.41 MinPt-O-SF 3605.23 3458.60 37.501 8164.48 3722.88 MinPt-O-SF 3586.9211 3442.641 37.92 8335.43 3724.17 MinPt-0-ADP 1 3586.7511 3442.81 38.01 8352.30 3724.40 MinPt-CtCt I 3014.9811 2832.821L 25.1511 10926.15 3759.01 MinPts OP13-103(P1)(DEF PLN PASS 55.7 51.07 36.18 300.00 300.00 MinPt-CtCt 56.16 50.6 26.92 379.46 379.46 MinPt-O-ADP 100.79 89.721 17.201 869.38 866.01 MinPt-O-SF 122.03 108.941 16.931 968.64 962.56 MinPt-O-SF Version DO 4.0(doc40x_100)SP 2.1-ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 4 of 9 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation L it Alert Status Ct-Ct(ft)I Dev.(ft) Fact. MD(ft) I TVD(ft)I Alert I Minor I Major 190.15 169.90 15.86 1202.97 1184.24 MinPt-O-SF 2947.22 2857.59 1 50.701 4920.88 3625.38 MinPt-O-SF 3658.25 3542.101 48.251 5853.82 3616.63 MinPt-O-SF 4077.99 3921.881 39.801 7744.41 3719.49 MinPt-O-SF 4034.41 3875.48J 38.661 8163.01 3722.88 MinPt-O-SF 4001.0311 3849.4111 40.22 8376.87 3724.77 MinPt-O-ADP 1 4000.2311 3850.24 40.66 8417.86 3725.48 MinPt-CtCt 1 3534.7611 3332.9011 26.5811 10926.15 3759.01 MinPts OP14-108(P1)(DEF PLN PASS 63.77 59.07 41.63 300.00 300.00 MinPt-CtCt 64.16 58.67 30.96 379.39 379.38 MinPt-O-ADP 130.74 117.56 18.00 972.49 96629 MinPt-O-SF 205.87 185.75 17.32 1199.10 1180.67 MinPt-O-SF 4538.13 4437.04 69.01 4916.03 3625.11 MinPt-O-SF 4609.78 4506.28 68.43 5028.17 3627.88 MinPt-O-SF 5137.24 5023.64 69.32 5370.47 3623.31 MinPt-O-SF 5892.16 5762.32 69.38 5851.96 3616.66 MinPt-O-SF 6766.80 6618.72 69.70 6380.58 3645.07 MinPt-O-SF 6775.07 6626.84 69.71 6384.21 3645.25 MinPt-O-SF 5335.69 5175.58 50.76 7918.03 3722.47 MinPt-O-SF 5379.55 5213.07 49.191 8196.86 3722.98 MinPt-O-SF 5081.92 4936.94 53.481 8857.58 3741.83 MinPt-O-SF 5078.7811 4935.901 54.24 8892.62 3743.23 MinPt-O-ADP 1 5077.6411 4937.04 55.12 8929.32 3744.26 MinPt-CtCt 1 5047.6511 4837.301 36.411 10926.15 3759.01 MinPts OP15-P08(P2)(DEF PLN PASS 71.82 67.11 47.09 300.00 300.00 Min Pt-CtCt 72.04 66.76 37.58 359.49 359.49 MinPt-O-ADP 266.66 244.45 20.101 1198.14 1179.78 MinPt-O-SF 5367.89 5260.59 76.801 4917.00 3625.16 MinPt-O-SF 5477.37 5367.43 76.431 5028.01 3627.88 MinPt-O-SF 6120.59 5999.85 77.621 5370.68 3623.31 MinPt-O-SF 7037.41 6899.41 77.881 5852.38 3616.65 MinPt-O-SF 7969.25 7814.20 78.341 6319.67 3641.38 MinPt-O-SF 8077.81 7920.39 78.191 6383.16 3645.20 MinPt-O-SF 8674.28 8506.89 78.891 6618.91 3655.43 MinPt-O-SF 5837.14 5666.75 52.131 8218.17 3723.08 MinPt-O-SF 5428.12 5279.65 55.761 8856.12 3741.76 MinPt-O-SF 5514.79 5300.26 39.001 10926.15 3759.01 MinPt-O-SF OP16-P03(P2)(DEF PLN PASS 79.81 75.10 52.51 300.00 300.00 MinPt-CtCt 79.90 74.99 48.16 324.77 324.77 MinPt-O-ADP 272.45 251.50 21.951 1199.26 1180.82 MinPt-O-SF 6117.34 6004.751 83.321 4910.25 3624.79 MinPt-O-SF 6130.54 6017.71 1 83.321 4916.46 3625.13 MinPt-O-SF 7454.46 7323.461 86.991 5445.97 3622.27 MinPt-O-SF 7626.94 7445.211 63.811 7511.20 3705.85 MinPt-O-SF ! 6149.96 5978.311 54.521 8248.64 3723.27 MinPt-O-SF 5663.29 5514.231 57.941 8857.15 3741.81 MinPt-O-SF 5850.37 5633.831 40.981 10926.15 3759.01 MinPt-O-SF OP17-P02(P3)(DEF PLN PASS 87.79 83.09 58.07 299.00 299.00 MinPt-CtCt 87.89 82.99 53.41 323.75 323.75 MinPt-O-ADP 297.12 276.71 24.671 1198.51 1180.13 MinPt-0-SF 5825.66 5709.251 76.68 5052.93 3627.55 MinPt-O-SF 6498.06 6373.551 79.86 5853.11 3616.64 MinPt-O-SF 6203.67 6030.341 54.45 7822.75 3721.59 MinPt-O-SF 6170.76 5992.841 52.74 8162.40 3722.88 MinPt-O-SF 5808.88 5655.111 57.58 8857.52 3741.82 MinPt-O-SF 5692.69 5474.261 39.53 10926.15 3759.01 MinPts OP18-107(P2)(DEF PLN PASS 95.80 91.57 81.04 250.00 250.00 MinPt-C1Ct 95.93 91.4 70.70 285.00 285.00 MinPt-O-ADP 353.48 333.21 29.641 1122.76 1109.51 MinPt-O-SF 7607.20 7504.31 113.63 4618.66 3586.71 MinPt-O-SF 8496.86 8386.92 118.59 4712.79 3603.82 MinPt-O-SF 10811.09 10691.53 138.50 4907.55 3624.64 MinPt-O-SF 11489.48 11365.25 141.54 5368.78 3623.33 MinPt-O-SF 12193.43 12060.74 140.45 5853.94 3616.63 MinPt-O-SF 9980.13 9812.20 90.47 7469.23 3702.49 MinPt-O-SF 6718.09 6561.91 65.55 8347.53 3724.33 MinPt-O-SF 6705.87 6549.98 65.55 8353.34 3724.41 MinPt-O-SF 6557.99 6355.37 49.14 10926.15 3759.01 MinPt-O-SF OP19-ENI#1(P1)(PLAN) PASS Version DO 4.0(doc40x_100)SP 2.1-ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 5 of 9 Offset Trajectory Sep. Jlow Sep. Subject Trajectory Separation F r Alert Status Ct-Ct(ft)1 Dev.(ft) Fact. MD(ft) 1 ND(ft)I Alert I Minor I Major 111.81 109.31 23559.59 0.20 0.20 Surface 111.81 107.00 70.98 295.20 295.20 MinPt-CtCt 112.19 106.56 52.58 379.14 379.13 MinPt-O-ADP 114.091 106.831 35.19 565.23 564.94 MinPt-O-ADP 154.49 141.07 20.89 1006.01 998.56 MinPt-O-SF 1319.02 1278.051 51.341 3256.58 2905.12 MinPt-O-SF 3121.96 3045.821 63.541 4405.83 3531.38 MinPt-O-SF 6399.23 6283.05 84.41 4990.41 3627.91 TD OP20-ENI#9(P1)(PLAN) PASS 119.84 117.33 25289.55 0.20 0.20 Surface 119.84 115.03 76.19 295.20 295.20 MinPt-CtCt 120.22 114.59 56.44 379.07 379.06 MinPt-O-ADP 168.75 156.57® 952.56 947.02 MinPt-O-SF 177.51 164.81 25.74 982.22 975.67 MinPt-O-SF 2239.48 2198.58 1-17351 3259.06 2907.18 MinPt-O-SF 6804.19 6705.00 105.52 4094.36 3429.85 TD OP21-ENI#10(P1)(PLA� PASS 127.79 122.93 79.75 300.00 300.00 MinPt-CtCt 127.95 122.80 70.88 354.17 354.17 MinPt-O-ADP 194.20 183.22 33.931 971.74 965.56 MinPt-O-SF 1629.21 1599.441 89.481 3257.92 2906.24 MinPt-O-SF 5688.32 5609.301 111.461 4122.93 3440.64 MinPt-O-SF OP22-ENI#1(P2)(DEF PLN PASS ® 131.07 90.74 299.00 299.00 MinPt-CtCt 136.181 130.661 66.37 382.66 382.65 MinPt-O-ADP 137.341 130.851 50.63 495.10 495.00 MinPt-O-ADP 138.56 130.60 37.38 645.27 644.60 MinPt-O-ADP 200.29 184.681 22.621 1125.72 1112.30 MinPt-O-SF 211.57 195.191 22.591 1163.19 1147.35 MinPt-O-SF 1313.64 1272.541 50.941 3257.00 2905.47 MinPt-O-SF 3122.48 3046.01.1 63.271 4405.81 3531.38 MinPt-O-SF 6402.37 6285.76 84.12 4991.31 3627.92 TD OP23-WW02(P6)(DEF I'PLN) PASS 11 143.8011 139.54 120.64 299.00 299.00 MinPt-CtCt 144.1711 139.1711 85 .27 377.67 377.66 MinPt-O-ADP 248.39 232.721 28.011 1201.76 1183.13 MinPt-O-SF 97.53 66.47 4.99 3448.49 3056.86 5.00 Enter Alert 84.2 51.86 4.10 3622.54 3179.91 MinPt-CtCt 84.4 51.6 4.06 3644.79 3194.54 MinPt-O-ADP 86.52 52.58 4.01 3696.57 3227.57 MinPt-O-SF 120.87 82.60 4.96 3928.66 3357.14 5.00 Exit Alert 2789.09 2714.471 57.961 7519.09 3706.49 MinPt-O-SF 6123.48 5999.12 75.35 8200.19 3722.99 TD OP23-WW02PB1(P1)(PLAN) PASS 1 143.8011 139.12 97.21 299.00 299.00 MinPt-CtCt 144.1711 138.73i1 72.29 377.67 377.66 MinPt-O-ADP 247.22 231.061 MIMI 1197.41 1179.11 MinPt-O-SF 98.99 67.50 4.99 3439.27 3049.94 5.00 Enter Alert 84.24 51.51 4.05 3622.54 3179.91 MinPt-CtCt 84.4 51.31 4.01 3644.79 3194.54 MinPt-O-ADP 86.52 52.26 3.97 3696.57 3227.57 MinPt-O-SF 123.02 84.21 4.98 3937.73 3361.56 5.00 Exit Alert 2789.09 2712.931 56.751 7519.09 3706.49 MinPt-O-SF 3536.43 3449.75 62.97 7838.82 3721.87 TD OP24-ENI#4(P2)(DEF PLN PASS 151.71 147.01 101.60 299.00 299.00 MinPt-CtCt 152.1 146.60 74.32 382.50 382.50 MinPt-O-ADP 303.38 282.97 25.211 1237.64 1216.13 MinPt-O-SF 767.65 736.021 39.391 2104.89 1949.89 MinPt-O-SF 1469.02 1420.421 47.721 3256.81 2905.31 MinPt-O-SF 3242.48 3150.871 54.541 4406.90 3531.71 MinPt-O-SF 5978.47 5795.451 49.661 8517.19 3727.83 MinPt-O-SF 5856.19 5671.521 48.201 9380.81 3750.33 MinPt-O-SF 5938.17 5748.901 47.671 9591.54 3758.04 MinPt-O-SF 6972.65 6764.65 50.88 10795.51 3760.28 TD OP25-DSPO1(P1)(DEF PLN PASS 373.23 368.27 225.63 300.00 300.00 MinPt-CtCt 373.47 368.01 188.06 346.43 346.42 MinPt-O-ADP 532.27 515.78 56.80 1199.85 1181.37 MinPt-O-SF 3691.41 3635.27 103.16 3849.78 3316.61 TD OP26-DSPO2(DEF SW) PASS 11 1 358.3611 355.8511 76696.4211 0.00 0.00 MinPts 1 358.621 353.87 236.75 348.71 348.71 MinPt-C[CI 347.38, 336.03 58.41 938.09 932.99 MinPt-CtCt Version DO 4.0(doc40x_100)SP 2.1-ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 6 of 9 I Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation i )r Alert Status Ct-Ct(ft) Dev.(ft Fact. MD(ft)I TVD(ft)I Alert 1 Minor 1 Major 347.6 335.77 55.25 970.70 964.56 MinPt-O-ADP 361.39 343.7811 35.611 1316.92 1287.98 MinPt-O-SF 364.18 328.38 16.30 2718.37 2458.72 MinPt-CtCt 364.24 MEM 16.24 2731.98 2470.01 MinPt-O-ADP 367.43 330.88 16.08 2816.32 2539.96 MinPt-O-SF 604.12 534.611 13.471 4610.00 3584.91 MinPt-O-SF 1549.37 1486.91 I 38.701 5892.11 3616.62 MinPt-O-SF 3093.95 3018.741 63.771 6380.27 3645.06 MinPt-O-SF 0101 SE8(P1)(DEF PLN) PASS II 17827.5711 17823.52. 17274.25 200.20 200.20 MinPt-CtCt 17827.8811 17823.1911 12224.35 255.20 255.20 MinPt-O-ADP 17828.48 17823.3011 9956.8911 301.37 301.37 MinPt-O-SF 17827.8511 17822.8411 10677.60 318.48 318.48 MinPt-O-ADP II 17827.841] 17822.86 10773.78 321.33 321.33 MinPt-CtCt 13492.661+ 13226.061 76.621 8947.10 3744.60 MinPts 13605.66 13370.56 87.72 10926.15 3759.01 TD 0104-SE7(P1)(DEF PLN) PASS 17829.761 17825.71 17279.43 200.20 200.20 MinPt-CtCt 17830.0911 17825.4011 12192.80 255.20 255.20 MinPt-O-ADP 17830.74 17825.5411 9916.7011 301.37 301.37 MinPt-O-SF 17830.0511 17825.0411 10668.06 318.48 318.48 MinPt-O-ADP I 17830.031 17825.05 10768.44 321.33 321.33 MinPt-CtCt 112273.551 11981.961 63.671 8856.02 3741.75 MinPts ® 11984.96 64.44 8868.92 3742.33 MinPt-CtCt 12402.54 12167.55 80.01 10926.15 3759.01 TD 0106SE6(P1)(DEF PLN) PASS 1117831.2211 17827.17 17282.88 200.20 200.20 MinPt-CtCt 17831.5111 17826.8711 12500.32 250.20 250.20 MinPt-O-ADP 17832.26 17827.0611 9880.5511 301.37 301.37 MinPt-O-SF 17831.5011 17826.5011 10712.63 319.91 319.91 MinPt-O-ADP 1 17831.49 17826.51 10763.48 321.34 321.34 MinPt-CtCt 11079.88 10778.30 55.56 8689.11 3734.02 MinPt-O-ADP 11072.58 1078623 58.50 8869.56 3742.35 MinPt-CtCt 11199.24 10962.41 71.67 10926.15 3759.01 MinPt-O-SF 0108SE5(P1)(DEF PLN) PASS 11 17833.4511 17829.41 17288.12 200.20 200.20 MinPt-CtCt 17833.7611 17829.1211 12477.71 250.20 250.20 MinPt-O-ADP 17834.57 17829.3511 9845.9211 301.37 301.37 MinPt-O-SF 17833.7411 17828.7411 10708.04 319.92 319.92 MinPt-O-ADP 11 17833.731 17828.75 10760.56 321.34 321.34 MinPt-CtCt 9879.70 9579.90 49.84 8695.78 3734.31 MinPt-O-ADP 9874.35 9585.84 51.77 8870.09 3742.38 MinPt-CtCt 9998.93 9758.78 63.10 10926.15 3759.01 MinPt-O-SF 0110-SE4(P1)(DEF PLN) PASS 11 17834.9611 17830.92 17291.65 200.20 200.20 MinPt-CtCt 17835.231 17830.6411 12836.11 245.20 245.20 MinPt-O-ADP 17836.14 17830.921 301.37 301.37 MinPt-O-SF 17835.2611 17830.2611 10711.53 319.92 319.92 MinPt-O-ADP 11 17835.251 17830.27 10814.33 322.78 322.78 MinPt-CtCt 8680.99 8380.00 43.61 8695.98 3734.32 MinPt-O-ADP 8676.18 8385.52 45.15 8869.83 3742.37 MinPt-CtCt 8800.11 8556.87 54.82 10926.15 3759.01 MinPt-O-SF 0112-FN8(P1)(DEF PLN PASS 17836.49 17832.44 17295.19 200.20 200.20 MinPt-CtCt 17836.751 17832.171 12856.32 245.20 245.20 MinPt-O-ADP 17837.67 17832.45 9849.68 301.37 301.37 MinPt-O-SF 17836.78 17831.78 10720.55 319.93 319.93 MinPt-O-ADP 11 17836.771 17831.80 10821.24 322.78 322.78 MinPt-CtCt 17839.72 17834.571 10062.421 385.57 385.56 MinPt-O-SF 0201-FN7(P1)(DEF PLN PASS 17838.70 17834.65 17300.33 200.20 200.20 MinPt-CtCt 17838.96 17834.39 12871.67 245.20 245.20 MinPt-O-ADP 17839.88 17834.66 9863.931 301.37 301.37 MinPt-O-SF 17838.9• 17834.00 10727.96 319.93 319.93 MinPt-O-ADP 11 17838.981 17834.01 10827.23 322.79 322.79 MinPt-CtCt 17841.94 17836.78 10064.59 385.59 385.59 MinPt-O-SF 0204-FN6(P1)(DEF PLN) PASS 17841.0 17837.00 17305.73 200.20 200.20 MinPt-CtCt 17841.31 1 17836.731 12905.66 245.20 245.20 MinPt-O-ADP 17842.20 17837.00 9898.32 301.37 301.37 MinPt-O-SF 17841.34 17836.35 10742.32 319.94 319.94 MinPt-O-ADP 1117841.331 17836.36 10837.90 322.79 322.79 MinPt-CtCt Version DO 4.0(doc40x_100)SP 2.1-ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 7 of 9 Offset Trajectory Sep. Jlow Sep. Subject Trajectory Separation P Alert Status Ct-Ct(ft)I Dev.(ft), Fact. MD(ft) I TVD(ft) Alert I Minor f Major 17844.29 17839.1311 10066.88 385.62 385.61 MinPt-0-SF 0205-N8(P1)(DEF PLN) PASS 17842.19 17837.261 10993.161 328.51 328.51 MinPt-0-SF 17845.07 17839.91 10067.64 385.63 385.62 MinPt-O-SF 0206-FN5(P1)(DEF PLN PASS 17842.62 17838.57 17309.35 200.20 200.20 MinPt-CtCt 17842.871 17838.301 12951.70 245.20 245.20 MinPt-0-ADP 17843.73 17838.54 9947.86 301.37 301.37 MinPt-0-SF 17842.91 17837.92 10760.30 319.94 319.94 MinPt-0-ADP 1 17842.901 17837.92 10806.86 321.37 321.37 MinPt-CtCt 17845.86 17840.70110068.411 385.64 385.63 MinPt-O-SF 0207-N7(P1)(DEF PLN) PASS 17844.57 17839.641 10996.321 328.52 328.52 MinPt-O-SF 17847.45 17842.29 10069.95 385.66 385.65 MinPt-0-SF 0210-SE3(P1)(DEF PLN) PASS 11 17846.6311 17842.58 17318.49 200.20 200.20 MinPt-CtCt 17846.9311 17842.3111 12627.22 250.20 250.20 MinPt-O-ADP 17847.71 17842.5311 9979.5011 301.37 301.37 MinPt-0-SF 17846.9111 17841.9311 10774.28 319.95 319.95 MinPt-0-ADP 1 17846.901 1 17841.93 10819.38 321.38 321.38 MinPt-CtCt rr 7475.47 7180.54 38.33 8721.40 3735.48 MinPt-CtCt 7620.29 7376.681 47.391 10926.15 3759.01 MinPts 0212-FN4(P1)(DEF PLN) PASS 17848.26 17844.21 17322.18 200.20 200.20 MinPt-CtCt 17848.551 17843.931 12661.42 250.20 250.20 MinPt-O-ADP 17849.31 17844.14 10015.90 301.38 301.38 MinPt-O-SF 17848.54 17843.55 10787.33 319.96 319.96 MinPt-O-ADP 11 17848.531 17843.56 10830.55 321.39 321.39 MinPt-CtCt 17851.49 17846.33 10073.87 385.70 385.69 MinPt-O-SF 0304-N6(P1)(DEF PLN) PASS 17853.49 17848.561 11008.031 328.55 328.55 MinPt-O-SF 17856.37 17851.21 10078.57 385.75 385.74 MinPt-O-SF 0307-FN3(P1)(DEF PLN) PASS 17856.50 17852.46 17340.72 200.20 200.20 MinPt-CtCt 17856.781 17852.1711 12740.73 250.20 250.20 MinPt-O-ADP 17857.49 17852.331 10098.7311 301.38 301.38 MinPt-O-SF 17856.78 17851 80 10820.74 319.98 319.98 MinPt-O-ADP 11 17856.771 17851.81 10860.05 321.41 321.41 MinPt-CtCt 17859.74 17854.58 10081.82 385.79 385.78 MinPt-0-SF 0308-SE2(P1)(DEF PLN) PASS 1117857.3611 17853.31 17342.63 200.20 200.20 MinPt-CtCt 17857.6611 17853.01i1 12487.95 255.20 255.20 MinPt-O-ADP 17858.25 17853.1211 10185.95i1 301.38 301.38 MinPt-O-SF 17857.6311 17852.6511 10810.28 318.55 318.55 MinPt-0-ADP 1 17857.621 17852.66 10882.45 321.41 321.41 MinPt-CtCt 6268.29 5971.55 31.94 8868.08 3742.29 MinPt-CICt 6389.37 6138.121 38.511 10926.15 3759.01 MinPts 0311-N5(P1)(DEF PLN) PASS 17860.30 17855.371 11016.881 328.57 328.57 MinPt-0-SE 17863.18 17858.03 10085.11 385.82 385.82 MinPt-0-SE 0312-FN2(P1)(DEF PLN PASS 17860.81 17856.77 17350.29 200.20 200.20 MinPt-CtCt 17861.111 17856.4711 12488.59 255.20 255.20 MinPt-O-ADP 17861.71 17856.581 10184.91i1 301.38 301.38 MinPt-O-SF 17861.08 EMU] 10813.02 318.55 318.55 MinPt-O-ADP 11 17861.081 17856.11 10885.74 321.42 321.42 MinPt-CtCt 17864.05 17858.89 10085.94 385.83 385.82 MinPt-0-SF 0402-N4(P1)(DEF PLN) PASS 17867.25 17862.321 11025.811 328.60 328.60 MinPt-0-SF 17870.13 17864.97 10091.75 385.89 385.88 MinPt-O-SF 0403-FN1(P1)(DEF PLN PASS 17867.79 17863.74 17365.65 200.20 200.20 MinPt-CtCt 17868.081 17863.4411 12527.34 255.20 255.20 MinPt-0-ADP 17868.66 17863.531 10223.5811 301.38 301.38 MinPt-0-SF 17868.06 17863.08 10832.70 318.57 318.57 MinPt-0-ADP 11 17868.051 17863.09 10902.23 321.44 321.44 MinPt-CtCt 17871.02 17865.87 10092.60 385.90 385.89 MinPt-0-SF 0406-N3(P1)(DEF PLN) PASS 17870.85 17865.921 11030.401 328.61 328.61 MinPt-O-SF 17873.73 17868.57 10095.18 385.93 385.92 MinPt-O-SF 0407-SE1(P1)(DEF PLN) PASS 11 17872.3211 17868.28 17375.54 200.20 200.20 MinPt-CtCt Version DO 4.0(doc40x_100)SP 2.1 -ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 8 of 9 Offset Trajectory Sep. ,allow Sep. Subject Trajectory Separation, ,r Alert Status Ct-Ct(ft) Dev. ft Fact. MD(ft) I TVD(ft) Alert I Minor T Major 17872.61 17867.97 12533.86 255.20 255.20 MinPt-O-ADP 17873.19 17868.0711 10228.431 301.38 301.38 MinPt-O-SF 17872.5911 17867.6211 10838.41 318.58 318.58 MinPt-O-ADP 17872.581 17867.63 10907.99 321.45 321.45 MinPt-CtCt 5068.51 4779.32 26.51 8868.80 3742.32 MinPt-CtCt 5187.09 4941.00' 31.931 10926.15 3759.01 MinPts 0408-N2(P1)(DEF PLN) PASS 17873.59 17868.661 11033.881 328.62 328.62 MinPt-O-SF 17876.47 17871.31 10097.78 385.95 385.95 MinPt-O-SF 0411-S1(P1)(DEF PLN) PASS 17876.01 17871.96 17383.54 200.20 200.20 MinPt-CtCt 17876.331 17871.6411 12289.77 260.20 260.20 MinPt-O-ADP 17876.81 17871.701 10302.1011 301.38 301.38 MinPt-O-SF 17876.27 OEM 10867.06 318.59 318.59 MinPt-O-ADP 11 17876.261 17871.30 10899.52 320.02 320.02 MinPt-CtCt 17879.24 17874.09 10100.40 385.98 385.97 MinPt-O-SF 0412-N1(P1)(DEF PLN) PASS 17877.30 17872.371 11038.571 328.63 328.63 MinPt-O-SF 17880.18 17875.02 10101.29 385.99 385.98 MinPt-O-SF 0501-S2(P1)(DEF PLN) PASS 11 17879.6511 17875.60 17391.40 200.20 200.20 MinPt-CtCt 17879.9411 17875.3011 12544.33 255.20 255.20 MinPt-O-ADP 17880.52 17875.4011 10236.24i1 301.38 301.38 MinPt-O-SF 17879.9211 17874.9411 10847.55 318.59 318.59 MinPt-O-ADP 1 17879.911 17874.95 10917.23 321.46 321.46 MinPt-CtCt 2672.42 2351.521 12.581 10926.15 3759.01 MinPts 0502-W1(P1)(DEF PLN) PASS 17880.96 17876.031 11043.181 328.64 328.64 MinPt-O-SF 17883.83 17878.68 10104.74 386.02 386.02 MinPt-O-SF 0505-S3(P1)(DEF PLN) PASS 1 17883.4511 17879.41 17399.57 200.20 200.20 MinPt-CtCt 17883.7511 17879.1111 12549.73 255.20 255.20 MinPt-O-ADP 17884.33 17879.2111 10240.2811 301.38 301.38 MinPI-O-SF 17883.7211 17878.7511 10852.27 318.60 318.60 MinPt-O-ADP II 17883.7111 17878.76 10922.00 321.47 321.47 MinPt-CtCt 1484.81II 1158.101 6.86 10418.97 3763.95 MinPt-O-ADP 1475.24 1156.35 6.981 10926.15 3759.01 MinPts 0506-W2(P1)(DEF PLN) PASS 17884.77 17879.841 11047.971 328.65 328.65 MinPt-O-SF 17887.64 17882.49 10108.34 386.06 386.05 MinPt-O-SF 0508-W3(P1)(DEF PLN) PASS 17887.67 17882.741 11051.591 328.66 328.66 MinPt-O-SF 17890.54 17885.39 10111.07 386.09 386.08 MinPt-O-SF 0510-W4(P1)(DEF PLN) PASS 17889.62 17884.691 11054.021 328.67 328.67 MinPt-O-SF 17892.49 17887.34 10112.90 386.10 386.10 MinPt-O-SF 0512-W5(P1)(DEF PLN) PASS 17891.58 17886.651 11056.461 328.67 328.67 MinPt-O-SF 17894.46 17889.30 10114.74 386.12 386.11 MinPt-O-SF 0601-WD1(P1)(DEF PLN) PASS 17862.60 NEM 10924.04 301.37 301.37 MinPts 17865.84 17860.68 10087.66 385.85 385.84 MinPt-O-SF Version DO 4.0(doc40x_100)SP 2.1 -ANTICOLLISION SUMMARY REPORT Generated 3/11/2010 1:42 PM Page 9 of 9 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 w 2.� a mZ°o n 20 0 r- '�z Z NI v 10 m CO ra U) O - a y - - - - \1/4110 V-n i I I I , ca > Z• °°I L I L1 91 m t ± h) r ---ir- \ -_ A O N Z m L \, - - - - I- A — 'V I • I a N mA ( c)r;° I� Z° mZo R r� �� m i ~N a. 44 41. 2 w 2 cn 2 [�f- D O cn —�i O g CA N.)0) 4..Q cn� O� 1 1 �GZj-0� �2�� N�t p� � .c �`r' m Z i a G-, .0 �\sip riZ�� �i�(=- �ZrnCo m02�1Co ga pg ZOO ' Z� O ---i 0 rn ' f c)c) c� �p c.na V, c�r,i CO V, e pR,'r 2O '' 2om� =y °'� o I Z 2 y 0 Z so O 2 ya rm Z in ti 0 cn 4: 1 8._4 1/4' E Q a a I s d 'o w I A V • I:' 5 -t. vi o �, II lil II II o A v: -a al A•i a v_ I I 11 ,. .. 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C T > 0 ,,..-E O O Cr (p m > z I z r Q) i r Q to r ea31 ai ._.. ,_.----, o Schlumberger Ce m CAD E*well cementing recommendation for 13-3/8" Surface Casing Operator : Eni Petroleum Well : OP08-PO4 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Joe Longo Location : Oliktok Point Proposal No. : Draft v2 Service Point : Prudhoe Bay,Alaska Date Prepared : 4-02-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford @slb.com 41/ n �-9 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 : OP08-PO4 Schlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2349.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi 10D20.in j 1 °— (d154ft Permafrost L--• Frac Pore I • I c }• I _ o OD 13.4 in °— (a�2349ft Permafrast •• • • . . ...,.,..... o 00_ LC 2289 ft Shale 1 • o Well Lithology Formation Press. Page 2 OP08-04.cfw;04-02-2010, LoadCase 13-3/8in Surface Casing:Version wcs-cem453_10 Client : Eni Petroleum Well : 0P08-PO4 Sikedirier String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 154.0 20 169.0 18.376 Landing Collar MD : 2269.0 ft Casing/liner Shoe MD : 2349.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2349.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 126.2% Mean OH Equivalent Diameter: 18.796 in Total OH Volume : 753.3 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1894.0 16.000 150.0 19.279 2349.0 16.000 35.0 16.822 Page 3 0P08-04.cfw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : 0PO8-PO4 Silli gel String : Surface Casing District : Prudhoe Bay,Alaska Y Country : US Loadcase : 13-3/8in Surface Casing Max. Deviation Angle : 34 deg Max. DLS : 3.257 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 359.0 0.000 41.0 41.0 0.0 359.0 0.000 100.0 100.0 0.0 359.0 0.000 200.0 200.0 0.0 359.0 0.000 300.0 300.0 0.0 359.0 0.000 400.0 400.0 1.5 359.0 1.500 500.0 499.9 3.5 359.0 2.000 600.0 599.6 5.5 359.0 2.000 700.0 698.9 7.5 359.0 2.000 800.0 797.8 9.5 359.0 2.000 900.0 895.9 12.8 359.0 3.250 1000.0 992.8 16.0 359.0 3.250 1100.0 1088.1 19.3 359.0 3.250 1200.0 1181.5 22.5 359.0 3.250 1201.0 1182.4 22.5 359.0 3.025 1300.0 1272.8 25.7 357.8 3.257 1400.0 1361.6 28.9 356.9 3.247 1500.0 1447.7 32.2 356.2 3.252 1555.6 1494.3 34.0 355.8 3.241 1600.0 1531.1 34.0 355.8 -0.000 1700.0 1614.1 34.0 355.8 0.000 1800.0 1697.0 34.0 355.8 0.000 1900.0 1779.9 34.0 355.8 0.000 2000.0 1862.9 34.0 355.8 0.000 2100.0 1945.8 34.0 355.8 0.000 2200.0 2028.8 34.0 355.8 0.000 2300.0 2111.7 34.0 355.8 0.000 2349.0 2152.4 34.0 355.8 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 154.0 11.20 9.00 Permafrost Sandstone 1849.0 12.00 9.00 Permafrast Sandstone 2349.0 14.00 9.00 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1901.0 1780.8 32 0.7 2349.0 2152.4 50 1.4 Page 4 OP08-04.cfw,04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 SCI imWr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing ft degF ft o_ 0 7f1 40 60 f 00 800 -1—Geoth.Profile Hori.Depart./ 1 � o N � T-_ -ti 0 WIE4 5 is. w o �n�ma0\1\1 ----1 — 0 N ®� O —co o � ',1 7_ _PIMMI141 o— N — —._. - \, .. MOtS N C -- _ ._ ___t EMI - ... - -__ (Ni -... MINIM R1 _ N co- N Temperature Hori. Departure Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface,500' 12.0 ppg DeepCRETE Slurry Tail Original fluid Mud 9.50 lb/gal k: 1.08E-2 Ibf.s^n/ft2 n :0.506 Ty: 15.43 lbf/100ft2 Displacement Volume 339.7 bbl Total Volume 847.3 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 10.20 k:2.26E-2 Ibf.s^n/ft2 n:0.435 Ty:13.81 lbf/100ft2 Lead Slurry 341.2 1849.0 0.0 10.70 k:1.24E-2 Ibf.s^n/ft2 n:0.412 Ty:9.87 lbf/100ft2 Tail Slurry 66.4 500.0 1849.0 12.00 k:8.21 E-2 lbf.sAn/ft2 n:0.350 Ty:6.54 lbf/100ft2 Mud 339.7 0.0 9.50 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43 lbf/100ft2 Page 5 OP08-04.cfw,04-02-2010: LoadCase 13-3/8in Surface Casing,Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Schiumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Static Security Checks Frac 4 psi at 154.0 ft Pore 14 psi at 154.0 ft Collapse 2043 psi at 2269.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton ft (x 1000) psi o 0 Hydrostatic 2 I I: Frac Pore O 0 o- 0 0 o— (4 0 0 O Fluid Sequence Static Well Security Page 6 OP08-04.cfw;04-02-2010, loadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Sclmmerger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing * CemCADE Client :Eni Petroleum Well :OP08-PO4 String :Surface Casing District : Prudhoe Bay,Alaska Country : US Depth= 160 ft _ Depth= 2349 ft` ___ Frac `— —Frac —We —Rre —Hydrostatic —Hydrostatic —Dynanic —Dynanic co d- el I to O- i rn -°' N ,-- E do m co CO NC N7 C� c U QCD Q _ t 0 N n M vo O cn O) N t- a cis _-_T- I -- ----- ---T 0 50 100 150 200 0 50 100 150 200 Time(min) Time(min) 4 0 a o Total Depth = 2349.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Seklaberpr Page 7 OPOB-04.ciw;04-02-2010; LoadCase 13-3/8in Surface Casing:Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Silinkrier String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in 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 lnj. 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 10.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 341.2 68.2 341.2 80 13-Start Mixing Lead Slurry Tail Slurry 5.0 66.4 13.3 66.4 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 320.0 37.6 320.0 80 19-Start Displacement Mud 3.0 19.7 6.6 339.7 80 21-Bump Top Plug Total 02:40 847.3 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks: Frac 2 psi at 154.0 ft Pore 4 psi at 154.0 ft Collapse 2043 psi at 2269.0 ft Burst 4822 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 70 degF Simulated BHCT 70 degF Max HCT Depth 2349.0 ft CT at TOC 61 degF Max HCT Time 02:40:44 hr:mn:sc Static temperatures: At Time 1 (hr:mn) 1 (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 1 20 degF Bottom Hole (degF) (degF) 50 degF Page 8 OP08-04.cfw,04-02-2010, LoadCase 13-3/8in Surface Casing.Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Schlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing o I —Calc.WHP -� 'C-7; Calc. Pump Press. : i_ Q_ Iliiil "`�� ' ^4—1 __'- -- I — I .�.. 0 25 50 75 100 125 150 175 Time (min) Fluids at 2349 ft --- 1=I ------ - — .- —Acquired Q Out —Acquired 0 In J Q —Q Out —i —Q In __ CU Li 0 25 50 75 100 125 150 175 Time (min) Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :2329.0 ft Casing Shoe :2349.0 ft NB of Cent. Used :13 NB of Floating Cent. :1 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 149.0 1 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 141.0 1869.0 0 0/0 0.0 149.0 2349.0 12 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 1876.6 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-ST-13 3/8-8-ST W131 13 3/8 18.386 14.685 No Hannover 16.000 1225.21 2996.70 A3B (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 :0.25 Total Drag Force :7 ton Hook load Down Stroke :89 ton Hook load Up Stroke :103 ton Page 9 OP08-04.cfw,04-02-2010, LoadCase 13-3/8th Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : 0P08-PO4 3dlimerger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing ft 0 711 0 60 80 100 _—Between Cent. ' + +Pt Cent. -I- O p O . - O- N O O s_ M- Pipe Standoff Page 10 OPOS-04.cfw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 ScIwm�rger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing CemCADE Client :Eni Petroleum Well :OP08-PO4 String :Surface Casing District :Prudhoe Bay,Alaska Country :US ft ton 0 0 20 40 60 80 100 120 —Hooldoad Up —— Hooldoad Dow n . Weight — — Drag Force - 1 \. \. I \ I \ \,. I e I \ ' j I \\ U $ I \ $ N I \ t I \ M 'Sc ■ U 0 8 tv)— f q Running Forces o Friction Factor=0.25 Total Depth = 2349.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Silimkerpr Page 11 OP08-04.cfw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 S hlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 5: WELLCLEAN II Simulator ft 0 I A0 60 80 100 -- Std Betw.Cent. —Cement Coverage 0 0 - 11 111111 I CD 0 0- cti 0 0 0 Cement Coverage Fluids Concentrations Risk Mud on the Wall YOa, 200 200 c: < -200 aoa= day 400 '' i h -dav 600- 600 s°a ! -600 800- 800 800 .,fl... 7- 800 1000- 1000 S '-.1---_ 1000 -1000 S _c 1200= 1200 .t _c 1200 ''-1200 . 0 1400- 1400 0 0 1400 I' 1400 0 1600- 1600 1600 w -1600 1600 1800 1600 - ` -1800 2000 2000 2000 -2000 2200 2200 2200 -2200 • 3 e _a o a 0 o x MI Mud LJ Lead Slurry = High ® Low Tail Slurry ( I MUDPUSH II 0 Medium FT None Page 12 OP08-04.crw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem4S3_10 Client : Eni Petroleum Well : 0P08-PO4 ScImierger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.08E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.506 Ty : 15.431bf/100ft2 Gel Strength :(Ibf/100ft2) MUD Mud Type :WBM Job volume :339.7 bbl Water Type : Fresh VOLUME FRACTION Solids :5.0% Oil :0.0% Water :95.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.20 lb/gal Rheo.Model : HERSCHEL_B. k :2.26E-2 lbf.s^n/ft2 At temp. :80 degF n :0.435 Ty : 13.81 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo.Model : HERSCHEL_B. k : 1.24E-2 lbf.s^n/ft2 At temp. :80 degF n :0.412 Ty :9.871bf/100ft2 Gel Strength :(lbf/100ft2) DESIGN BLEND SLURRY Name : B809 Mix Fluid : 19.043 gal/sk Job volume :341.2 bbl Dry Density : 105.47 lb/ft3 Yield :4.33 ft3/sk Quantity :442.57 sk Sack Weight : 188 lb Solid Fraction :41.2% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 19.043 gal/sk Page 13 OP08-04.cfw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : 0P08-PO4 String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Tail Slurry DESIGN Fluid No:4 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k :8.21E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.350 Ty :6.541bf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid :5.232 gal/sk Job volume :66.4 bbl Dry Density : 110.20 lb/ft3 Yield : 1.61 ft3/sk Quantity :230.92 sk Sack Weight : 100 lb Solid Fraction :56.7% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.082 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D185A 0.050 gal/sk blend Dispers. LT D186 0.100 gal/sk blend Accelerator D153 1.500%BWOC Antisettling 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 5.0 100.0 20.0 100.0 7-Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 4-Drop Bottom Plug Lead Slurry 5.0 341.2 68.2 341.2 13-Start Mixing Lead Slurry Tail Slurry 5.0 66.4 13.3 66.4 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 18-Drop Top Plug Mud 8.5 320.0 37.6 320.0 19-Start Displacement Mud 3.0 19.7 6.6 339.7 21-Bump Top Plug Total Pumping Time : 02:40 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 401 bbl Page 14 OP08-04 cfw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 ScImierger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing MIXING PREPARATION MUDPUSH 11 Volume : 100.0 bbl Density: 10.20 lb/gal Code Quantity Design Fresh water 92.153 bbl D046 64.404 lb 0.200%BWOW D182 552.917 lb 6.000 lb/bbl of base fluid D031 10020.897 lb 100.21 lb/bbl of spacer Lead Slurry Volume :475.4 bbl Density : 10.70 lb/gal Yield :4.33 ft3/sk Dry Phase Liquid Phase Blend: 115934 lb Design _ Mix Water 279.6 bbl 10.0 bbl LAS Design B809 115933.961 Fresh water 279.600 bbl 10.001 bbl lb Tail Slurry Volume:69.8 bbl Density : 12.00 lb/gal Yield : 1.61 ft3/sk Dry Phase Liquid Phase Blend: 24535 lb Design Mix Water 30.2 bbl 10.0 bbl LAS Design 12.0 PPG Lit 24264.080 lb Fresh water 29.361 bbl 9.714 bbl D046 48.528 lb 0.200%BWOB D185A 12.132 gal 4.014 gal 0.050 gal/sk blend D153 222.218 lb 1.500%BWOC D186 24.264 gal 8.028 gal 0.100 gal/sk blend Page 15 OP08-04.cfw;04-02-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem453_10 Schlumberger CemCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP08-PO4 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Joe Longo Location : Oliktok Point Proposal No. : Draft v2 Service Point : Prudhoe Bay,Alaska Date Prepared : 4-6-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford@slb.com Q� t;7 �L 9�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 : OP08-PO4 Schlum baler String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US 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 : 4908.0 ft BHST : 85 degF Bit Size : 12 1/4 in ft (x 1000) psi 0020.in 0 7 2 3 o (�154ft . L Fran . . . . . Pore Permafrast• OD 13.4 in .-= ' ' ' ' @ 2340ft o . . . . Shale T/Cosh 1 • 1. OD 9.62 in @ 4908ft LC QA4828 ft 1 0 Well Lithology Formation Press. Page 2 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Sddliberier String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2349.0 13 3/8 68.0 12.415 Landing Collar MD : 4828.0 ft Casing/liner Shoe MD : 4908.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 4908.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Page 3 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem453_10 Client : Eni Petroleum Well : 0P08-PO4 Sc bmlirger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US 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 : 408.7 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 4.007 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 359.0 0.000 41.0 41.0 0.0 359.0 0.000 100.0 100.0 0.0 359.0 0.000 200.0 200.0 0.0 359.0 0.000 300.0 300.0 0.0 359.0 0.000 400.0 400.0 1.5 359.0 1.500 500.0 499.9 3.5 359.0 2.000 600.0 599.6 5.5 359.0 2.000 700.0 698.9 7.5 359.0 2.000 800.0 797.8 9.5 359.0 2.000 900.0 895.9 12.8 359.0 3.250 1000.0 992.8 16.0 359.0 3.250 1100.0 1088.1 19.3 359.0 3.250 1200.0 1181.5 22.5 359.0 3.250 1201.0 1182.4 22.5 359.0 3.025 1300.0 1272.8 25.7 357.8 3.257 1400.0 1361.6 28.9 356.9 3.247 1500.0 1447.7 32.2 356.2 3.252 1555.6 1494.3 34.0 355.8 3.241 1600.0 1531.1 34.0 355.8 -0.000 1700.0 1614.1 34.0 355.8 0.000 1800.0 1697.0 34.0 355.8 0.000 1900.0 1779.9 34.0 355.8 0.000 2000.0 1862.9 34.0 355.8 0.000 2100.0 1945.8 34.0 355.8 0.000 2200.0 2028.8 34.0 355.8 0.000 2300.0 2111.7 34.0 355.8 0.000 2348.8 2152.2 34.0 355.8 0.000 2400.0 2194.7 34.0 355.8 0.000 2500.0 2277.6 34.0 355.8 0.000 2600.0 2360.5 34.0 355.8 0.000 2700.0 2443.5 34.0 355.8 0.000 2800.0 2526.4 34.0 355.8 0.000 2900.0 2609.4 34.0 355.8 0.000 3000.0 2692.3 34.0 355.8 0.000 3100.0 2775.3 34.0 355.8 0.000 3200.0 2858.2 34.0 355.8 0.000 3258.6 2906.8 34.0 355.8 0.000 3300.0 2940.8 35.6 356.1 3.991 3400.0 3020.0 39.6 356.9 4.003 3500.0 3094.8 43.6 357.4 3.999 3600.0 3164.8 47.5 358.0 4.007 3700.0 3229.7 51.5 358.4 3.995 3800.0 3289.2 55.5 358.8 4.003 3900.0 3342.9 59.5 359.2 4.002 4000.0 3390.6 63.5 359.5 4.001 4100.0 3432.0 67.5 359.8 4.000 4200.0 3467.1 71.5 0.1 4.000 Page 4 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a(;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 ScIunlerger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4208.1 3469.6 71.8 0.1 3.943 4300.0 3498.3 71.8 0.1 0.000 4400.0 3529.5 71.8 0.1 0.000 4408.1 3532.1 71.8 0.1 0.000 4500.0 3558.7 74.6 0.1 3.004 4600.0 3582.8 77.6 0.1 3.000 4700.0 3601.7 80.6 0.1 3.000 4800.0 3615.5 83.6 0.1 3.000 4900.0 3624.2 86.6 0.1 3.000 4908.0 3624.6 86.8 0.1 3.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 2349.0 14.00 9.00 T/Cosh 1 Shale 4908.0 15.00 9.00 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1849.0 1737.6 32 0.7 4908.0 3624.6 85 1.8 Page 5 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem453_10 Client : Eni Petroleum Well : 0P08-PO4 Schiumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) ft degF (x 1000)ft 0 I 60 90 n 1 2 3 —Geoth.Profile —Hori.Depart. I t i — - 1 \ ____.. ' ____L_____ 71. _ 0 �� ___ ma- o . a — -• :___ _ — v. _ \ Imilmm__ , v N — —_ _f_ I , ' _ Mill \� N — T' a. a. 1 1 Temperature Hori. Departure Section 2: fluid sequence Job Objectives: TOC 3,732';Zonal Isolation Original fluid Mud 9.50 lb/gal k: 1.08E-2 Ibf.s^n/ft2 n :0.506 Ty: 15.43 Ibf/100ft2 Displacement Volume 353.4 bbl Total Volume 491.3 bbl TOC 3732.0 ft Fluid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 50.0 717.1 3014.9 11.00 k:2.26E-2 Ibf.s^n/ft2 n:0.435 Ty:13.81 Ibf/100ft2 12.5 ppg 87.9 1176.0 3732.0 12.50 k:1.78E-3 lbf.s^n/ft2 n:0.987 Ty:20.24 Ibf/100ft2 DeepCRETE Mud 353.4 0.0 9.50 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43 lbf/100ft2 Page 6 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Schlumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) Static Security Checks: Frac 503 psi at 2349.0 ft Pore 56 psi at 2349.0 ft Collapse 4485 psi at 4828.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 69 ton ft (x 1000) psi 0- 0 1 3 I– Hydrostatic - —Frac 1 ---- Pore 0 0 0— I I i\\ \.1 ,, ' I 0 0 O- tt I i 0 1 I I 0 CI— Fluid cquence Static Well Security Page 7 0P08-04.c(w,04-06-2010, LoadCase 9-5/B Intermediate Casing(al;Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Sillmberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :OP08-PO4 String : Intermediate Casing District : Prudhoe Bay,Alaska Country :US Depth= 2349 ft Depth= 4908 ft___ I in ,`- :—Frac — —Frac I —Pore —Pore —Hydrostatic —Hydrostatic 1 —Dynanic —Dynanic M 11 t N Td M- a m`- Y N N '.. 3 7 7 N N CO CO> `) N 0-r- 0 • C C 3 -13 (z) I o d era• rn U o a N.J, J 3 ----r- 0 I T--T I I I T-- I co 20 40 60 80 100 0 20 40 60 80 100 Time(min) Time(min) 4 °ao Total Depth =4908.0 ft Top of Cement= 3732.0 ft *Mark of Schlumberger Selimberier Page 8 OP08-04 cfw:04-06-2010. LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Stillibrill String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) 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 4.0 50.0 12.5 50.0 80 7-Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 80 4-Drop Bottom Plug 12.5 ppg 5.0 87.9 17.6 87.9 80 9-Start Cement Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 335.0 39.4 335.0 80 19-Start Displacement Mud 3.0 18.4 6.1 353.4 80 21-Bump Top Plug Total 01:30 491.3 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks: Frac 408 psi at 2349.0 ft Pore 56 psi at 2349.0 ft Collapse 4485 psi at 4828.0 ft Burst 6567 psi at 0.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 85 degF Simulated BHCT 60 degF Max HCT Depth 4908.0 ft CT at TOC 61 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 75 degF Bottom Hole (degF) (degF) 85 degF Page 9 OP08-04.cfw,04-06-2010, LoadCase 9-5/8 Intermediate Casing)a);Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 Schlumdcrgcr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) o -Cala.WHP un Cale.Pump Press. Q :,,,,,,>/ i 0 20 40 60 80 100 Time (min) Fluids at 4908 ft —O ------------- Acquired -------------- _ ---Acquired 0 In -__1..__ I 1 - QOut Q In / Ix 1 O ,,) L.T. O 0 20 40 60 80 100 Time (min) Section 4: centralizer placement Top of centralization :3700.0 ft Bottom Cent. MD :4888.0 ft Casing Shoe :4908.0 ft NB of Cent. Used :30 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 4908.0 30 1/1 NW-TR-9 5/8-6-TR 3A W090 71.5 4908.0 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 10D specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.25 Total Drag Force :7 ton Hook load Down Stroke :99 ton Hook load Up Stroke :113 ton Page 10 OP08-04.cfw.04-06-2010, LoadCase 9-5/8 Intermediate Caning al Version wcs-cem453_1 0 Client : Eni Petroleum Well : OP08-PO4 ScImberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) ft 00 0 711 0 60 80 100 Between Cent. i - + +At Cent. 0 o N II I II - t , o • } 0 . ,— o— v 1 0 Pipe Standoff Page 11 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcscem453_10 Client : Eni Petroleum Well : 0P08-PO4 Scl��rg�r String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client :Eni Petroleum Well :OP08-PO4 String : Intermediate Casing District :Prudhoe Bay,Alaska Country :US ft ton 0 0 20 40 60 80 100 120 I —Hooldoad Up V —— Hooldoad Down 1 - - - - Weight S. — — Drag Force •. - I \ o \ _ I \ N I \ v I \ a ( \ 3 I I \ > I \ \ \ ;, 1 1 € 1 I \ I : U o ' jJ rp— S Running Forces Friction Factor=0.25 Total Depth =4908.0 ft Top of Cement= 3732.0 ft *Mark of Schlumberger Page 12 OP08-04.cfw;04-08-2010: LoadCase 9-5/8 Intermediate Casing(al;Version wcscem453_10 Client : Eni Petroleum Well : OP08-PO4 Schlumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft o, 61 I 80 90 100 Std Betw. Cent. Cement Coverage 0 0 o- cv o r 0 o— v o 0 0 cn— Cement Coverage Risk Mud on the Wall Fluids Concentrations z° z° I 1 4. 1 3800 3800 3800 3800 3900 3900 3900 -3900 4000 4000 4000 -4000 4100 4100 4100 -4100 - 4200 4200 4200 -4200 --7-- s 4300 4300 L s 4300 -4300 s o 4400 4400 IL 0 44 -4400 0 ° 4500 4500 ° ° 4500 -4500 ° 4600 4600 4600 `': 4600 4700 -4700 4700 "`a 4700 4600 4600 4600 4800 4900 -490b 4900 4900 I o o -12 o z 2 MI Mud . High = Low ED 12.5 ppg DeepCRETE Medium = None I1 MUDPUSH II Page 13 OP08-04.cfw,04-06-2010; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem453_10 1 Client : Eni Petroleum Well : OP08-PO4 Scil�m�rger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo.Model : HERSCHEL_B. k : 1.08E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.506 Ty : 15.431bf/100ft2 Gel Strength :(Ibf/100ft2) MUD Mud Type :WBM Job volume :353.4 bbl Water Type : Fresh VOLUME FRACTION Solids :8.0% Oil :0.0% Water :92.0% MUDPUSH II DESIGN Fluid No:2 Density : 11.00 lb/gal Rheo. Model : HERSCHEL_B. k :2.26E-2 lbf.sAn/ft2 At temp. :80 degF n :0.435 Ty : 13.81Ibf/100ft2 Gel Strength :(Ibf/100ft2) Job volume :50.0 bbl 12.5 ppg DeepCRETE DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo.Model : HERSCHEL_B. k : 1.78E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.987 Ty :20.24Ibf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5 ppg Lit Mix Fluid :4.974 gal/sk Job volume :87.9 bbl Dry Density : 117.67 lb/ft3 Yield : 1.52 ft3/sk Quantity :324.74 sk Sack Weight : 100 lb Solid Fraction :56.2% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :4.604 gal/sk Additives Code Conc. Function D206 0.200 gal/sk blend Anti-Foam D185A 0.070 gal/sk blend Dispers. LT D186 0.100 gal/sk blend Accelerator D167 0.350%BWOB Fluid loss Page 14 OP08-04.cfw;04-06-2010, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 ScIokerpr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US 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 4.0 50.0 12.5 50.0 7-Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 4-Drop Bottom Plug 12.5 ppg 5.0 87.9 17.6 87.9 9-Start Cement Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 18-Drop Top Plug Mud 8.5 335.0 39.4 335.0 19-Start Displacement Mud 3.0 18.4 6.1 353.4 21-Bump Top Plug Total Pumping Time : 01:30 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 80 bbl MIXING PREPARATION MUDPUSH II Volume: 50.0 bbl Density: 11.00 lb/gal Code Quantity Design Fresh water 44.655 bbl D046 31.209 lb 0.200%BWOW D182 267.931 lb 6.000 lb/bbl of base fluid D031 7196.477 lb 143.93 lb/bbl of spacer 12.5 ppg DeepCRETE Volume: 87.9 bbl Density : 12.50 lb/gal Yield : 1.52 ft3/sk Dry Phase Liquid Phase Blend: (lb) Design Mix Water 38.5 bbl 10.0 bbl LAS Design 12.5 ppg Lit 32473.844 lb Fresh water 35.594 bbl 9.257 bbl D167 113.658 lb 0.350%BWOB D206 64.948 gal 16.891 gal 0.200 gal/sk blend D185A 22.732 gal 5.912 gal 0.070 gal/sk blend D186 32.474 gal 8.446 gal 0.100 gal/sk blend Page 15 OP08-04.ctw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem453_10 Client : Eni Petroleum Well : OP08-PO4 SIIImberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client :Eni Petroleum Well :OP08-PO4 String :Intermediate Casing District :Prudhoe Bay,Alaska Country :US Annulus ID:9.625 in-OD: 12.823 in co -MUDPUSHII -Mud to_- 12.5 ppg DeepCRETE NI- O 't O o O Mt r O_ ° N cr F., d N 3 . M .5 N e N > N G M v U LL Eti. M d o M— t I I I I I I I I I I I c 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbVmin) 't.'4 °aa ■Mud Herschel:k=1.08E-2 Ibf.s^n/ft2 n=0.506 Ty=15.43 Ibf/100ft2 ■MUDPUSH II Herschel:k=2.26E-2 Ibf.s^n/ft2 n=0.435 Ty=13.81 Ibf/100ft2 ®12.5 ppg DeepCRETE Herschel:k=1.78E-31bf.s^n/ft2 n=0.987 Ty=20.24 Ibf/100ft2 *Mark of Schlumberger Seilliiberpr Page 16 OP08-04.cfw;04-06-2010; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem453_10 iroiliiii Oliktok Point Nikaitchuq Field North 2n� peirolleum OP08-04 Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle I X-65 0° 20"Conductor Shoe 154' 154' Driven Welded N/A O GR/Res - Surface Csa Dir/PWD a 13-3/8" c D 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r- L-80,BTC 8.8 -9.5 Lost Circulation B/Permafrost 1,849' 1,738' Hole Cleaning Casing Sections KOP:300' Casing Wear DLS: Surface T/Tail Cement 1,849' 1,738' - 0-3.25°/100' i cS m0 , Is< VI na Hole Angle 1p'= 33.96 Deg 13-3/8"Csg 2,349' 2,152' ■ 16" 50°F WBM GR/RES Neutron/Density/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 47 lbs/ft MW(ppg) Hole Cleaning L-80,BTC-M 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 71.8 Deg T - BHA Expense Intermediate TOC 3,732' 3249.3 Pick-up Top of Sand Top N Sand 4,232' 3,477' TOL 4,708' 3,603' Hole Angle "- 074 86.8 Deg 9-518"Csg 4,908' 3,851' 12-1/4" 85°F LSND GR/RES Neutron/Density/PWD Wellbore Stability Lost Circulation 6' Slotted Liner Hole Cleaning d 5-1/2" Torque&Drag a m 17 lbs/ft MW(ppg) Casing Sections Xceed 675 to L-80,IBT-M 9.0-9.3 Casing Wear E BHA Expense r- m m m Hole Angle 90.56 Deg TD/5-1/2"Lnr 10,926' 3,759' 8-1/2" 85°F MOBM Formation Integrity And Leak Off Test Procedure Drilling Operations 1. After cementing casing and nippling up BOP Equipment,RIH to top of cement and pressure test the casing to the test pressure specified in the well plan(usually 2500-3000 psi)for 30 minutes and record on a chart(AOGCC required casing integrity test).The slowest possible pump rate is preferred to allow detection of leaks. Pump rates of 1/4 to 1 BPM are typical;however,adjust the pump rate to match the test pump capability to maintain a constant pump rate. Record pressures approximately every 1/4 bbl on the Pressure Integrity Test(PIT)Form(you can locate on the drilling N drive).Plot the casing pressure test(volume versus pressure),and indicate how long the pressure is held on the casing. Verify that the test data forms a straight line and there is no air entrained in the mud,or leaks in the system.Repeat the casing pressure test if needed,especially if a straight line cannot be established at the higher test pressures. 2. Drill 20'to 50'of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system(required for a good downhole pressure test).Pick up into the shoe. 4. Close the blowout preventer(ram or annular). 5. Pump down the drill string at a rate approximating that used to test the casing in Step No. 1. Lower pump rates are preferred in order to minimize friction pressures losses(especially with long strings of small drillpipe)which are ignored in the calculations;however,adjust the pump rate to match the test pump capability and maintain a constant pump rate. Pump rates between 1/4 and 1-1/2 BPM are typical,with higher rates applicable to tests conducted with large intervals of open hole. 6. On the PIT Form,plot the fluid pumped(volume or strokes)vs.drill pipe pressure. Record pressures approximately every 1/4 bbl pumped. The data points should initially form a straight line with a similar slope to the casing integrity test as the system compressibility's are similar. Eventually,the formation begins to take fluid;at this point the pressure will continue to rise,but at a slower rate and the data points will deviate from the straight line. The first,sustained occurrence of this departure is the leak-of point(see Figure 1). Pump an additional 3 bbls after the suspected leak-off point is reached to assure continued decreasing slope on the pressure versus volume plot. If a straight line cannot be established during initial pumping(suggesting a surface leak or air in the system)or a clear leak-off point is not indicated,consider re-running the test. Be sure to bleed all pressure off the system prior to re-running the test. A slightly higher pump rate may be considered if a clear departure is not indicated on the pressure versus volume plot. Small filtration fluid losses can cause a slope change,especially at slow pump rates,and confuse the identification of a more definitive leak off point. Note:If the maximum EMW specified in the wellplan is reached without indication of leak-off,shut down and hold the pressure there.This becomes the data for a formation integrity test(FIT)instead of a leak off test(LOT) 7. Shut down when the leak-off point is observed and 3 bbls of mud have been pumped into the formation. Record the instantaneous shut-in pressure(ISIP).With the pump shut down,monitor and record a 15 second and 30 second shut-in pressure and the shut-in pressures for a minimum of 10 minutes(at 30 second intervals)or until the shut-in pressure stabilizes.Plot the information and record the LOT point or FIT point on the PIT Form. Bleed the pressure off and record the fluid volume recovered if possible. If in doubt of the leak off point,contact the Drilling Superintendent to discuss and evaluate the test. Upon completion of the test,forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the proper Agencies. NOTE: Pumping to the leak-off point plus 3 bbls is less critical for casing shoes other than surface casing,but it is important to pump enough to ensure a good LOT and not a spurious departure. 8. Corrective measures will be performed if the open hole pressure integrity fails to meet predetermined standards. The Drilling Supt.is to be notified immediately of any LOT or FIT that results in less than adequate formation integrity as defined in the Well Plan. Do not drill ahead until the inadequate formation integrity is addressed. Ideal LOT • A ,Maximum Pre Ism - 4_4 4e" Ia.' IM " — 8 . )..") 111 Formation • BreakdOwn , • .• Anticipated.Pries sure.- IFFAIPArm, ..Fraciure Leak Off Point D FAII Propagation Al ri Alb. L. . PrerIstre Start In orim o • o o F rachrie • .Closure, :nSIP nt Lojen oPoressuo ke a pPP' Pressure Volume and Shut-in Time 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 Oliktok CI 11 INTAKE OLIKTOK 5 Point MODULE DOCK R� ppp '1`THIS cSb I P. I,p. i5 SURVEY ell . % - N .s.• r- �? t y lA DS-3R DEW UNE 0 SITE STP ` OLIKTOK POINT MODULES NOC STAGING AREA% T13N, R9E 1 DS-30 1 1 t..1 : 1 i \,; i5 SCALE: 1" = 150' ..\___, Ds,30 19 11/‘; 21\ ,,2. S TP PAD \`\ VICINITY MAP 00 \ SCALE: 1" = 1 Mile o0x-.1-o 0 0o°-0°w°C'ON-)\ \ o090 a° \ O°-o 0�c,z \. oa �aa° s o z 0-o o \o,a Ac\,\ O ° �°0O `D O 00 0 S G p� • \ �0 Z 0,0 0 \ \ _ .• OLIKTOK \\ 2 POINT PAD \ N-36, \ o• 0 / O'o� \ / \\ SEE SHEET 3 FOR NOTES / \\ / \ • Existing Conductor / LOUNSBURY �`�/ & ASSOCIATES, INC. • Conductor Asbuilt this survey / s ICYoRS ENGINEERS PLANNERS AREA: MODULE: UNIT: fC��i Ir' 't�rolle �ll ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-61 PART: 1 OF 3 REV: 2 REV DATE BY CK APP DESCRIPT1ON 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 O.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 OPUS 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 O.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: IT..... Eiri '� &tiff©lletuii� WELL OCONDUCTOR D 111 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. SURVEYOR'S CERTIFICATE �1, :_ ••� • . . h i\ I HEREBY CERTIFY THAT I AM PROPERLY 0 • REGISTERED AND LICENSED TO PRACTICE 0 0 iI.. ,,, r LAND SURVEYING IN THE STATE OF 0 i� ROOKUS o i ALASKA AND THAT THIS PLAT REPRESENTS --. OP:). S-803 ,,� A SURVEY DONE BY ME OR UNDER MY � I i DIRECT SUPERVISION AND THAT ALL **;<- ....44111/0...•'Fa �i DIMENSIONS T AND OTHER DETAILS ARE DECEMBER 23, 2008. ,,,,"1.1ws30•♦•� 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE UNIT: • trCM P i©IIGNhn OLIKTOK D WELL CONDUCTOR ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 3 OF 3 2 p Eni Petroleum 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi @enipetroleum.com 4/8/2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer Well OP08-04 Dear Commissioners, Eni US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore Producer Well OP08-04. The well will be drilled and completed using Nabors rig 245E. The planned spud date for OP08-04 is 6/26/2010. Eni US Operating Co. Inc.would like the AOGCC to consider implementing a fourteen(14)day BOP testing schedule at this time. OP08-04 will be the fifth(5th)well drilled by Eni and the seventh(7t')well drilled at Oliktok Point. To date four(4)wells have been drilled at Oliktok Point without any well control incidents. 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 Joseph Longo at 907-865-3323 or Jason Brink at 907-865-3321. Sincerely, . � V Maurizio Grandi Well Operation Project Manager 00 CO CO O 0 01 0 O 0 O 0 0 0 0 0 0 O 0 0 0 0 O 0 O m o n • IN > 01 N ;a 0 mil 00 0 117 CD a 3 D 1 M _. 71 ° O J M 0 J 0 O O y O ...1,..t...17.1.79 LI O 1 CO O • IV O O W , 00 O O i O O O TRANSMITTAL LETTER CHECKLIST WELL NAME . i �"2_� (CV L- (- (- PTD# 7 -/C V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: A'// ICVLZt % POOL: 47(kL-41( f��C ' ( l C:C2 Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (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 full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 m -a 0 • v c0 .D 3 o _m o D O co 3 -0 -• 1, T 0 CO CD 3 O m ._N. j r 3 p A A 3 A v O co rn °(Q. N) m N) m N v 7 O 3 7 O N N O O 0 (LD 0 0 0 O O O w w CO w w w w w w w Ni Ni N Ni N) N N) N) N) N . . . . . --, -, -, CO CA -4 C) Ol A G) N.) -, 3 CO Co V C) 01 A w N) — O c0 Co -.I O) Ul A w Ni 0 O Co -4 O) 01 A w N) --k 0 n U) 0) D m (, * n w 03 D D �. D n n n own z v D g n m m O O = 0) g * * c .< x O 0 m co m m ° ? 0 0 . 0: n 0 n CU K K K o o o ' m o co m •0 -° a c m m m 7. 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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 P 9 Y organize this category of information. RECEIVED JUL 2 8 2010 Alaska 011&Gas Cent.C nnission Anchorage ° ° 2nn E n1II tirOIIetuiinnl FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP08-04 and OP08-04 PB1 OLIKTOK POINT, ALASKA I '%.'1; .vet.si , . Provided by: CANRIG Approved by: Andrew Buchanan Compiled by: Emil Opitz John Lundy Tollef Winslow Distribution: July 28, 2010 Date: July 8, 2010 gc I Nikaitchuq OP08-04 and PB1 eni 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 3 GEOLOGICAL INFORMATION 6 3.1 Hole Information 6 3.2 Daily Activity Summary 7 3.3 Target and Reference Well Correlation Points 9 3.4 Lithostratigraphy 10 3.5 Mudlog Summary 11 3.6 Connection Gases 29 3.7 Trip(Wiper) Gases 29 3.8 Sampling Program/Sample Dispatch 30 3.9 Approved Sample Plan OP08-04 31 4 PRESSURE/FORMATION STRENGTH DATA 32 4.1 Pore Pressure Gradient Evaluation 32 4.2 Quantitative Methods 32 5 DRILLING DATA 33 5.1 Survey Data 33 5.2 Bit Record 38 5.3 Mud Record 39 6 DAILY REPORTS 42 Enclosures 2"/100' Formation Log (MD/TVD) 2"/100' LWD Combo Log (MD/TVD) 2"/100' Gas Ratio Log (MD/TVD) 5"/100' Formation Log (MDTVD) 2"/100' Drilling Dynamics Log (MD&TVD) Show Reports Final Data CD 2 CANRIG Nikaitchuq OP08-04 and PB1 eni MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Downtime Parameter Equipment Type/Position Comments (hours) Casing Pressure Cable to 1502 transducer for BOP 0 tests only. Computer—Drill Floor Monitor Azonics IP conflicts Computer—Pit Monitor Azonics 0 Computer for Company Man, Rigwatch Remote (HP Compaq) 0 camp Computer for Company Man/ Rigwatch Remote (HP Compaq) Service/Repair Toolpusher, office (wireless) 36 receiver antenna Computer for Mud Engineer Rigwatch Remote (HP Compaq) 0 Computer for Toolpusher Rigwatch Remote (HP Compaq) 12 Service/Repair receiver antenna Com uters for Mud loggers 3 Data editing, Rigwatch Master, and p gg ( ) Rigwatch Remote(all HP Compaq) 3 K-Box software QGM Agitator Ditch gas (Mounted in possum belly) Clean/repair/adjust Flame Ionization Detector(FID)Total 2 Gas and Chromatography. gas trap Hook Load/Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes/Minute and Pump Output 0 Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 24 C/O Transducer Pump stroke counters(2) 2 proximity sensors 0 Rate of penetration Crown Fast Sheave proximity p sensors 3 K-Box software RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to Rigwatch Master 0 Computer 3 CANRIG IOW Nikaitchuq OP08-04 and PB1 eni 1.2 Crew Unit Type • Arctic Unit Number : ML014 Years Days Mudloggers ,1 *2 Sample Catchers Years Days Technician Days Emil Opitz 2 20 Dean Kekuaulua 2 24 Allen Williams 2 Zach Beekman 2 17 Zach Mester 1 5 Howard Lamp 3 John Lundy 18 10 Doug Acker 1 19 Tollef Winslow 2 7 *1 Years experience as Mudlogger *2 Days at wellsite between spud and completion at a total depth of 11,240 feet. Two loggers remained at the rig until completion. RI 4 AN Nikaitchuq OP08-04 and PB1 eni 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OP08-04 API Index#: 50-029-23424-00-00 Nikaitchuq OP08-04 PB1 API Index#: 50-029-23424-70-00 Lat. 70*30' 39.76185" Field: Nikaitchuq Surface Co-Ordinates: Long.-149*51' 47.92539" Borough: North Slope Primary Targets: Schrader Bluff; OA Sand State: Alaska Primary Target Depth: 4827' MD, -3565'TVDSS Rig Name/Type: Nabors 245E/Arctic Triple TD Depth: 11240'MD/-3652.67' TVDSS Spud Date: June 20, 2010 Ground Elevation: 12.2 FT MSL TD Date: July 8, 2010 RT Elevation: 53.3' MSL @ RKB Days Drilling: 18 TD Formation: Schrader Bluff OA Sand Classification: Producer 2.2 Hole Data The Borehole extends from the surface to a TD at 11240'MD/3652.67'TVD and has three sections designated by hole diameter:the 16"Surface Borehole;the 12W Intermediate Borehole;and the 8W Production Lateral Borehole (Lateral Borehole). The well was designed as a production well. FIT Maximum Hole Section Mud Shoe Depth LOT Depth TD Dev. Casing/ Weight o- Formation ( mc) Liner MD TVD (ppg) MD TVD (ft) (ft) (ft) (ft) Conductor 154 154 Recent 8.8 0 20"casing 154 154 N/A 16" Surface Borehole 2344 2159 Ugnu 9.4 33.97 13%"casing 2333 2150 13.8 12W 5020 3634 OA Sand 8.9 84.91 9%"casing 4999 3629 12.0 8%" 11240 OA Sand 8.9 5 1/2" Liner 11113 3706 N/A CANRIG 5 Nikaitchuq OP08-04 and PB1 eni 3 GEOLOGICAL INFORMATION 3.1 Hole Information Additional Comments: The well was spudded on the 20th of June 2010, entering a pre set conductor pipe at a depth of 154', and 16" hole was drilled to a depth of 2344'. 13 3/8"surface casing was set at 2333'. The float equipment and shoe were drilled out and new hole was drilled to 2370'.A Leak Off Test(LOT)was performed to 13.8 ppg The intermediate section was drilled with a hole diameter of 12.25"to 5020' MD. Slight losses were encountered beginning at approximately 3670' MD/3290'TVD at a rate of 5-10 bph. Total losses over the intermediate section about 100 bbl. Total losses to date for this well at about 140 bbl. 9 5/8"Casing was run into the hole without difficulty and set at 5004'.After drilling out to 8797'a Leak Off Test(LOT)was 12 ppg equivalent mud weight. The hole was completed drilling 8.5" hole to a depth of 11240'MD. For additional detail, see daily summary below. 6 CANRIG IRK Nikaitchuq OP08-04 and PB1 eni 3.2 Daily Activity Summary 6/20/2010; Building spud mud. Continue rig up and work on lines. 6/21/2010; Worked on riser and R/U lines. Picked up 5"drill pipe. Picked up BHA#1 and drilled out to make room for BHA#2. Currently picking up BHA#2. 6/22/2010; Continued picking up BHA#2. Drilled ahead to 255'to make room to pick up the rest of BHA. Drilled to 788'and rig up and run Gyro Survey. Continued drilling ahead to current depth of 1268'as of report time. 6/23/2010; Continued drilling ahead to TD at 2344'. Pumped sweep and circulated at TD. Pulled out of hole with tight spot around 2180'and 1180'. Run in hole and pumped sweep. Circulated another bottoms up. Tripping out of hole as of report. 6/24/2010; Circulated several bottoms up until hole was clean. Pulled out of hole and laid down the BHA. Serviced pipe skate. Rig up casing equipment and run in hole with 13 3/8"casing. Run in hole to 2278'as of report. 6/25/2010; Finished running in hole with 13 3/8"casing and conditioned hole. Cemented casing in at a depth of 2,333.6 feet MD/2,350.9'TVD. Testing BOP as of report time. 6/26/2010; Continued to test BOP. Picked up BHA#3. Run in hole. Test casing pressure to 2500 psi for 30 minutes. Wash and ream. Drill out to shoe at 2333'. Drilled 26'of new hole to 2370'. Displaced out old mud with new mud. Run leak off test to 13.8 ppg EQMW. Drilling ahead as of report. 6/27/2010; Drilling ahead from 2370'to depth as of report at 3930'. 6/28/2010; Continued to drill from 3930'to TD at 5020'. High gas was at 700 units. Circulated 2 bottoms up before beginning to trip out. Tripping out of hole as of report. 6/29/2010; Circulated 2 bottoms up then pulled out of hole on elevators. Serviced rig, changed and tested rams. Running in hole with 9 5/8"casing. Currently at 2000'as of report. 6/30/2010; Continued running in 9 5/8" casing to a depth of 5000' without issues. Conditioned hole and cemented. Plugs bumped and held. Empty and cleaned pits to change mud. Picking up pipe as of report. 7/1/2010; Continued to pick up pipe and clean mud pits. Run in hole to 3300'stop and circulate. Continue running in hole to bottom and circulate bottoms up. Test casing as of midnight. 7/2/2010; Drill out of cement, perform LOT. Drill ahead 7/3/2010; Drilled ahead as of midnight last night. RigWatch locked up and was down for a couple of hours in the early morning. Drilled ahead. Continuing to drill as of report. 7/4/2010; Circulate and prepare for sidetrack at 8123'; begin open hole sidetrack, work/rework section to 8175'. Steering tool failure. Circulate hole clean and pull out of the hole to surface. Lay down steering tool. L/D nuclear source. Download MWD data. Test BOPs. 7/5/2010; Continue testing BOPs per plan.Pick up/make up BHA#6,load nuclear source and run into hole to bottom. Orient and locate sidetrack. Drill ahead from 8176'to 9035' 7/6/2010; Drill from 9035'to 10490'. 7 CANRIG Nikaitchuq OP08-04 and PB1 eni 7/7/2010;Drill to TD at 11240'at 09:40AM. Rotate and reciprocate while circulating hole clean. Wipe 10 stands. Run into hole to bottom. Circulate hole clean, 141u Gas. Continue circulating hole clean. Pull out of the hole with elevators 18 stands. Continue wiping hole back reaming to 8452'. 7/8/2010; Drill to TD at 11240'at 09:40AM.Rotat and reciprocate while circulating hole clean.Wipe 10 stands. Run into hole to bottom. Circulate hole clean, 141u Gas. Continue circulating hole clean. Pull out of the hole with elevators 18 stands. Continue wiping hole back-reaming to 8452'. 7/9/2010;Continue wiping hole,back-reaming to casing shoe at 4999'.Cut and slip drilling line. Run into hole to bottom. Circulate hole clean. Wiper gas 297u. Continue circulating hole clean. Displace to new mud. Mix and pump dry job. 7/10/2010; Pull out of the hole on elevators 41 stands. Continue pulling out of the hole laying down singles. Lay down 272 singles.Lay down BHA/MWD,lay down nuclear source and download MWD data.Rig up to run production liner.Run into hole with production liner. 7/11/2010; Run 5.5"slotted liner, lay down drill pipe, run in production pumps 7/12/2010; Test Plug assembly to 10,000 PSI for 15 min. Rig up and run 4.5"tubing 7/13/2010; Nipple down BOPs. Nipple up and test production tree. 8 CANRIG Nikaitchuq OP08-04 and PB1 enu 3.3 Target and Reference Well Correlation Points Surface OP08-04 Prognosis P03-P03PB1 OP-11 1 OP-12-PB01 OP26-DSPO2 MD TVDSS TVDSS TVDSS TVDSS TVDSS SV-4 719 -665 -657.7 -659.1 SV-3 970 -910 -907.6 -902.8 SV-2 1243 -1172 -1174.0 -1169.0 -1163.2 SV-1 1777 -1663 -1671.1 -1671.2 -1647.0 -1648.1 Permafrost Base 1900 -1725 -1722.1 -1726.8 -1724.3 Ugnu Top(UG4) 2158 -1971 -1984.8 -1984.8 -1931.5 -1957.2 13 3/8 SCP 2345 -2120 UG-2 Coal Marker 2757 -2447 -2512.7 -2488.2 -2422.0 -2428.2 L Ugnu 3618 -3117 -3140.3 -3274.3 -3060.0 -3122.5 Schrader Bluff 3985 -3326 -3387.3 -3511.3 -3341.9 -3325.0 N Sand Top 4184 -3406 N Sand Bottom 4324 -3450 -3523.5 -3640.5 -3424.4 -3423.3 OA Sand Top 4827 -3565 -3789.6 -3518.2 -3536.4 Fault 1 No Prog. 9 5/8" ICP 5920 -3572 Total Depth 10938 -3707 Final Top Picks: LWD tops and bases refer to provisional picks by the wellsite geologist. 9 CANRIG Nikaitchuq OP08-04 and PB1 enu 3.4 Lithostratigraphy ENI PROGNOSED LWD PICK FORMATION MD TVD/TVDSS MD TVD/TVDSS (ft) (ft) (ft) (ft) SV-4 719 717/-665 717 714/-662 SV-3 970 962/-910 973 985/-933 SV-2 1243 1224/-1172 1251 1224/-1172 SV-1 1777 1715/-1663 1785 1687/-1635 Permafrost Base 1900 1777/-1725 1874 1765/-1713 Ugnu Top(UG4) 2158 2023/-1971 2181 2024/-1972 13'/5"Surface Casing Point 2345 2172/-2120 2333 2150/-2098 TD 16" Hole Section 2344 2159/-2107 UG-2 Coal Marker 2757 2499/-2447 2778 2517/-2465 L Ugnu 3618 3169/-3117 3623 3183/-3131 Schrader Bluff 3985 3378/-3326 3974 3373/-3321 N Sand Top 4184 3458/-3406 4191 3459/-3407 N Sand Bottom 4324 3502/-3450 4314 3502/-3450 OA Sand Top 4827 3617/-3565 4976 3627/-3575 Fault 1 4920 3624/-3572 4999 3629/-3577 9%" Int.Casing Point 4920 3624/-3572 4999 3629/-3577 TD 12.25"Hole Section 5020 3631/-3579 Total Depth 10938 3759/-3707 11240 3706/-3653 10 CANRIG Nikaitchuq OP08-04 and PB1 eni 3.5 Mudlog Summary The Permafrost section of the OP08-04 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, contained no hydrocarbon shows. Permafrost Section; Recent/Quaternary Deposits-Surface to 2181.6' MD/-1971.0'TVDSS Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 378 7 185 292 0 40 This interval extends from surface down to the top of the Ugnu at 2181.6' 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. Claystone (1000-1090) = medium gray to olive gray to predominantly medium gray, slightly adhesive, moderately cohesive, cuttings in sample are clumpy, dull earthy luster, silty to gritty texture, very slightly calcareous with minimal reaction to hcl. Sand (1000-1060) = dark gray to gray to dark reddish brown, abundant clear quartz, lower fine to lower medium grain fair to moderately sorted, subangular, moderate to high sphericity,trace blue green to green glauconite<5%, scattered pyrite throughout sample>5%. Claystone(1090-1110)=olive gray to dark gray to medium gray,moderately adhesive,moderately cohesive, dull earthy luster, silty to clayey texture, slight to no reaction with hcl. Claystone (1120-1180) = medium gray to predominantly dark gray, slightly to moderately adhesive, moderately cohesive, cuttings are clumpy to pasty,dull earthy luster,silty to gritty texture, gritty due to sand reworked into clay. Claystone (1180-1210) = medium gray to dark gray to medium dark gray, slightly to moderately adhesive when prodded, moderately cohesive,massive cuttings habit,cuttings over the shakers are clumpy,dull earthy luster, clayey to smooth texture, no reaction to hcl. Claystone (1210-1270) = medium gray to dark gray to medium dark gray, slightly to moderately adhesive when prodded, moderately cohesive,massive cuttings habit,cuttings over the shakers are clumpy,dull earthy luster, clayey to smooth to very slightly gritty texture, gritty texture due to sand being reworked into clay, no reaction to hcl. Claystone (1270-1300) = medium gray to dark gray to medium dark gray, slightly to moderately adhesive when prodded, moderately cohesive,massive cuttings habit,cuttings over the shakers are clumpy,dull earthy luster, clayey to smooth texture, no rxn to hcl. Claystone(1300-1390)=olive gray to brownish gray to medium gray throughout sample interval;slightly to moderately adhesive;moderately cohesive;comes over shakers as mechanically reworked globular masses containing sand grains;dull earthy luster;smooth clayey to silty texture turning to more gritty and granular with increasing depth due to inclusion of sand and gravel grains; no reaction to hcl. 11 CANRIG Nikaitchuq OP08-04 and PB1 eni Sand/Conglomeratic sand(1330-1450)=translucent to milky white to brownish black to olive gray to grayish orange pink grains throughout sample interval; sand grains sizes typically range from upper fine to lower coarse;fair sorting;subangular to subrounded with moderate to low sphericity;conglomerate sand consists of bb to pea sized grains; poorly sorted; subrounded to rounded typically with low to moderate sphericity; accessory minerals consist of the following throughout the sample interval; micas, namely muscovite;fine to medium grained black lithics; few brilliant green to light blue green to translucent light green fine grained glauconite; pyrite is fairly abundant throughout sample interval both as individual crystal grains and as growths on the surfaces of the sand and gravel grains, as well as inclusions within the same grains; no reaction to hcl. Sand/Conglomeratic sand (1450-1570) =translucent to olive gray to brownish black to milky white to few grayish orange pink grains throughout sample interval; sand grains ranged from upper very fine to lower coarse; poorly sorted throughout sample interval; subangular to subrounded with moderate to low sphericity; conglomeratic sands consist of pea to bb sized grains and is mostly poorly sorted;subrounded to rounded with low to moderate sphericity; accessory minerals include fine to medium grained black lithics; micas, both small books and disseminated sheets of mainly muscovite; brilliant green to light blue green to moderate green to translucent light green fine grained glauconite; pyrite is both individual grains and crystal growths and inclusions within other mineral grains; no reaction to hcl. Sand (1570-1660) = translucent to brownish black to olive gray to some grayish orange pink grains; size ranges from upper fine to lower medium throughout interval and is well sorted; subangular to subrounded; moderate sphericity;few micaceous pieces throughout samples;pyrite is in this interval both as independent grains and as growths on the surfaces and within other minerals; no reaction to hcl. Sand (1660-1750) =translucent to olive gray to brownish black to grayish orange pink; upper fine to lower medium grain size with angular coarse grains interdispersed throughout sample interval; subangular to subrounded;moderate to low sphericity;some small pieces of mica,mostly muscovite;pyrite occurs as grains and also as growths on the surfaces and within the other minerals in this sample interval; no reaction to hcl. Sand(1750-1840)=olive gray to translucent to brownish black;upper fine to upper medium with occasional lower fine grains; subangular to angular to subrounded; low to moderate sphericity; muscovite fragments throughout sample interval;brilliant green to light green to translucent light blue green glauconite occasionally seen in samples;pyrite occurs both as individual crystalline grains and as growths within and on the surfaces of other minerals; no reaction to hcl. Claystone (1780-1840) = olive gray to brownish gray to medium gray; slightly to moderately adhesive; moderately cohesive;comes across shakers as mechanically reworked globular masses containing sand and conglomerate and other accessory minerals;dull earthy luster;smooth clayey to gritty texture when including sand grains; no reaction to hcl. BASE OF THE PERMAFROST: 1874.4' MD/-1711.7'TVDSS Sand(1840-1960)=translucent to olive gray to brownish black throughout sample interval;lower fine to upper medium with occasional coarse grains;subangular to angular to subrounded;moderate to low sphericity;fine grained black lithics within samples; pyrite occurs both as individual grains and as growths within and on the surfaces of other grains in samples;some carbonaceous material in the 1900-1960 interval as petrified wood, some poorly developed; no reaction to hcl. Claystone(1860-2020)=olive gray to medium gray to brownish gray throughout sample interval; slightly to moderately adhesive;moderately cohesive;samples are reworked masses containing sand and pebbles and accessory minerals; curdy and mushy consistency; dull earthy luster; smooth clayey texture to gritty texture when included with sand grains; no reaction to hcl. Sand(1960-2050)=olive gray to translucent to medium gray to brownish black; upper fine to upper medium 12 CANRIG Nikaitchuq OP08-04 and PB1 eni with some lower fine grains; subangular to angular to subrounded with moderate to low sphericity; pyrite occurs as individual grains and also as crystalline growths within and on the surfaces of other grains in the samples; no reaction to hcl. Claystone(2020-2110)=olive gray to brownish gray to medium gray throughout sample interval; slightly to moderately adhesive; moderately cohesive; samples are reworked globs containing sand and pebbles and accessory minerals;curdy consistency;dull earthy luster;smooth clayey texture to gritty texture when included with sand grains; no reaction to hcl. Sand(2050-2140)=olive gray to translucent to medium gray to brownish black; lower fine to upper medium with some coarse grains;subangular to angular to subrounded;moderate to low sphericity;pyrite occurs both as individual grains and also as growths within and on the surfaces of other grains in the samples; no reaction to hcl. Sand(2140-2230)=translucent to olive gray to medium gray to brownish black; lower fine to upper medium throughout sample interval; subangular to angular to subrounded with moderate to low sphericity; pyrite throughout samples occurs both as crystalline grains and as growths within and on the surfaces of other grains; coal is within the interval of 2140 and 2180; decently developed lignite; blocky fracture; wedgelike tabular cuttings habit; dull earthy to slightly resinous luster; matte like texture occasionally; no visible structures. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 1449 73 16692 1629 203 40460 1712 180 35569 1800 308 60005 2147 106 21891 Ugnu Top(UG4): 2181.6' MD/-1971.0'TVDSS Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 330 3 147 45 0 16 The Ugnu formation consists of two units, upper and lower Ugnu. The upper portion of the formation is essentially similar in nature and appearance to the overlying material. However,the sands are generally finer grain and exhibit slightly greater wear through transport/erosion. The section consists primarily of thickly bedded sand/sandstone occasionally grading to sandstone conglomerate and conglomerate.Moderate to thin claystone and siltstone interbeds occur throughout. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Sand (2230-2344) =olive gray to translucent to medium gray to brownish black; lower fine to lower medium with some upper medium grains; subangular to angular to subrounded, moderate to low sphericity; moderate to well sorted; pyrite occurs throughout the sample as both individual grains and as growths within and on the surfaces of other grains in the samples; no reaction to hcl. Claystone(2230-2344)=olive gray to brownish gray to medium gray throughout sample interval; slightly to moderately adhesive; moderately cohesive; samples are reworked globs containing sand and pebbles and accessory minerals; curdy consistency; dull earthy luster; smooth to clayey to gritty texture, gritty texture comes from the reworking of sand grains in with clay, no reaction with hcl. 13 CANRIG Nikaitchuq OP08-04 and PB1 eni Sand (2380-2430) =translucent to light olive gray to medium light gray to brownish black, upper very fine to lower medium,well sorted, angular to subangular with low to moderate sphericity, scattered pale blue green to bluish green glauconite throughout, trace black lithics scattered in sample, no reaction to hcl. Sand(2440-2530)=translucent to light olive gray to light gray to brownish black with quartz being mainly clear to translucent, upper very fine to lower upper fine to few lower medium, moderate to well sorted, angular to subangular with low to moderate sphericity, quartz predominately clear to translucent white to very light gray,trace black lithic throughout the sample interval with trace orange lithics in the 2470 sample, pale blue green to bluish green glauconite throughout sample interval, non calcareous, no reaction to hcl. Sand(2530-2590)=overall sample color is medium light gray, color ranges from light gray to medium gray, moderately sorted to well sorted, lower medium to upper fine and upper very fine grained, angular to subangular with low to moderate sphericity, quartz are predominately very light gray to translucent white to clear, trace to abundant dark minerals and lithics, slight amount of carbonaceous material, thinly interbedded coal/carbonaceous beds, mainly grain supported with locally clay matrix supported, slightly calcareous with low reaction to hcl. Sand(2590-2680)=overall sample color is medium light gray, color ranges from light gray to medium gray, moderately sorted to well sorted, lower medium to upper fine and upper very fine grained, angular to subangular with low to moderate sphericity, quartz are predominately very light gray to translucent white to clear,trace to abundant dark minerals and lithics,trace to abundant pale blue green to bluish green glauconite,thinly interbedded claystone/carbonaceous beds, mainly grain supported with locally clay matrix supported, slightly calcareous with little reaction to hcl. Sand (2680-2740)= light gray to medium light gray, moderately sorted, angular to subangular with low to moderate sphericity, soft to friable, quartz very light gray to translucent white to clear predominates, pale blue green to bluish green glauconite throughout sample, slightly calcareous with little reaction to hcl. Carbonaceous shale(2710-2780)=black to brownish black to dusky brown; crumbly to crunchy and brittle; subblocky fracture; mostly tabular cuttings; dull earthy to slightly waxy greasy luster; matte texture; some thin fissile laminae throughout sample interval of dark to dusky brown; some oxidation has occurred leaving reddish brown to dark brownish red cuttings; interbedded with minor claystones and sands. Sand(2740-2860)=translucent to medium gray to milky white; lower fine to upper medium with some coarse grains throughout sample interval; subangular to angular to few subrounded grains; moderate to poor sphericity; samples are all abundant with fine to very fine grained black lithics giving a salt and pepper appearance; brilliant green to moderate green to translucent blue green glauconite throughout sample interval, fine to medium grained, subrounded to subangular with high to moderate sphericity, some samples have>10%; pyrite occurs throughout samples both as individual grains and as growths on the surfaces and within other minerals, approximately 5%; micaceous sheet fragments, namely muscovite, noted throughout sample interval, <5%; slight reaction to hcl, partly due to some shell fragments; shell fragments are white with medium gray streaks; no sample fluorescence. Sand(2860-2980) =translucent to milky white to medium gray to dusky brown; upper fine to lower medium with some lower fine and upper medium grains; very well sorted throughout sample interval; subangular to subrounded with moderate sphericity; very fine to fine grained black lithics throughout sample interval giving a salt and pepper appearance; bluish green to moderate green to translucent brilliant green fine grained glauconite, subrounded to subangular with moderate to high sphericity, 5-10%; pyrite occurring both as growths on the surfaces and within grains, but more commonly as individual crystalline grains throughout sample interval, approximately 5%; mica fragments, mostly muscovite,white to light gray with a vitreous luster and an opalescent sheen, <5%; very slight reaction to hcl. Siltstone(3030-3150)= light gray to medium gray with some light brown hues throughout sample interval; soft to easily friable; consistency is generally mushy and pasty to semi clumpy; moderately cohesive; RIG 14 CAN Nikaitchuq OP08-04 and PB1 eni moderate to poor adhesiveness; massive cuttings come over shakers as reworked blobs with sand and other mineral grains consolidated within the masses; dull earthy to slightly vitreous and waxy luster; clayey silty to gritty texture, depending on the amount of sand grains worked into the masses; otherwise a clayey siltstone throughout sample interval; no reaction to hcl. Sand(2980-3200)= medium gray to translucent to milky white to dusky brown; mostly upper fine to lower medium with upper medium and lower fine grains intermixed at lesser quantities; very well sorted; subangular to subrounded to angular; moderate sphericity; fine to very fine black lithics giving a salt and pepper appearance; translucent bluish green to brilliant green fine grain glauconite, subrounded to subangular with moderate to high sphericity, approximately 5-10%; rare mica sheet fragments, muscovite, white to very light gray with a vitreous luster and opalescent sheen; slight reaction to hcl. Siltstone(3150-3270)= medium gray to light gray to dusky brown in some cuttings; samples consist of reworked globular masses containing sand and other accessory mineral grains; grades between clayey siltstone and silty claystone throughout the interval; mushy and pasty consistency; moderately cohesive; slightly adhesive; texture varies between clayey silty to silty and gritty; very slight reaction to hcl. Sand(3200-3340)=translucent to light gray to medium gray to milky white with some dusky brown grains; lower fine to upper medium throughout sample interval; subangular to angular to occasional subrounded grains with moderate to low sphericity; fine to very fine black lithics giving a salt and pepper appearance; bluish green to brilliant green to translucent moderate green glauconite, very fine to fine grained, subrounded to subangular with moderate sphericity, approximately 5-10%; occasional pyrite growths on the surface of other mineral grains were seen; slight reaction to hcl. Siltstone(3270-3350)= light gray to medium gray to dusky brown; samples consist of mechanically reworked globular masses containing sand and other accessory minerals; cuttings grade between silty claystone and clayey siltstone throughout the sample interval; mushy to pasty consistency; moderately cohesive; slightly to non adhesive;texture follows makeup of cuttings, varying from silty and clayey to gritty and silty; no reaction to hcl. Sand (3340-3550)=translucent to milky white to medium gray to dusky brown; lower fine to upper medium grains throughout sample interval;well sorted; subangular to angular to subrounded with moderate to low sphericity;very fine to fine grained black lithics throughout sample interval giving a salt and pepper appearance; bluish green to translucent brilliant green to moderate green fine to very fine grained glauconite, subrounded to subangular with moderate sphericity, approximately 5-10%throughout sample interval; pyrite occurs both as individual crystalline grains and as growths occurring within and on the surfaces of other mineral grains, approximately 5%; slight reaction to hcl. Siltstone(3490-3610)= light gray to medium gray to dusky brown; samples consist of mechanically reworked globular masses containing sand and other accessory minerals; cuttings grade between silty claystone and clayey siltstone throughout the sample interval; mushy to pasty consistency; moderately cohesive; slightly to non adhesive; texture follows makeup of cuttings, varying from silty and clayey to gritty and silty; no reaction to hcl. LOWER UGNU at 3623.3' MD/-3129.7'TVDSS Sand (3610-3700) = translucent to milky white to medium gray to dusky brown, upper very fine to upper medium grains well sorted,subangular to angular,moderate to low sphericity,very fine grain black lithics still present giving salt and pepper appearance,easy friable to friable, locally gritty to granular,trace pyrite found only as individual crystalline to very few growths on other grains,very pale green to brilliant green glauconite, upper very fine to lower medium grained, subrounded to subangular with moderate sphericity, slightly to moderately calcareous. Siltstone(3670-3730)=light gray to medium gray to dusky brown,samples consist of mechanically reworked 15 CANRIG Oki Nikaitchuq OP08-04 and PB1 eni globular masses containing sand and other accessory minerals, cuttings grade between silty claystone and clayey siltstone throughout the sample interval, mushy to pasty consistency, very soft to few easily friable, moderately cohesive,slightly to non adhesive,texture follows makeup of cuttings,varying from silty and clayey to gritty and silty, no reaction to hcl. Sand (3700-3790)=translucent to milky white to medium gray to dusky brown, lower fine to upper medium grains well sorted, subangular to angular, moderate to low sphericity, very pale green to brilliant green glauconite, upper very fine to lower medium grained, subrounded to subangular with moderate sphericity, slightly calcareous. Sand(3790-3850)=transparent to milky white to very light gray to dusky brown, upper fine to upper medium grained,poor to moderate sorting,subangular to angular to trace subrounded,low to moderate sphericity,fine grained black lithics throughout sample gives a salt and pepper appearance, decreased amounts of glauconite, all very fine to fine grained, scattered trace amounts of orange lithics; sand is slightly calcareous, slight reaction to hcl. Sand (3850-3910) = clear to milky white to medium gray to dusky brown, upper fine to upper medium predominate with few lower fine grained, moderately sorted, subrounded to subangular to locally angular grains, low to moderate sphericity, quartz grains vary between transparent to slightly smokey to light gray, trace pyrite, glauconite ranges from very pale green to brilliant green, sample is slightly calcareous. Siltstone(3910-4000)=light gray to medium gray to dusky yellowish brown,sample consist of mechanically reworked globular masses containing sand and other accessory minerals, cuttings grade between silty claystone and clayey siltstone throughout the sample interval, mushy to pasty consistency, moderately cohesive,slightly to moderately adhesive,texture follows makeup of cuttings,varying from silty and clayey to gritty and silty, no reaction to hcl. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 2763 38 6472 3038 41 7589 3153 45 8900 3312 35 7336 Schrader Bluff: 3974.0' MD/-3320.0'TVDSS Drill Rate(ft/hr Total Gas(units) Maximum Minimum Average Maximum Minimum Average 260 3 111 700 0 101 The upper portion of the Schrader Bluff is a series of moderately thick sand beds separated by intervening siltstone interbeds.The lower part of the formation gradually becomes dominated by siltstone and claystone with minor sand interbeds.This well encountered significant oil shows in the"OA"sands. The bottom(lateral) section of the hole was drilled with periscope steering in order to drill lateral production footage in both the upper and lower lobes of the"OA"sand. Sand (3910-4110) = a medium gray to light gray semblance consisting of translucent to light gray to milky white to dusky brown quartz grains;lower fine to upper medium with some coarse grains throughout interval; subangular to angular to subrounded; moderate to poor sphericity; samples contain fine to very fine black lithics;translucent light green to bluish green to brilliant green glauconite throughout sample interval,fine to medium grained, subrounded to subangular with moderate to high sphericity; pyrite occurs throughout samples both as individual grains and as growths within and on the surface of other mineral in the samples, approximately 5-10%; high reaction to hcl, however primarily attributed to safe carb mud additive. 16 CANRIG Nikaitchuq OP08-04 and PB1 em Siltstone(4000-4210)= medium gray to light gray; predominantly soft to some easily friable cuttings; most cuttings are reworked globular masses of clayey siltstone and silty claystone with sand and other accessory mineral grains worked in as well;moderately cohesive;slightly adhesive when prodded;dull earthy to a slightly vitreous and waxy luster throughout sample interval;texture varies depending on clay to silt ratio as well as amount of sand and other mineral grains within the mass, generally silty clayey to gritty and silty; some pure brittle siltstone cuttings contain reddish brown to dusky brown thin laminations;no noticeable reaction to hcl above safe carb additive. TOP"N"SAND at 4191.0' MD/-3405.9'TVDSS Sand(4110-4350)=light gray to medium gray semblance of light gray to translucent to milky white to dusky brown quartz grains; lower fine to upper medium throughout sample interval; subangular to angular to subrounded with predominantly moderate sphericity; samples consist of very fine to fine black lithics; light green to translucent brilliant green to moderate green glauconite,fine to very fine,subrounded to subangular, moderate to high sphericity, approximately 5%; pyrite grains occur as individual crystals and as growths on other mineral surfaces,<5%;shell fragments are seen occasionally,pale yellowish orange to moderate orange pink to moderate reddish orange;few white to very light gray muscovite sheet fragments;approx 10%patchy moderately bright yellow fluorescence; no noticeable oil odor. Siltstone (4210-4440) = medium gray to medium light gray; cuttings are mechanically reworked globular masses containing sand and accessory minerals; grades in between clayey siltstone and silty claystone throughout sample interval;slight to poor adhesiveness;moderate cohesiveness;consistency is predominantly pasty with some mushy cuttings; dull earthy luster; texture varies with clay and silt amounts, but is typically clayey silty to silty gritty throughout sample interval;no visible structures;slight effervescence above safe carb mud additive. BASE"N"SAND at 4314.0' MD/-3449.5'TVDSS Sand (4350-4590) = light gray to translucent to milky white to dark brown grains throughout sample interval;upper very fine to lower medium predominantly;subangular to angular to subrounded with moderate sphericity;samples consist of very fine to fine black lithics;occasional grains of light green to brilliant green to translucent bluish green glauconite,very fine to medium,subrounded to subangular,moderate sphericity,<5%; pyrite occurs as individual grains as well as growths on other mineral surfaces; occasional muscovite sheet and shell fragments throughout sample interval;moderate reaction to hcl;approximately 10-20%moderately bright yellow sample fluorescence; no noticeable oil odor. Claystone (4450-4620) = medium gray to medium dark gray to medium light gray; cuttings are reworked globular masses containing decreasing amounts of sand and other accessory minerals as depth increases; cuttings intergrade between clayey siltstone and silty claystone, with increasing clay and decreasing silt as depth increases; pasty to mushy consistency; moderate to occasionally high cohesive properties; predominantly slight adhesiveness when prodded; dull earthy luster; texture varies with grain content and depth, but generally is clayey silty to silty gritty;no visible structures in samples; moderate reaction to hcl; no sample fluorescence. Siltstone(4440-4680) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; sand content increases with sample depth; very slight reaction to hcl; no sample fluorescence. Claystone(4620-4830)=medium gray to medium dark gray;reworked globular masses containing sand and other accessory mineral; pasty to mushy consistency; moderately to high cohesive; poorly adhesive; intergrades between silty claystone and clayey siltstone;dull earthy luster;silty clayey texture to locally gritty RIG 17 CAN Nikaitchuq OP08-04 and PB1 eni due to reworked sand; no reaction to hcl; no oil indicators. Siltstone (4680-4830)= medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey;no visible structures;very slight reaction to hcl; no sample fluorescence. Sand(4740-4830)=clear to light gray to dusky brown;subrounded to subangular;low to moderate sphericity; lower fine to upper medium grained;<5%pyrite throughout sample interval as individual grains and as growths on other grains;trace pale green glauconite and trace shell fragments throughout interval;very slight reaction to hcl. Siltstone (4830-5010) = light gray to medium gray; pasty consistency throughout sample interval; low to moderately cohesive;poor to non adhesive;dull earthy luster;clayey intergrades between silty claystone and clayey siltstone,with increasing silt and decreasing clay with depth;silty to gritty to locally clayey texture;gritty texture varies due to increase in amount of reworked sand and accessory minerals; no visible structures; no reaction to hcl. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 4018 80 17559 60 4163 140 24680 191 60 86 40 63 20 4202 392 62937 591 243 308 193 233 64 4294 528 88612 885 322 256 125 149 22 4404 371 62238 637 275 211 108 138 22 4571 91 15461 137 80 55 61 63 32 4657 60 9948 83 60 47 46 50 33 4819 111 18368 173 135 88 109 60 41 TOP"OA"SAND at 4976.0' MD/-3574.4'TVDSS Sand (4950-5020) = clear to very light gray to medium gray; upper very fine to upper fine; subangular to subrounded with low to moderate sphericity; moderately to well sorted;trace orange lithics,shell fragments, and brilliant green glauconite; slightly calcareous; slight odor, 50%-60% light brown stain, 50% even dull yellow fluorescence, streaming amber cut with streaming bright white cut fluorescence, heavy dark brown residue with dull yellow residue fluorescence. "OA"SAND Sub-Lobe 3 at 5085.5' MD/-3581.5'TVDSS Sand/Sandstone(5020-5140) =olive black to brownish black semblage of translucent to very light gray to light gray individual grains; upper very fine to lower fine with occasional upper fine grains; very well sorted; subangular to subrounded with moderate to high sphericity;translucent brilliant green to moderate green to bluish green fine grained glauconite, subrounded, high sphericity, approximately 5-10%; approx 10% black lithics throughout sample interval; moderate orange pink to pale yellowish orange shell fragments increasing in abundance as with depth;moderate to strong oil odor;dark to light brown stain within sandstone cuttings when prodded open;even to 75%patchy moderately bright yellow to orange within opened sandstone cuttings sample fluorescence;streaming bright white to immediate bright bluish white cut fluorescence;amber to dark brown visible cut; dark straw to amber cut residue; dull yellow residue fluorescence. CAN 18 Nikaitchuq OP08-04 and PB1 enl "OA"SAND Sub-Lobe 4 at 5215.0' MD/-3591.9'TVDSS Sand/Sandstone(5140-5290)=olive black to brownish black overall;clear to light gray to medium light gray individual grains; upper very fine to lower fine grained; very well sorted; cuttings are friable to firm friable; subangular to subrounded with moderate sphericity;light green to moderate green glauconite;fine grain;high sphericity; 5-10% in samples throughout interval; moderate to strong odor; dark to light brown stain within sandstone cuttings when broken open; 60-80% patchy dull yellow to orange fluorescence within opened sandstone cuttings; streaming bright white fluorescence cut, amber to dark brown visible cut; dark stray to amber cut residue; dull yellow residue fluorescence. Sand/Sandstone(5290-5410)=olive black to brownish black overall sandstone;transparent to very light gray to light gray individual sand grains; upper very fine to upper fine;very well sorted;subangular to subrounded with moderate to high sphericity;sandstone cuttings are friable to firm friable;very calcareous; light green to moderate green glauconite; fine grained; high sphericity and about 5-10% in samples throughout interval; moderate to strong odor;light brown stains within sandstone cutting when prodded open;even to 75%patchy dull yellow fluorescence to 25% patchy orange within opened sandstone cuttings; streaming bright white fluorescence cut; amber to dark brown visible cut; dark straw to amber cut residue; dull yellow residue fluorescence. "OA"SAND Sub-Lobe 4 at 5403.0' MD/-3592.4'TVDSS Sand/Sandstone(5410-5530) =dark gray to brownish black to grayish black assemblage of transparent to very light gray to light gray individual grains;disaggregated sand;upper very fine to lower fine with occasional upper fine grains;well sorted;subangular to subrounded with moderate to high sphericity;5-10%throughout the sample interval of light green to translucent brilliant green to moderate green fine grained glauconite; subrounded with moderate to high sphericity; approx. 10% upper very fine grained black lithics throughout sample interval; low to moderate odor mainly masked by oil based mud; even dull yellow fluorescence also due to oil based med; streaming bright white fluorescence cut; light straw to straw visible cut; no visible residue; very dull yellow residue fluorescence. Sand/Sandstone (5530-5650) = medium light gray to olive gray to medium dark gray assemblage of transparent to very light gray to light gray individual grains;disaggregated sand;upper very fine to lower fine with occasional upper fine grains; well sorted; subangular to subrounded with moderate to high sphericity; approximately 5% shell fragments in the 5620-5650 sample interval; very calcareous; approx 5-10% throughout the sample interval of light green to translucent brilliant green to moderate green fine grained glauconite;subrounded with moderate to high sphericity; 10%upper very fine grained black lithics throughout sample interval; no oil stain present in sample interval; low to moderate odor mainly due to oil based mud; even dull yellow to 10-20%patchy orange fluorescence;streaming bright white fluorescence cut;light straw to straw visible cut; no visible residue; dull yellow residue fluorescence. Sand/Sandstone(5650-5680)= medium light gray to olive gray; upper very fine to upper fine grained;well sorted;moderate sphericity;disaggregated sand;very calcareous;approximately 5%fine grained glauconite; subrounded with moderate to high sphericity;low odor even dull fluorescence;light straw visible cut;no visible residue; dull yellow residue fluorescence. Sandstone(5680-5740) =dusky yellowish brown to brownish black to grayish black; very fine grain; easily friable;calcareous cemented extremely reactive to hcl;approx 5-10%shell fragments throughout interval;little to no odor; 10-20% patchy fluorescence; streaming bright white to dull yellow cut fluorescence; light straw visible cut;very dull yellow residue fluorescence. Sand/Sandstone(5740-5800) = light gray to olive gray to medium light gray; predominately transparent to translucent disaggregated quartz sand; upper very fine to lower fine with occasional upper fine grains; moderate well sorted;subangular to subrounded with high sphericity;sandstone pieces are hard to very hard and cemented; little to no odor above obm; 10-20% patchy dull yellow sample fluorescence. 19 CANRIG Nikaitchuq OP08-04 and PB1 eni Sand/Sandstone(5800-5950)=olive black to brownish black to medium dark gray semblage of translucent to light gray to very light gray quartz grains; predominantly upper very fine to lower fine with occasional lower very fine and upper fine grains throughout sample interval; very well sorted; subangular to subrounded with moderate to high sphericity; bluish green to translucent brilliant green to moderate green very fine to fine grained glauconite,subrounded to subangular,high sphericity,approximately 5-10%;approximately 10-15% very fine to fine grained black lithics throughout sample interval; pale yellowish orange to moderate orange pink to dark yellowish orange shell fragments;moderate to slight oil odor;most sandstone cuttings have brown stain inside when prodded apart; 30-50% patchy bright yellow to orange sample fluorescence transitioning to 100%even moderately bright yellow with few dark yellow to orange scattered cuttings as depth increases; streaming bright white cut fluorescence; amber to light amber visible cut; light pale straw visible cut residue; dull yellowish white cut residue fluorescence. "OA"SAND Sub-Lobe 4 at 6031.0' MD/-3604.8'TVDSS Sand/Sandstone(5950-6070)= brownish black to olive black to dark gray semblage of translucent to light gray to very light gray individual grains;upper very fine to lower fine with some lower very fine grains;very well sorted;subrounded to subangular;moderate to high sphericity;bluish green to moderate green to translucent brilliant green very fine to fine grained glauconite, predominantly subrounded with high sphericity, approximately 5-10%; fine to very fine grained black lithics throughout sample interval, approximately 10%; moderate to slight oil odor above obm;light brown to dark brown oil stain within sandstone cuttings observed when prodded open; 90-100% even moderately bright yellow sample fluorescence, oil stained split open sandstone cuttings fluoresce dark yellow to orange;immediate faint to dull white cut fluorescence;light amber to dark straw visible cut; medium dark straw to amber visible residue; bright white residue fluorescence. Siltstone/Shale (6070-6220) = grayish black to olive black to brownish black throughout sample interval; moderately hard to friable predominantly with occasional friable and hard cuttings; tough and dense to few crumbly cuttings; subblocky fracture; wedgelike massive tabular cuttings habit; resinous and greasy on the exterior surfaces of cuttings,and typically waxy luster on interior surfaces of prodded and split open cuttings; silty smooth to silty and gritty texture throughout sample interval;grades from shaly silt to silty shale;moderate reaction to hcl; slight oil odor noticed above obm; due to color of cuttings, amount of stain is difficult to estimate, however light brown stain can be seen on some cuttings; even moderately dull yellow sample fluorescence grades to 50-60% patchy bright orange to yellow as depth increases; slow blooming dull white cut fluorscence; straw visible cut; light amber visible residue; moderately bright yellowish white residual fluorescence. "OA"SAND BASE at 6274.0' MD/-3623.6'TVDSS Shale/Siltstone(6220-6400)=olive black to brownish black to grayish black;moderately hard to firmly friable to hard throughout sample interval;tough and dense tenacity with occasional crumbly cuttings; subblocky to planar fracture;tabular wedgelike massive cuttings habit; greasy resinous luster on the exterior surfaces of cuttings, with waxy to slightly vitreous luster when prodded and split open; silty and gritty to occasional silty smooth texture throughout sample interval;no visible structures;slight reaction to hcl;slight odor above obm; due to color of cuttings, stain is difficult to estimate; approximately 40-60% patchy dark yellow to yellow to orange sample fluorescence;slow streaming bright milky white cut fluorescence;amber visible cut;heavy dark brown visible cut residue; bright yellow to orange residual fluorescence. Shale/Siltstone (6400-6490) = brownish black to olive black to grayish black throughout sample interval; moderately hard to firmly friable to occasional friable cuttings; tough dense tenacity; subblocky fracture; massive tabular and wedgelike cuttings habit; greasy resinous exterior surface luster on cuttings; waxy to slightly vitreous luster when prodded and on interior surfaces when cuttings are split open;silty gritty texture; moderate reaction to hcl;slight to no oil odor above obm;due to color of cuttings,stain is difficult to estimate; 0-10%patchy dull yellowish white fluorescence;very slow faint white cut fluorescence;pale straw visible cut; no visible residue;faint bluish white residual fluorescence. CANRIG Nikaitchuq OP08-04 and PB1 eni Shale/Siltstone(6490-6580) = olive black to brownish black to grayish black throughout sample interval; moderately hard to friable;tough dense tenacity;subblocky fracture;massive tabular wavelike cuttings habit; resinous greasy luster on exterior cuttings surfaces,waxy and slightly vitreous luster when prodded as well as on the interior surfaces of split open cuttings; gritty and silty texture throughout sample interval; no visible structures; moderate reaction to hcl; very slight to no oil odor; because of the color of the cuttings, stain is difficult to estimate; 0-10% patchy dull yellowish orange sample fluorescence; very slow dull white cut fluorescence; straw visible cut; no visible residue;faint yellow residual fluorescence. Shale/Siltstone(6580-6700)=dark gray to olive black to grayish black;firm friable to moderately hard;dense to tough tenacity; subblocky facture; massive tabular cuttings habit and buttercurl cuttings habit throughout; waxy to greasy luster;silty to gritty texture; moderate to high reaction with hcl;no visible structures exist;little to no odor present;sample shows little to no stain; 10-20%patchy yellowish orange sample fluorescence;dull white cut fluorescence; no visible cut; no visible residue; faint bluish white residual fluorescence. Sand (6690-6720) = clear to translucent to milky white quartz sand; lower fine to upper medium with occasional upper medium grained; subangular to subrounded with high sphericity; well sorted; dull even fluorescence; faint odor; no visible stain; slow dull white cut fluorescence; no residue; faint white residual fluorescence. Shale/Siltstone (6700-6790) = olive black to brownish black to dark gray; moderately hard to firm; tough dense tenacity; irregular to subblocky fracture; massive buttercurl to tabular cuttings habit; waxy to slightly resinous luster;texture is silty increasing to gritty with depth; moderate reaction to hcl; no visible structures; very faint odor;stain is difficult to see;0-10%patchy yellow with faint orange hue fluorescence;slow dull white cut fluorescence; no visible cut; no visible residue; faint bluish white residual fluorescence. "OA" SAND Sub-Lobe 4 at 6874.0' MD/-3675.8' TVDSS Sand/Sandstone(6770-6910)=medium gray to dark gray to olive black overall;lower fine to lower medium occasional upper very fine grained;subangular to subrounded with moderate to high sphericity;predominately moderate to locally well sorted;local sandstones are soft to easily friable;oil staining is present within opened sandstone; 5% fine grained glauconite present throughout sample interval; very pale green to translucent brilliant green to moderate blue green; subrounded with moderate to high sphericity; low to moderate odor; staining present within opened sandstone pieces; approximately 50-60% patchy yellowish orange sample fluorescence; streaming translucent white cut fluorescence; streaming straw to light amber visible cut;faint amber visible residue; dull yellow residual fluorescence. Shale/Siltstone(6910-7000)=olive black to grayish black to brownish black throughout sample interval;firm to moderately hard;tough dense tenacity; irregular fracture; massive to almost platy cuttings habit; resinous greasy luster to a waxy luster when broken open or prodded; silty to gritty texture to locally granular in the scattered fine grained sandstone;no visible structures present in sample interval;no reaction to hcl;slight odor present;trace light brown stain present;20-30%patchy dull yellow fluorescence;slow dull yellowish orange cut fluorescence;slow straw to light amber visible cut; medium amber residue;dull yellowish orange residual fluorescence. "OA"SAND Sub-Lobe 4 at 7010.0' MD/-3682.0'TVDSS Sand/Sandstone(7000-7090)= medium light gray to medium dark gray to olive black overall; lower fine to lower medium grained;subangular to predominately subrounded;moderate to high sphericity;scattered light brown to moderate brown highly spherical grains; trace orange lithics; very pale green to light bluish green glauconite; subrounded with moderate to high sphericity; amount of glauconite decreases with depth; shell fragments found throughout the sample interval, amount increases with depth from trace amounts in 7000 sample to 5-10% in the 7120 sample; sample is very calcareous; sandstones are soft to easily friable; sandstones have visible oil staining; a very faint odor is present;even dull yellow sample fluorescence;slow dull yellow cut fluorescence; light straw visible cut; no visible residue; faint yellow residual fluorescence. 21 CANRIG Nikaitchuq OP08-04 and PB1 eni Sand/Sandstone(7100-7240)=medium gray to olive gray to brownish black overall;upper very fine to lower medium grained;very well sorted;subrounded to subangular with high sphericity;trace orange lithics scattered throughout sample within the interval;shell fragments still abundant but decreasing now with depth; 10-20% within the 7150 to 7180 samples but far few in deeper samples;glauconite still abundant with 5%in samples throughout the interval;very fine grained to locally lower fine;subrounded with high sphericity;sample is very calcareous and effervesces violently with hcl mainly due to mud additive;trace staining is visible;slight odor is present; overall a faint even yellow fluorescence with 30-40% patchy dull yellowish orange; streaming dull yellowish white cut fluorescence; streaming dark straw visible cut; light amount of dark straw residue; faint yellow residual fluorescence. Sand/Sandstone (7240-7330) = medium gray to dark gray to brownish black; lower fine to lower medium grained;well sorted;subangular to subrounded with moderate sphericity;very fine to fine grained glauconite ranging from translucent pale green to light blue green to moderate bluish green;sandstone pieces are soft; slight odor but could be masked by oil based mud;trace staining throughout sample interval;even dull yellow sample fluorescence; streaming dull yellow cut fluorescence; light amber visible cut; light amber visible residue; faint bluish yellow residual fluorescence. Sand/Sandstone(7330-7420)=clear to medium light gray to olive black;lower fine to lower medium clear to translucent quartz grains; subrounded to subangular with moderate sphericity; 5% very fine grained black lithics; <5%very fine grained bluish green glauconite at top of sample interval,amount increases with depth; no staining present in sand grains but trace amounts in sandstone; slight odor present; even dull yellowish white sample fluorescence streaming bright white cut fluorescence; streaming light amber visible cut; dull yellowish orange residual fluorescence, medium straw visible residue. Shale/Siltstone (7430-7540) = brownish black to olive black to grayish black; friable to firm; dense brittle tenacity; subblocky fracture; tabular to wedgelike cuttings habit; resinous to fairly greasy luster on surface, when prodded or broken open has waxy luster;silty to predominately gritty texture;no visible structures found within sample interval; very slight reaction to hcl;fair odor present in samples; stain is difficult to see due to color of samples, 70-80% patchy dull orangish yellow sample fluorescence; streaming bright white cut fluorescence;streaming light amber to amber visible cut; medium amber visible residue;dull yellowish white residual fluorescence. "OA"SAND Sub-Lobe 4 at 7537.0' MD/-3697.8'TVDSS Shale/Siltstone(7540-7630)=dark gray to brownish black to olive black firm to moderately hard;tough dense to locally brittle tenacity; irregular fracture; tabular to buttercurl cuttings habit; waxy to greasy to slightly resinous luster;silty to gritty texture to locally granular when worked in with the fine grained sands; no visible structures present;slight reaction with hcl;fair odor is present within sample interval; no stain is visible within shale/siltstone, but trace in sandstone; 60-70% patchy dull yellow to faint orange sample fluorescence; streaming bright white cut fluorescence;streaming dark brown visible cut;medium dark brown residue;heavy yellowish orange residual fluorescence. Shale/Siltstone(7630-7720)=olive black to medium gray to brownish black;firmly friable to moderately hard to easily friable; tough and dense tenacity predominantly; subblocky fracture; massive tabular to wedgelike cuttings habit;greasy resinous luster on exterior of cuttings to waxy and slightly vitreous on prodded and split open surfaces;silty to gritty to slightly clayey texture throughout sample interval;thin black laminations noticed in lighter colored cuttings; slight reaction to hcl; fragrant oil odor; approximately 50-70% patchy moderately bright yellow to orange sample fluorescence;slow blooming dull white cut fluorescence;dark straw visible cut; medium straw residue; faint yellow residual fluorescence. Sandstone/Sand(7720-7900)=olive gray to dark gray to brownish black; upper very fine to upper fine with some lower very fine grains; very well sorted throughout sample interval; subangular to subrounded with moderate sphericity;translucent to light gray to dusky brown quartz grains predominantly make up free sands; moderate green to brilliant green to light blue green very fine to fine grained glauconite grains, 22 CANRIG Nikaitchuq OP08-04 and PB1 eni subrounded to subangular with moderate to high sphericity, approximately 5-10%;fine grained black lithics throughout sample interval, 10%; moderate orange pink to pale yellowish orange shell fragments, <5%; moderate to slight oil odor above obm;sandstone cuttings exhibit dark brown staining inside when split open; even moderately bright yellow sample fluorescence for free sands,yellow to orange for sandstone cuttings; slow streaming bright white cut fluorescence; amber visible cut; light pale straw visual residue; medium dull yellowish white residual fluorescence. Sand/Sandstone(7900-8050)=olive black to grayish black to brownish black semblage of cuttings;light gray to dusky brown to translucent quartz grains;upper very fine to upper fine throughout sample interval;very well sorted; moderate sphericity; subangular to subrounded; moderate green to brilliant green to light blue green very fine to fine grained glauconite, subrounded to subangular with moderate to high sphericity, 5-10%; approximately 10-15%fine grained black lithics in samples; moderate to high reaction to hcl, in part due to safe carb mud additive; calcite supported cement; slight to moderate oil odor above obm; dark brown stain within sandstone cuttings when split open; 100%even moderately bright yellow to yellowish white sample fluorescence;immediate bright white cut fluorescence;amber to dark amber visible cut;medium straw residue; dull white residual fluorescence. Sand/Sandstone (8050-8150) = grayish black to brownish black to olive black semblage of cuttings; translucent to light gray to dusky brown individual quartz grains; see op08-04-pb1 Sand/Sandstone(8150'-8210')=medium dark gray to medium gray; lower very fine to lower fine grained; well to very well sorted; spherical to sub-prismoidal sphericity; sub rounded to rounded; sandstone is easily friable to friable;matrix is siliceous;sandstone is grain supported;texturally immature;compositionally mature; quartz is the predominate mineral; glauconite and pyrite are present; porosity and permeability are visually estimated to be good; white sample fluorescence with a bright bluish white blooming cut, residual cut is uniformly bright white. "OA"SAND Sub-Lobe 3 at 8253.5' MD/-3693.3'TVDSS Sand/Sandstone(8120'-8330')=dark medium gray to medium gray with olive gray sub tones; lower very fine to upper fine in size;spherical to sub-prismoidal sphericity;angular to sub-rounded rounding;moderate to moderately well sorted; sand is unconsolidated, sandstone is very friable to friable; cement is indeterminate and/or missing;sand is grain supported;texturally immature;compositionally sub-mature;sand/sandstone is composed of quartz approximately 10%carbonaceous material at the beginning of the interval dropping to< 1% at the end of the interval, glauconite and pyrite are present; no other secondary features or accessories noted; sample fluoresces a bright white; sample cut begins as a streaming bright white progressing to a blooming bright white with a hallow effect progressing to a solid bright white; residual cut is a bright white; porosity and permeability are visually estimated to be good. Siltstone(8360'-8450')=olive gray to light olive gray; soft to easily friable; tenacity is crumbly to crunchy; fracture is irregular;cuttings habit is massive with a few bladed cuttings; luster is dull to earthy;texture is silty to gritty;structure is massive,in some places, micro laminations of carbonaceous material are present;lower very fine quartz sand grains present as well as some fine grained sand;fluorescence is a bright white,cut is a medium to medium fast stream,residual cut is a bright white;porosity and permeability are visually estimated to be good. Siltstone(8450'-8510') =olive gray to olive black in color; soft to easily friable in hardness; very poorly to poorly indurated;crumbly to crunchy tenacity;irregular fracture;massive cuttings habit;luster is dull to earthy; silty to gritty texture; structure is massive with micro laminations; sample fluoresces white with a light green undertone;odor masked by naf drilling fluids;cut is a medium to medium fast streaming cut,bright milky white in color; residual is solid milky white; porosity and permeability visually estimated to be good. RI 23 G IOW Nikaitchuq OP08-04 and PB1 e n9 Siltstone (8510'-8600') = color is olive gray to olive black with some dark greenish gray; easily friable to friable hardness;very poorly to poorly indurated;brittle to crumbly tenacity;fracture is earthy;cuttings habit is massive; luster is dull to earthy; texture is silty to gritty; structure is massive; sample fluoresces a bright greenish white(90%);odor is masked due to naf drilling fluid;cut is a fast,blooming,bright white;residual cut is a uniform bright white;grayish orange pink lithics present in interval(5%);porosity and permeability visually estimated to be good. Siltstone(8600'-8720')=olive gray to olive black with some dark greenish gray;siltstone is easily friable to friable; very poorly to poorly indurated; tenacity is brittle to crumbly;fracture is irregular and earthy; cuttings habit is massive with bladed cuttings at the end of the interval; luster is earthy to dull;texture is silty to gritty; structure is overall massive with thin micro-laminations where carbonaceous material is present;translucent quartz sand present which are lower fine grained;carbonaceous material in laminated beds with in siltstone; bright white fluorescence(85%); no odor due to naf drilling fluid;white, medium blooming cut;white residual cut; porosity and permeability visually estimated to be good. Siltstone(8720'-8810')=olive gray to light olive gray with dark greenish gray subtone; hardness is friable to easily friable; poorly to very poorly indurated;tenacity is crumbly to crunchy;fracture is earthy and irregular; cuttings habit is massive with some tabular cuttings; luster is dull to earthy;texture is silty to gritty;structure is massive; cuttings fluorescence is 95% bright light greenish white; cut is a fast bright and streaming; odor is masked due to naf fluid;residual cut is intense bright white;porosity and permeability are visually estimated to be good. "OA" SAND Sub-Lobe 3 at 8829.5' MD/-3696.9' TVDSS Sand/Sandstone (8810-8930) = medium to medium dark gray; firm to dis-aggregated; friable;well sorted; samples collected as loose sand with scattered sandstone fragments and variably abundant siltstone fragments; sand is primarily fine lower to very fine upper grain;common very fine lower and fine upper grain; occasional trace medium grain; sub angular to angular and sub-spheroidal;fine lower and fine upper grain; translucent white to grayish brown and clear quartz;trace dark mafic mineral grains;material appears to have partial matrix support;matrix material is silt lithologically similar to the associated siltstone;some grains exhibit trace crystal overgrowth; good visible porosity; 80 to 100%dull yellow white sample fluorescence; good fast streaming cut to milky bright yellow white; moderate brownish amber residue ring cuts readily to milky yellow white;trace raw oil odor over obm background odor;slight stain on some sand grains;marked brownish stain on interior of intact sandstone fragments; trace to common shell fragments; slightly calcareous. Sand/Sandstone (8930-9110) = medium to medium dark gray; firm to dis-aggregated; friable; well sorted; samples collected as loose sand with scattered sandstone fragments and variably abundant siltstone fragments; sand is primarily fine lower to very fine upper grain;common very fine lower and fine upper grain; occasional trace medium grain; sub-angular to angular and sub-spheroidal;fine lower and fine upper grain; translucent white to grayish brown and clear quartz; trace dark mafic mineral grains; trace glauconite and glauconite stained quartz grains; trace to common shell fragments; trace light tan calcite; occasional thin medium gray to brownish gray siltstone and thin silty gray shale material appears to have partial matrix support;matrix material is silt lithologically similar to the associated siltstone;some grains exhibit trace crystal overgrowth;good visible porosity;80 to 100%dull yellow white sample fluorescence;good fast streaming cut to milky bright yellow white;moderate brownish amber residue ring cuts readily to milky yellow white;trace raw oil odor over obm background odor; slight stain on some sand grains; marked brownish stain on interior of intact sandstone fragments; trace to common shell fragments; moderately to very calcareous. Siltstone(9050-9200)=medium gray to medium light brownish gray;firm to moderately hard;silty to slightly sandy texture;dull earthy to slightly micro-sparkly luster;trace shaly siltstone;hydrophilic and expansive when water wet; trace micro-thin carbonaceous lamina; somewhat mottled appearance; carries the same fluorescence and cut regime as the associated sandstone; slightly calcareous. 24 CANRIG Nikaitchuq OP08-04 and PB1 eni "OA" SAND Sub-Lobe 4 at 9236.0' MD/-3713.6' TVDSS Sand/Sandstone (9110-9350) = medium to medium dark gray; firm to dis-aggregated; friable; well sorted; samples collected as loose sand with scattered sandstone fragments and variably abundant siltstone fragments; sand is primarily fine lower to very fine upper grain;common very fine lower and fine upper grain; occasional trace medium grain; sub- angular to angular and sub-spheroidal;fine lower and fine upper grain;translucent white to grayish brown and clear quartz; trace dark mafic mineral grains; trace to abundant glauconite as a secondary cement; trace glauconite stain on sand grains;trace light tan chalky material;trace very fine shell;sand grains stained dark amber; slight odor of oil; sample fluoresces greenish white;fast streaming bluish white cut; residual cut faint bluish white; porosity and permeability visually good;visible oil at shakers. "OA" SAND BASE at 9402.0' MD/-3717.8'TVDSS Sand(9350'-9440')=dark gray to grayish black with brownish sub tones;lower fine to upper very fine grains with occasional lower medium; sub-prismoidal to sub-discoidal sphericity; sub-angular to sub-rounded rounding;well to moderately well sorted;unconsolidated sand;cement missing;matrix missing;texturally sub- mature;compositionally mature;sand is translucent quartz;abundant pyrite;green lithics present;fluoresces greenish white; instantaneous streaming bluish white cut; residual cut faint bluish white; porosity and permeability visually good. Siltstone (9440' - 9530') = brownish black to grayish black; friable to easily friable with some firm friable; poorly to moderately indurated; tenacity is brittle to dense; fracture is irregular; cuttings habit is rounded tabular or massive;luster is dull to earthy;texture is silty to gritty;massive structure;pyrite is abundant through out the interval; amber oil staining observed; even, dim, bluish white fluorescence; faint oil odor; instant blooming bluish white cut;faint residual cut; porosity and permeability visually good. Siltstone(9530'- 9590')=grayish black to black with brownish black sub tones;friable to firm friable;tenacity is crumbly to brittle to dense;fracture is irregular;cuttings habit is rounded elongated; luster is dull to earthy; texture is silty to gritty;structure is massive;dull white fluorescence over in siltstone,sand grains fluoresce a bright white; medium blooming bluish white cut; dull white residual cut; pyrite present; porosity and permeability visually good. Siltstone(9590'-9680')=black to grayish black with brownish black sub-tones;friable to firmly friable;poorly to moderately poorly indurated; tenacity is brittle to dense; fracture is earthy and irregular; cuttings habit is massive with some bladed; luster is dull to earthy; silty to gritty texture; massive structure; pyrite through out the interval; no oil staining noted; slight oil odor;very faint milky white fluorescence with sand grains a bright white;faint blooming bluish white cut;residual cut is very faint dull white;no oil indicators at shakers;porosity and permeability visually good. "OA" SAND BASE at 6884.5' MD/-3713.4'TVDSS Sand/Sandstone (9680'-9770') = color is brownish black to brownish gray; lower fine to upper very fine grains;sphericity is spherical to sub-discoidal;rounding is sub-angular to sub-rounded;well to moderately well sorted; unconsolidated sand, sandstone is friable; sandstone is matrix supported;texturally grains are sub- mature;compositionally sand/sandstone is sub-mature;grains are translucent quartz;green lithics,pyrite an shell fragments through out; sample fluoresces light greenish white; instantaneous streaming to blooming bluish white cut; residual cut is bright white; faint oil odor; porosity and permeability visually good. 25 CANRIG Pit Nikaitchuq OP08-04 and PB1 eni "OA"SAND Sub-Lobe 4 at 9458.0' MD/-3710.4'TVDSS Sand/Sandstone(9770'-9860')=olive black to olive gray in color; upper fine to lower fine with some lower medium and upper very fine; spherical to sub-discoidal sphericity; angular to sub-angular rounding; well to moderately well sorted;unconsolidated sand,sandstone is poorly consolidated;sandstone is grain supported; texturally sand grains are immature; compositionally sand/sandstone is mature; translucent quartz is the primary mineral,some green lithics,at 9830'light pinkish volcanics observed;sample fluoresces 100%even light green; sample cuts an extremely fast streaming bloom, milky white; slight oil odor; no oil at shakers; porosity and permeability visually good. Sand / Sandstone (9860' - 9980') = greenish black to dark greenish black; upper very fine to upper fine grained;spherical to sub-discoidal sphericity;sub-angular to angular rounding;well to moderately well sorted; sand is unconsolidated,sandstone is moderately consolidated;texturally grains are immature;compositionally the sand is mature;grains are predominately translucent quartz,some green lithics and shell fragments;very light amber staining, light bright green fluorescence; sample cut is instantaneous streaming becoming blooming bright milky white; residual cut is milky white; slight oil odor; no oil at shakers; permeability and porosity visually estimated to be good. Sand (9980' - 10070') = black to greenish black; upper very fine to lower fine grained; spherical to sub- discoidal sphericity; sub-angular to sub-rounded rounding; well to very well sorted; unconsolidated sand; cement is missing; matrix is missing sand is grain supported;texturally sand is sub-mature; compositionally mature;sand is translucent quartz,pyrite,green lithics and shell fragments present;sample fluoresces 100% light bright green; instantaneous bluish white streaming becoming blooming cut; light oil staining on some grains; no oil at shakers; slight oil odor; residual cut bright bluish white; porosity and permeability visually good. Sand/Sandstone (10100-10220) = medium to medium light gray with a distinct brownish oil stain as secondary hue; sample collected as dis-aggregated sand with trace to common firm friable sandstone fragments; well to very well sorted; very fine upper to fine lower gradually coarsening to fine lower and very fine upper with trace to common medium lower grain; 10220 sample return to very fine upper;sub-angular to sub-spheroidal and angular;translucent white to clear quartz predominates;common slightly smokey quartz; trace light to medium gray mineral/lithics; trace to common tan shell fragments; trace orange and brown grains;scattered glauconite stained quartz;trace dark mafic mineral/lithics;appears entirely grain supported; some grains exhibit slight pitting and grain overgrowth residues; slight to pronounced oil stain throughout; 100%dull yellow white fluorescence mottled with brighter sticky oil soaked sandstone fragments; fast streaming cut to milky bright yellow white;wide brownish amber residue ring cuts immediately to yellow white; slight oil odor over obm; very calcareous. Sand/Sandstone (10220-10370) = medium to medium light gray with a distinct brownish oil stain as secondary hue; sample collected as dis-aggregated sand with trace to common firm friable sandstone fragments; well to very well sorted; very fine upper to fine lower gradually coarsening to fine lower and very fine upper with trace to common medium lower grain; 10220 sample returns to very fine upper;sub-angular to sub-spheroidal and angular;translucent white to clear quartz predominates;common slightly smokey quartz; trace light to medium gray mineral/lithics;trace to common tan shell fragments;trace orange jasper and brown lithics;scattered glauconite stained quartz grains and brown lithics; trace dark mafic mineral/lithics;appears entirely grain supported;some grains exhibit slight pitting and grain overgrowth residues;slight to pronounced oil stain throughout; 100% dull yellow white fluorescence mottled with brighter sticky oil soaked sandstone fragments; fast streaming cut to milky bright yellow white; brownish amber residue ring cuts immediately to yellow white; slight oil odor over obm; very calcareous Sand/Sandstone(10400-10550)=medium to medium light gray with a slight brownish oil stain as secondary hue;sample collected as dis-aggregated sand with trace firm friable and scattered hard sandstone fragments; heavily masked by safe-carb contamination;well to very well sorted;very fine upper to fine lower grain;sub- angular to sub-spheroidal and angular grain; translucent white to clear and slightly smokey quartz predominate;trace light to medium gray lithics; trace black mafic mineral grains; trace orange jasper and CA it 26 INS Nikaitchuq OP08-04 and PB1 eni light to medium brown mineral/lithics;trace shell fragments;occasional shale and siltstone fragments;material appears entirely grain supported with trace crystalline overgrowth residue on quartz grains;slight to moderate oil stain; 100% dull yellow white fluorescence mottled with brighter sticky oil soaked sand masses; cuts to milky yellow white; dark straw to amber brown residue cuts readily to yellow white; very calcareous may be due to safe-carb contamination. Sand/Sandstone(10550-10700)=medium to medium light gray with a slight brownish oil stain as secondary hue;sample collected as dis-aggregated sand with trace firm friable and scattered hard sandstone fragments; heavily masked by safe-carb contamination;well to very well sorted;very fine upper to fine lower grain; sub- angular to sub-spheroidal and angular grain; translucent white to clear and slightly smokey quartz predominate;trace light to medium gray lithics;trace black mafic mineral grains;trace orange jasper and light to medium brown mineral/lithics; trace shell fragments; occasional shale and siltstone fragments; material appears entirely grain supported with trace crystalline overgrowth residue on quartz grains;slight to moderate oil stain; 100% dull yellow white fluorescence mottled with brighter sticky oil soaked sand masses; cuts to milky yellow white; dark straw to amber brown residue cuts readily to yellow white; very calcareous may be due to safe-carb contamination. Sand/Sandstone (10700-10820) = medium to medium dark gray with a moderate brownish oil stain as secondary hue;sample collected as dis-aggregated sand with trace firm friable and scattered firm sandstone fragments;fragments tend to be slightly silty; reduced safe-carb contamination; very fine upper to fine lower grain;trace medium lower;sub-angular to sub-spheroidal and angular;translucent white to light gray and clear quartz predominate; trace medium to light gray lithics; trace dark gray to black mafic mineral/lithics; rare glauconite stain; trace to common tan to light reddish brown shell fragments; appears primarily grain supported;trace cementation residues;scattered to trace siltstone;moderate to pervasive oil stain; 100%dull yellow white fluorescence mottled with brighter sticky oil soaked sand masses; cuts to milky yellow white; dark straw to amber brown residue cuts readily to yellow white; very calcareous may be due to safe- carb contamination. Sand/Sandstone(10820'-10940')= olive gray to olive black to brownish black;fine grained with occasional lower medium or upper very fine grains sub-prismoidal to sub-discoidal sphericity; sub-angular to rounded rounding;well to very well sorted; unconsolidated sand,sandstone is very friable;grain supported;texturally sand is sub-mature;compositionally sand is mature;translucent quartz is the primary mineral,green lithics and shell fragments also present;sample fluoresces even light bright green;instantaneous bluish white streaming cut; amber oil staining on sand grains; residual cut is bluish white; slight oil odor; no oil at shakers; porosity and permeability visually good. "OA" SAND Sub-Lobe 3 at 10937.0' MD/-3693.0'TVDSS "OA" SAND Sub-Lobe 2 at 11014.0' MD/-3685.9'TVDSS Sand(10940'-11130')=olive black to grayish black; upper very fine to lower fine grained; spherical to sub- discoidal sphericity; sub-angular to sub-rounded roundness; well to very well sorted; unconsolidated sand; grain supported;texturally sub-mature;compositionally mature;translucent quartz dominates with some green lithics,and shell fragments;light amber oil staining;sample fluoresces even bright light green;instantaneous streaming to blooming bright bluish white cut; residual cut bluish white; no oil at shakers; porosity and permeability visually good. "OA"SAND Top at 11112.0' MD/-3673.9'TVDSS Sand(11130'-11220')=olive black to grayish black to black;lower fine to upper very fine grains;spherical to sub-discoidal sphericity; sub-rounded to sub-angular roundness; well to very well sorted; sand is unconsolidated; grain supported; texturally sub-mature; compositionally mature; translucent quartz predominate mineralogy with green lithics and shell fragments; staining at times a light amber; sample 27 CANRIG Iiiit Nikaitchuq OP08-04 and PB1 eni fluorescence even bright light green;instantaneous streaming to blooming bright bluish white cut;residual cut bluish white; faint oil odor; porosity and permeability visually good. Siltstone(11220'-11240')=olive black to black with brownish sub tones;hardness is easily friable to friable; poorly to moderately indurated;tenacity is crumbly to brittle;fracture is irregular;cuttings habit is elongated to nodular; waxy to greasy luster; texture is silty to gritty; structure is massive; very fine grained sandstone present; sample fluoresces a light bright green (50%) in a speckled pattern; siltstone cuts a instantaneous blooming bright bluish white; slight oil odor; residual cut bluish white; no oil at shakers; porosity and permeability visually good. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 4998 700 116385 1561 1464 981 1146 680 427 5074 456 85117 378 168 77 84 35 28 5154 655 119306 574 270 119 128 53 30 5436 663 127766 711 361 185 196 95 51 5625 565 102963 603 321 177 204 105 70 5729 620 99845 745 542 401 472 299 157 6775 370 58729 326 128 70 60 31 15 7062 471 115985 592 213 168 186 151 100 7360 487 102160 577 156 107 103 70 40 7566 501 125024 633 214 168 184 142 94 7862 541 108920 523 142 109 111 68 38 28 CANRIG Nikaitchuq OP08-04 and PB1 eni 3.6 Connection Gases 1 unit=0.05%Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 8602 28 8698 22 8787 25 3.7 Trip(Wiper)Gases 1 unit=0.05%Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 8175 0 314 11240 4999 141 11240 0 297 CAN 29 Nikaitchuq OP08-04 and PB1 eni 3.8 Sampling Program/Sample Dispatch Set Type/Purpose Frequency Interval Dispatched to Unwashed Headspace 500' per Weatherford Laboratories A Samples(Iso-Jars)with plan and 5020'— 11000' 8845 Fallbrook Drive bactericide, selected Houston, TX 77064 Set owner: ENI intervals 500' per Weatherford Laboratories B Gas Samples in Iso-Tubes, plan and 5020'— 11000' 8845 Fallbrook Drive Set Owner: ENI selected Houston, TX 77064 intervals Washed-and-dried Fugro Data Solutions C Reference Samples, 30'/20' 1000'-5020' 3311 S. US Hwy 77 Set Owner: ENI per plan Schulenburg, TX 78956 Washed-and-dried AOGCC D Reference Samples, per p an 1000'-5020' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage,AK 99501 Washed, Spin-dried Fugro Data Solutions E Reference Samples(vials), 30 5020'— 11240' 3311 S. US Hwy 77 Set Owner: ENI per plan Schulenburg, TX 78956 Washed, AOGCC in-dried p OGCC F Reference Samples(vials), per plan 5020'— 11240' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage,AK 99501 30 CANRIG Nikaitchuq OP08-04 and PB1 eni 3.9 Approved Sample Plan OP08-04 Dry samples: 2 Sets every 30'from 1000'to TD. Note: increase to 20' intervals in the N Sand. Iso-Tubes: Every 500'from intermediate casing shoe to TD. Note:increase to 100'intervals for shows in the Ugnu. Canned Mud Samples:(In Iso-Jars)Every 500'from intermediate casing shoe'to TD. Note:Increase to 100' intervals for shows in the Ugnu. In ZOI,sample frequency is increased as specified,beginning 100'above the listed"Top"and continuing to 30' past the predicted base of the ZOI. N Sand top 4184' MD/-3406'TVDSS N Sand BASE 4324' MD/-3450'TVDSS 20' samples from 4090'to 4350'. Lateral Section: Washed, centrifuged and lightly dried samples, 2 sets, on 30' intervals Iso-Jars and Iso-Tubes on 500' intervals and peaks/zones of interest as identified by site Geo or Andrew Buchanan. cIG 31 a)) 0 $ Eot co as •- w .N y L 0 C m N m n O 0 0 w ; rn c a) _ (a 0 ~ C m m a) C c m ( c73 0) 00 73 _c m C 'p a) C C Q O m 7 aa)) UC- 0ai a) W H E O > � `� > co N _ c 0_ a) a) J m — -0 D > c Q NI w w N 0 -a - J O> 2 J C N L w p),.- 3 •c H Q O C O D U -p CO C L O w V) C N C co w as Q O• O O c 2 w C O Q U 0 d Cl) N C) O w co I i m N .c-c2 a) .. o N c>-.) O N d c Q do O) rn C c - C > cwa) my t a co ad 0o aS m O w 3 -O - ( O s C c CO 1 U) J •— to N •6' 7 ai m O Cl) u 1 i C y "O QN •O. co L 2 O p - Q p >, Q„ pOj M t C "a X m N a � r M O • i E E f(0 T 0 a 3 'Oa) crn ..-s 43 �i to m _ -O TA U a) a) m CO E c) _Q) O d M in � 0 �. . II o " ° c ° e N N- o � y ` v C70 a p CO '- O) w a) U m .. a V) -O C N _ 3 C co N M (/) > N U O X a C - 0 a) 0 I— 3 O` N 01 c O 5O m Y_ a T 7 o _c a) a 0 U -0 N Q m 1Ti 'c vs Cfl ZN a- CO > 'C O (C w 4 o c to C -0 0_ a) •' '6 ~ N a) O O U) O .. O m C °) m E 0 O C > V .0 0 43 U) M — 0 N U > p N m ui Z C L N J U C >. V) 11 2 p O E m ' N a) LU IX -a as /O U) (n U C ° m O ° O I— N N C O C C +6 m • ._. N Cl) f0 r 0 ,O C •5• c <D = 7 m eu Q 0 u) 3 0 o m m C E � O U N o O O o C 0 o o (n > Cl) O m W O Q co a C O m U m w U i N LU O m C O O O C7 c E .0 X 0U m y C T ++ G N a 'i r E N 0 N N d C 0 ill Cp >O a) i•E O d d J d V) > C O a. (6 N C7 f4 E as_ C j (/) O LL c L U U a�imLU• = a ° W a) a) m m u, .. m m 3 p L c • CU U 7 •C ., O M N• N N N w (p N y a U t/) Q L ` = O m U m Q) Q as Ce C N O E a1 E O) a N 7 O O C• m f6 m i D m O O O. o n' O c Cl) r U E rnm -o E cu U O LL a U •C Y C Cl) _ 0 O) c Q w N cm � ` cn ° 3 O _c o s a) w w r 0 V 0 H z H .CWQ � H y N CIE a c •- co a) et co o c 0o �- o — O. O n co co a _c Z •� ca co •3 ca a� L wC W .co co aS co C7 a a Nikaitchuq OP08-04 and PB1 eni 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth Vertical (ft) (ft) Section Rate (ft) (0) (0) Depth(ft) N(+),S(-) E(+),W(-) (ft) (°MOOft) 0 0 0 0 0 0 0 0 112.5 0.09 63.88 112.5 0.04 0.08 0.01 0.08 172.58 0.89 345.74 172.58 0.51 0 0.48 1.46 203.04 1.78 351.99 203.03 1.21 -0.12 1.18 2.96 275.61 4.14 3.54 275.49 4.94 -0.12 4.68 3.33 366.81 5.92 2.63 366.34 12.92 0.30 12.04 1.96 459.65 5.56 8.23 458.72 22.16 1.17 20.43 0.72 551.95 6.07 10.29 550.54 31.39 2.68 28.59 0.59 644.69 7.82 7.64 642.60 42.46 4.39 38.41 1.92 740.49 10.41 3.34 737.18 57.55 5.76 52.13 2.79 834.52 11.23 4.18 829.55 75.16 6.93 68.28 0.89 896.64 12.19 0.85 890.37 87.75 7.46 79.93 1.90 993.08 15.23 1.43 984.05 110.60 7.93 101.25 3.16 1089.72 20.29 3.07 1076.06 140.04 9.15 128.50 5.26 1186.30 23.64 5.10 1165.61 176.06 11.76 161.47 3.56 1280.07 27.26 4.13 1250.27 216.22 14.98 198.11 3.89 1376.83 31.29 2.92 1334.66 263.43 17.86 241.51 4.21 1473.10 31.28 3.90 1416.93 313.33 20.83 287.40 0.53 1568.21 29.94 3.20 1498.78 361.67 23.84 331.81 1.46 1664.79 29.68 2.06 1582.59 409.63 26.04 376.13 0.65 1 1758.88 30.20 1.45 1664.12 456.57 27.48 419.76 0.64 1854.17 28.32 359.98 1747.25 503.13 28.08 463.32 2.11 1950.91 32.86 0.14 1830.50 552.35 28.13 509.57 4.69 2047.04 32.37 359.05 1911.48 604.16 27.77 558.39 0.80 34 CANRIG ilk Nikaitchuq OP08-04 and PB1 enu Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth Vertical (ft) (ft) Section Rate (ft) (°) (°) Depth(ft) N(+), S(-) E(+),W(-) (ft) 0100ft) 2141.98 33.35 355.26 1991.23 655.58 25.19 607.60 2.4 2239.16 33.55 353.31 2072.32 708.88 19.86 659.52 1.12 2261.41 33.62 352.61 2090.85 721.09 18.35 671.51 1.77 2370.73 34.15 353.22 2181.60 781.60 10.84 730.95 0.58 2466.56 35.11 352.80 2260.46 835.65 4.21 784.02 1.03 2562.74 35.64 352.58 2338.88 890.88 2.88 838.35 0.57 2658.81 35.04 350.96 2417.25 945.87 10.83 892.75 1.16 2754.05 31.92 349.54 2496.68 997.65 19.69 944.44 3.38 2850.42 30.82 349.21 2578.96 1046.95 28.94 993.94 1.16 2945.98 30.94 347.58 2660.97 1094.99 38.81 1042.46 0.88 3041.17 30.57 348.70 2742.78 1142.63 48.81 1090.65 0.72 3135.73 33.30 351.48 2823.02 1191.89 57.37 1139.88 3.28 3232.13 37.41 356.13 2901.64 1247.31 63.27 1193.99 5.09 3327.35 40.37 358.52 2975.75 1307.01 66.02 1251.04 3.48 3424.14 42.94 359.44 3048.06 1371.33 67.16 1311.88 2.73 3519.23 47.25 359.57 3115.18 1438.66 67.73 1375.36 4.53 3612.98 51.26 359.25 3176.35 1509.67 68.47 1442.36 4.29 3710.84 54.29 357.85 3235.55 1587.55 70.46 1516.26 3.30 3806.86 57.54 0.59 3289.36 1667.05 71.51 1591.32 4.13 3902.39 60.86 358.94 3338.27 1749.09 71.87 1668.55 3.78 3998.42 64.05 0.06 3382.68 1834.22 72.60 1748.82 3.48 4094.17 67.10 358.70 3422.26 1921.38 73.55 1831.07 3.44 4189.87 68.37 356.14 3458.53 2009.84 77.55 1915.58 2.81 4285.68 69.74 354.02 3492.78 2098.98 85.23 2001.99 2.51 4381.78 70.65 355.70 3525.34 2189.03 93.32 2089.39 1.90 4476.91 72.39 355.76 3555.50 2279.00 100.04 2176.25 1.83 4572.34 76.39 356.30 3581.17 2370.67 106.40 2264.59 4.23 4668.22 80.59 359.00 3600.30 2464.51 110.23 2354.10 5.18 Measured Incl. Azim. True Latitude Departure Vertical Dogleg 35 CANRIG PI Nikaitchuq OP08-04 and PB1 eni Depth (°) (°) Vertical (ft) (ft) Section Rate (ft) Depth(ft) N(+),S(-) E(+),W(-) (ft) 0100ft) 4764.23 85.05 359.95 3612.30 2559.74 111.10 2443.91 4.75 4860.42 86.76 2.32 3619.18 2655.66 109.20 2533.41 3.02 4954.89 85.86 2.20 3625.28 2749.85 105.48 2620.68 0.94 4995.29 84.88 1.60 3628.54 2790.10 104.15 2658.05 2.84 5090.62 85.72 1.68 3636.35 2885.07 101.43 2746.39 0.89 5185.77 86.26 2.70 3643.01 2979.92 97.80 2834.30 1.21 5282.57 89.40 0.53 3646.67 3076.59 95.08 2924.24 3.94 5378.21 92.11 357.85 3645.41 3172.19 96.43 3014.56 3.98 5474.05 91.84 357.67 3642.11 3267.90 100.17 3105.80 0.34 5569.84 91.18 356.80 3639.58 3363.55 104.79 3197.28 1.14 5665.80 90.22 356.29 3638.41 3459.33 110.57 3289.27 1.13 5762.39 87.12 355.99 3640.65 3555.66 117.07 3382.04 3.22 5857.79 87.28 355.47 3645.31 3650.68 124.17 3473.77 0.57 5953.47 85.95 354.89 3650.96 3745.85 132.19 3565.97 1.52 6049.46 85.17 355.37 3658.39 3841.21 140.32 3658.37 0.95 6145.11 85.47 357.65 3666.20 3936.36 146.12 3749.78 2.40 6240.29 85.85 358.72 3673.40 4031.21 149.13 3839.97 1.19 6336.42 86.10 358.86 3680.15 4127.09 151.15 3930.77 0.30 6431.96 85.43 359.11 3687.21 4222.35 152.84 4020.89 0.75 6528.20 85.82 0.73 3694.55 4318.30 152.97 4111.13 1.73 6623.06 83.51 2.12 3703.37 4412.72 150.63 4199.07 2.84 6719.64 84.20 2.87 3713.71 4508.65 146.45 4287.81 1.05 6815.13 84.37 4.17 3723.22 4603.48 140.61 4374.96 1.37 6910.60 86.32 1.49 3730.96 4698.51 135.92 4462.67 3.46 7005.88 89.85 359.54 3734.15 4793.71 135.06 4551.87 4.23 7102.02 89.37 357.16 3734.80 4889.80 137.83 4643.13 2.53 7198.25 87.69 355.27 3737.27 4985.78 144.18 4735.51 2.63 7293.45 86.69 352.05 3741.94 5080.27 154.68 4827.91 3.54 7388.53 86.64 348.18 3747.47 5173.77 170.97 4921.35 4.06 Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth (°) (°) Vertical (ft) (ft) Section Rate RIG 36 CAN Nikaitchuq OP08-04 and PB1 eni (ft) Depth (ft) N(+), S(-) E(+),W(-) (ft) (°/100ft) 7485.15 89.92 346.17 3750.37 5267.91 192.40 5017.16 3.98 7581.02 91.01 342.53 3749.59 5360.21 218.26 5112.74 3.96 7675.80 90.00 339.13 3748.76 5449.72 249.38 5207.49 3.74 7771.80 87.72 333.61 3750.67 5537.61 287.83 5303.23 6.22 7868.63 88.53 333.57 3753.84 5624.29 330.88 5399.39 0.84 7963.27 90.26 334.12 3754.84 5493.47 5709.23 -372.59 1.92 8059.61 92.46 330.14 3752.55 5588.84 5794.35 -417.60 4.72 8155.50 92.56 330.42 3748.35 5683.25 5877.55 -465.09 0.31 8251.21 90.87 327.65 3745.49 5777.15 5959.57 -514.31 3.39 8347.22 91.80 323.92 3743.25 5870.16 6038.92 -568.27 4.00 8442.41 89.18 319.13 3742.43 5960.39 6113.42 -627.47 5.74 8538.67 89.38 315.49 3743.64 6049.15 6184.15 -692.72 3.79 8635.00 90.79 313.62 3743.50 6136.10 6251.73 -761.36 2.43 8730.56 87.95 308.43 3744.55 6219.62 6314.43 -833.41 6.19 8826.07 87.50 304.82 3748.35 6299.27 6371.35 -909.99 3.81 8922.00 88.32 301.18 3751.84 6375.78 6423.55 -990.38 3.89 9016.04 86.32 297.98 3756.24 6447.24 6469.92 -1072.06 4.01 9110.20 87.58 300.83 3761.25 6518.59 6516.08 -1153.96 3.31 9206.64 88.47 299.85 3764.58 6592.74 6564.76 -1237.14 1.37 9305.37 89.60 300.34 3766.24 6668.42 6614.26 -1322.55 1.25 9398.41 87.21 300.80 3768.83 6740.21 6661.56 -1402.62 2.62 9490.77 89.27 299.83 3771.67 6811.21 6708.15 -1482.31 2.47 9590.41 92.10 302.22 3770.48 6888.61 6759.50 -1567.67 3.72 9686.50 93.81 304.54 3765.52 6965.58 6812.29 -1647.80 3.00 9782.84 92.93 303.56 3759.86 7043.39 6866.13 -1727.48 1.37 9878.55 91.32 303.44 3756.31 7120.23 6918.92 -1807.23 1.69 9974.25 90.95 303.21 3754.41 7196.93 6971.49 -1887.18 0.46 10069.87 90.78 302.95 3752.97 7273.33 7023.67 -1967.29 0.32 10165.95 91.15 303.36 3751.35 7350.17 7076.21 -2047.72 0.57 10261.51 91.95 303.01 3748.77 7426.60 7128.49 -2127.66 0.91 Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth (°) (°) Vertical (ft) _ (ft) Section Rate 37 CANRIG Nikaitchuq OP08-04 and PB1 end (ft) __Depth (ft) N(+), S(-) E(+),W(-) (ft) 0100ft) 11122.43 98.56 301.22 3724.68 8097.71 7576.00 -2861.45 2.61 11155.34 99.80 301.72 3719.42 8123.11 7592.96 -2889.16 4.06 11177.42 99.05 301.95 3715.81 8140.23 7604.45 -2907.66 3.55 38 CANRIG 2 n ,- N 0 / I Cl) z z p Ca m 2 / -r \ \ \ % o 9 / N CL ' 2 2 o 0. a Q N N CO 2 a @ ¥ / o_ > N § A ± r-- # CO k C ,- /a N _ co @ N- a) N ill _ N () N \ 2 • 0 0 a) k o Q▪ N In w CO C _ 0 / 7 q q ■ N 2 0 co 6 m co & n w ' N / ,- /- - to CO c It / 0_ # \ CO k 40 o ¥ G \ CO S CD CO in o N- G n >, CO N o / % 2 CC N 2 2 2 0 ° 4) 2 0 co 0 cc CU cm 0 0 2 I I > 2 2 N CO N e ® 2 CO CO § ,- N n ƒ r as O O O O O O O O C.) E N CO 00 CD' N N N N 0 NI- O O 0 0 0 0 O O O O O O U) O V Co Co U) Co 1 LO 0 U) U) i 0 E N I- .:1"M CO CO CO N- M 0 N 00 a) Co u) Tr I NI- CD co O U) N. N O CD (0 CO 0. ° a) co co a) _ CT 00 mU) N 0 N- N. Nr 2 N N N N r r h v O O O N- () N N U) M N 0 CO 4 r+ N N N N N v 0 ea N r N N N N. N. CO a00 N. N. 0 r ~ N Nr a) LO d b C C M Co CO (O . co ,a O co co ti U) _ U C0 O co Nt V - N N . . N N N O LL V I . , . ' ' . I C N _. d J V co Co Lo C. re) Co co CO N. N 0 ; LL (A (O (O . I I 4 4 2 t m CO (t) a Q) O O 4 N. CO r N N 1 M N ,- N N 0 VJ _ a) N (O N Co N. co N N CO NJ- Y O d N CO co Cb C ,- N. M N N ,- N N Z N O N Co CO W O 'a' N 0 N N '- , N N Co 0 d ' M Co N O ,- N- .- a) O 0 M V '- a) 0) >- N N N N N N d' N > N N co C') N M N N- N CO .- 0) 0 d N r N N N N N ,- N Z 5 N CO 0) , CO Co U) U i i i i i M N O ?� al co O co M O a) ,— Co 00 a) a) a) O 2 0. 00 O) w a) a) co a) a) a) a) co 00 w O a) 0) •_ U 6 u C LO■ 0 0 .a 0 ) N 0) a) a) a) M CO a) M N- CD C2 = 0 v M in U) Lo Lo M O to U) In CO N \ > > Co O N CO a) a) a) CO N N. N- V 0 o. t ,- ,- N N N N M M CO M M M 01 ' CO M Nd C) N. a Nt 0 Nt 0 N- 0 O 0 Co a) O Cn et — a_ 0 Co C') Nt Co N- CO N N CO N N- N O c., M M co co co 0 0 O CO co co N N N N C') Co Co Cn Co CD CO CO 20 n o >, N I— 0 0 00 0000 000 0 0 0 0 0 • C 0) O 0 0 0 0 0 0 0 0 0 0 O N N N N N N N N N N N O O O 0 0 U 0 0 N N N N N N N N 0) 0 ,-CV CV CV CV CV N M Nr Cn CD CD CO CD CO CO CD CD CD CD CD N- N. N N- N— (O (O CO CO CO CO CO CO CO (O CO I* N. N- N- ti • E 0 0 0 0 0 o O C O O O 00 COC) U) in U o 0 0 r� Lo smo E co v rn CO 00 00 CL I N y I- U) U) r` U) U) O O co N v v v v N 0 12 2 00 000 t[) N U) u) 1 cn to in in dN O O O C t0 U M M 4 LL II^ O V O OLL lllll 7 t N ti r N N N N N N 4 ('4 Z CO Ns CL CO LO CO CO o0 > v rn 00 0 In 1.11 u) CL N r r N v- 07 a 1 1 1 1 I 1 6 > N1 Q O O) 0) CO M M M • 2 0. co co co 0) O) O) CA co co (0 CO co CO w M M M M M M O CD CS)• O) CV V' tt N N N N N O CO 0 0 0 0 0 0 0 0 d o O O O O O N N N CV N CV N O N CO Ns CO 0) c- N T N N 0 C jp O 7 N U L L_ U ? a) a) m m S IS 0.) U O WY — O II Lt O it W LLLL O Z. N C O U a) N m O - d ° _ O LL II p II II a O LT - t .r Z p) C ° u' L N — L N O fd II U a N• II II 0 0 a E a) t6 � f6 a) L y .O O O a) d r 73 a) 'CO "0 t O N N 5 2 } L II II II II J Q 2 CO >- cANRIG SHOW REPORT NO. 1 L)„„—Ter uVUU4n Llu. ENI Petroleum OP08-04 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 4180 TO 4465 (MD) TOTAL FTG 285 3455 TO 3552 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619S-PDC BIT HOURS- 33.65 AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 170 174 220 133 WOB 6.8 8.6 9.7 9.3 RPM 121 122 123 121 MUD WT 9.1 9.16 9.2 9.2 CHLORIDE 600 733 800 800 TOTAL GAS 42 221 528 93 C1 (ppm) 7482 37.331 88612 15901 C2(ppm) 64 368 886 83 C3(ppm) 23 142 322 123 C4(ppm) 48 184 382 23 C5(ppm) 28 91 172 RATIO ROP INCREASE TO GAS INCREASE: (4/179) SAMPLE CUTTINGS FLUORESENCE%: 10-20% COLOR Yellow INTENSITY:Medium CUT: MUD FLUORESCENCE: FORMATION DESCRIPTION: Sand/Siltstone= light gray to medium gray semblance of light gray to translucent to milky white to dusky brown quartz grains; lower fine to upper medium throughout sample interval; subangular to angular to subrounded with moderate sphericity;very fine to fine black lithics; light green to translucent brilliant green to moderate green glauconite,fine to very fine, subrounded to subangular, moderate to high sphericity,approx 5%; occasional pyrite grains and growths as well as shell fragments and muscovite sheet fragments. SHOW RATING: (T,P,F,G) trace LOGGING GEOLOGIST(S): Emil Opitz CANRIG SHOW REPORT NO. 2 !)RIIIPG TLHNni(un L-i H. ENI Petroleum OP08-04 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 4950 TO 5020 (MD) TOTAL FTG 70 3625 TO 3630 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619S-PDC BIT HOURS- 33.65 AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 130 154 202 130 WOB 7.8 _ 7.6 10.4 4.8 RPM 80 79 80 78 MUD WT 9.3 9.3 9.3 9.3 CHLORIDE 850 850 850 850 TOTAL GAS 50 280 700 92 C1 (ppm) 79000 69934 116806 13998 C2(ppm) 998 915 1561 187 C3(ppm) 937 861 1468 180 C4(ppm) 1382 1280 2144 316 C5(ppm) 717 653 1124 118 RATIO ROP INCREASE TO GAS INCREASE: (+24/+230) SAMPLE CUTTINGS FLUORESENCE%: 50-60% COLOR Yellow INTENSITY: Dull CUT: Amber MUD FLUORESCENCE: FORMATION DESCRIPTION: Sand-clear to very light gray to medium gray; upper very fine to fine grained;subangular to subrounded with low to moderate sphericity; moderately to well sorted; trace orange lithics, shell fragments,and brilliant green glauconite; slightly calcareous. SHOW RATING:(T,P,F,G) Fair LOGGING GEOLOGIST(S): Zachary Beekman 6 DAILY REPORTS 43 CANRIG Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El 0P08-04 REPORT FOR Sam Beauchamp/Dave Morris/Andrew Buchanan DATE Jun 19,2010 DEPTH 0 PRESENT OPERATION R/U and pressure tests TIME 24:00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION NA NA NA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 0 MW NA VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Can CCI MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE(C-2) NA @ NA @ NA AVG NA PROPANE(C-3) NA @ NA @ NA CURRENT NA BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Building spud mud.Continue rig up and work on lines. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2845;Rig Watch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/20/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikailchuq DAILY WELLSITE REPORT El OP08-04 REPORT FOR S.Beauchamp/D.Morris/A.Buchanan DATE Jun 20,2010 DEPTH 164 PRESENT OPERATION P/U BHA#2 TIME 24:00:00 YESTERDAY 0 24 HOUR FOOTAGE 164 CASING INFORMATION 20"@ 120 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 1 16" HUGHES MX-1 6073602 3020;1016 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 164 MW 8.8 VIS 93 PV 22 YP 21 FL 16 Gels 20/25/33 CL- 1250 FC 4/- SOL SD OIL MBL 25 pH 10.0 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE(C-2) NA @ NA @ NA AVG NA PROPANE(C-3) NA @ NA @ NA CURRENT NA BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Worked on riser and RN lines.Picked up 5"drill pipe.Picked up BHA#1 and drilled out to make room for BHA#2.Currently picking up BHA#2 EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\Documents and Settings\EpochAdmin\Desktop\20100621.htm 6/21/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP08-04 REPORT FOR S.Beauchamp/D.Smith/Andrew Buchanan DATE Jun 21,2010 DEPTH 1268 PRESENT OPERATION Drilling TIME 0305:10 YESTERDAY 164 24 HOUR FOOTAGE 1104 CASING INFORMATION 20"@ 154' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1186.2 26.74 2.82 1164.47 1089.72 20.26 008 1076.03 SURVEY DATA 993.08 15.32 1.38 984.04 896.64 12.17 0.81 890.38 834.52 1123 4.18 829.55 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 2542.4 @ 1189.00000 7.0 @ 202.00000 157.7 190.15424 FT/HR SURFACE TORQUE 16045 @ 118300000 0 @ 1262.00000 1118.1 1.77311 AMPS WEIGHT ON BIT 40 @ 1189.00000 0 @ 818.00000 180 20.45249 KLBS ROTARY RPM 47 @ 932.00000 0 0 1259.00000 14.9 0.02127 RPM PUMP PRESSURE 1136 @ 1240.00000 337 0 250.00000 754.9 974.70892 PSI DRILLING MUD REPORT DEPTH 1100' MW 9.0 VIS 92 PV 12 YP 23 FL - Gels 22/36/46 CL- 2200 FC 4/- SOL - SD - OIL - MBL 22 pH 9.6 Ca+ 80 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 9 @ 1259.00000 0 @ 872.00000 0.9 TRIP GAS NA CUTTING GAS 0 @ 1268.00000 0 @ 1268.00000 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 1815 @ 1234.00000 -1 @ 1059.00000 980 CONNECTION GAS HIGH NA ETHANE(C-2) 19 @ 1083.00000 -1 @ 1059.00000 1.2 AVG NA PROPANE(C-3) 7 @ 1215.00000 -1 @ 1059.00000 0.1 CURRENT NA BUTANE(C-4) 24 @ 1215.00000 -2 @ 1059.00000 0.9 CURRENT BACKGROUND/AVG 5/3 PENTANE(C-5) 11 @ 1232.00000 -2 @ 1059.00000 0.2 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION ,• LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 90%,Sand 10% DAILY ACTIVITY Continued picking up BHA#2.Drilled ahead to 255'to make room to pick up the rest of BHA.Drilled to 788'and rig up and run Gyro Survey.Continued drilling ahead to current depth of SUMMARY 1268'as of report lime. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3145;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/22/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitehuq DAILY WELLSITE REPORT OP08-04 REPORT FOR S.Beauchamp/D.Smith/Andrew Buchanan DATE Jun 22,2010 DEPTH 2344 PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 1268 24 HOUR FOOTAGE 1076 CASING INFORMATION 20"@ 154' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2261.41 33.62 352.61 2090.85 SURVEY DATA 2239.14 33.55 353.31 2072.32 2141.98 33.35 355.26 1991.23 2047.04 32.37 359.05 1911.48 1950.91 32.86 0.14 1830.5 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX-1 6073602 3x20,1x16 154 2344 2190 22:20:51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 378.4 @ 2177 13.6 @ 1651 190.7 75.92374 FT/HR SURFACE TORQUE 9050 @ 2274 0 @ 2245 2391.7 4788.37988 AMPS WEIGHT ON BIT 36 @ 1288 0 @ 1396 19.0 17.52701 KLBS ROTARY RPM 47 @ 2271 0 @ 2243 21.2 42.39373 RPM PUMP PRESSURE 1872 @ 2328 720 @ 1300 1169.6 1678.08545 PSI DRILLING MUD REPORT DEPTH 2344 MW 9.4 VIS 119 PV 20 YP 25 FL - Gels 15/42/55 CL- 1500 FC 2/- SOL - SD - OIL - MBL 21 pH 9.0 Ca, 80 COI - MWD SUMMARY INTERVAL 154 TO 2344 TOOLS Gamma,Resistivity,Direction,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 292 @ 1825.00000 0 @ 1431.00000 84.2 TRIP GAS- • CUTTING GAS 0 @ 2344.00000 0 @ 2344.00000 0.0 WIPER GAS 55 • CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 57083 @ 1825.00000 221 @ 1431.00000 17583.9 CONNECTION GAS HIGH 36 ETHANE(C-2) 0 @ 2344.00000 0 @ 2344.00000 0.0 AVG 34 PROPANE(C-3) 0 @ 2344.00000 0 @ 2344.00000 0.0 CURRENT- BUTANE(C-4) 0 @ 2344.00000 0 @ 2344.00000 0.0 CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) 0 @ 2344.00000 0 @ 2344.00000 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION • LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 50%,Sand 50% DAILY ACTIVITY Continued drilling ahead to TD at 2344'.Pumped sweep and circulated at TD.Pulled out of hole with tight spot around 2180'and 1180'.Run in hole and pumped sweep.Circulated SUMMARY another bottoms up.Tripping out of hole as of report EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;Rig Watch-$1450 REPORT BY Z.Beekman • file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 6/23/2010 Daily Report Page 1 of 1 EM Petroleum Li EPOCH Nikaaehuq DAILY WELLSITE REPORT OPO4-07 REPORT FOR S.Beauchamp/D.Smith/Andrew Buchanan DATE Jun 23,2010 DEPTH 2344' PRESENT OPERATION RIH w/13 3/8"CSG TIME 24:00:00 YESTERDAY 2344' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 154' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2261.41 33.62 352.61 2090.85 2239.16 33.55 353.31 2072.32 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX-1 6073602 3x20,1016 154 2344 2190 2220:51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA 0 NA 0 NA NA PSI DRILLING MUD REPORT DEPTH 2344' MW 9.4 VIS 87 PV 24 VP 22 FL - Gels 9/32/39 CL- 1500 FC 2/- SOL - SD - OIL - MBL 20 pH 8.8 Ca+ 60 CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA `GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) NA 0 NA 0 NA CONNECTION GAS HIGH NA • ETHANE(C-2) NA 0 NA 0 NA AVG NA PROPANE(C-3) NA 0 NA 0 NA CURRENT NA BUTANE(C-4) NA 0 NA 0 NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA 0 NA 0 NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 50%,Sand 50% DAILY ACTIVITY Circulated several bottoms up until hole was clean.Pulled out of hole and laid down the BHA.Serviced pipe skate.Rig up casing equipment and run in hole with 13 3/8"casing.Run in SUMMARY hole to 2278'as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\DESKTOP\EMIL\OPO4-07 D... 6/24/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OPO4-07 REPORT FOR S.Beauchamp/D.Smith/Andrew Buchanan DATE Jun 24,2010 DEPTH 2344 PRESENT OPERATION Testing BOP TIME 24:00:00 YESTERDAY 2344 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 154' 133/8"@ 2333.6' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2261.41 33.62 352.61 2090.85 2239.16 33.55 353.31 2072.32 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX-1 6073602 3x20,1x16 154 2344 2190 22:20:51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 2344' MW 9.6 VIS 47 PV 21 YP 8 FL - Gels 8/-/- CL- - FC - SQL - SD - OIL - MBL 17 pH 8.7 Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 50%,Sand 50% DAILY ACTIVITY SUMMARY Finished running in hole with 13 3/8"casing and conditioned hole.Cemented casing in at a depth of 2,3316 feet MD/2,350.9'TVD.Testing BOP as of report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 • REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\DESKTOP\EMIL\OPO4-07 D... 6/25/2010 Daily Report Page 1 of 1 ENI Petroleum ® EPOCH Nikaitchuq DAILY WELLSITE REPORT 0P08-04 REPORT FOR S.Beauchamp/D.Smith/Andrew Buchanan DATE Jun 25,2010 DEPTH 2370' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 2344' 24 HOUR FOOTAGE 26' CASING INFORMATION 20"@ 154' 13 3/8"@ 2333' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2261.41 33.62 352.61 2090.85 2239.16 33.55 353.31 2072.32 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 121/4" Hycalog MSX619S-PDC 225024 6,16 2344 2370 26 00:40:00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 142.9 @ 2345.00000 52.3 0 2370.00000 111.4 52.25874 FT/HR SURFACE TORQUE 5340 @ 2345.00000 4788 0 2344.00000 5354.8 4979.02734 AMPS WEIGHT ON BIT 17 @ 2344.00000 2 @ 2346.00000 5.3 3.98219 KLBS ROTARY RPM 59 0 2346.00000 42 @ 2344.00000 60.2 58.30587 RPM PUMP PRESSURE 1678 0 2344.00000 807 @ 2345.00000 884.0 829.59833 PSI DRILLING MUD REPORT DEPTH 2370 MW 8.9 VIS 47 PV 5 YP 11 FL - Gels 617/9 CL- 350 FC <1/- SOL 3 SD - OIL 1/97 MBL - pH 9.7 Ca+ 20 CCI - MWD SUMMARY INTERVAL 2344 TO 2370 TOOLS Gamma,Resistivity,Inclination/Azimuth,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 27 @ 2344.00000 2 0 2345.00000 9.9 TRIP GAS 0 CUTTING GAS 0 @ 2370.00000 0 0 2370.00000 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 5740 0 2344.00000 611 0 2345.00000 2069.0 CONNECTION GAS HIGH NA ETHANE(C-2) 0 0 2370.00000 0 @ 2370.00000 0,0 AVG NA PROPANE(C-3) 0 0 2370,00000 0 0 2370.00000 0.0 CURRENT NA BUTANE(C-4) 0 0 2370.00000 0 0 2370.00000 0.0 CURRENT BACKGROUND/AVG 17/10 PENTANE(C-5) 0 0 2370.00000 0 0 2370.00000 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Cement,Sand,Claystone PRESENT LITHOLOGY Cement 70%,Sand 20%,Claystone 10% DAILY ACTIVITY Continued to test BOP.Picked up BHA#3.Run in hole.Test casing pressure to 2500 psi for 30 minutes.Wash and ream.Drill out to shoe at 2333'.Drilled 26'of new hole to 2370'. SUMMARY Displaced out old mud with new mud.Run leak off test to 13.8 ppg EOMW.Drilling ahead as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman I file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/26/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El I OP08-04 REPORT FOR J.Keener/D.Smith/Andrew Buchanan DATE Jun 26,2010 DEPTH 3930' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 2344' 24 HOUR FOOTAGE 1586' CASING INFORMATION 20"0154' 133/8"02333' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3806.86 57.51 1.21 3286.66 SURVEY DATA 3710.84 54.26 358.0 3235.8 3612.98 51.2 0.15 3176.54 351923 47.2 0.39 311529 3424.14 42.89 0.57 3048.12 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hycalog MSX619S-PDC 225024 6x16 2370 3930 1586' 20:50:00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 329.4 0 2732.00000 3.2 0 3930.00000 147.5 3.24821 FT/HR SURFACE TORQUE 12232 0 3869.00000 1455 0 2717.00000 5324.3 5604.04199 AMPS WEIGHT ON BIT 27 0 3870.00000 0 0 3237.00000 4.0 25.50372 KLBS ROTARY RPM 135 0 3721.00000 42 0 2344.00000 91.5 59.17705 RPM PUMP PRESSURE 1707 0 3780.00000 456 0 237320000 12283 1252.76917 PSI DRILLING MUD REPORT DEPTH 3865' MW 9.1 VIS 51 PV 13 YP 27 FL - Gels 11/15/20 CL- 650 FC 1/- SOL 5 SD 0.1 OIL 2/93 MBL 8.75 pH 10.0 Ca, 20 CCI - MWD SUMMARY INTERVAL 2344' TO 3930' TOOLS Gamma,Resistivity,Inclination/Azimuth,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 45 0 3153.00000 0 0 3928.00000 16.3 TRIP GAS- ' CUTTING GAS 0 0 3930.00000 0 0 3930.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 8900 0 3153.00000 49 0 3638.00000 3368.4 CONNECTION GAS HIGH NA ETHANE(C-2) 0 @ 3930.00000 0 0 3930.00000 0.0 AVG NA PROPANE(C-3) 0 0 3930.00000 0 0 3930.00000 0.0 CURRENT NA BUTANE(C-4) 0 0 3930.00000 0 0 3930.00000 0.0 CURRENT BACKGROUND/AVG 5/5 PENTANE(C-5) 0 0 3930.00000 0 0 3930.00000 0.0 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sillslone PRESENT LITHOLOGY Sand 80%,Silistone 20% DAILY ACTIVITY SUMMARY Drilling ahead from 2370'to depth as of report at 3930'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;Rig Watch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/27/2010 Daily Report Page 1 of 1 ENI ait EPOCH Nikaitchup enuq DAILY WELLSITE REPORT OP08-04 REPORT FOR J.Keener/D.Smith/Andrew Buchanan DATE Jun 27,2010 DEPTH 5020' PRESENT OPERATION Tripping Out TIME 24:00:00 YESTERDAY 3930' 24 HOUR FOOTAGE 1090' CASING INFORMATION 20"@ 154' 13 3/8"@ 2333' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4954.89 85.8 2.7 3626.2 4860.42 86.68 323 3620.01 SURVEY DATA 4764.23 85 0.11 3613.03 4668.22 80.54 359.63 3600.95 4572.34 76.34 357 3581.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 121/4" Hycalog MSX619S-PDC 225024 6x16 2344' 5020' 2676' 33.65 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 260.6 @ 4273 3.2 @ 3930 111.0 123.38 FT/HR SURFACE TORQUE 9868 @ 4144 1651 @ 4683 61262 4894.31 AMPS WEIGHT ON BIT 28 @ 4988 0 @ 3940 8.8 4.71 KLBS ROTARY RPM 140 @ 3948 48 @ 3931 109.3 79.92 RPM PUMP PRESSURE 1895 @ 4941 598 @ 4748 1664.4 1849.23 PSI DRILLING MUD REPORT DEPTH 5020' MW 9.3 VIS 51 PV 12 YP 21 FL - Gels 8/17/24 CL- 850 FC 1/- SOL 6 SD 0.1 OIL 2/92 MBL 14 pH 9.6 Ca-) 20 CCI - MWD SUMMARY INTERVAL 2344' TO 5020' TOOLS Gamma,Resistivity,Inclination/Azimuth,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 700 @ 4998 0 @ 3930 101.0 TRIP GAS NA CUTTING GAS 0 @ 5020 0 @ 5017 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 116806 @ 4999 184 @ 3930 17439.6 CONNECTION GAS HIGH 40 ETHANE(C-2) 1561 @ 4998 0 @ 4001 167.9 AVG- PROPANE(C-3) 1468 @ 4999 0 @ 4144 99.5 CURRENT- BUTANE(C-4) 2144 @ 4999 2 @ 4144 147.1 CURRENT BACKGROUND/AVG 6/50 PENTANE(C-5) 1124 @ 4999 0 @ 4743 83.7 HYDROCARBON SHOWS 1)4180-4465;2.)4950-5020 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 4180-4465;4950-5020 sand/siltstone 1.)528 max 2.) Slight odor,50%-60%light brown slain,50%even dull yellow fluorescence,streaming amber cut with streaming bright white cut fluorescence, 700 max heavy dark brown residue with dull yellow residue fluorescence. LITHOLOGY Sand,Siltstone PRESENT LITHOLOGY Sand 70%,Siltstone 30% DAILY ACTIVITY SUMMARY Continued to drill from 3930'to TD at 5020'.High gas was at 700 units.Circulated 2 bottoms up before beginning to trip out.Tripping out of hole as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/28/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikailchuq DAILY WELLSITE REPORT Ell OP08-04 REPORT FOR J.Keener/D.Smith/Andrew Buchanan DATE Jun 28,2010 DEPTH 5020' PRESENT OPERATION RIH w.9 5/8"casing TIME 24:00:00 YESTERDAY 5020' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 154' 133/8"@ 2333' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4954.89 85.86 220 362528 4860.42 86.74 2.32 3619.18 SURVEY DATA 4764.23 85.05 359.95 3612.30 4668.22 80.59 359.0 3600.30 4572.34 76.39 356.30 3581.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hycalog MSX619S-PDC 225024 6x16 2344' 5020' 2676' 33.65 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 5020' MW 9.4 VIS 52 PV 13 YP 19 FL - Gels 9/17/- CL- 850 FC 1/- SOL 6 SD 2/92 OIL 0.1 MBL 14 pH 9.6 Ca, 20 CCI - MWD SUMMARY INTERVAL 2344' TO 5020' TOOLS Gamma,Resistivity,Inclination/Azimuth,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS 528 CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE(C-2) NA @ NA @ NA AVG NA PROPANE(C-3) NA @ NA @ NA CURRENT NA BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS none INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Siltstone PRESENT LITHOLOGY Sand 70%,Siltstone 30% DAILY ACTIVITY SUMMARY Circulated 2 bottoms up then pulled out of hole on elevators.Serviced rig,changed and tested rams.Running in hole with 9 5/8"casing.Currently at 2000'as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;Rig Watch-$1450 REPORT BY Z.Beekman • file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/29/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El OP08-04 REPORT FOR J.Keener/D.Smith/Andrew Buchanan DATE Jun 29,2010 DEPTH 5020' PRESENT OPERATION Picking up pipe TIME 24:00:00 YESTERDAY 5020' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 154'13 3/8"@ 2333'9 5/8"@ 5000' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4954.89 85.86 2.20 3625.28 4860.42 86.74 2.32 3619.18 SURVEY DATA 4764.23 85.05 359.95 3612.30 466822 80.59 359.00 3600.30 4572.34 76.39 356.30 3581.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 121/4" Hycalog MSX619S-PDC 225024 6x16 2344' 5020' 2676' 33.65 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 5020' MW 9.5 VIS - PV 12 VP 9 FL - Gels 3/8/- CL- - FC -/- SOL - SD - OIL -/- MBL - pH 8.8 Can - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA i GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 14 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE(C-2) NA @ NA @ NA AVG NA PROPANE(C-3) NA @ NA @ NA CURRENT NA BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS none INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Siltstone PRESENT LITHOLOGY Sand 70%,Siltstone 30% DAILY ACTIVITY Continued running in 9 5/8"casing to a depth of 5000'without issues.Conditioned hole and cemented.Plugs bumped and held.Empty and cleaned pits to change mud.Picking up SUMMARY pipe as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman I it file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/30/2010 Daily Report Page 1 of 1 ENI Petroleum PI EPOCH Nikaitchuq DAILY WELLSITE REPORT OP08-04 REPORT FOR J.Keener/J.Longo/Andrew Buchanan DATE Jun 30,2010 DEPTH 5020' PRESENT OPERATION Testing Casing TIME 24:00:00 YESTERDAY 5020' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 154' 13 3/8"0 2333'9 5/8"@ 5000' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4954.89 85.86 2.20 3625.28 SURVEY DATA 4860.42 86.74 2.32 3619.18 4764.23 85.05 359.95 3612.30 4668.22 80.59 359.00 3600.30 4572.34 76.39 356.30 3581.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" MSR616M-A3D-Z-R 125858 5x12,1x13 5000' - - - - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 5020' MW 8.8 VIS - PV 17 YP 10 FL - Gels 6/7/- CL- 475000 FC -/- SOL 8 SD - OIL 77/15 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE(C-2) NA @ NA @ NA AVG NA PROPANE(C-3) NA @ NA @ NA CURRENT NA BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS none INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Siltstone PRESENT LITHOLOGY Sand 70%,Siltstone 30% DAILY ACTIVITY SUMMARY Continued to pick up pipe and clean mud pits.Run in hole to 3300'stop and circulate.Continue running in hole to bottom and circulate bottoms up.Test casing as of midnight. • EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 • REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN'\MY DOCUMENTS\MY WEL... 7/1/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT Ell OP08-04 REPORT FOR J.Keener/D.Smith/A.Buchanan DATE Jul 01,2010 DEPTH 5750.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 5020.00000 24 HOUR FOOTAGE 730 CASING INFORMATION 20"@ 154' 13 3/8"@ 2333'9 5/8"@ 5000' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5762.39 87.23 355.65 3640.45 SURVEY DATA 5665.80 90.17 356.21 3638.26 5569.84 91.17 356.75 3639.38 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog MSR616M-A3D-Z-R 125858 5x12,1x13 5000' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 339.0 @ 5367.00000 3.4 @ 5146.00000 226.6 49.21798 FT/HR SURFACE TORQUE 6713 @ 5729.00000 3445 @ 5021.00000 4385.0 5204.37549 AMPS WEIGHT ON BIT 25 @ 5051.00000 0 @ 5626.00000 3.2 676026 KLBS ROTARY RPM 122 @ 5602.00000 80 @ 5052.00000 109.2 122.25452 RPM PUMP PRESSURE 2339 @ 5435.00000 1101 @ 5145.00000 2052.0 2286.91284 PSI DRILLING MUD REPORT DEPTH 5660' MW 8.9 VIS PV 22 YP 13 FL 7.7 Gels 14/22/30 CL- 53000 FC -/2 SOL 8.11 SD - OIL 77/23 MBL pH Cat- 0.82 CCI MWD SUMMARY INTERVAL 5000 TO 5750 TOOLS PDGR/Inc/GR/PWD/RES/Sury/Density/Neutron • GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 664 @ 5437.00000 0 @ 5300.00000 313.8 TRIP GAS- CUTTING GAS 0 @ 5750.00000 0 @ 5750.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 127766 @ 5436.00000 81 @ 5228.00000 57589.1 CONNECTION GAS HIGH - ETHANE(C-2) 807 @ 5565.00000 0 @ 5228.00000 353.4 AVG- PROPANE(C-3) 633 @ 5674.00000 0 @ 5300.00000 212.8 CURRENT- BUTANE(C-4) 1045 @ 5674.00000 0 @ 5300.00000 261.1 CURRENT BACKGROUND/AVG 40u/60u • PENTANE(C-5) 602 @ 5674.00000 0 0, 5300.00000 116.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5020-5750 sand/sandstone 664u Strong odor,brown staining within sandstone cuttings,bright even yellow to orange fluorescence to 70%patchy,streaming bright white cut,dark amber max to brown visible cut.Oil shows decrease substantially from 5500,while gas remains high. LITHOLOGY Sand,Sandstone,Siltstone,Shell Fragments PRESENT LITHOLOGY 50%sand,50%sandstone DAILY ACTIVITY SUMMARY Drill out of cement,perform LOT.Drill ahead. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3125;Rigwatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 7/2/2010 Daily Report Page 1 of 1 ENI t EPOCH Nikeiaitchuq chuq DAILY WELLSITE REPORT Ell 0P08-04 REPORT FOR J.Keener/D.Morris/A.Buchanan DATE Jul 02,2010 DEPTH 7435' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 5750' 24 HOUR FOOTAGE 1685' CASING INFORMATION 20"@ 154' 13 3/8"@ 2333'95/8"@ 4999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7388.53 86.73 348.59 3747.32 SURVEY DATA 7293.45 86.79 352.05 3741.95 7198.25 87.79 355.28 3737.44 7102.02 89.23 357.16 3734.94 7005.88 89.76 359.54 3734.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog MSR616M-A3D-Z-R 125858 5x12,1x13 5000 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 843.5 @ 7349.00000 1.0 @ 5886.00000 199.5 189.11536 FT/HR SURFACE TORQUE 7488 @ 7235.00000 4061 @ 6000.00000 5349.6 6306.21338 AMPS WEIGHT ON BIT 1937 @ 5900.00000 0 @ 5792.00000 5.1 4.01376 KLBS ROTARY RPM 141 0 6001.00000 99 @ 7032.00000 120.1 124.30801 RPM PUMP PRESSURE 2637 @ 6692.00000 1462 0 5763.00000 2328.4 2464.13379 PSI DRILLING MUD REPORT DEPTH 7170' MW 8.9 VIS - PV 21 VP 14 FL - Gels 17/22/24 CL- 50500 FC -/- SOL 10 SD - OIL 78/22 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 5000'TO 7435' TOOLS PDGR/Inc/GR/PWD/RES/Surv/Density/Neutron GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 487 @ 7349.00000 1 @ 5916.00000 148.0 TRIP GAS- CUTTING GAS 0 @ 7435.00000 0 @ 7435.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 500075 @ 6747.00000 416 @ 6679.00000 35092.3 CONNECTION GAS HIGH- i ETHANE(C-2) 2884 @ 6747.00000 0 @ 6673.00000 195.0 AVG- PROPANE(C-3) 1142 @ 6747.00000 0 @ 6673.00000 88.1 CURRENT- BUTANE(C-4) 2095 @ 5792.00000 0 @ 6673.00000 133.5 CURRENT BACKGROUND/AVG 34/70 PENTANE(C-5) 2094 @ 5792.00000 0 @ 6673.00000 87.8 HYDROCARBON 6700-7435 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6700-7435 Sand/Sandstone 487u Trace stainging is visible;slight odor is present;overall a faint even yellow fluorescence with 30-40%patchy dull yellowish orange;streaming dull yelbwish while cut fluorescence;streaming dark straw visble cut;light amount of dark straw residue;faint yellow residual fluorescence. • LITHOLOGY Sand,Sandstone • PRESENT LITHOLOGY 70%Sand,30%Sandstone DAILY ACTIVITY SUMMARY Drilled ahead as of midnight last night.RigWatch locked up and was down for a couple of hours in the early morning.Drilled ahead.Continueing to drill as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3325;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 7/3/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitcnuq DAILY WELLSITE REPORT Ell OP08-04 REPORT FOR J.Keener/D.Morris/A.Buchanan DATE Jul 02,2010 DEPTH 7435' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 5750' 24 HOUR FOOTAGE 1685' CASING INFORMATION 20"@ 154'13 3/8"@ 2333'9 5/8"@ 4999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7388.53 86.73 348.59 3747.32 7293.45 86.79 352.05 3741.95 SURVEY DATA 7198.25 87.79 355.28 3737.44 7102.02 89.23 357.16 3734.94 7005.88 89.76 359.54 3734.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog MSR616M-A3D-Z-R 125858 5x12,1013 5000 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 843.5 @ 7349.00000 1.0 @ 5886.00000 199.5 189.11536 FT/HR SURFACE TORQUE 7488 @ 7235.00000 4061 @ 6000.00000 5349.6 6306.21338 AMPS WEIGHT ON BIT 1937 @ 5900.00000 0 @ 5792.00000 5.1 4.01376 KLBS ROTARY RPM 141 @ 6001,00000 99 @ 7032.00000 120.1 124.30801 RPM PUMP PRESSURE 2637 @ 6692.00000 1462 @ 5763.00000 2328.4 2464.13379 PSI DRILLING MUD REPORT DEPTH 7170' MW 8.9 VIS - PV 21 YP 14 FL - Gels 17/22/24 CL- 50500 FC -1- SOL 10 SD - OIL 78/22 MBL - pH - Ca* - CCI - MWD SUMMARY INTERVAL 5000'TO 7435' TOOLS PDGR/Inc/GR/PWD/RES/Surv/Density/Neutron GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 487 @ 7349.00000 1 @ 5916.00000 148.0 TRIP GAS- CUTTING GAS 0 @ 7435.00000 0 @ 7435,00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- • METHANE(C-1) 500075 @ 6747.00000 416 @ 6679.00000 35092.3 CONNECTION GAS HIGH- ETHANE(C-2) 2884 @ 6747.00000 0 @ 6673.00000 195.0 AVG- PROPANE(C-3) 1142 @ 6747.00000 0 @ 6673.00000 88.1 CURRENT- BUTANE(C-4) 2095 @ 5792.00000 0 @ 6673.00000 133.5 CURRENT BACKGROUND/AVG 34/70 PENTANE(C-5) 2094 @ 5792.00000 0 @ 6673.00000 87.8 HYDROCARBON 6700-7435 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6700-7435 Sand/Sandstone 487u Trace slainging is visible;slight odor is present;overall a faint even yellow fluorescence with 30-40%patchy dull yellowish orange;streaming dull yellowish white cut fluorescence;streaming dark straw visible cut;light amount of dark straw residue;faint yellow residual fluorescence. LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY 70°%Sand,30%Sandstone ' DAILY ACTIVITY SUMMARY Drilled ahead as of midnight last night.RigWatch locked up and was down for a couple of hours in the early morning.Drilled ahead.Continueing to drill as of report. • EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3325;RigWatch-$1450 REPORT BY Z.Beekman I file://C:\Documents and Settings\EpochAdmin\MVly Documents\My Wells\ENI\Daily Report... 7/4/2010 Daily Report Page 1 of 1 ENI Petroleum El EPOCH Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT OP08-04 PB1 REPORT FOR D.Morris S.Beauchamp;J.Keener DATE 04/07/2010 DEPTH 8840.00000 PRESENT OPERATION Circulate Prior to sidetracking TIME 2400 YESTERDAY 7921.00000 24 HOUR FOOTAGE 919 CASING INFORMATION 9 5/8"@ 4900' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8775.51 96.01 302.5 3700.18 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 Hycolog MSR616M-A3D-Z-R 125858 5X12,1X13 5000 7921 2921 84.33 1-1-CT-S-X-1-NO-BHA BHA 4RR 8.5 Hycolog MSR616M 123905 3x12,6x11 7921 8840 919 7.58 STILL IN DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 460.8 @ 8347.00000 4.5 @ 8292.00000 194.3 115.65200 FT/HR SURFACE TORQUE 10964 @ 8229.00000 5445 @ 7924.00000 7378.5 7579.30800 AMPS WEIGHT ON BIT 13 @ 8294.00000 0 @ 8028.00000 5.6 7.71000 KLBS ROTARY RPM 144 0 7930.00000 92 0 8027.00000 132.6 101.06000 RPM PUMP PRESSURE 2843 0 7925.00000 970 0 8663.00000 2623.1 2703.21900 PSI DRILLING MUD REPORT DEPTH MW 9.0 VIS - PV 20 YP 19 FL 4.1 Gels 24/26/26 CL- 48500 FC -/2 SOL 8,95 SD - OIL 70 MBL - pH - Ca+ - CC! MWD SUMMARY • INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 633 @ 8351.00000 5 @ 8602.00000 182.6 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS WA CHROMATOGRAPHY(porn) SURVEY N/A METHANE(C-1) 121854 @ 8351.00000 948 @ 8602.00000 28277.4 CONNECTION GAS HIGH 28 ETHANE(C-2) 674 @ 8351.00000 6 @ 8798.00000 139.3 AVG 25 ' PROPANE(C-3) 255 @ 8348.00000 2 @ 8823.00000 49.2 CURRENT 22 • BUTANE(C-4) 398 @ 8349.00000 3 @ 8823.00000 89.1 CURRENT BACKGROUND/AVG 5 i PENTANE(C-5) 432 @ 8571.00000 0 @ 8696.00000 95.1 HYDROCARBON 7921-8450 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 7921-8450 SAND-SANDSTONE 200- ABOVE OBM;DARK BROWN OIL STAINING WITHIN SANDSTONE CUTTINGS WHEN SPLIT OPEN;80-100%EVEN YELLOW SAMPLE • 633 FLUORESCENCE;0-20%DARK YELLOW TO ORANGE PATCHY SAMPLE FLUORESCENCE,DUE TO OIL SOAKED SANDSTONE CUTTINGS; IMMEDIATE FAINT WHITE CUT FLUORESCENCE;DARK STRAW TO LIGHT AMBER VISIBLE CUT;MEDIUM AMOUNT OF DARK STRAW VISIBLE • RESIDUE;MODERATELY BRIGHT YELLOW TO YELLOWISH WHITE RESIDUAL FLUORESCENCE LITHOLOGY .Interbedded silty shale and shaly sillstone with occasional thin sandy intervals. PRESENT LITHOLOGY 30%Shale,60%Sillstone,10%Sand DAILY ACTIVITY SUMMARY Drill aheasd from 7921'to 8598'.Circulate and ream dogleg.Drill ahead iron 8598'to 8440'.Circulate bottoms up and pull out of the hole 10 stands for sidetrack at 8123'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3325,RW 1450 REPORT BY John Lundy • file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 7/5/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq/Olik[ok Point DAILY WELLSITE REPORT El OP08-04 REPORT FOR J.Keener,D.Merris,A.Buchanan DATE Jul 05,2010 DEPTH 8175.00000 PRESENT OPERATION Testing BOPS TIME 2400 YESTERDAY 8123.00000 24 HOUR FOOTAGE 52 CASING INFORMATION 9 5/8"@ 4999' 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 5RR 8.5" Hycolog MSR616M 123905 3x12s,60115 8123 8175 52 9.78 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 391.8 @ 8123.00000 4.2 @ 8173.00000 56.6 18.83673 FT/HR SURFACE TORQUE 7818 @ 8123.00000 6122 @ 8140.00000 6596.8 6452.97559 AMPS WEIGHT ON BIT 2 @ 8174.00000 0 @ 8155.00000 0.3 0.66318 KLBS ROTARY RPM 142 @ 8124.00000 80 0 8168.00000 121.5 101.19550 RPM PUMP PRESSURE 2836 0 8166.00000 2607 0 8155.00000 2759.6 2775.12891 PSI DRILLING MUD REPORT DEPTH 8175/3746 MW 9.0 VIS - PV 19 YP 19 FL - Gels 22/24/25 CL- 49000 PC - SOL 9.53 SD - OIL 68 MBL - pH - Ca. - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 350 @ 8123 2 @ 8165.00000 11.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 53283 @ 8123 326 @ 8164 1793.5 CONNECTION GAS HIGH ETHANE(C-2) 243 @ 8123 0 @ 8171 6.4 AVG PROPANE(C-3) 61 @ 8123 0 @ 8171 2.1 CURRENT BUTANE(C-4) 90 @ 8123. 0 @ 8171 3.4 CURRENT BACKGROUND/AVG 1-2 PENTANE(C-5) 60 @ 8123. 2 @ 8169 12.4 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Interbedded sand,shale and siltstone PRESENT LITHOLOGY 70%Sand/sandstone;20%Sittstone;10%shale DAILY ACTIVITY Circulate and prepare for sidetrack at 8123';begin open hole sidetrack,work/rework section to 8175'.Sterring tool failure.Circulate hole clean and pull out of the hole to surface.Lay down SUMMARY steering tool.UD nuclear source.Download MWD data.Test BOPs. EPOCH PERSONNEL ON BOARD 4, DAILY COST DML 3325;RW 1450 REPORT BY John Lundy file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 7/6/2010 Daily Report Page 1 of 1 ENI Petroleum PI EPOCH Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT OP08-04 REPORT FOR J.Keener,D.Morris,A.Buchanan DATE Jul 06,2010 DEPTH 9035.00000 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 8176.00000 24 HOUR FOOTAGE 859 CASING INFORMATION 9 5/8"@ 4999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9016.04' 86.32 297.38 3757.06' BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" HycologMSR616M 1239.5 3x12s,6x11s 8123 Still In 912 17.28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 628.9 @ 8993.00000 4.2 @ 8974.00000 207.8 244.36601 FT/HR SURFACE TORQUE 10691 0 8992.00000 5681 0 8222.00000 7618.4 8009.18408 AMPS WEIGHT ON BIT 46 @ 8176.00000 0 @ 8178.00000 6.4 5.07444 KLBS ROTARY RPM 141 0 8978.00000 78 0 8183.00000 119.0 141.56425 RPM PUMP PRESSURE 2789 99 8202.00000 2027 @ 8621.00000 2598.4 2669.42725 PSI DRILLING MUD REPORT DEPTH 8999/3755 MW 8.9 VIS - PV 24 VP 16 FL 4 Gels 18/29/32 CL- 48000 FC -/3 SOL 11,42 SD - OIL 70 MBL - pH - Ca. - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 803 @ 8903.00000 3 @ 8985.00000 367.9 TRIP GAS 314u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 123841 @ 8915 674 @ 8985 55962.4 CONNECTION GAS HIGH ETHANE(C-2) 575 @ 8913 1 @ 8176 259.3 AVG PROPANE(C-3) 199 @ 9005 0 @ 8176 65.2 CURRENT BUTANE(C-4) 710 @ 9004 0 @ 8176 111.6 CURRENT BACKGROUND/AVG 6/10 PENTANE(C-5) 1299 @ 9004 0 @ 8474 76.6 HYDROCARBON 8176-9035 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8176-9035 Sand/sandstone 10010 80 TO 100%DULL YELLOW WHITE SAMPLE FLUORESCENCE;GOOD FAST STREAMING CUT TO MILKY BRIGHT YELLOW WHITE;MODERATE 803 BROWNISH AMBER RESIDUE RING CUTS READILY TO MILKY YELLOW WHITE;TRACE RAW OIL ODOR OVER OBM BACKGROUND ODOR; SLIGHT STAIN ON SOME SAND GRAINS;MARKED BROWNISH STAIN ON INTERIOR OF INTACT SANDSTONE FRAGMENTS LITHOLOGY Interbedded sand/sandstone and Siltstone PRESENT LITHOLOGY 90%Sand/sandstone,10%Siltstone DAILY ACTIVITY SUMMARY Continue testing BOPS per plan.Pick up/make up BHA#6,load nuclear source and run into hole to bottom.Orient and locate sidetrack.Drill ahead from 8176'to 9035' EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3565,RW 1450 REPORT BY John Lundy file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\20100706.htm 7/7/2010 Daily Report Page 1 of 1 ENI Petroleum Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT EPOCH OP08-04 REPORT FOR J.Keener,D.Morris,A.Buchanan DATE Jul 07,2010 DEPTH 10490.00000 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 9035.00000 24 HOUR FOOTAGE 1455 CASING INFORMATION 9 5/8"0 4999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10261.51' 91.83 302.53 3750.10' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" HycologMSR616M 12395 3x12s,6-11s 9123 Still in 1367 30.68 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 378.8 @ 9750.00000 4.6 @ 9322.00000 185.1 187.50000 FT/HR SURFACE TORQUE 12391 0 9805.00000 7568 @ 9271.00000 9106.9 9682.55800 AMPS WEIGHT ON BIT 18 @ 10172.00000 0 @ 10149.00000 6.6 6.08300 KLBS ROTARY RPM 144 0 9103.00000 117 @ 10270.00000 123.3 122.28400 RPM PUMP PRESSURE 2967 0 10483.00000 1419 @ 9157.00000 2747.1 2952.11900 PSI DRILLING MUD REPORT DEPTH 10126/3753 MW 8.9 VIS - PV 19 VP 15 FL 4.8 Gels 17/25/27 CL- 48000 FC -/3 SOL 9.47 SD - OIL 71 MBL - pH - Ca* - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 738 @ 9771.00000 4 @ 9111.00000 256.3 TRIP GAS CUTTING GAS 0 @ 10490.00000 0 @ 10490.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 112662 @ 9771.00000 883 @ 9110.00000 40976.1 CONNECTION GAS HIGH ETHANE(C-2) 675 @ 10113.00000 0 @ 9625.00000 205.9 AVG PROPANE(C-3) 290 @ 10111.00000 0 @ 9625.00000 56.6 CURRENT BUTANE(C-4) 680 @ 10111.00000 0 @ 9625.00000 115.2 CURRENT BACKGROUND/AVG 12/8 PENTANE(C-5) 450 @ 9041.00000 0 0 9625.00000 82.8 HYDROCARBON 9035-10500 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9 035-1 050 0 Sand/sandstone 100- Slight to pronounced oil slain throughout;100%dull yellow white fluorescence mottled with brighter sticky oil soaked sandstone fragments;fast streaming 738u cut to milky bright yellow white;brownish amber residue ring cuts immediately to yellow white;slight oil odor over obm. LITHOLOGY Sand/Sandstone PRESENT LITHOLOGY 100%Sand/Sandstone DAILY ACTIVITY SUMMARY Drill from 9035'to 10490'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3125,RW 1450 REPORT BY John Lundy file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 7/8/2010 Daily Report Page 1 of 1 ENI Petroleum PI EPOCH Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT 0P08-04 REPORT FOR J.Keener,D.Morris,A.Buchanan DATE 8 July 2010 DEPTH 11240 PRESENT OPERATION POOH to wipe atTD TIME 2400 YESTERDAY 10490 24 HOUR FOOTAGE 750 CASING INFORMATION 9 5/8"@4999 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA (P)11240 TD 99.05 301.95 3705.97 11177 99.05 301.95 3715.81 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" Hycolog MSR616M 12395 3x125,6-11s 9123 11240 2117 36.2 Still In TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 455.9 @ 10910 6.2 @ 10737 2072 0.00000 FT/HR SURFACE TORQUE 14425 @ 10938 9554 @ 10493 11030.7 AMPS WEIGHT ON BIT 18 @ 10737 0 @ 10983 7.8 0.00000 KLBS ROTARY RPM 143 @ 10544 119 @ 10512 140.8 RPM PUMP PRESSURE 3165 @ 10739 1037 @ 10984 2892.9 PSI DRILLING MUD REPORT DEPTH 11240/3706 MW 8.9 VIS - PV 18 YP 15 FL 5 Gels 16/24/25 CL- 46000 FC -/3 SOL 11.5 SD - OIL 71 MBL - pH - Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 592 @ 10723 11 @ 10733 312.9 TRIP GAS CUTTING GAS @ @ WIPER GAS 141 CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 110852 @ 10723 1854 @ 10733 57103.8 CONNECTION GAS HIGH ETHANE(C-2) 810 @ 10731 8 @ 11198 288.1 AVG PROPANE(C-3) 362 @ 10731 7 @ 11198 85.1 CURRENT BUTANE(C-4) 855 @ 10731 14 @ 11198 143.6 CURRENT BACKGROUND/AVG 23/30 PENTANE(C-5) 645 @ 10731 13 @ 11198 111.2 HYDROCARBON 10490-11140 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10490-11140 Sand/Sandstone 100 to Sample fluoresces even light bright green;instantaneous bluish white streaming cut;amber oil staining on sand grains;residual cut is bluish white; 592 slight oil odor;no oil at shakers;porosity and permeability visually good LITHOLOGY Sandstone/Sand and siltstone PRESENT LITHOLOGY 100%Siltstone DAILY ACTIVITY Drill to TD at 11240'at 09:40AM.Rotat and reciprocate while circulating hole clean.Wipe 10 stands.Run into hole to bottom.Circulate hole clean,141u Gas.Continue circulating hole SUMMARY clean.Pull out of the hole with elevators 18 stands.Continue wiping hole backreaming to 8452. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3315;RW 1450 REPORT BY jOHN IUNDY file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 7/9/2010 Daily Report Page 1 of 1 ENI Petroleum [ EPOCH Nikaitehuq/oliktek Point DAILY WELLSITE REPORT OP08-04 REPORT FOR J.Keener,D.Merris,A.Buchanan DATE 9 July 2010 DEPTH 11240 PRESENT OPERATION Prep to POOH TIME 2400 YESTERDAY 11240 24 HOUR FOOTAGE 750 CASING INFORMATION 9 5/8"@4999 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA (P)11240 TD 99.05 301.95 3705.97 11177 99.05 301.95 3715.81 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" Hycolog MSR616M 12395 3x12s,6-11s 9123 11240 2117 36.2 Still In 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 11240/3706 MW 9.3 VIS - PV 20 YP 6 FL - Gels 2/2/3 CL- 191000 FC - SOL 10.5 SD - OIL 45.5 MBL - pH - Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 297 CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 6/10 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone/Sand and siltstone PRESENT LITHOLOGY 100%Siltstone DAILY ACTIVITY Continue wiping hole,back-reaming to casing shoe at 4999'.Cut and slip drilling line.Run into hole to bottom.Circulate hole clean.Wiper gas 297u.Continue circulating hole clean. SUMMARY Displace to new mud.Mix and pump dry job. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3700;RW 1450 REPORT BY John Lundy file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\20100709.h... 7/10/2010 Daily Report Page 1 of 1 ENI Petroleum HI EPOCH Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT 0P08-04 REPORT FOR S.BEAUCHAMP D.Morris,A.Buchanan DATE 10 July 2010 DEPTH 11240 PRESENT OPERATION RIH with liner TIME 2400 YESTERDAY 11240 24 HOUR FOOTAGE CASING INFORMATION 9 5/8"@4999 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA (P)11240 TD 99.05 301.95 3705.97 11177 99.05 301.95 3715.81 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" Hycolog MSR616M 12395 3512s,6-11s 9123 11240 2117 36.2 Still In 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 11240/3706 MW 9.3 VIS - PV 15 YP 8 FL - Gels 3/4/4 CL- 187500 FC - SOL 10 SD - OIL 45.25 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 3 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone/Sand and siltstone PRESENT LITHOLOGY 100%Siltstone DAILY ACTIVITY Pull out of the hole on elevators 41 stands.Continue pulling out of the hole laying down singles.Lay down 272 singles.Lay down BHA/MWD,lay down nuclear source and download MWD SUMMARY data.Rig up to run production liner.Run into hole with production liner. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3125;RW 1450 REPORT BY John Lundy file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 7/11/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT lEil OP08-04 REPORT FOR S.BEAUCHAMP D.Morris,A.Buchanan DATE 11 July 2010 DEPTH 11240 PRESENT OPERATION Rig Up to run liner TIME 2400 YESTERDAY 11240 24 HOUR FOOTAGE CASING INFORMATION 9 5/8"@4999 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA (P)11240 TD 99.05 301.95 3705.97 11177 99.05 301.95 3715.81 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" Hycolog MSR616M 12395 3x12s,6-11s 9123 11240 2117 36.2 Still In 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 11240/3706 MW 9.3 VIS - PV 15 VP 8 FL - Gels 2/4/5 CL- 185500 FC - SOL 10 SD - OIL 45.25 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 3 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone/Sand and siltstone PRESENT LITHOLOGY 100%Silistone DAILY ACTIVITY SUMMARY Run 5.5"slotted liner,laydown drill pipe,run in production pumps. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3125;RW 1450 REPORT BY Tollef Winslow file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 7/12/2010 Daily Report Page 1 of 1 ENI Petroleum El EPOCH Nikaitchuq/Oliktok Point DAILY WELLSITE REPORT OP08-04 REPORT FOR S.BEAUCHAMP D.Morris,A.Buchanan DATE 12 July 2010 DEPTH 11240 PRESENT OPERATION RIH 4.5"Liner TIME 2400 YESTERDAY 11240 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@4999 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA (P)11240 TD 99.05 301.95 3705.97 11177 99.05 301.95 3715.81 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR5 8.5" Hycolog MSR616M 12395 3s12s,6-11s 9123 11240 2117 36.2 Still In TO 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 11240/3706 MW 9.3 VIS - PV 15 YP 8 FL - Gels 2/4/5 CL- 185500 FC - SOL 10 SD - OIL 45.5 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 3 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone/Sand and siltstone PRESENT LITHOLOGY 100%Siltstone . .__..— DAILY ACTIVITY SUMMARY Test Plug assembly to 10,000 PSI for 15 min.Rig up and run 4.5"tubing EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3125;RW 1450 REPORT BY Tollef Winslow file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\EN1\Daily Repor... 7/13/2010
