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Home My WebLink About211-1011. 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 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: NIKAITCHUQ 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,601 main 13,590 L1 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Main Liner Slotted L1 Liner Slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG 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 NA NA NA 13,531 6,103 7,428 5-1/2" See Schematic 907-777-8438 keith.lopez@hilcorp.com Operations Manager January 26, 2026 13,5707,865 4-1/2" 3,900 Perforation Depth MD (ft): See Schematic 3,8805-1/2" 20" 13-3/8" 160 9-5/8"6,103 2,669 NA 5,020psi 160 2,479 3,999 160 2,669 L-80 TVD Burst 5,550 Slotted MD 5,750psi Hilcorp Alaska, LLC Length Size Proposed Pools: 3,872 main 3,897 L1 13,531 main 13,590 L1 3,880 main 3,897 L1 1,138 SCHRADER BLUFF OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388571, ADL0388574, ADL0388583, ADL0391283 211-101 and 221-016 NA NIKAITCHUQ SP18-N05 and L1 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23453-00-00 and 60-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Slotted Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Keith Lopez 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: No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2026.01.09 15:12:09 - 09'00' Sara Hannegan (2519) 326-022 By Grace Christianson at 4:17 pm, Jan 09, 2026 A.Dewhurst 12JAN26MGR09JAN2026 DSR-1/16/26 10-404 * BOPE pressure test to 2500 psi. 48 hour notice to AOGCC for opportunity to witness. 01/20/26 Well: SP-18 PTD: 211-101 API: 50-629-23453-00-00 Well Name:SP-18 API Number:50-629-23453-00-00 Current Status:Producer Rig:Team Snubbing 101 Estimated Start Date:1/26/26 Estimated Duration:10 days Regulatory Contact:Darci Horner Permit to Drill Number:211-101 First Call Engineer:Keith Lopez (907) 777-8438 (O) (907) 903-5432 (M) Second Call Engineer:Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (M) Current Bottom Hole Pressure: est 1,537 psi @ 3,994 TVD |7.4 PPGE Max Potential Surface Pressure: 1,138 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 83° Sail Angle at end of motor set depth of 5,687 MD Brief Well Summary: SP18 was drilled and completed as a dual lateral Schrader Bluff Oa sand producer in November 2019. This well has had 2 conventional ESPs run with an average run life of 2 years. The current ESP ran for 1.75 years before failing on 11/23/25. Objectives: Pull ESP completion, perform wellbore cleanout as necessary, and run new ESP completion. Notes Regarding Wellbore Condition: Casing was tested on 04/19/2021 from 5,826 to 1,500 psi for 30 minutes (good test). HWO Conditions Traditional well control approach will be implemented. KWF will be a barrier at all times during HWO operations. No snubbing operations are planned during this work. Team Snubbings BOP stack will be used for this operation (see attachment). Pre-Rig Procedure (Non Sundried Work) Operations: 1. Bleed off gas cap from IA before the rig move to the well. HWO Procedure (Begin Sundried Work) 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit 101, ancillary equipment, and lines. 2. Displace corrosion inhibitor from capillary line prior to pulling ESP. 3. Kill well by bullheading the tubing string and the IA with injection water. a. Tubing volume 85.2 bbls. b. Annulus volume 328.5 bbls. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. 5. Install BPV/TWC inside tubing hanger as per Vault. 6. Nipple up BOP. Well: SP-18 PTD: 211-101 API: 50-629-23453-00-00 7. Conduct BOP Test. 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 8. Pull BPV/TWC from the tubing hanger per Vault procedure. 9. Call out ESP Contractor to pull ESP and pull tubing hanger. 10. RU tubing handling equipment. 11. Pump approximately 10 bbl/hour (+ pipe displacement while pulling pipe) of injection water down the annulus throughout the operations to maintain well fill. 12. POOH with 4-1/2 ESP completion laying down tubing and ESP. Record number of clamps recovered. 13. PU cleanout assembly and cleanout casing and liner as deep as practical. 14. RIH with ESP completion on 3-1/2 or 4-1/2 tubing to +/- 5,650 pump discharge set depth. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. 15. Land tubing hanger. Use extra caution to not damage cable. 16. Lay down landing joint. 17. Set BPV/TWC, ND BOP. 18. NU tree and test, pull BPV/TWC. 19. RDMO TS HWO 101. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Snubbing BOP diagram (TSI) 4. HWO Fluid Flow Diagrams (TSI) 5. Snubbing stack stabilization diagram (TSI) 4-½ 12.6 ppf TK15-XT W563Production TubingSP18-N5L1Dual Lateral Producerwith ESP LiftNikaitchuq Field Spy IslandAs Completed: March 20245,705' MD / 3,975' TVDBaker SLXP LinerHanger/Packer~5,765 5,782' MD,Casing Exit Windowx-cplg cable clamps, for ESP PowerCable, (2ea) 3/8" Chem Inj Line with2500 psi check valve at bottom5,684' MD / 3,972' TVD Bottom of Motor Centralizer Centrilift, Conventional ESP, 65 Stage Flex 8013570' MD / 3.897 TVDBent Joint withEccentric ShoeTD 8 3/413,590' MD3,897' TVD90.5º Inc.5-½ 15.5 ppf L80Slotted LinerSealbore Receptacle4.75" ID5-½ Silver Bullet Ecc. Nose Guide Shoe13,531' MD, 3880' TVD, 97º Inc. Interm. Casing9-5/8", 40#, 6103' MD, 3999' TVD, 91ºInc.Zonal Isolation SwellPackersSwell Packer MDs (ft):#1) 11,755#2 11,213#3) 8,393#4) 7,490Lower lateral BakerSLXP Liner Hanger/Packer #1Surf. Casing13-3/8", 68 # BTC2,669' MD, 2,479' TVD20º Inc. Lower lateral BakerSLXP Liner Hanger/Packer #2Swell Packer MDs (ft):L1#1) 12,093L1#2 11,887L1#3) 11,567L1#4) 11,115L1#5) 10,632L1#6) 10,474L1#7) 10,195L1#8) 10,047L1#9) 5,872L1#10) 5,8185548' MD / 3955' TVD XN-Nipple5598' MD / 3962' TVD Discharge Gauge5607' MD / 3963' TVD Pump 2 Flex 805629' MD / 3966' TVD Pump 1 5385639' MD / 3967' TVD Gas Separator5659' MD / 3969' TVD Motor 562XP5687' MD / 3972' TVD Bottom of Shroud 3-½ 9.3 ppf 13Cr or 4-½ 12.6 ppf TK15-XTW563 Production TubingSP18-N5L1Dual Lateral Producerwith ESP LiftNikaitchuq Field Spy IslandProposed: Jan 20265,705' MD / 3,975' TVDBaker SLXP LinerHanger/Packer~5,765 5,782' MD,Casing Exit Windowx-cplg cable clamps, for ESP PowerCable, (2ea) 3/8" Chem Inj Line with2500 psi check valve at bottom5,684' MD / 3,972' TVD Bottom of Motor Centralizer Centrilift, Conventional ESP, 65 Stage Flex 8013570' MD / 3.897 TVDBent Joint withEccentric ShoeTD 8 3/413,590' MD3,897' TVD90.5º Inc.5-½ 15.5 ppf L80Slotted LinerSealbore Receptacle4.75" ID5-½ Silver Bullet Ecc. Nose Guide Shoe13,531' MD, 3880' TVD, 97º Inc. Interm. Casing9-5/8", 40#, 6,103' MD, 3999' TVD91º Inc.Zonal Isolation SwellPackersSwell Packer MDs (ft):#1) 11,755#2 11,213#3) 8,393#4) 7,490Lower lateral BakerSLXP Liner Hanger/Packer #1Surf. Casing13-3/8", 68 # BTC2,669' MD, 2,479' TVD20º Inc. Lower lateral BakerSLXP Liner Hanger/Packer #2Swell Packer MDs (ft):L1#1) 12,093L1#2 11,887L1#3) 11,567L1#4) 11,115L1#5) 10,632L1#6) 10,474L1#7) 10,195L1#8) 10,047L1#9) 5,872L1#10) 5,818~5548' MD / 3955' TVD XN-Nipple~5598' MD / 3962' TVD Discharge Gauge~5607' MD / 3963' TVD Pump 2 Flex 80~5629' MD / 3966' TVD Pump 1 538~5639' MD / 3967' TVD Gas Separator~5659' MD / 3969' TVD Motor 562XP~5687' MD / 3972' TVD Bottom of Shroud TEAM SNUBBINGINTERNATIONALSP-12BOP Stack Drawing54.13"33.8"33.8"24.0"13 5/8"00 PSI Annular5000 PSI Single Gae VBR:2 7/8" - 5 1/2"5000 PSI Single GaeBlinds5000 PSI Flow Cross5000 PSI Riser5013 5/8" 13 5/8" 13 5/8" 13 5/8" New Plugback Esets 6/21/2024 Well Name API Number PTD Number ESet Number Date Kaladachabuna 2 PB1 50-283-20169-70-00 212-157 T38946 5-3-2013 Kaladachabuna 2 PB2 50-283-20169-71-00 212-157 T38947 5-3-2013 Kaladachabuna 2 PB3 50-283-20169-72-00 212-157 T38948 5-3-2013 Kaladachabuna 2 PB4 50-283-20169-73-00 212-157 T38949 5-3-2013 ODSN-18 PB1 50-703-20624-70-00 210-142 T38950 2-18-2011 ODSN-18 PB2 50-703-20624-71-00 210-142 T38951 2-18-2011 ODSN-18 PB3 50-703-20624-72-00 210-142 T38952 2-18-2011 ODSN-18 PB4 50-703-20624-73-00 210-142 T38953 2-18-2011 ODSN-18 PB5 50-703-20624-74-00 210-142 T38954 2-18-2011 ODSN-24 PB1 50-703-20662-70-00 212-178 T38955 6-13-2013 ODSN-24 PB2 50-703-20662-71-00 212-178 T38956 6-13-2013 PBU 18-27E PB2 50-029-22321-72-00 212-131 T38957 2-12-2013 PBU 18-27E PH 50-029-22321-71-00 212-131 T38958 2-12-2013 Redoubt Unit 7 PB1 50-733-20526-70-00 203-150 T38959 10-22-2003 SP18-N05 PB1 50-629-23453-70-00 211-101 T38960 7-11-2016 3K-103 PB1 50-029-23392-70-00 208-115 T38961 2-3-2009 3K-103 PB2 50-029-23392-71-00 208-115 T38962 2-3-2009 3K-103 PB3 50-029-23392-72-00 208-115 T38963 2-3-2009 3K-103 PB4 50-029-23392-73-00 208-115 T38964 2-3-2009 3K-103 PB5 50-029-23392-74-00 208-115 T38965 2-3-2009 ODSN-25 PB1 50-703-20656-70-00 212-030 T38966 8-11-2012 ODSN-25 PB2 50-703-20656-71-00 212-030 T38967 8-11-2012 ODSN-25 PB3 50-703-20656-72-00 212-030 T38968 8-11-2012 ODSN-25 PB4 50-703-20656-73-00 212-030 T38969 8-11-2012 SP18-N05 PB1 50-629-23453-70-00 211-101 T38960 7-11 -2016 From:Brooks, Phoebe L (OGC) To:Rig 15 Cc:Regg, James B (OGC) Subject:RE: Rig 15 SP-18-5N BOP test 3-22-24 Date:Thursday, April 18, 2024 9:48:39 AM Attachments:Doyon 15 03-22-24 Revised.xlsx Attached is a revised report correcting the well name to reflect NIK SP18-N05, adding the test time (based on the start/stop times), and the HCR test result to the Control System Response Times. Please review and update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. -----Original Message----- From: Rig 15 <rig15@doyondrilling.com> Sent: Saturday, March 23, 2024 6:55 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: Rig 15 SP-18-5N BOP test 3-22-24 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Your message is ready to be sent with the following file or link attachments: BOP Test SP-18-5N 3-22-24.xlsx Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 1LNDLWFKXT631 37' revised report well name test time HCR test STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 3/22/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2111010 Sundry #323-674 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250-3500 Annular:250-3500 Valves:250-3500 MASP:1302 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1FP Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 3-1/2x6"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 3-1/2x6"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8"-5k P Time/Pressure Test Result HCR Valves 4 3-1/8"-5k P System Pressure (psi)2950 P Kill Line Valves 4 3-1/8"-5k P Pressure After Closure (psi)2150 P Check Valve 0NA200 psi Attained (sec)12 P BOP Misc 0NAFull Pressure Attained (sec)53 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10@4200 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 9 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0NA #3 Rams 8 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:5.5 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/20/24@09:21 Waived By Test Start Date/Time:3/22/2024 8:00 (date) (time)Witness Test Finish Date/Time:3/22/2024 13:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Doyon All test performed with test plug, Test Annular 250-3500psi/5min. with 4-1/2" test jt. Upper and Lower Preventors 3-1/2x6" variable with 4-1/2" test jt. 250-3500psi/5min.ea. F/P Lower Kelly valve on low pressure test- serviced valve and retest Good. T.Shones / T.Kruger ENI T.Ashley / M.Grubb Nikaitchuq SP18-N05 Test Pressure (psi): rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2024-0322_BOP_Doyon15_Nikaitchuq_SP18-N5 9 99 999 9 9 9 9 9 9 - 5HJJ 9 F/P Lower Kelly valve FP From:Brooks, Phoebe L (OGC) To:Rig 15 Cc:Regg, James B (OGC) Subject:RE: Rig 15 BOP Test SP18-N5 Date:Wednesday, April 17, 2024 3:35:41 PM Attachments:Doyon 15 03-15-24 Revised.xlsx I revised report to include "NA" in all fields that included "0". Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. -----Original Message----- From: Rig 15 <rig15@doyondrilling.com> Sent: Saturday, March 16, 2024 3:27 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Ashley Timothy <Timothy.Ashley@external.eni.com> Cc: Bruce.Simonson@external.eni.com; ENI SID COMPANY MAN (SIDDrilling@eni.com) <SIDDrilling@eni.com>; Enipetroleum AKRigClerksDoyon15 (AKRigClerksDoyon15@eni.com) <AKRigClerksDoyon15@eni.com> Subject: Rig 15 BOP Test SP18-N5 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Your message is ready to be sent with the following file or link attachments: SP18-N5 BOP test 3-15-24.xlsx Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 1LNDLWFKXT631 37' revised STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 3/14/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2111010 Sundry #323-674 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250-3500 Annular:250-2500 Valves:250-3500 MASP:1302 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 3-1/2 x 6"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 3-1/2 x 6"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8"x 5k P Time/Pressure Test Result HCR Valves 4 3-1/8"x 5k P System Pressure (psi)2975 P Kill Line Valves 2 3-1/8"x 5k P Pressure After Closure (psi)2200 P Check Valve 0NA200 psi Attained (sec)12 P BOP Misc 0NAFull Pressure Attained (sec)47 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10@4150 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 13 P #1 Rams 10 P Coiled Tubing Only:#2 Rams 11 P Inside Reel valves 0NA #3 Rams 11 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:11.0 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-9-24@1:50pm Waived By Test Start Date/Time:3/15/2024 1:00 (date) (time)Witness Test Finish Date/Time:3/15/2024 12:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Josh Hunt Doyon All test performed with hanger and Standing Valve installed, test Annular with 4-1/2" test jt. Upper & Lower rams 3-1/2x6" variable with both 4-1/2 & 5" test jt. Annular 250-3500psi/5min. Preventers and choke valves 250-3500psi/5min. T.Shones / T.Kruger ENI B.Simonson / Nikaitchuq SP18-N05 Test Pressure (psi): rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2024-0315_BOP_Doyon15_Nikaitchuq_SP18-N5 9 9 9 9 9999 9 9 9 9 -5HJJ 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _ESP Changeout___ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,601 feet N/A feet true vertical 3,872 feet N/A feet Effective Depth measured 13,531 feet N/A feet true vertical 3,880 feet N/A feet Perforation depth Measured depth 6103-13,531 feet True Vertical depth 3,999-3,880 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 5,548' 3,955' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci 4/15/2024 Digital Signature with Date:Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3300 323-674 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG 80 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 2532 15629 205 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 404 192 Slotted Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 780 3002594 N/A Length 160 2669 160Conductor Surface Intermediate 2480 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-101 50-629-23453-00-00 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: SP18-N5 MD Burst Collapse measured true vertical Packer N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 391283, 388583, 388574, 388571 Nikaitchuq/Schrader Bluff Oil Pool 160 Eni US Operating Co. Inc. 5210 6890 measured TVD Production Plugs Junk measured 47909.625" Liner 6103 7428 Casing Structural 3999 5.5" 6103 13531 3880 2669 2479 20" 13.375" Size p k ft t Fra O s 211 6. A G L PG , _ Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov io Iannucci 4 By Samantha Coldiron at 8:45 am, Apr 15, 2024 RBDMS JSB 041824 DSR-4/23/24 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/7/2024 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -22.7 Wind SW @ 9 MPH Days LTI (days) 1,524.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Rig move to SP18-N5. 24h Summary Cleaning pill pits. Prep Equipment for rig move Operation at 07.00 Laying herculite and setting mats. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB M 1 P PJSM Complete cleaning pill pit #1 and #2 Pull and stow electrical cables for Mud pump #3 06:00 12:00 6.00 12.00 MOB M 1 P Completed cleaning pit #2 started cleaning pit #5, clean out cutting box, R/D steam loop, freeze protect sub pressure washer pump, blow down steam in pump #3 MOD, R/D steam and air interconnects, prep mod for move, remove plugs in all centrifuges pump snails, clean out containment of fluids, artic lifting inspect, ODS bop bridge crane, man rider and mud pits pallets winch. 12:00 18:00 6.00 18.00 MOB M 1 P Prep to move MP3 / fuel cold start on MP3 B/D rod wash pumps and pull plugs on snails / start cleaning pit #5 replace bad steam line on rig floor. 18:00 00:00 6.00 24.00 MOB M 1 P Finish clean pit #5 / continue replacing bad steam line on rig floor / B/D water in pits and pump room / move MP#3 away from rig and stage on pad / Install false door on pump room, receive 1.500 gals of fuel Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/8/2024 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -24.0 Wind SW @ 10 MPH Days LTI (days) 1,525.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Rig move to SP18-N5. Spot Rig and Equipment over well 24h Summary Prep Equipment for rig move Operation at 07.00 Skid Rig Floor. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB M 2 P PJSM, Move MP#3 Mod and spot on west side of location, remove cuttings chute and Mob cuttings tank, R/D suit cases and mud plant /diesel suit cases, bag all connections, Prep SP18 location for Herculite. 06:00 12:00 6.00 12.00 MOB M 2 P PJSM Clear snow away from well bay and prep location for Herculite as per ENI Electrical spool up HI-Line cable, freeze protect washer and pressure washer pump in pits. Set top drive in slips and secure torque tube with chain and binders. Weld guard for beaver slide heater steam pipe. Set up pipe shed for splitting Mods. 12:00 18:00 6.00 18.00 MOB M 2 P PJSM Lay out Herculite, fuel rig generator day tank, Lay out rig mats on SP18, perform derrick inspection, prep to blow down steam on rig floor. 18:00 00:00 6.00 24.00 MOB M 2 P Blow down steam loop rig floor and mezzanine, continue laying out rig mats for rig move to SP18-N5. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/9/2024 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -22.7 Wind W @ 5 MPH Days LTI (days) 1,526.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Continue spotting Equipment and rigging up, take on 8.6 ppg brine in pits. 24h Summary Rig move SP18-N5 spot sub and equipment. Operation at 07.00 Rig Move. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 2 P PJSM Blow down steam heaters and lines in pit and pump module. Prep to skid rig floor, check pressures in all rig tires. Turn sub tires to pull away from well bay, disconnect steam, water, boiler blow down interconnects between sub and pump pit module. 06:00 12:00 6.00 12.00 MOB A 2 P PJSM, Skid rig floor to rig move travel position, raise stompers, perp pipe shed for travel, clear snow ice and debris away from travel path of pit module, lay out matting boards tracks for rig travel, Mob pit module to clear sub turn rear sub tires to move away from well. 12:00 18:00 6.00 18.00 MOB A 2 P Rig move to SP18-N5 spot over center of well 18:00 00:00 6.00 24.00 MOB A 2 P Shim sub structure with timbers, move and spot mud pits to sub structure Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/10/2024 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -36.2 Wind SW @ 8 MPH Days LTI (days) 1,527.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Fill pits 8.6 ppg brine, well kill operations, N/D Tree N/U Bops 24h Summary Spot and Rig up pits, and Pump Modules, skid rig floor, Berm modules Operation at 07.00 Cold Weather Equipment Hold, Prepping Rig Up. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 2 P PJSM, Set stompers and lock nuts, spot and shim pits / pump module. 06:00 12:00 6.00 12.00 MOB A 2 P Install pipe shed, sub roof capes, lower pipe shed transitions and remove hand rails, skid rig floor over well center SP18, prep to M/U flow line, prep to shim rear of pit module. 12:00 18:00 6.00 18.00 MOB A 2 P Build walkways for on/off rig floor, install heater in pump room, close up false door in pump room, cut shims for rear of pits module, prep to jack up and shim mud pits rear, install 24’ suit case start beaming round rig module, take on rig fuel via fuel truck. 18:00 23:00 5.00 23.00 MOB A 2 P Continue beaming round rig module. Turn steam loop back onto pit module, pipe shed and pump room, Help ACS with seam weld herculite together for MP#3 install, Turn steam onto mezzanine deck, pipe shed and bops deck. Temperatures below -35 Degrees @ 23:00 stop all loader operations. 23:00 00:00 1.00 24.00 MOB A 2 TW01 Temperatures below -35 Degrees @ 23:00 stop all loader operations. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/11/2024 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -31.0 Wind SW @ 7 MPH Days LTI (days) 1,528.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Fill pits 8.6 ppg brine, well kill operations, N/D Tree N/U BOPs, test BOPs. 24h Summary Spot MP#3. Continue setting Matting boards. Pressure test lines in suit, continue Berming modules. Change out broken steam lines through the rig. Operation at 07.00 Rigging up, continue berming around rig. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 2 TW01 Ambient temperatures below-35 degrees all loader operation are on hold. SIMOPS: PJSM. Blow down steam on mezzanine, BOP deck, pipe shed, repair steam line in wheel well, change out steam valve ODS under floor. Change out leaking bleeder valves on steam heaters, hang Absorbent holders throughout rig. 06:00 12:00 6.00 12.00 MOB A 2 TW01 Ambient temperatures below-35 degrees all loader operation are on hold. SIMOPS: Continue changing out steam heater bleeders on sub and pipe shed, change out faulty steam trap on pipe shed heater. Make up flow line and mud gas line between pits and sub, raise pipe shed supports and stow hand rails, turn on steam to lower sub and mezzanine. Finish beaming along well bay, pull High-Line cable into rig. 12:00 18:00 6.00 18.00 MOB A 2 P Change out valve on steam supply line on rig floor, turn on steam to rig floor, continue with beaming around the rig, take on boiler water to rig tank, install plugs in centrifuges in pump room. Went on High-Line power @ 13:30 hrs. 18:00 00:00 6.00 24.00 MOB A 2 P PJSM. Set mud shack in place. Continue berming around rig, move and set MP#3 into place. Replace steam union in pump room, hook up choke lines on roof top of pits, hook up steam to MP#3, install plugs in rod wash pump on MP#3, hook up diesel line to suit cases and tested, received fuel to the rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/12/2024 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -24.2 Wind SW @ 6 MPH Days LTI (days) 1,529.00 Days RI (days) POB 52.0 Daily Summary Operations 24h Forecast Install kill lines to tree, well kill operations. Install BPV, N/D Tree N/U BOPs, and test BOPs. 24h Summary Continue rigging up on SP18-N5. Spot and berm up koomy unit. Load 4.5” Completion tubing in pipe shed. Fill pits 8.6 ppg brine. Operation at 07.00 Continue rigging up. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 1 P PJSM. Make up flare bluy and mgs bypass interconnects between pits and sub. Make up choke and water vac lines under rig floor, lay herculite spill containment and build berming for koomy unit. 06:00 14:00 8.00 14.00 MOB A 1 P Continue to make up flare interconnects between pits and sub, pull cables and plug in MP #3, make up high psi mud line under rig floor. Make up high psi mud line and secondary kill between pump room and sub, install cuttings chute on auger. Change out riser cable between pits 3 and 4, replace pill pit 2 and mixing pit 2 suction valves. 14:00 19:00 5.00 19.00 MOB A 25 TR99 Repair 3” water line on rig water tank. 19:00 00:00 5.00 24.00 MOB A 1 P Received 150 joints of 4.5” tubing from AFP. Warm up scissor lift for bringing pipe in shed. Load pipe shed with 145 joints of 563 tubing. Prep to receive 8.6 brine from mud plant. Fill pits with 700 bbl. 8.6 brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/13/2024 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) -25.4 Wind SW @ 13 MPH Days LTI (days) 1,530.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast N/D Tree N/U BOPs, and test BOPs. Make up landing joint pull hanger. Lay down 4.5” tubing and ESP Assembly. 24h Summary Load 4.5” Completion tubing in pipe shed. Fill pits 8.6 ppg brine. Install kill lines to tree, well kill operations, install BPV. Operation at 07.00 Nippling up BOP. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 20 P Load pipe shed with 145 joints of 4.5” 12.6# L-80 W563 TK-15XT Completion tubing. Receive 700 bbl of 8.6 ppg brine from mud plant, install valve springs, suction and discharge caps on mud pumps #1 and #2. Pull Accumulator hoses from unit to the sub. 06:00 12:00 6.00 12.00 MOB A 1 P Completed pulling accumulator hoses from unit to the sub, clean throughout rig clear all walkways and egresses, make up high pressure hoses for secondary kill and tubing and annulus for well kill operations, empty trip tank for deicing and repair manual float, turn on H2O to pits and pump room, fill wash rod wash pumps on #1 and #2, prime pumps #1 and #2 with 8.6 ppg brine. 12:00 15:00 3.00 15.00 MOB M 1 P Fill rod was up on pump #3 set pop-off on MP#3, walk lines and double check line ups for well kill operations. 15:00 21:00 6.00 21.00 MOB M 12 P Pressure test mud lines on pumps 3,500 psi, OA 180 psi, tubing 0 psi, IA 34 PSI, open up to tubing and start pumping, 1.6 bpm at 435 psi, pumped 58 bbl. Pressure started to climb to 800 psi, shut down pump and let bleed down to 100 psi. Begin pumping at 1.1 bpm at 885 psi. Final circulating pressure 910 psi, with a total 115 bbl pumped. Shut down, let tubing pressure bleed to 0 psi, shut in tubing, open up to IA and start pumping at 3 bpm at 81 psi. Final circulating pressure 3 bpm at 6 psi. Total pumped 450 bbl. Shut down pumps, let well pressure bleed down to 0 psi and shut well in. 21:00 22:00 1.00 22.00 MOB M 1 P Monitor tubing and IA pressures. One hour both Pressures reading 0 psi and are on a vacuum. 22:00 00:00 2.00 24.00 MOB C 5 P Vault rep install BPV and blanking plug. Rig down kill hoses and pumping equipment on well head, start to Nipple down tree as per Vault rep. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/14/2024 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -34.8 Wind SW @ 10 MPH Days LTI (days) 1,531.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Continue to test BOPE as per AOGCC and program. Make up landing joint, pull hanger. Lay down 4.5” tubing and ESP pump assembly. 24h Summary Begin to test BOPE as per AOGCC and program. Load 183 joints 5” Drill pipe in shed spot ESP unit run power Operation at 07.00 Continue to test BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. C 5 P PJSM. Nipple down tree as per Vault rep. clean void seal face and prep for install of riser. Nipple up high pressure riser. Nipple 18”x 13-5/8” spool on bottom of BOPE stack. Torque all bolts to 2,300 ft./lbs. Clear all API rings grooves, prep flange bolts. 04:00 12:00 8.00 12.00 W.O. C 5 P Nipple up BOPE. Torque all bolts on 18” flange. High pressure riser to 2,300 ft./lbs. Make up primary and secondary choke and kill lines blocks, make up choke and kill hoses, torque all flanges to spec. Nipple up flow riser, center BOPE stack, install flow line. 12:00 18:30 6.50 18.50 W.O. C 20 P Continue Nippling up. Install SRL’S, drain hoses, flow line, half shell in drip pan, half shell around riser, accumulator hoses, center BOPE stack, splash guard in drip pan. 18:30 00:00 5.50 24.00 W.O. C 12 P Pressure up on Accumulator system- check for leaks. Make up test joint, make up TWC to dart valve with test sub. Make up sub on top drive, grease choke manuals on stack and upper and lower IBOP’S on top drive. Make up test joint test dart on hanger. Rig up test equipment, fill BOPs stack, choke and test joint with water, start to perform shell test. Rig up 2’ hose to bleed tank from IA. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/15/2024 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -33.2 Wind SW @ 9 MPH Days LTI (days) 1,532.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Pull out of the hole lay down 4.5” tubing and ESP pump assembly. Finish loading 5” Drill pipe and Clean out BHA assembly for next run. 24h Summary Test BOPE as per AOGCC and program. Make up landing joint, pull hanger. Rig up Baker Hughes Centralift and GBR tools and equipment prior to laying down tubing. Operation at 07.00 Pull out of the hole lay down 4.5” tubing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. C 1 P PJSM. Rig up 2” high pressure hose from IA to bleed tank. 01:00 12:30 11.50 12.50 W.O. C 12 P Test BOPs with 4.5” and 5” test jnt 250 PSI low, 3500 PSI high, Annular 250 psi low, 3500 PSI high as per AOGCC requirements. Test 3.5”x6” UPR, B/S rams, 3.6”x 6” LPR. Test choke valves 1-15, hydraulic and manual choke. Test kill line valve, choke and kill manual and HCR valves. Test upper and lower IBOP on top drive. Test XT-39 FOSV and dart valve. Test PVT and gas alarms. Perform accumulator draw down test, accumulator pressure 2,975 psi, after function 2,200 psi, 200 psi recovery 12 sec, full recovery 49 sec, number of N2 bottles - 10 total. Average pressure 4,150 psi. All tests are Good test. AOGCC Josh hunt Witness waived 3-11-2024 @ 06:13hrs. 12:30 16:00 3.50 16.00 W.O. C 1 P Rig down test equipment, blow down choke and kill lines, pull test dart and lay down. Pick up T-bar and make up to BPV, check for pressure ( no pressure in tubing) remove BPV. 16:00 18:00 2.00 18.00 W.O. M 20 P Make up TIW valve to landing joint make up into hanger. Perform Derrick inspection. 18:00 20:00 2.00 20.00 W.O. M 5 P Vault rep BOLDS, pull tubing hanger off seat @ UP WT= 195K. Pull hanger to the rig floor with a steady UP/WT of 120k. Break and lay down landing joint and tubing hanger. Make up TIW valve on tubing. Pump 10 bbl/hr of 8.6 brine. 20:00 00:00 4.00 24.00 W.O. M 1 P PJSM. Rig up baker Hughes ESP tools and equipment on rig floor. Pump 10 bbl/hr. 8.6 brine. Note: 24 Hour Loss of 8.6 ppg Brine = 0 bbls. Total Loss of 8.6 ppg Brine = 0 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/16/2024 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -26.5 Wind NW @ 5 MPH Days LTI (days) 1,533.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Pull out of the hole from 701’ to ESP pump. Break and lay down ESP Assembly. Clear and clean tools and equipment from rig floor. Load Clean out assembly in pipe shed. 24h Summary Rig up ESP cable sheaves and elephant trunk in the derrick. Feed rope through the sheaves to the ESP and capillary spools. Pull out of the hole laying down 4 ½” L-80 12.6# hyd 563 tubing with ESP, capillary line from 5,634’ to 701’ MD. Operation at 07.00 Cleaning the rig and pipe shed from ESP equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. L 1 P PJSM. Rig up ESP cable sheaves and elephant trunk in the derrick. Feed rope through the both sheaves to the ESP and capillary spools. Received rig fuel to day tank. 06:00 08:30 2.50 8.50 W.O. L 25 P Continue to rig up GBR and Baker Centralift equipment. Rig electrician trouble shooting pipe skate operating issues. 08:30 12:00 3.50 12.00 W.O. L 4 P PJSM. Pull out of the hole from 5,634’ to 3,854’ MD laying down 4 ½” L-80 12.6# hyd 563 tubing with ESP, capillary line. Fill hole with 8.6 ppg brine 10 bbl/ hr. plus pipe displacement. 12:00 22:00 10.00 22.00 W.O. L 4 P Continue pulling out of the hole from 3,854’ to 707’ MD laying down 4 ½” L-80 12.6# hyd 563 tubing with ESP, capillary line. Fill hole with 8.6 ppg brine 10 bbl/ hr. plus pipe displacement. At 1,480’ MD notice oil on outside of tubing unable to wash off with 8.6 brine. 22:00 00:00 2.00 24.00 W.O. L 4 P Rigged up pressure washer washed tubing while tripping out of the hole from 701’ MD, pulling wet. Notice diesel in tubing. Rigged up to circulate tubing volume at 0.5 bpm at 625 psi. Rig down circulation tools and equipment. Note: 24 Hour Loss of 8.6 ppg Brine = 256 bbls. Total Loss of 8.6 ppg Brine = 256 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/17/2024 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -22.4 Wind NE @ 17 MPH Days LTI (days) 1,534.00 Days RI (days) POB 43.0 Daily Summary Operations 24h Forecast Loading pipe shed 189 joints 5’ drill pipe. Making up Fishing BHA Retrieve ESP pump clamp guides. 24h Summary Pull out of the hole from 701’ to ESP pump. Break and lay down ESP Assembly. Motor clamp centralizers are missing. Clear and clean tools and equipment from rig floor. Rig down GBR and Baker Centralift equipment. Remove the elephant trunk from the derrick. Install the wear bushing. Operation at 07.00 Prepare to pick up cleanout assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. L 4 P PJSM. Pull out of the hole from 701’ to ESP pump assembly. Observed both pumps locked up. The motor is grounded. Motor clamp centralizers are missing. Total clamps recovered 136, 1 Splice clamp, 5 Protectorlizer clamps, 5 Motor clamps, 1 Half clamp. 06:00 09:00 3.00 9.00 W.O. L 1 P Rig down GBR and Baker centrlift equipment. Rig down the elephant trunk from the derrick. Clean and clear the rig floor. Fill hole with 8.6 ppg brine 10 bbl/ hr. 09:00 12:00 3.00 12.00 W.O. M 1 P Change elevators. Rig up and install wear bushing. Fill hole with 8.6 ppg brine 10 bbl/ hr. 12:00 18:00 6.00 18.00 W.O. M 25 U Standby for Worley clamp loader tire to be repaired. Housekeeping around the rig, Weather proof Rig areas. Fill hole with 8.6 ppg brine 10 bbl/ hr. 18:00 00:00 6.00 24.00 W.O. M 20 P Worley clamp loader unload tubing from pipe shed. Bring in baker boxes to load used Pump assembly, warm up scissor lift, drill pipe drift tally drill pipe. Clear used esp. clamps from rig floor. Hoist Clean out BHA up to the rig floor. Begin to load 189 joints 5’ drill pipe in the shed. Fill hole with 8.6 ppg brine 10 bbl/ hr. Note: 24 Hour Loss of 8.6 ppg Brine = 272 bbls. Total Loss of 8.6 ppg Brine = 528 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/18/2024 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -10.1 Wind NE @ 20 MPH Days LTI (days) 1,535.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Cut and Slip Drilling line. Wash last stand to top of liner at 5705’. Conduct Fishing operations. Trip out of the hole. Break and lay down fishing BHA. Clean magnets and reverse basket. 24h Summary Load and process 189 joints TT-525 5”. Make up Fishing BHA assembly. Trip in the hole with Fishing assembly and TT-525 5” drill pipe from 69’ to 4,537’. Operation at 07.00 Cut and slip drill line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. M 1 P PJSM. Continue to load and process 189 joints TT-525 5” drill pipe in the shed. Fill hole with 8.6 ppg brine 10 bbl/ hr. 06:00 12:00 6.00 12.00 W.O. M 5 P Mobilize Baker fishing tools to the rig floor and measure. Make up Fishing BHA tool assembly. Fill hole with 8.6 ppg brine 10 bbl/ hr. 12:00 18:00 6.00 18.00 W.O. M 4 P PJSM. Pick up Singles from pipe shed. Trip in the hole with TT-525 5” drill pipe from 69’ to 2,703’ PUW=70K, SOW= 84K. Fill hole with 8.6 ppg brine 10 bbl/ hr. 18:00 00:00 6.00 24.00 W.O. M 4 P Trip in the hole singles from the pipe shed from 2703’ to 4,537’ PUW=150k SOW= 135k. Lubricate rig (Grease blocks and top drive). Fill hole with 8.6 ppg brine 10 bbl/ hr. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Craig Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 208 816-6803 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Eni representative Marco Mazzocchi Eni WOP Compliance Coordinator marco.mazzocchi@eni.com (907) 223-9811 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/19/2024 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -10.5 Wind NE @ 13 MPH Days LTI (days) 1,536.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Clear and clean floor. Bring on fuel and Brine. Rig up GBR. Make up and run in hole with VAC’s tool with 800’ of 2-7/8” stinger to clean out L1 lateral. Single out of hole with Vac’s tool BHA laying down 5” drill pipe to pipe shed. 24h Summary Pick up singles run in the hole from pipe shed TT525 5’ drill pipe from 4,537’ to 5705’, wash last stand to TOL at 5705’, conduct fishing operations. Trip out of the hole stand back 63 stands in derrick. Break and lay down fishing BHA, assembly. Clean magnets and reverse basket. Clean and clear floor. Staging Vac’s tool BHA. Operation at 07.00 Run in hole with with 800’ of 2-7/8” stinger to clean out L1 lateral. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. M 4 P Cont. Pick up singles run in the hole from pipe shed TT-525 5’ drill pipe from 4,537’ to 5,630’. Wash down with 2 attempts from 5,630’ to 5,705’ TOL Drill pipe measurement. PU=160k, SO= 131k 04:00 05:00 1.00 5.00 W.O. M 4 P Trip out of the hole lay down 2 singles of 5” drill pipe from 5705’ to 5650’. Blow down top drive. 05:00 06:30 1.50 6.50 W.O. M 20 P PJSM. Pressure test brine transfer line from mud plant to rig, good test. Take on 459 BBLS of 8.6 ppg brine to rig pits. 06:30 08:30 2.00 8.50 W.O. M 1 P PJSM. Prepare for slip and cut drilling line. Make up 5” drill pipe in slips. Hang blocks in derrick. 08:30 13:00 4.50 13.00 W.O. M 20 P General housekeeping. Cut and slip 101’ of drilling line. 13:00 20:30 7.50 20.50 W.O. M 4 P Pull out of hole with reverse junk basket and 2 Baker magnets from 5650’ to BHA at 61’. Adding 10 BPH 8.6 PPG brine and pipe displacement. 20:30 22:30 2.00 22.50 W.O. M 20 P Lay down BHA. Recover 2 small pieces of metal strap of 2” each and 11 pound of metal shavings on magnets. Recover 3 ribs from clamps in the reverse junk basket. 22:30 00:00 1.50 24.00 W.O. M 1 P Load 30 joints of 2-7/8” PH6 in pipe shed. Clean and clear floor. Note: 24 Hour Loss of 8.6 ppg Brine = 526 bbls. Total Loss of 8.6 ppg Brine = 1215 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Eni representative Marco Mazzocchi Eni WOP Compliance Coordinator marco.mazzocchi@eni.com (907) 223-9811 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/20/2024 Report #: 14 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 0.3 Wind NE @ 24 MPH Days LTI (days) 1,537.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Single out of hole with Vac’s tool BHA laying down 5” drill pipe to pipe shed from 5237’ to 946’ MD. Lay down VAC’s tool BHA from 946’ MD to surface. 24h Summary Staging Vac’s tool BHA. Load 2-7/8” PH6 and VAC’s tools in pipe shed. Clear and clean floor. Bring on brine to rig. Make up and run in hole with VAC’s tool with 800’ of 2-7/8” stinger to clean out L1 lateral to 6512’ MD. Pull out of hole with VAC’s tool BHA laying down 5” drill pipe to pipe shed from 6512’ to 5237’ MD Operation at 07.00 Pulling out of hole with Vac's toll BHA. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 1 P Lay down beaver slide Baker clean out assembly BHA. Mobilize baker handling equipment for Vac’s tool and GBR tongs and handling equipment for 2-7/8” PH6. Continue adding 10 BPH of 8.6 ppg brine every hour to well. 02:30 04:30 2.00 4.50 W.O. M 20 P Finish loading 30 joints of 2-7/8” PH6, strap and tally. Load VAC’s tool in pipe shed. SIMOPS: take on brine from mud plant to pits, 556 BBLS. 04:30 06:00 1.50 6.00 W.O. M 1 P Rig up GBR equipment, change out elevators on top drive. Load baker completion boxes in short side of pipe shed. 06:00 13:30 7.50 13.50 W.O. M 5 P Pick up and make up Baker VAC’s tool and BHA with 26 joints of 2-7/8” PH6 drill pipe. Run in hole from surface to 946’ MD. Continue adding 10 BPH of 8.6 PPG brine. 13:30 21:00 7.50 21.00 W.O. M 4 P Run in hole with vacs tool assembly BHA with 5“ drill pipe out of derrick from 946’ to 5705’. UW=160 k, DW=135 K. Wash down from 5705’ to 6512’ MD at 3BPM, starting pressure 135 psi, final pressure 165 psi. Pumped 260 BBLS of brine, no returns. RW=148 k, 20 RPM, 6 K TQ, (did not rotate when washing down). Continue adding 10 BPH of 8.6 PPG brine. 21:00 22:00 1.00 22.00 W.O. M 1 P Pick up thread protectors from beaver slide. Blow down top drive. Prepare pipe shed for laying down drill pipe. 22:00 00:00 2.00 24.00 W.O. M 4 P PJSM. Pull out of hole with VAC’s tool BHA laying down 5” drill pipe to pipe shed from 6512’ to 5237’ MD. Continue adding 10 BPH plus displacement of 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 0 bbls. Total Loss of 8.6 ppg Brine = 1215 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/21/2024 Report #: 15 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 10.6 Wind E @ 14 MPH Days LTI (days) 1,538.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Remove wear bushing. Rig up annulus fill line. Install test plug and prepare 4 ½” test assembly. Test the BOPE. Prepare and start running completion. 24h Summary Pull out of hole with VAC’s tool BHA laying down 5” drill pipe to pipe shed from 5237’ MD to the Baker BHA. Lay down magnets and Vacs tools. Clean up the rig floor. Rig up GBR and pull out of the hole laying down the PH6 2 7/8” tubing. Clean out pipe shed of drill pipe and 2 7/8” tubing. Operation at 07.00 Prepare to test BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. M 4 P PJSM. Pull out of hole with VAC’s tool BHA laying down 5” drill pipe to pipe shed from 5237’ to 3241’ MD. Continue adding 10 BPH plus displacement of 8.6 PPG brine. 04:00 04:30 0.50 4.50 W.O. M 25 P Service rig, grease draw works, blocks and pipe skate. 04:30 08:00 3.50 8.00 W.O. M 4 P Continue to pull out of hole with VAC’s tool BHA laying down 5” drill pipe to pipe shed from 3241’ to BHA. Continue adding 10 BPH plus displacement of 8.6 PPG brine. 08:00 12:30 4.50 12.50 W.O. M 5 P Lay down Baker BHA and Vacs tool. Vacs tool had 90% brine with 10% Oil. Cleaned floor and Duck pond of brine with oil mixture. 12:30 16:30 4.00 16.50 W.O. M 4 P PJSM. Rig up GBR. Pull out of the hole lay down the 26 joints of 2-7/8” PH6 tubing, 2 flapper vavles, mule shoe and pup. The tubing is pulling wet. 16:30 20:30 4.00 20.50 W.O. M 5 P Clean BHA and lay down beaver slide. Lay down bakers cross overs, dog collar clamps, drill pipe slips, collar slips, string magnets, GBR’s air slips and 2-7/8” elevators. 20:30 00:00 3.50 24.00 W.O. M 1 P Unload from pipe shed Bakers VAC’s tool, jars and bumper sub. Prep and unload 30 joints of 2-7/8” drill pipe. Clean rig floor mats and floor. Clean rig floor of dog house. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/22/2024 Report #: 16 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 12.4 Wind NE @ 12 MPH Days LTI (days) 1,539.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Pick up ESP BHA. Make up cap tubing and test check valves. Pick up and make up first tubing joint. Make ESP cable splice to MLE and test. Run in hole with 4.5” completion. 24h Summary Finish cleanup of rig floor. Remove wear bushing. Install test plug and test BOPE. Test waived by AOGCC Kam StJohn Rig down test assembly. Blow down choke manifold and all lines. Cleaned and organized the rig floor. Reviewed the derrick inspection procedure and inspected the derrick. Rig up and pick up motor and seal assembly. Operation at 07.00 Make ESP cable splice. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. M 1 P Continue to clean rig floor mats and floor. Check pulled completion string tubing thread protectors to ensure tight prior to transporting. 03:30 08:00 4.50 8.00 W.O. C 1 P Prepare to test BOPE. Rig up hi-pressure hose to IA from trip tank. Remove wear bushing. Install test plug and perform shell test. 08:00 13:30 5.50 13.50 W.O. C 12 P Test BOPE to 250 psi low/3500 psi high with 4 ½” test joint as per AOGCC requirements. Test 3.5”x6” UPR, B/S rams, 3.6”x 6” LPR. Test choke valves 1-15. Test gas alarms and PVT. Perform accumulator draw down test. Starting pressure 2975 psi, after function 2150 psi. 200 psi increase 12 seconds, full recovery 53 seconds. 10 Nitrogen backup bottles 4200 psi average. All good tests. Witness waived by AOGCC rep Kam StJohn. Continue to pump 10 BPH down the well. 13:30 17:00 3.50 17.00 W.O. C 1 P Rig down test assembly and blow down all lines and choke manifold. Clean and organize the rig floor. Reviewed the derrick inspection procedures, held PJSM, and performed derrick inspection. Continue adding 10 BPH of 8.6 PPG brine. 17:00 22:00 5.00 22.00 W.O. K 1 P Mobilize tubing hanger to rig floor, drifted with 3.833 drift. Mobilize Baker centerlift equipment and GBR handling equipment to rig floor. Change out one sheave rope. Pull dual cap tube and ESP cable over the sheaves in the derrick. Continue adding 10 BPH of 8.6 PPG brine. 22:00 00:00 2.00 24.00 W.O. K 5 P PJSM. Pick up motor and sensor. Check free rotation, good. Pick up centralizer and make up to sensor. Pick up seal assembly, check rotation and make up to motor. Service seal section, start filling with oil and bleeding air. Note: 24 Hour Loss of 8.6 ppg Brine = 168 bbls. Total Loss of 8.6 ppg Brine = 1886 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/23/2024 Report #: 17 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 21.2 Wind SW @ 23 MPH Days LTI (days) 1,540.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Continue run in hole to with completion to 5640’ and makeup spacer pup, upper and lower swivel joint to tubing hanger. Wash stack and drain, land out tubing hanger with TWCV at 5687’ MD. Test tubing hanger body seals. Pull landing joint. Rig down GBR. Nipple down stack. 24h Summary Pick up ESP Assembly. Check rotation and service. Make up cap tubing and test. Function check valves. Dump test GBR tongs. Splice MLE to ESP cable on spool. Run in the hole with the 4 ½” ESP completion from 47’ to 4090’ MD. Test continuity each 1000’ run and circulate the tubing volume every 3000’. Operation at 07.00 Terminate ESP line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. K 5 P PJSM. Make up pump assembly and DGU. Run in hole to 47’ MD, service and check rotation. Continue adding 10 BPH of 8.6 PPG brine. 02:00 06:00 4.00 6.00 W.O. K 12 P Terminate cap dual tube lines. Test check valve #1, 250 psi, no leak. 1000 psi for 10 minutes, 2000 psi for 10 minutes. Function test open at 5418 psi, closed at 3450 psi. Check valve #2, 250 psi, no leak, 1100 psi for 10 minutes, 2000 psi for 10 minutes. Function test open at 4976 psi and closed at 2932 psi. All good tests. 06:00 09:00 3.00 9.00 W.O. K 4 P Terminate the DGU line on DHZ, apply 1000 psi on the Cap lines. Terminate MLE. Clamp MLE line, cap DGU lines to seals and pumps. Terminate DGU line. Perform dump test with GBR tongs witnessed by Superior thread rep. Good test. Run in hole from surface to 88’ MD. 09:00 12:00 3.00 12.00 W.O. K 20 P Splice MLE to ESP cable on spool. Witnessed by ENI electrician. 12:00 20:30 8.50 20.50 W.O. K 4 P PJSM with all personnel involved with the job. Run in the hole with the ESP completion with 4 ½” HYD 563, coated, 12.6 PPF, tubing from 88’ to 3038’ MD. Each connection inspected and make up by Superior thread rep, torqued to 3800 ft/lbs. Installing cross collar clamp each joint. Test continuity every 1000’. Keeping cap tube pressurize at 1000 psi. Circulate the tubing volume every 3000’. Adding 10 BBLS per hour down annulus of 8.6 ppg brine. 20:30 21:00 0.50 21.00 W.O. K 9 P Rig up and pump tubing volume of 47 BBLS of 8.6 PPG brine down tubing staging up flow to 2 BPM, 560 psi. 21:00 00:00 3.00 24.00 W.O. K 4 P Run in the hole with the ESP completion with 4 ½” HYD 563, coated, 12.6 PPF, tubing from 3038’ to 4090’ MD. Each connection inspected and make up by Superior thread rep, torqued to 3800 ft/lbs. Installing cross collar clamp each joint. Test continuity every 1000’. Keeping cap tube pressurize at 1000 psi. Circulate the tubing volume every 3000’. Adding 10 BBLS per hour down annulus of 8.6 ppg brine. Note: 24 Hour Loss of 8.6 ppg Brine = 245 bbls. Total Loss of 8.6 ppg Brine = 2131 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/24/2024 Report #: 18 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 12.7 Wind NE @ 18 MPH Days LTI (days) 1,541.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Pull high pressure riser from well head. Inspect seal areas and install VG seal in top of multibowl as per Vault procedure. Install control lines through upper ports. Install tree. Test tubing hanger. Perform Passport test as per Vault. Pull TWCV. Perform final checks, ESP cable and motor electrical integrity as per Baker. Freeze protect well. Secure well and handover to production. Rig down and move rig. 24h Summary Continue run in hole to with completion from 4090’ to 5651’ MD and makeup spacer pup, upper and lower swivel joint to tubing hanger. Splice cap lines, test, and function. Splice ESP cable to PFD connector and terminate on hanger. Land tubing and completion string at 5687’ MD. Energize lock downs. Test seals to 5000 psi. Rig down GBR and Baker. Nipple down BOP stack. Operation at 07.00 Passport testing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. K 4 P Run in the hole with the ESP completion with 4 ½” HYD 563, coated, 12.6 PPF, tubing from 4090’ to 5651’ MD. Make up swivel joint and tubing hanger with BPV installed. Each connection inspected and make up by Superior thread rep, torqued to 3800 ft/lbs. Install cross collar clamp each joint. Test continuity every 1000’. Keeping cap tube pressurize at 1000 psi. Circulate the tubing volume every 3000’. Adding 10 BBLS per hour down annulus of 8.6 ppg brine. 04:00 06:00 2.00 6.00 W.O. K 12 P Perform cap testing. Test ESP cable. 06:00 07:30 1.50 7.50 W.O. K 20 P Splice ESP cable to PFD connector and terminate on hanger. 07:30 10:30 3.00 10.50 W.O. K 12 P Splice cap lines from 3/8” to 1/4” & terminate on hanger. Test cap line hanger connection to 5000 psi. Test cap line #1 to 250 psi, no leaks. 1000 psi for 10 minutes. Function test open to 4596 psi for 5 minutes. Close 2220 psi; #2 test to 250 psi no leaks, 1000 psi for 10 minutes. Function test open to 4983 psi for 5 minutes. Close 3352 psi. Good tests. 10:30 12:00 1.50 12.00 W.O. K 20 P Land tubing. Run in lock downs. Test seals to 5000 psi. Good test. Lay down ESP cable and Cap line. 12:00 14:00 2.00 14.00 W.O. K 1 P Lay down landing joint. Rig down GBR and Baker equipment and remove off the rig floor. Clean pollution pan. Cleaning mud pits. 14:00 18:00 4.00 18.00 W.O. K 1 P Lay down mouse hole. Nipple down low pressure riser, flow line. Blow down all 3 mud pumps. Offloading brine from pits. 18:00 21:00 3.00 21.00 W.O. K 20 P Begin to nipple down choke and kill lines. Nipple down HCR and manual valves. Continue to off load pits and start cleaning pits. 21:00 00:00 3.00 24.00 W.O. C 5 P Nipple down BOP stack and set back on stump. Secure stack forrig move. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 Well Name: SP18-N5 OR Wellbore Name: SP18-N5 Well Code: 25788 Job: WORKOVER WCEI Level: LEVEL 3 Daily Report Date: 3/25/2024 Report #: 19 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.87 Ground Level (ft) 40.77 First Flange (ft) 21.59 RKB - Base Flange (ft) 32.28 RKB - Tubing Spool (ft) 31.70 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 8.8 Wind NW @ 9 MPH Days LTI (days) 1,542.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Final report. No further operations. Move to SP42-NE4. 24h Summary Pull high pressure riser from well head. Clean seal areas and install VG seal in top of multibowl. Install tree. Test tubing hanger bonnet 5000 psi for 10 minutes, witnessed by co-man. Perform passport test with Vault. Perform final checks with Baker Centralift on ESP lines and equipment. Continue rigging down. Prep for skidding the rig floor into rig move position. Dis-connect interconnects. Move pump #3 and cuttings box. Blow down water lines. Laying matting boards for SP42. Operation at 07.00 Final report. No further operations. Move to SP42-NE4. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. C 1 P PJSM. Nipple down high pressure riser from well head. Secure for rig move 01:00 04:30 3.50 4.50 W.O. C 5 P Vault hand clean and inspect top of hanger and VG hub. Install VG seal in top of multi-bowl. Nipple up tree, terminate cap lines. Test tubing hanger bonnet to 5000 psi for 10 minutes, good test, witnessed by co-man. Off hi-line power at 03:00 SIMOPS: lay Herculite for SP42-NE4. 04:30 08:00 3.50 8.00 W.O. C 12 P PJSM. Rig up and perform passport test as per vault. Shell test at 3500 psi for 10 minutes, good test. Swab valve 3500 psi for 30 minutes, good test. Master valve 3500 psi for 30 minutes, good test. Pull TWCV. Test tree cap 3500 psi for 10 minutes, good test. Simops: Lay out rig mats for SP42-NE4. 08:00 12:00 4.00 12.00 W.O. A 1 P Rigging down the rig for the move to SP42-NE4. Remove discharge caps from mud pump #s 1, 2, & 3. Blow down water and steam lines from mud pump #3. Rig down interconnects. Rig down choke flare, choke bypass, flow line interconnects on pits roof top. Rig down high pressure mud line, choke, water lines under the rig floor. Break down water lines on the sub base. Secure the torque tube on the TDS. Rig down koomy hoses. Remove plugs from centrifugal pumps. 12:00 18:00 6.00 18.00 W.O. A 1 P Clean all sumps in the pump rooms. Finish rigging down pump #3 complex. Take on fuel to bulk tank. Prepare rig to skid into rig move position. Take down burming around rig. Blow down water lines in pits and Pump room. Prepare and unplug power to shop. Koomy unit, MI mud lab, sub to pump interconnect and top drive VFD. Rig down and blow down hot well water feed. Rig down boiler blow down line to pits. 18:00 00:00 6.00 24.00 W.O. A 1 P Move pump #3 complex and stage out of the way. Roll up top drive cables in off driller’s side no man’s land. Secure top and bottom of beaver slide. Rig down 2” airline in no man’s land. Offload water bulk tank to super sucker. Move cuttings box out. Dis-connect rig ground cable. Rig down Hi-line cable from rig. Rig down ESP and cap line sheaves from derrick. Prepare rig roof top for skidding rig floor. SIMOPS: Laying matting boards for SP42-NE4. Note: 24 Hour Loss of 8.6 ppg Brine = 50 bbls. Total Loss of 8.6 ppg Brine = 3008 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Company Representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Company Representative Adam Groendyke ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Shones Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0727 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L-80 5,848.5 13,531.0 3,880.1 11/15/2011 4-½” 12.6 ppf TK15-XT W563 Production TubingSP18-N5L1Dual Lateral Producer with ESP LiftNikaitchuq Field –Spy IslandAs Completed: March 20245,705' MD / 3,975' TVDBaker SLXP Liner Hanger/Packer~5,765 – 5,782' MD, Casing Exit Windowx-cplg cable clamps, for ESP Power Cable, (2ea) 3/8" Chem Inj Line with 2500 psi check valve at bottom5,684' MD / 3,972' TVD Bottom of Motor Centralizer Centrilift, Conventional ESP, 65 Stage Flex 8013570' MD / 3.897’ TVDBent Joint with Eccentric ShoeTD 8 3/4” 13,590' MD 3,897' TVD90.5º Inc.5-½” 15.5 ppf L80 Slotted LinerSealbore Receptacle4.75" ID5-½” Silver Bullet Ecc. Nose Guide Shoe13,531' MD, 3880' TVD,97º Inc. Interm. Casing 9-5/8", 40#6103' MD, 3999' TVD91º Inc.Zonal Isolation Swell PackersSwell Packer MD’s (ft):#1) 11,755#2 11,213#3) 8,393#4) 7,490Lower lateral Baker SLXP Liner Hanger/Packer #1Surf. Casing13-3/8", 68 # BTC2,669' MD, 2,479' TVD 20º Inc. Lower lateral Baker SLXP Liner Hanger/Packer #2Swell Packer MD’s (ft):L1#1) 12,093L1#2 11,887L1#3) 11,567L1#4) 11,115L1#5) 10,632L1#6) 10,474 L1#7) 10,195L1#8) 10,047L1#9) 5,872L1#10) 5,8185548' MD / 3955' TVD XN-Nipple5598' MD / 3962' TVD Discharge Gauge5607' MD / 3963' TVD Pump 2 Flex 805629' MD / 3966' TVD Pump 1 5385639' MD / 3967' TVD Gas Separator5659' MD / 3969' TVD Motor 562XP5687' MD / 3972' TVD Bottom of ShroudDate Activity2011Ͳ11Ͳ19DrillandCompletemainLateralwithTTCͲESP2021Ͳ05Ͳ01DrillLateral1andcompletewithconventionalESP2024Ͳ03Ͳ24 RWOtoreplaceconventionalESPWellHistory 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 Changeout_ 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?N/A Yes No SP18-N5 9. Property Designation (Lease Number):10. Field: Niakitchuq Schrader Bluff Oil Pool Schrader bluff oil pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,531 1302 N/A Casing Collapse Structural Conductor Surface 2480 Intermediate 4790 Production Liner slotted Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Giorgio Iannucci 12/15/2023 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 907-865-3300 January 20th, 2024 13,5317428 4.5" 3,880 N/A Perforation Depth MD (ft): 6103 6103-13,531 5.5" 3,999-3,880 20" 13.375" 160 9.625"6103 2669 160 2479 3999 160 2669 Proposed Pools: L80 TVD Burst 5,550 MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 211-101 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-629-23453-00-00 Eni US Operating Co. Inc. AOGCC USE ONLY slotted Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: 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 Length Size 3,880 13,531 3,880 N/A Well Operations Project Manager Amjad Chaudhry amjad.chaudhry@eni.com 6890 5210 m n P s 2 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov rgio Iannucci By Grace Christianson at 8:22 am, Dec 18, 2023 323-674 BOP test to 2500 psig Annular preventer test to 2500 psig SFD SFD 12/20/2023 DSR-12/18/23 X X 13,601 VTL 01/03/2024 3,872 10-404 JLC 1/16/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.16 10:54:15 -09'00'01/16/24 RBDMS JSB 011624 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone: 907-865-3300 December 15 th, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP18-N5 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP18-N5. SP18-N5 was completed on Spy Island on November 19 th, 2011, with an electric submersible pump set at a depth of 5,778’ MD. This ESP producer was completed without a packer. The well was started up for production in November 2011. In 2021 a second lateral was drilled, and the well was completed with a conventional ESP. Well continued producing until November 13 th, 2023, when an ESP failure occurred. Plan is to swap ESP completion with a new tubing and ESP system. The estimated date for beginning this work is January 20 th, 2024. 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- 865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager y, SP18-N5 Workover – Summary Page PTD#:211-101 Current Status SP18-N5 is currently shutdown. Scope of Work The scope of this workover is to pull out existing tubing and run new tubing and new ESP. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1700 psi (3,982’ TVD) during the time of workover. SP18-N5 MASP Shut-in BHP (Max) 1,700 psi, Depth 3,982 ft (TVD) Gradient 0.1 psi/ft MASP 1,302 psi Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 1500 psi on April 4th, 2021. Well type: Producer Estimated start date: January 20th, 2024. Drilling rig: Doyon 15 Sr. Drilling Engineer: Amjad Chaudhry: Amjad.chaudhry@eni.com Work: 907-865-3300 Well Operations Project Manager: Giorgio Iannucci: Giorgio.Iannucci@eni.com Work: 907-865-3300 Procedure: 1. MIRU Doyon 2. Bullhead 8.6 ppg brine down tubing through conventional ESP. 3. Bullhead brine down the Annulus A 4. ND tree, NU BOPE and test 5. POOH with 4-1/2” tubing. 6. Contingency: RIH with 9-5/8” Casing Scraper and clean / scrape to LHP 7. Contingency: RIH with 5-1/2” L1 lateral cleanout assembly to 800ft 8. Contingency: RIH with 9-5/8” Retrieve-O-Matic Test Packer assembly and pressure test the casing 9. RIH with 4-1/2” ESP completion string 10. Land hanger 11. Install BPV, ND BOPE, NU Tree 12. Passport test 13. Contingency: bullhead LVT freeze protection 14. RDMO Below the current schematic of the well: Planned completion will be the same and will be set at the +/- same depth. Number of Failures: 0 1 Test Results Test Time 4.5 Remarks: Two test joints 4 1/2 and 5". All Gas and PVT Systems tested good- No sundry. V STATE OF ALASKA Reviewed By: J&L OIL AND GAS CONSERVATION COMMISSION P.I. Supry —QO7-( BOPE Test Report for: NIRAITCHUQ SP18-N05 IComm Contractor/Rig No.: Doyon 15 PTD#: 2111010 " DATE: 4/13/2021 - Inspector MattHerrera - Insp Source Operator: Eni US Operating Company Inc. Operator Rep: Simonson/Gueco Rig Rep: PankratrJKroeger Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopMFH21041410404R i Rams: Annular: Valves: MASP: Type Test: [NIT 250/3500 • 250/3500 , 250/3500 1303 ✓ Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P - Trip Tank P P System Pressure _ 3020 P Housekeeping: P ' Pit Level Indicators P P Pressure After Closure 2100 - P PTD On Location P ' Flow Indicator P P _ ' 200 PSI Attained 10 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 60 P Well Sign P 142S Gas Detector P P Blind Switch Covers: _YES - P Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): 10@,)4000 - P Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly I P Stripper 0 NA_ No. Valves 15 _ _ _ P- lower Kelly 1 P : Annular Preventer 1 -13 5/8" P Manual Chokes I P' Ball Type 1 P ' #1 Rams 1 '41/2 x 7" 1— Hydraulic Chokes 1 P Inside BOP 1 P" #2 Rams 1 Blindshear P CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 ' 3 1/2 x 6" P #4 Rams 0 NA _ 45 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 2 31/8" " P - Quantity P/F HCR Valves 4 " 31/8" • P - Inside Reel Valves 0 NA Kill Line Valves 2 '31/8" P ' Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 1 Test Results Test Time 4.5 Remarks: Two test joints 4 1/2 and 5". All Gas and PVT Systems tested good- No sundry. V . • .......d ix"m m N O n N n ..._.c.,_ M W m N N f� m O m 0 / O LL r' 0,,,.. DO) O) n N N .- N 0 h 01 h N N o N r N m y �/ (7 U 0, LL U b co o a. Vm) o m n m N co Is v v N N U N,€ N N a N N M a N Y n 3 . 0 N Clt II 0 r2_ co i b L: CC) B0N0) NANOMNN M j YO) O m 0m m 0 Qi m m OP m U5- _ mC O N NN V M U) N A m 0 < .- N 10 N 0) ) N e) NNV O el Y Y 2 O k O m o) m m 0) 0) (Si O m m m N. W n n m m O) A Is t. 0) m n CO 0) I < N N N U) Q E C O 0 O b W O co c a o m J C a ' m 10 8 {m{o�t .- mNm N pOp m (M'' O mm to r.-. 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LU Q •y N N a' N Z 1- 0 s-Lia Q 2 P2 y O C m c H o J o a) s ra A N C T E C o N U u_ L N a a V N M J QN r` No ,-- O' O '- r Z Y C,1 a a0 N o N rn G � a rn Ill m a - c U) U P? 3 o r- 1- Q N N N- o Q ael Z o 0 Iii 01 NA fa z m • N C 03 0 M w t0Z ci6 i i O @O �� Q m r O 2 >- a' N a' Of O' O - O. a' - ..C-, z ami E J a: m 25 o W z U U Z D O M Cl) Z a C C 0 O O D 0) d CO U CO ' E a U 0 = a >. m a 2 Q U QW U U HALLI B U RTON Sperry Drilling To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 Anchorage, AK 99501 Attn: Howard Oakland From: Sperry Drilling -Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield( Halliburton.com Re: Eni Well — SP18-N5 AFE # 5275 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports ` l 1 Final Data Listing on CD-ROM I 1 Sets of Final Logs —each contains: • 2" Color Log — Formation Evaluation TVD • 2" Color Log — Formation Evaluation MD • 2" Color Log — Drilling Engineering MD • 2" Color Log — Gas Ratio MD Received By: )--1-bwour,L OkLel Print Name C iL Si n Name Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� 15:1(v DATE: January 19, 2012 P. I. Supervisor FROM: John Crisp, SUBJECT: No Flow Test Petroleum Inspector ENI Spy Island Nikaitchuq SP18-N05 PTD 2111010 January 19, 2012: I traveled to ENI Petroleum Alaska's Spy Island to witness a No-Flow test on well SP18-N05. Delton Carol was ENI Lead Operator in charge of the No-Flow test. Hovercraft from the beach arrived on Spy Island at 0620 hrs. I immediately inspected well SP18-N05 to make sure valves were open & no flow test could begin in accordance with 20 AAC 25.265(k). I immediately realized that tubing & IA were both open & IA was venting outside to a bleed trailer. Tubing was R/U with calibrated AOGCC required test flow meter & pressure gauge. With ESP packerless completion the IA & tubing are in communication so the IA was shut in to witness communication or pressure build from IA to tubing. My first readings taken @ 0630 hrs with IA shut & tubing open to 5 gal bucket of water were: Tubing = 0.25 psi with less than 1.5 SCF/hr on Flow Meter IA = 0 psi OA = 200 psi Second readings taken @ 0730 hrs were: Tubing - .25 psi with less than 1.5 SCF/hr on Flow Meter IA = 0.6723 psi OA = 200 psi Third readings taken @ 0830 hrs were: Tubing = 0.25 psi with less than 1.5 SCF/hr on Flow Meter IA = 0.9426 psi OA = 200 psi Fourth readings taken @ 0930 hrs were: Tubing = 0.25 psi with less than 1.5 SCF/hr on Flow Meter IA = 1.3291 psi OA = 200 psi Tubing was next shut in for an hour to witness SVS test on well SP27-N1. No Flow Test ENI Spy Island SPI8-N5 01-19-12 2 Readings taken @ 1030 hrs after tubing had been shut in for 1 hour were: Tubing = 11.25 psi IA = 1.3145 psi OA = 200 psi Opened tubing to atmosphere thru 1" line & Flow Meter for readings; initial readings while flowing @ 1035 hrs were: Tubing = 5 psi with 5 SCF/hr on Flow Meter IA = 1.3145 psi OA = 200 psi Readings taken after 10 minutes with tubing open to atmosphere @ 1045 hrs were: Tubing = 1.5 psi with less than 1.5 SCFH on flow meter IA = 1.3276 psi OA =200 psi Finished No Flow test. Summary: I witnessed a No-Flow test on ENI's Spy Island Nikaitchuq Field well SP18-N05 as per regulation (20 AAC 25.265(k)). Data will be turned in to PI Supervisor Jim Regg for review & No Flow determination. Attachments: Flow meter calibration records. 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I... , . _ . .... oi 0 1.. ..c 4".°. 0 \ \i k• ..k.: 0 0 Pre: 4.4 (0 tf... :), ' I , Scblumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No SP18-N5 Date Dispatched: 12-Jan-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP18-N5-Logs: 1 II hL L, 2 in MD 1 2inTVD 1 (N51iN "TN MIJ Received By: -- V '—� Please sign and return one copy to: / t 3800 Centerpoint Drive,Suite 300 ( � J t Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan@enipetroleum.com LWD Log Delivery V2.1,03-06-06 ;SII-- IC3i Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No SP18-N5PB1 Date Dispatched: 10-Jan-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP18-N5PB1 -Logs: 1 # I d,6 2 in MD 1 2inTVD 1 Sir\ Tvb Received By: v Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 st L Anchorage,Alaska 99503, Andrew Buchanan an,drew.buchanan@enipetroleum.com LWD Log Delivery V2.1,03-06-06 ? t1 — t(-3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: SK19 Service ❑ Stratigraphic Test ❑ i 2.Operator Name: 5.Date Comp.,Susp, 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 11011 211-101 3.Address: 6.Date Spudded: " 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 10/22/2011 50-629-23453-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4451 FSL,1375 FEL,S19 T14N R9E UM 11/11/2011 SP18-N5 Top of Productive Horizon: 8.KB(ft above MSL): 53.87 15.Field/Pool(s): 835 FSL,1451 FEL,S18 T14N R9E UM GL(ft above MSL): 13.1 Nikaitchuq/Schrader Bluff Oil Pool Total Depth: 9.Plug Back Depth(MD+TVD): 453 FSL,2026 FEL,S12 T14N R8E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511535.62 y-6053631.53 Zone- 4 13601'MD/3872'TVD ADL 391283,388583,388574,388571 TPI: x- 511450.64 y-6055295.07 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 505795.80 y-6060185.83 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes ❑✓ No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1879'MD/1763'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den N/A 23. 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 37 160 37 160 Driven N/A N/A 13.375 68 L-80 35 2669 35 2479 16 10.7 ppg ASL: 450 bbls N/A 12.5 ppg DeepCRETE:68 bbls 9.625 40 L-80 33 6103 • 33 3998 12.25 12.5 ppg DeepCRETE:192 bbls N/A 5.5 15.5 L-80 5926 13531 ,3998 3880 8.75 Slotted Liner N/A 24.Open to production or injection? Yes❑ No If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5 5778'MD N/A R �� D 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. h'.tt;wry DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Al JAN Q 6 2Q12 Masks ati 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 11/24/2011 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/24/2011 20 Test Period -1257 0 0 42/64ths N/R Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 178.5 0 24-Hour Rate .► 1508 0 0 21.4 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Sidewall Cores Acquired? Yes ❑ No❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS JAN 0 9 20 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submital 0:311y, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑Yes do If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top Surface Surface and submit detailed test information per 20 AAC 25.071. SV-4 762 758 SV-3 1145 1120 SV-2 1435 1381 Permafrost Base 1879 1764 SV-1 2074 1935 Ugnu Top(UG4) 2435 2262 UG-2 Coal Bed Marker 3035 2819 Lower Ugnu 3964 3502 Schrader Bluff 4797 3775 N Sequence Top 4900 3806 N Sand Top 5074 3854 N Sand Bottom 5274 3901 N Sequence Base 5502 3949 OA Sand Top 5875 3993 OA sbl 2 5934 3998 Formation at total depth: OA Sbl 1 13601 3872 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joseph Longo(907)865-3323 Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: J Phone: (907)865-3320 Date: 1/5/2012 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: 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 30: 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. 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Eni E&P Division (Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • APIIU WI:50-629-23453-00-00 2^• Date:10/14/2011 - Report#: 1 II II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) •Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31 70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 -7.69 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 0 0 97.0 28.4 Cloudy,WC-2' 80'E @ 30.6 mph Daily summary operation 24h Summary Prepare rig for moving,move derrick complex to SP18 and spot sub over hole,begin building ramps for moving pit complex off double stacked mats,stage 80'diverter line section to set on top of well house. Operation at 07.00 Moving rig. 24h Forecast Move dg to SP18,rig up and prepare rig,diverter system and rig up grind and inject facility Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00.00 24.00 24.00 MOB A 2 'P -Fabricate diverter strut braces and install,power down rock washer,building ramps for moving rig off of double mats,skid rig floor,raise stompers,move sub complex off double mats,stage sub for mat pick up and for laying herculite,spotting 6g mats for spotting ng over well,layed out main herculite 120x120 and begin spotting rig mats. (Note)high winds caused real problems trying to get the herculite layed. Move demck complex to SP18 and spot sub over well,begin building ramps for moving pit complex off double stacked mats,stage 80'diverter line section to set on top of well house. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ilENI Co Rep michael.ross@enipetroleum corn 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobbywalls@enipetroleum.corn 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norwg ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher 907-685-0716 Eni representative Mike Seward ENI Project Advisor mrke.seward@enipetroleum.com 907-685-1283 907-952-7880 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CONDUCTOR 20 18.250 X65 0.0 1600 1/15/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) ilfil°11*1- Eni E&P Division I Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO e Date:10/15/2011 - Report#: 2 APIIUWI:50-629-23453-00-00 2"in page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 -6.69 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 91.0 30.0 C;oudy.WC-5` 76°ENE @ 44 mph Daily summary operation 24h Summary Move rig to SP18,rig up and continue to rig up,work on fabricate and install diverter line,move pump module and spot in place,nipple up diverter and knife valve,install berm around ng,housekeeping around last well. Operation at 07.00 Continue rigging up and continue working on diverter line. �• 24h Forecast Continue rigging up,continue working on and rigging up diverter line,set in place#3 mud pump.,MI mud shack,Schlumberger shack,and Halliburton shack. Start to load pipe shed with pipe and continue connecting all fluid lines and electrical lines through rig. Using extreme caution due to high winds. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:00 — 24.00 24.00 MOB A 2 P Move the derrick complex to SP18-N55 and spot substructure over well and set in place. Nipple up drilling T and diverter, bolt up the 90'section of diverter line that run along top of well houses,move and spot in place the pump section of the rig, set in place another 45'section of diverter line. High winds have really hampered rig up operations. Holding extra safety meetings due to high winds. Vetco-Gray install new starting head on SP18,lock down and test to 500 psi. Nipple up Vetco riser,test ODC 500 psi.test upper ODCx20'flange to 500 psi.nipple up 20"hydril and knife valve,set herculite and matting boards,spot rock washer. Install berm around rig,housekeeping around last well. Winds in excess of 50 mph. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division ENI Petroleum CO.Inc. Daily Report L IWell Name:SP18-N5 Well Code:25788 Field Name:NIKAITCHUO e Date:1011612011 - Report#: 3 APIIUWI:50-629-23453-00-00 en" page 1 of 1 Wellbore name: SP18-N5 Well Header PermitlConcession N" Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOVON DRILLING DOYON 15 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) 5018-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 -5.69 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature("F) Weather WInd 0.0 91.0 29.7 Cloudy,WC 17.2 88'E @ 18.8 mph, Gusts to 25 mph Daily summary operation 24h Summary Continue rigging up,continue working on and rigging up diverter line,set in place#3 mud pump.,MI mud shack,Schlumberger shack,and Halliburton shack. Start to load pipe shed with pipe and continue connecting all fluid lines and electrical lines through rig. Using extreme caution due to high winds. Operation at 07.00 V Put 5"drillpipe in pipe shed,drift 13/38"casing. 24h Forecast Complete wireline work on disposal well,complete diverter line. 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.Reser. 00:00 09.00 9.00 9.00 MOB A 2 P Continue nipple up diverter,begin pre-spud list,build ramp for positioning pump#3,stage rock washer away from rig to spot#3 pump. Spot#3 pump module and back rock washer up to rig and connect. 09:00 18:00 9.00 18.00 MOB A 2 P Continue to berm up around rig and work on pm-spud check list. Continue to connect#3 pump module to rig. Begin removing excess herculite and matting boards from disposal well and make ready herculite for disposal. 18:00 19:00 1.00 19.00 MOB A .2 P Pin together loader ramp and set in place. Function test sissor lift and torque up loose set screws in hydraulic pipe stops. Continue to weld on#3 pop-off line. (Note)Diverter test waivered on 10/16/2011 at 1400 hrs.by Chuck Scheve. 19.00 20.00 1.00 20.00 PREP A 2 P Rig up and transfer HWDP from off-drillers side of pipe rack to drillers side. Continue welding on#3 pop-off line. 20 00 00.00 4.00 24.00 PREP A 20 'P Bring in 57 joints of 13 3/8"casing into pipe shed. Start bringing in 5"drilipipe to pipe shed. Continue install#3 mud pump pop-off line. (Note)Waiting on completion of wireline work on disposal well before completing diverter line. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norvig ENI Rig Clerk tom.norvg@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Dulling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) f _� Eni E&P Division Iweu Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • 2 n Date:10117/2011 - Report#: 4 APIIUWI:50-629-23453-00-00 page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40 77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOVON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP18-N5 DRILLING 10/22/2011 13,628.0 11.953.00 145.08 82.4 -4.69 Daily Information End Depth(ftKB) End Depth(ND)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 0.0 93.0 29.8 Cloudy,WC 17° 92°E @ 19.3 mph, Gusts to 25 mph Daily summary operation 24h Summary Load and strap 192 Its of 5"drillpipe into shed,perform accumulator draw down,berm around new oil dock,install mouse hole,pick up 192 jts of drillpipe and stand back,remove and reposition production wing valve,service top drive run power cable from shop to rig,finish loading 133/8"casing in pipe shed,remove protectors. Operation at 07.00 Working on diverter line,testing gas alarms,and prepare rig for drilling. 24h Forecast Complete wireline work on DS-1,continue installing diverter line,continue installing lines for grind and inject. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) Time Log StartCum _. — +'I Timeime Time Dur(hr) Dur(hr) Phase Opr. Act. Plan •••r.Descr. s----��---.� 00:00 08.00 8.00 8.00 PREP A 20 P Load and strap 192 ffs of 5"drillpipe into pipe s -d. Perform accumulator and diverter draw down and function t.--. Start l'a")( with 3,000 psi,pumps off,function and stabilize.i . • 850 psi.back to full pressure in 147 secs. Knife val •pen in 16 secs.and annular closed in 31 secs. 1�// 08:00 10:30 2.50' 10.50 PREP A 20 P Continue to strap and tally pipe,complete berm around new oil dock with ACS hands,pick up and install mouse hole, ,.�,�"' service rig. 10:30 18:00 7.50 18.00 PREP 'A 20 P Pick up 192 joints of 5"drillpipe and stand in derrick. 18:00 20:00 2.00 20.00 PREP C 20 P Remove and reposition production manifold to wing valve on OS-1 for Little Red Services. 20:00 21:00 1.00 21.00 PREP 'A 20 P Service top drive and install cable reel guard on stabbing board. 21:00 22:00 1.00 22.00 PREP A 20 P Run power line from shop to rig and make connection,continue working on DS bridge crane. 22:00 00:00 2.00 24.00 PREP 'A 20 P Finish loading shoe track and rest of 13 3/8"casing in pipe shed and remove thread protectors,continue with general housekeeping. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norvig ENI Rig Clerk tom.norvg@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Dnlling Tool Pusher 907.685-0716 Tool Push Chad Johnson Doyon Dnlling Tool Pusher 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(ftKB) TOO(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division IWeIIName:SP18-N5 P911* ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • Date:10/18/2011 - Report#: 5 APIIUWI:50 629-23453-00-00 2'r "' page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 -3.69 . Daily Information End Depth(11KB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 0.0 94.0 23.7 Cloudy,WC 15.8' 123'ENE @ 11.9 mph Daily summary operation 24h Summary Halliburton completed wire-line work and testing on DS37-DSP1-EPA satisfied with results and signed off-went to town @ 1800 hrs.\Work on and replace top drive pipe handle cylinders.\Finished welding on rig pump pop-off.\Install Gallagher submergible pumps in rock washer.\WIF 2"injection line nearly completed and Schlumberger 80%completed. Operation at 07.00 ✓l Prep ng to drill. 24h Forecast Install last section on diverter line\Work on lines to WIF(slurry lines will have to be insulated)\Construction lined-up @ 0600 hrs.to complete fabrication-N/U of tree flanges and sensors on DS37-DSP1.\ Schlumberger DO and MWD out @ 1200 hrs.to prep tools and PIU part of BHA. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 PREP A 20 P PJSM-Load pipe shed with 13 3/8"csg.(688 L-80 BTC)-remove thread protectors,drift and strap\Continue organizing and rig floor after move. 06:00 12,00 6.00 12.00 PREP A 20 P Organized and housekeeping on rig in all areas.\Welding on pump pop-off.\Assisted Halliburton wire-line with operations on SD37-DSP1.Cement transferred from bulk tanks farm to pods @ WIF. 12:00 18:00 6.00 18.00 PREP A 20 P Fabricated pump mounts and install both Gallagher submergible pumps in rock wash.\Remove off driller's side cylinder on pipe handler and replace with rebuilt and continued perform preventive maintenance on rig and housekeeping.\ Schlumberger 80%completed on cement line to WIF.\Temporary 2"(1502)injection line to disposal well is nearly installed. Continue assisting Halliburton in wire-line operation-tools to surface @ 1800 hrs.\Disposal well testing is completed and EPA satisfied with result and going to town @ 1800 hrs.\Cement transfer completed. 18:00 00:00 600 24.00 PREP A 20 P Removed driller's side link tiff cylinder for repairs.\Continue R/U-organize and housekeeping.\Little Red freeze protected IA @ 1700 hrs.with 40 bbls.diesel.\Assisted Halliburton in R/D of tool string,lubricator.\Assisted Vecto Gray rep install of 4"valve on SD37-DSP1 tree and secure well. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10-* Eni E&P Division I Well Name:SP18-N5 EN!Petroleum Co.Inc. Daily Report well Code:25788 Field Name:NIKAITCHUQ ik Date:10/19/2011 - Report#: 6 APIIUWI:50-629-23453-00-00 2" " page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13.628.0 11.953.00 145.08 82.4 -2.69 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 92.0 30.2 Clear,WC 20.7` 80'E @ 4 mph Daily summary operation 24h Summary Working on fabricating and installing 4"temporary slurry manifold/line to WIF from Doyon rack washer.\Construction installing/field weld on SD37-DSP1 injection tree manifold.\General R/U to spud and PM on equipment. Operation at 07.00 Fabricate working on 4"Slurry line WIF to ground level for line from Doyon rock washer. 24h Forecast Complete 4"victaulic X 20'line to WIF and fabricate down drop from WIF to same,heat trace and insulate same.)Construction to finish SP37-DSP1 tree injection manifold in well house(X-ray&hydro test fanges)I P/U BHA#1/Build mix spud mud(depending on time line for support line)-immediate plan to install all temporary line in and set suit cases while we are drilling. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00 00 06 00 ' 6.00 6.00 PREP A 20 P Remove rig mats and herculite after Schlumberger equipment removed for slurry line to WIF.)Install two manifold valves on conductor pipe for surface cement 09.1 Check and adjust valves in mud pits.\Continue PM's on equipment. 06:00 12.00 6.00 12.00 PREP A 20 P Fabrication work on last section of diverter line)Cut 4"x4"blocking material and start laying out 4"victaulic lines from rock washer temporary slurry line to WIF.\Continue checking and adjusting mud pits valves.)Construction working on SP37- DSP1 manifold to tree injection well.)Doyon engineer on location for suit case system install. 12:00 18:00 6.00 18.00 PREP A 20 P Install final section of diverter line and work on pipe saddles.)Fabricate temporary 4"manifold from Gallagher pumps and make penetration in wall of rock wash for 4"slurry line.\Finish lay out 4"X20'victaulic line and connect two section together from rock wash to WIF.)Install rebuilt link tilt cylinder on TDS-8.\Continue PM on rig equipment 18.00 00:00 6.00 24.00 PREP A 20 P Install 4"manifold on Gallagher pump and fabricate drop down line from rock washer to ground level,continue connecting two 20'section of line together to WIF.)Re-locate Schlumberger MWD shack and work on electrical power.)Continue PM on rig equipment-pipe skate hydraulic unit-work on cellar box drain plumbing-adjust brake coolant pump pressure gauge-work on drillers side bridge crane. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3050 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) �. -_n Eni E&P Division [Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • API/U W I:50-629-23453-00-00 2^n Date:10/20/2011 - Report#: 7 i If I' page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 -1.69 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind ' 0.0 97.0 30.1 Foggy,WC 20.7 128`SE @ 2MPH Daily summary operation 24h Summary Fabricate and install 4"slurry line installing to WIF from Doyon rack washer-(heat trace).\Construction installing injection manifold on SD37-DSP1 tree.)Dummy run 13 3/8"landing joint.)Prep to move Doyon parts house)Work on rock washer shake ramp and remove LVT pump to install new submersible pump.)PM on equipment. Operation at 07.00 P/U 5"drill pipe. 24h Forecast V Finish heat trace and insulating slurry line from Doyon rack wash to WIF.\Hydro test and X-ray SP37-DSP1 tree injection manifold,(test injection line to WIF)\Load pipe shed with 5"drill pipe to TD well and P/U same.\P/U BHA#1(Schlumberger tech to inspect threads))Install vortex pump @ WIF.\Build mix spud mud and transfer to rig form mud plant.)Prep to spud well. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00 00 06 00 6 00 6.00 PREP A 20 P Run 4"temporary slurry lines from Doyon rock washer across pad to WIF containment,block up for heat trace and insulation of same.)Install fabricated 4"x 90°fitting from WIF slurry input outlet.)Check torque on all bolts of diverter line and saddle clamps.)CH2MHill cleared and leveled pad for injection and cement line to cross pad @ WIF.)Continue PM on equipment—set rebuilt motor for bridge crane-Repair dead line saver as per derrick inspection.)CH2MHill dressing east ramp on island for hover craft use. 06:00 12:00 6.00 12.00 PREP A 20 P Option measurement from 90°on WIF and remove to fabrication line.)Confirm 20"load shoulder measurement 37.041 Work on rock washer shaker ramp.)Held man-down drill response time 1 min.&25 sec.1 Load landing joint in pipe shed.) Continue PM on equipment.)Simops-Construction work on SP37-DSP1 manifold and bolt-up to tree.)Began heat tracing slurry line.)CHM2Hill dressing east ramp to island. 12:00 18:00 6.00 18.00 PREP A 20 P Continue assembly of slurry line to WIF—install section to ground level.)Schlumberger and MlSwaco connected cement& injection lines across access path @ WIF\Assembly landing joint with Vetco Gray rep.)CH2MHill continue heat tracing slurry line.)Began relocating equipment and organizing east pad area of rig.)Continue work on SP37-DSP1 well head. 18:00 00:00 6.00 24.00 PREP A 20 P Continue working on slurry line(fabricate and install end manifold to WIF)\P/U landing joint and perform dummy run with Vetco Gray rep L/D in pipe shed,also set well head in cellar of rig.)Pulled LVT pump form pits and prep to install new submersible pump.U4ove drill pipe tubs to access form P/U 5"DP.)Move HWDP to off drillers side.)Prep to move parts house. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Eni representative Tom Norvig ENI Rig Clerk lom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CONDUCTOR 20 18.250 X65 00 160.0 1/15/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 1"1* Eni E&P Division (Well Name: SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • 2^ Date:1012112011 - Report#: 8 APIIU Wl:50-629-23453-00-00 I( I�ii page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77. 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13.628.0 11,953.00 145.08 82.4 -0.69 Daily Information End Depth(/0/B) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 0 0 104.0 28.9 Cloudy,WC 19.6° 238°WSW @ 3.6 MPH Daily summary operation 24h Summary Load pipe shed with 5"drill pipe and transfer to long side.)Load Schlumberger tools in pipe shed.)P/U 231 joints of 5"drill pipe and rack back in derrick.)P/U Schlumberger BHA components(2 Flex and 1 NMDC,also jars)and rack back in derrick.)Finished heat trace 4"slurry line to WIF.)Construction completed X-ray SP37-DSP1 tree injection manifold. Operation at 07.00 Mix spud mud and transfer to rig pits. 24h Forecast P/U BHA#1 clean out assembly and hang in block.)Lay containment under temporary 4"slurry line,needs to be insulated to WIF and secure.)Results from X-ray on manifold.\Install vortex pump @ WIF for cuttings.\Build spud mud @ plant and Vac truck to rig pits.)Prep spud meeting and spud well. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 PREP A 20 P Organized 8 prep pipe shed.)Load with 231 joints 5"drill pipe(strapped)and transferred to long side.)Prep Doyon parts house for move from in front of east corner well house. 03:30 04:30 1.00 4.50 PREP A 20 P Load short side pipe shed with BHA#1 components.)Move Doyon parts house. 04:30 12:00 7.50 12.00 PREP E 4 P PJSM-P/U 5"drill pipe(4 1/2"IF,S-135—2.90"drift).)Finish heat trace 4"slurry to WIF. 12:00 13:00—1'.00 13.00 PREP E 25 P Service rig and PJSM to P/U pipe. 13:00 17:30 4.50 17.50 PREP E 4 P Continue P/U 5"drill pipe(4 1/2"IF,S-135—2.90"drift).)UD mouse hole and clean and clear floor of protectors. 17:30 21:00 3.50 21.00 PREP E 20 P P/U Schlumberger BHA components and steam clean box/pins.)UD and send to shop for inspection.)Spot east bulk valve house with crane.)Construction X-ray welds on SP37-DSP1 tree manifold. 21:00 00:00 3.00 24.00 PREP E 4 P P/U and M/U 2 Flex NMDC and 1 NMDC-M/U jars on double 5"HWDP-rack back in derrick as per Schlumberger.)Work on install containment under temporary 4"slurry line)Finished X-rays of tree manifold. Daily Contacts Position Contact Name Company Title E-mail office Mobile Eni representative Jack Keener ENI Senior Co Rep -jack.keener@enipetroleum '907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(BKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:SP18-N5 1 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • Date:10/22/2011 - Report 9 APIIUWI:50629-23453-0400 ( I I I page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date •Target Depth(RKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 0.31 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) P013 Temperature("F) Weather Wind 160 0 160.0 160.00 1.25 128.0 107.0 28.9 Cloudy,WC 6.4° 44°NE @ 23.6 MPH,Gusts to 32 MPH Daily summary operation 24h Summary Build berm containment for 4"temporary slurry line to WIF and prep rock wash shaker,pits and Gallagher pumps\P/U BHA#1.1 SP37-DSP1 tree injection manifold signed off for injection.\Held Pm-spud meeting\Pressure test line surface line and fill conductor-no leaks.\Spud well Tag @ 60'and clean out conductor to 160'and POOH\P/U BHA#2\PJSM with Halliburton and Gyro Data and R/U same. Operation at 07.00 Drilling ahead MWD and Gyro Survey as needed. 24h Forecast • Drill ahead f/160'-MWD 8,Gyro Data surveys as needed and per well plan to surface TD. - Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 0.07 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 PREP E 1 P Continue working on rock washer shaker,pits and install air line to blow down temporary slurry line.\Load floor with XO and UBHO as per Schlumberger DD.\Build herculite berm under temporary 4"slurry line to WIF. 03:30 05:30 2.00 5.50 PREP E 4P P/U BHA#1 clean out assembly and hang in blocks.\Continue lay out Herculite berm for 4"slurry line to WIF and spot rig mat on each side of line. 05:30 12:30 7.00 12.50 PREP E 1 P Finished berm of 4"slurry line to WIF-strip and secure line\Prep Gallagher pumps in rock wash(adjust belts and finish pumping).\P/U Schlumberger power pulse(back-up)and break top service break-remove saver sub off MWD tool.\SD37 -DSP1 well injection manifold signed off.\Off line:move east bulk valve house and first suit case section from corner well house to prep pad-line up flanges and prep to connect. 12:30 15:30 3.00 15.50 PREP E 20 P Pressure test 4"line slurry line to WIF-tighten connection @ 45'and W°fittings and retest good.\Install centrifuge cutting pump @ WIF for solid cuttings.\Off line:Continue prep pad and reset east bulk valve house into place and first suit case. 15:30 16:30 1.00 16.50 DRILL E1 P Held Pm-spud meeting.\Pressure test lines and check interconnect-fill stack and check same and flow line for leaks- good. 16:30 18:30 2.00 18.50 DRILL E 3 P Spud well-Tag @ 60'-Clean out conductor to 160'with pump rate 450 psi.@ 450 psi.1 30 rpm @ 2K torque.\WOB=5- 10K.\Up wt 90K-Dn wt.90K-Rot wt.8610 Mud wt.=8.7 ppg.\Pump out hole to 60'with 84 gpm @ 150 psi.20 rpm @ 1K torque.\POOH on elevators to bit and check OK. 18:30 22:00 3.50 22.00 DRILL E 4 P M/U BHA#2 as per well plan-UD 16"stab-PIU power pulse,ARC,NM XO and NM UBHO. 22:00 00:00 2.00' 24.00 DRILL E 20 P Halliburton spotted E-line unit.\Held PJSM with Halliburton and Gyro Data-re-head line and check out tools-R/U sheaves in derrick. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907,685-0722 3552607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) - CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off I ,ure(psi) Eni E&P Division I Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO rii* • APIIU W I:50-629-23453-00-00 2^ Date:10/23/2011 - Report#: 10 • II I' page 1 of 1 Wellbore name: SP18-N5 Well Header • PermitlConcession N° Operator ENI Share)%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13,6280 11,953.00 145.08 82.4 1.31 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 923.0 912.7 763.00 5.76 132.5 107.0 24.5 Cloudy, WC 9.3` 52°NE @ 11 MPH, 18 MPH Daily summary operation 24h Summary Finished R/U Halliburton/Gyro Data\Drill Slide/Rotate with mud motor f/160'-6277'-survey with Gyro Data and MWD @ 30'intervals\Circulate clean and monitor well-static.\POOH 1/100'&P/U remaining BHA#2 from derrick 11230'\Wash f/230'-6277'\Drill Slide/Rotate with mud motor f/277'-1/923'-survey as needed with Gyro Data and MWD(Schlumberger survey good @ 851'). Operation at 07.00 Drilling ahead as per well plan with Schlumberger MWD surveys. 24h Forecast Drill Slide/Rotate with mud motor f/923'to well plan 13 3/8"surface csg.proposed TD @ 2664'.\R/D Halliburton/Gyro Data.\Continue working off line on service line suit cases. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. k" 00:00 01:00 1.00 1.00 DRILL E 20 P Finished R/U Halliburton/Gyro data equipment and tools string.\Perform surface survey check shot. 01:00 05:30 4.50 5.50 DRILL E 3 P Drill Slide/Rotate with mud motor f/160'-1/277'\Gyro Data/Schlumberger MWD surveys as needed\Pump 500 gpm @ 550 psi.\40 rpm @ 1-2K torque./WOB=0-15K./Up wt 92K-Dn wt.92K-Rot wt.92K.1 Mud wt.=8.9 ppg.\ECD=10.75 ppg.\ Transfer cutting to WIF with CH2MHill and 4"slurry line.\Continue monitor conductor for breaching.\ADT=1.22 hrs.-ART= 0.16 hrs.-AST=1.06 hrs.\Jars=8802 hrs. 05:30 06:00 0.50 6.00 DRILL E 7P Circulated until hole clean-Monitor well-static. 06:00 07:00 1.00 7.00 DRILL E 4 P POOH f/277'-1/100'-detected+5K over pull-RIH back 1/260'and pumped out hole into conductor-pump rate 184 gpm @ 100 psi. 07:00 08:30 1.50 8.50 DRILL E 4P RIH f/100'-1/230'\P/U remaining BHA#2(NM DC and Flex DC from demck). 08:30 09:00 0.50 9.00 DRILL E 6 P Break circulation and wash f/230'-1/277'\Pump rate 300 gpm @ 200 psi.\30 rpm @ 1-2K torque. 09:00 12:00 3.00 12.00 DRILL E 3P Drill Slide/Rotate with mud motor f/277'-1/345'(345'TVD)\Gym Data/Schlumberger MWD surveys as needed\Pump 480 gpm @ 550 psi.\40 rpm @ 1-2K torque.\WOB=2-20K.I Up wt 105K-Dn wt.105K-Rot M.105K.1 Mud wt.=9.0 ppg.\ ECD=10.53 ppg.1 Continue transfer to WIF via super sucker and 4"slurry line.)Monitor conductor.\ADT=0.86 hrs.-ART= 0.23 hrs.-AST=0.63 hrs.\Jars=88.88 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Slide/Rotate with mud motor f/345'-0640'(63T TVD)1 Gyro Data/Schlumberger MWD surveys as needed\Pump 600 gpm @ 750 psi.\40 rpm @ 2K torque.\WOB=15K.\Up wt 115K-Dn wt.115K-Rot wt.115K.1 Mud wt.=8.9 ppg.\ECD= 9.71 ppg.\Transfer to WIF.\Monitor conductor.\ADT=2.27 hrs.-ART=0.26 hrs.-AST=2.01 hrs.\Jars=91.15 hrs.Off line: Work on bulk transfer valve house and suit cases on east side of rig. 1800 00:00 6.00 24.00 DRILL E 3 P Drill Slide/Rotate with mud motor f/640'-1/923'(913'TVD)\Gyro Data/Schlumberger MWD surveys as needed\Called town and discussed traveling cylinder to plan well for close approach to tolerance line @ 640'.\Pump 650 gpm @ 850 psi.\40 rpm @ 1-2K torque.\WOB=2-20K.)Up at 127K-Dn wt.120K-Rot wt.125K.1 Mud at 9.1 ppg.\ECD=10.02 ppg.I Transfer to WIF.\Monitor conductor.\ADT=1.41 hrs.-ART=0.13 hrs.-AST=1.28 hrs.\Jars=92.56 hrs. Total ADT=5.76 hrs. • Total AST=4.98 hrs. Total ART=0.78 hrs. Total Jar=92.56 hrs Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Sr,* Eni E&P Division I Well Name:SP18-N5 I EN!Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • Date:10/24/2011 - Report#: 11 APIIUWI:50-629-23453-00-00 en II page 1 of 1 Wellbore name: SP18-N5 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 2.31 Daily Information End Depth(ftKB) End Depth(ND)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather Wind 1,687.0 1,597.1 764.00 5.37 142.3 107.0 20.5 Cloudy,WC 4.8` 92°E @ 22MPH, Gusts 35MPH Daily summary operation 24h Summary Halliburton/Gyro Data multi shot well\Drill Slide/Rotate 1/923'-1/1402'with SLB MWD surveys.\Ream out dog leg and SLB MWD tool started having problems sync,due to noise level in spectrograph- Drill(/1402'-1/1436'(varied pump parameters and check surface equipment).\Monitor well-static and back ream f/1436'-V185'.\Work BHA#2-L/D MWD and P/U spare MWD for BHA#3\RIH 1/185'- V1,402'shallow test SBL MWD @ 830'(good)\Wash down(/1402'-1/14361 Drill Slide/Rotary 1/1436'-1/1687'. Operation at 07.00 Drill ahead as per well plan to 13 3/8"surface casing point. 24h Forecast Drill Slide/Rotate with 1.83°motor(/1687'as per well plan to surface csg.point.\Off line activity:make-up connect between service line suit cases on eastern side of rig. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P Gyro Data/Halliburton perforin multi-shot survey of well after Schlumberger good MWD survey. 00:30 05:30 5.00 5.50 DRILL E 3 P Drill Slide/Rotate with mud motor f/923'-111402'(1352'TVD)\MWD surveys\Pump 650 gpm @ 1200 psi.\40 rpm @ 5-6K torque./WOB=9-35K.\Up wt 139K-Dn wt.132K-Rot wt.134K.\Mud wt.=9.2 ppg.\ECD=10.15 ppg.\Transfer to WIF./ Monitor conductor.\R/D Halliburton/Gyro Data.\ADT=3.58 hrs.-ART=1.48 hrs.-AST=2.09 hrs.\Jars=96.14 hrs. Total ADT=9.34 hrs. Total AST=7.08 hrs. Total ART=2.26 hrs. Total Jar=96.14 hrs. 05:30 08:30 3.00 8.50 DRILL E 6 XD99 Back ream and ream section 1/1402-V1305'to reduce 7.09°dog leg serve @ last survey point 1328'(1290'TVD).-Re- survey and reduce to 6.47'dog leg. 08:30 10:30 2.00 10.50 DRILL E 19 XDO1 Began trouble shooting MWD-drilled f/1402'-1/14361(tool would not sync-back ground noise-Schlumberger consulted with town).\Check/clean suction/discharge screens and pressure on mud pump pulsation dampeners all good./Tool failure. 10:30 15:30 5.00 15.50 DRILL E 4 P Monitor well-static.\POOH back reaming with BHA#2-(/1436'-1/185'to change out MWD.\Pump rate 550 gpm @ 650 ,,/ psi./40 rpm @ 3-4K torque./Hole condition dictated speed.\Monitor well during hovercraft operation. 15:30 18:30 3.00 18.50 DRILL E 4 P Held PJSM work BHA#2 as per Schlumberger DD/MWD\Down bad data from ARC 825-L/D MWD and P/U back-up and orientate. 18:30 19:00 0.50 19.00 DRILL E 25 P Service rig equipment. 19:00 20:30 1.50 20.50 DRILL E 4 P RIH with BHA#3 f/96'-V830'and perform MWD shallow test-Flow rate 650 gpm @ 950 psi.-Good 20:30 21:00 0.50 21.00 DRILL E 4 P Continue RIH f/830'-V 1400'\Break circulation and wash down f/1400'-t/14361 flow rate 650 gpm @ 980 psi.\40 rpm @ 3 -5K torque. 21:00 00:00 3.00 24.00 DRILL E 3 P Drill Slide/Rotate with mud motor(/1436'-V1687'(1597'ND)1 Pump 650 gpm @ 1290 psi.\40 rpm @ 3-5K torque/WOB= 25K.\Up wt 150K-Dn wt.130K-Rot wt.13510 Mud wt.=9.2 ppg.\ECD=10.10 ppg.\ADT=1.79 hrs.-ART=1.79 hrs.- AST=0.0 hrs.\Jars=97.93 hrs. Total ADT=1.79 hrs. Total AST=0.0 hrs. Total ART=1.79 hrs. Total Jar=97.93 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spauldirg@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2011 Last Leakoff Test Depth(RKB) ND(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) * Eni E&P Division `Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO eDate:10/25/2011 - Report#: 12 API/UWI:50-629-23453-00-00 e "11 page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31 70 Rig Information Contractor Rig Name Rig Type • DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(f11hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 3.31 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather Wind 2.684.0 2.403 1 997.00 6.77 147 3 102.0 22.5 Partly cloudy,WC- 59'ENE @ 39.8 2.5° MPH,Gusts 55MPH Daily summary operation 24h Summary Drill Slide/Rotate(/1687'-1/2684'(TD for 13 3/8"csg.)\Circulate 4X CBU until clean-rack back stand per BU(/2684'-1/23561 POOH back reaming 1/2356'-08201 Circulate until clean(4X).1 POOH 1/820'to BHA#3-L/D as per Schlumberger DD/MWD. Operation at 07.00 P/U 13 3/8"csg.(68#,L-80,BTC)as per well plan. --- 24h Forecast Finish LID BHA#3 and clear floor of components.\R/U GBR equipment and Frank's fill-up toot PJSM and P/U 13 3/8"csg.\Circulate and condition mud for cement job.\PJSM with Schlumberger and cement 13 3/8"csg as per well plan.\Flush out stack and N/D 20"Diverter system N/U 13 5/8"BOP stack. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 600 6.00 DRILL E 3P Drill Slide/Rotate with mud motor f/1687'-1/2264'(2106'TVD))Pump rate 650 gpm @ 1400 psi.)40 rpm @ 8-9K torque.) WOB=10-25K.1 Up wt 160K-Dn wt.130K-Rot wt.14210 Mud wt.=9.4 ppg.\ECD=10.28 ppg.\ADT=3.44 hrs.-ART= 2.12 hrs:AST=1.32 hrs.\Jars=101.37 hrs. 06 00 12:00 6.00 12.00 DRILL E 3P Drill Slide/Rotate withmud motor 1/2264'-02557(2375'TVD))Pump 650 gpm @ 1400 psi.)40 rpm @ 8-10K torque.) WOB=10-30K./Up wt 168K-Dn wt.148K-Rot wt.150K./Mud wt.=9.4 ppg.\ECD=10.15 ppg.\ADT=2.16 hrs:ART= 0.17 hrs.-AST=1.99 hrs.\Jars=103.53 hrs. 12.00 14-.00 ' 2.00 14.00 DRILL E 3 'P Drill Slide/Rotate with mud motor 62557'-1/2684'(2493'TVD)1TD for 13 3/8"csg.1 Pump 650 gpm @ 1350 psi.)40 rpm @ 8- 15K torque.)WOB=10-30K.1 Up wt 180K-Dn wt.148K-Rot wt.150K.\Mud wt.=9.4 ppg.\ECD=10.2 ppg.1 ADT=1.17 his.-ART=0.04 hrs.-AST=1.13 hrs.)Jars=104.70 hrs. Total AOT=8.56 hrs. Total AST=4.44 hrs. Total ART=4.12 his. • Total Jar=104,70 hrs. ' 14:00 17:30 3.50 17.50 DRILL E 7P Circulate hole clean.)Reciprocate and rotated string.)CBU 4X-pumping 700 gpm @ 1350 psi.40-50 rpm @ 5-15K torque.) Rack back one stand after each CBU 1/2684'-112356'. 17:30 20:00 2.50 20.00 DRILL E 4P POOH back reaming 1/2356'-1/820to HWDP)Pump rate 750 gpm @ 1425 psi.40-50 rpm @ 5-17k torque.)Hole condition dictated pulling speed 20:00 21:00 1.00 21.00 DRILL E 7P Circulated hole until clean-820'@ HWDP-bottoms-up 4X-reciprocate and rotated string.)Pumping 775 psi.@ 1320 psi. 50-60 rpm @ 5K torque.Reciprocate and rotated string. 21:00 00:00 3.00 24,00 DRILL E 4 P POOH 1/820-U1251 Held PJSM L/D BHA#3 as per Schlumberger DD/MWD)Down load data from ARC 825 in pipe shed.\ Flush BHA components with water twice. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keenen@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum,com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john,spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 36.9 2.669.0 10/2612011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division 'Well Name: SP18-N5 riliiiS ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • Date:1012612011 - Report#: 13 APIIUWI:5062923453-00-00 2" " page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N^ Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 4.31 Daily Information End Depth(RKB) End Depth(TVD)(L..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2.684.0 2.493.1 0.00 107.0 22.0 Cloudy,Windy,WC 76°ENE @ 15.8 9° MPH,Gusts to 22 MPH Daily summary operation 24h Summary Finish L/D BHA and clear floor\R/U GBR for 13 3/8"csg.\P/U 13 3/8"csg(68#,L-80,BTC)02669'\Circulate and condition mud L/D Frank's tool and P/U cement head\Continue circulating-PJSM with Schlumberger for cement job\Test lines t/3000 psi.\Schlumberger cemented 13 3/8"csg.in place @ 2321 hrs.with 150 bbls.cement returns back to surface.\Flush stack and equipment. Operation at 07.00 N/D 20"Diverter system. 24h Forecast R/D Schlumberger&GBR equipment.\Flush out diverter and Flow lines.\N/D Diverter stack.\N/U Vetco Gray Multi-bowl.\N/U 13 5/8"BOP stack and test as per AOGCC requirements./Off line:Clean active and prep for LSND mud\Will update AOGCC. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 4 P Finished L/D BHA#3 as per Schlumberger DD/MWD-Continue ARC down load in pipe shed. 01:00 03:00 ' 2.00 3.00 DRILL E 4 P Clear and remove floor of BHA#3 components-blow rig floor section of cement 03:00 05:30 ' 2.50 5.50 DRILL G 1 P Held PJSM\R/U GBR 13 3/8"csg.handing equipment&Frank's fill-up tool. 05:30 13:00 7.50 13.00 DRILL G 4 P Held PJSM\P/U 13 3/8"68#,L-80,BTC casing.\M/U shoe track and check floats good-RIH t/2669'\Install centralizer as per well plan.\Filling pipe every joint and top off every 101 Break circulation @ 1840'-stage pump rate from 42 gpm to 168 gpm with final pressure @ 170 psi.\Monitor returns for lose.\P/U landing joint with Vetco Gray. 13:00 16:30 3.50 16.50 DRILL G 7 P Circulate and condition mud for cement job(reciprocate pipe 15')1 Stage pump rate to 210 gpm @ 230 psi.\Up wt.=260K- Dn wt.=190K\Monitor returns./Load plugs in cement head,ENI reps.witness./Gave 24 hour notification to AOGCC for BOP test @ 1500 hrs.and John Crisp return call-will update tomorrow. 16:30 17:00 0.50 17.00 DRILL H 5 P L/D GBR Frank's fill-up-blow down top drive-P/U Schlumberger 13 3/8"cement head. 17:00 19:00 2.00 19.00 DRILL H 7 P Continue to circulate condition mud while reciprocate 13 3/8"csg.through cement head pumping 210 gpm @ 200 psi.\Up wt.=280K-Dn wt.=190K\PJSM for cementing 13 3/8"csg.with Schlumberger and all parties involved. 19:00 00:00 5.00 24.00 DRILL H 7 P Shut down rig pumps and Schlumberger pumped 14 bbls.H2O to fill lines and tested lines 03000 psi.-good.\Switched back rig pumping 100 bbls.of Mud Push II @ 10.1-rate of 5.2 bpm @ 210 psi./Shut-down drop bottom plug.\SLB mix& / pump Lead slurry 450 bbls.@ 10.7 ppg.\Class ActicSet Lite/1087 sks.[2.33 Yield,mix water at 10.367 gal/sk.]-Pump C•0404/4 rate of 5.9 bpm @ 740 psi.\SLB mix and pump Tail slurry 68 bbls.@ 12.5 ppg./Class DeepCRETE\255 sks.[1.50 Yield, mix H2O at 4.736 gal/sk.]-Pump rate of 4.2 bpm @ 660 psi./Shut down&drop top plug-SLB pump 10 bbls H2O and wash up.\Displace with 398 bbls.@ 9.3 ppg mud with rig pump at 5.2 bpm w/490 psi,at 354 bbls away slow pump to 3 bpm with 290 psi.FCP with full returns\Bump plug to 500/psi,over FCP to 790 psi.-Hold for 5 minutes and bleed off-check floats are holding-Good/Cement in place @ 2321 hrs.with a total of 151bets.10.7 ppg cement returns to surface. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representafive Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk lohn.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3,8 12.415 L80 36.9 2,669.0 10/26/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) alr* Eni E&P Division [Well Name: SP18-N5 I EN/Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • Date:1012712011 - Report#: 14 APIIUWI:50-629-23453-00-00 2r' r'o page 1 of 1 Wellbore name: SP18-N5 Well Header PermitConcession N° Operator ENI Share(%( Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13.628.0 11,953.00 145.08 82.4 5.31 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,684.0 2.493.1 0 00 99.0 21.0 Cloudy,Breezy,WC 86°E @ 11 MPH, 9° •Gusts to 15 MPH Daily summary operation 24h Summary R/D Schlumberger and GBR equipment\Flush stack from 20"conductor valves to rock washer with cement retarder pill.\L/D landing jt.\Flush stack and equipment again.\N/D 20"Diverter system.\N/U 13 5/8"BOP stack.\Test BOP-AOGCC waived witness of test @ 1500 hrs.\Clean active pits and WIF injected all fluids. Operation at 07.00 Finishing testing BOP stack and Schlumberger prep BHA#4 to be P/U. 24h Forecast Finish testing BOP components to AOGCC requirement(AOGCC waived witness of test).\P/U BHA#4 as per well plan and RIH above float collar.\Perform 13 3/8"casing test to 2500 psi.f/30 mins. (chart record).\Drill out float/shoe and 20'-50'new hole.\Displace well bore to new LSND mud.\Perform LOT/FIT Drill ahead intermediate hole section.\Start prep for 9 5/8"csg. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 5 P Rig down Schlumberger cement head and lines.\R/D GBR csg.equipment\Rinse out&lay down landing joint\R/D long bails&install short bails\Pump cement retarder pill from conductor valves to rock washer tanks\P/U stand 5"DP and stack washer tool flush out diverter and flow line with second retarder pill,\UD GBR equipment off rig floor.\Install work landing @ BOP cellar area.\Start transfer 750 bbls.spud mud to WIF for injection. 05:00 10:30 550 10.50 DRILL C 5 P N/D 20"Diverter system and Vetco Gray riser and starting head.\R/D conductor valve manifolds I Clean rig active pit system. 10:30 14:00 3.50 14.00 DRILL C 5 P N/U Vetco Gray Multi-bowl and well head valves(3)with mp.\Test seals to 5000 psi for 10 minutes-good./Lower lock down screws RKB 35.10'.\Set well house hatch cover on and N/U riser.\Continue cleaning active pits. 14:00 20:00 6.00 20.00 DRILL C 5 P N/U 135/8"BOP stack-install choke&kill lines,bell nipple,flow lines.\John Crisp w/AOGCC waived witness of BOP test @ 1500 hrs. 20:00 22:00 2.00 22.00 DRILL C 1 P Function test BOP and install test plug(Vetco Gray rep.)-Ft/LI to test-fill stack.\Retighten Gary Lock clamp on 13 3/8" riser.\Pick-up and organize BOP level\Fill gas buster with H2O-(12 bbls.volume and 95 seconds with the trip tank pump). 22:00 00:00 2.00 24.00 DRILL E 12 P Test BOP to AOGCC requirements on 5"tubular.\Perform accumulator draw down test(Recovery times:f/1450-U1650 psi. 7 (200 psi.)in 40 seconds with final @ 3000 psi in 235 seconds-5 Nitrogen bottles @ 2450 psi average).\Test annular @ ^(..:"1250 psi./2500 psi.\Top pipe rams,choke manifold 250 psi./3500 psi.-Chart record all test for 5 mins.)Check 16 Y accumulator bladder pre-charge avg.=1100 psi.\Tested was waived by AOGCC. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 -715-6434 Eni representative David F Smith ENI Co Rep david.t.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackernan@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 133/8 12.415 L80 36.9 2,669.0 10/26/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) *Ail Eni E&P Division Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO n• e n N Date:10/28/2011 - Report#: 15 APIIUWI:50-629-23453-00-00 page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOVON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 6.31 Daily Information End Depth(ftKB) End Depth(ND)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 3,233.0 2,999.7 549.00 7.89 69.6 99.0 23.0 Cloudyy,WC 9° 36°NE @ 19.1 MPH,Guststo 29 MPH Daily summary operation 24h Summary Finish testing BOP components./R/D test equipment and install wear bushing./Service rig./Held PJSM-P/U BHA#4(L/D MWD-debris inside and P/U back-up MWD)./RIH t/1024'&POOH L/D 17 jts. of HWDP and slick NMDC.\RIH with P/U ghost reamer 1/1044'-shallow test tools.\Slip&cut drilling line,Schlumberger re-calibrated block height./RIH 1/1044'-1/23861 Circulate bottoms-up./Perform 13 3/8"csg.test 2500 psi f/30 mins./Break circulate RIH tag @ 2570'.1 Drill shoe track(float collar @ 2586,shoe @ 2669')-clean out old hole to 2670'. Operation at 07.00 Drilling rotary steeable ahead 12 1/4"intermediate hole section as per well plan.%FIT 13.08 ppg. 24h Forecast Clean out old hole 1/2670'-1/2684'.\Drill f/2684'-1/2710'(26'new hole).\Displace well bore to new LSND mud./Perform LOT/FIT\Drill ahead 12 1/4"intermediate tale section. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 925 Time Log Start End Cum Time Time Dur(hr) Dur(hr). Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50' 4.50 DRILL E 12 P -Completed testing BOP to AOGCC requirements on 5"tubular./Lower pipe&blind rams,mud cross valves and HCR's, choke manifold(18 valves),floor and top drive valves 250 psi./3500 psi.-Chart record for 5 mins.\Tested gas sensors. 04:30 05:30 1.00' 5.50 DRILL E 12 P 'R/D test equipment and pull test plug-install wear ring(12 5/16")-Vetco Gray rep.\Blow down choke manifold and top drive. 05:30 06:00 0.50 6.00 DRILL E 25 P Service rig-top drive,blocks,draw-works,crown. 06:00 12:00 6.00 12.00 DRILL E 4 P PJSM-P/U BHA#4 as per well plan and Schlumberger DD/MWD.\Surface test Power Drive 900 with 580 gpm @ 350 psi.\ P/U MWD and found debris inside-L/D same and P/U new MWD.\RIH f/91'-1/1024' 12:00 15:30 3.50 15.50'DRILL E 4 P POOH UD 17 joints of HWDP and one NMDC-RIH P/U BHA(ghost reamer)with 5"DP 1/1044'and perform shallow test on MWD-good.\K&M calibrations for BHA weight. 1530 17:00 1.50 17.00 DRILL E 25 P Slip and cut drilling line-perform PM inspection on dog nut and brake linkage-adjusted 17:00 18:00 1.00 18.00 DRILL E 20 'P Lubricate and service rig components.\Schlumberger recalibrated block height. 18:00 19:00 1.00 19.00 DRILL E 4 'P RIH(/1044'-02389'. 19:00 19:30 0.50 19.50 DRILL E 7 P •Circulate bottoms-up pump rate 550 gpm @ 580 psi./Reciprocate pipe-stand.\Up wt.=150K-On wt.=120K. 19:30 21:30 2.00' 21.50 DRILL E 12 P R/U and perform 13 3/8"csg test 02500 psi f/30 minutes(chart record)./R/D test equipment lines. 21:30 22:30 1.00 22.50 DRILL E 6 P RIH(/2389'-02570'tag w/10K-Break circulation and wash(/2570'-1/25831 Pump rate 675 gpm @ 900 psi./40 rpm @ 4- y 7K torque./WOB=2-4K.%Up wt.=150K-Dn wt.=120K.-Rot wt.=140K. 22:30 00:00 1.50' 24.00'DRILL E 3 'P -Drill shoe track-(FC @ 2586,shoe @ 2669')and old hole to 2670'.\Pump rate 675 gpm @ 950 psi.\60 rpm @ 8-10K torque./WOB=8-10K.\Up wt.=150K-Dn wt.=130K.-Rot wt.=143K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 36.9 2,669.0 10/26/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,6690 2,478.97 LSND 9.20 500.0 13.08 1,684.8 "" ' Eni E&P Division IWeIIName:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ n Date:10/29/2011 - Report#: 16 API/UWI:50-629-23453-00-00 2 t' „ page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 71I 101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(f/hr) DFS(days) DRILLING 10/22/2011 13,628.0 11.953 00 145.08 82.4 7.31 Daily Information End Depth(1168) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 2,999.7 0.00 99.0 14.4 Parity Cloudy.WC 46 NE @ 4.3 MPH, 4.8° Gusts 4.8 MPH Daily summary operation 24h Summary Wash/ream U2670.-1/2684'(old hole))Drill rotary steerable f)2684'-1/2710'(26'new hole).\Displace well bore to new LSND mud.)Perform FIT 13.08 ppg\Drill rotary steerable f/2710'-1/3233'-could not get enough angle(dog leg)for well bore directional plan.)Circulate bottoms-up and attempted to POOH elevators-decide to back ream to 13 3/8'csg.)POOH on elevator f/26001 UD BHA#4 and P/U BHA#5)Continue loading pipe shed with 9 5/8'csg and prep same. Operation at 07.00 Drilling ahead mud motor assembly. 24h Forecast Finish P/U BHA#5 and shallow test.)RIH 1/277'-32331 Drill 12 1/4"intermediate hole section with mud motor assembly. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum Time Time Dur(Cr) Dur(Cr) Phase Opr. Act • Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 7 P Clean rat hole section f/2670'-1/2684'.)Pump rate 675 gpm @ 950 psi.)60 rpm @ 5-7K torque.\WOB=5-8K.I Up wt.= 150K-Dn wt.=130K.-Rot wt.=140K. 00:30 01:00 0.50 1.00 DRILL E 3 P Drill rotary steerable f/2684'-122710'(26'new hole-2517'TVD))Pump rate 675 gpm @ 950 psi.)60 rpm @ 6-8K torque.) WOB=615K.\Up wt.=150K-Dn wt.=130K.-Rot wt.=143K.\Mud wt.=9.4 ppg.\ECD=9.43 ppg.\ADT=1.03 hrs.\Jars= 105.73 hrs. 01:00 02:00 1.00 2.00 DRILL E 7 P Circulate and reciprocate pipe f/2710'-1/267131 Held PJSM)Displace well to new LSND 9.2 ppg.while fluids shipped to WIF.)550 gpm @ 580 psi.)60 rpm @ 5.5K torque.Up wt.=150K-Dn wt.=130K.-Rot wt.=143K.1 Continue circulate for balanced mud weight 9.2 ppg.\Pull into shoe @ 2583'. . .- `, 02:00 03:00 1.00 3.00 DRILL E 12 P R/U and perform FIT with 9.2 ppg LSND-surface pressure of 500 psi.-EMW=1�.)R/D.)Off line:clean surface r equipment from displacement and transfer fluids to WIF. 03:00 03:30 0.50 3.50 DRILL E 7 P Wash f/2583'-122710'.\Pumping 850 gpm @ 1000 psi.)60 rpm @ 5K torque. 03:30 06:00 2.50 6.00"DRILL E 3 -P Drill rotary steerable(/2710'-1/2865(2662'TVD)-Pump rate 520 gpm @ 3080 psi.)60 rpm @ 8-11K torque.)WOB=6-7K) Up wt.=156K-Dn wt.=135K-Rot wt.=145K)MW=9.2 ppg)ECD 9.43 ppg.\ADT=1.98 hrs.\Jars=107.71 hrs. 06:00 13:00 7.00 13.00 DRILL E 3 P Drill rotary steerable(/2,865'-1/3233'(3000'TVD)-Pump rate 900 gpm @ 1450 psi.)70-90 rpm @ 5-8K torque.)WOB=20- 30K\ 0- 30K\Up wt.=158K-Dn wt.=142K-Rot wt.=150K)MW=9.3 ppg\ECD 9.60 ppg.\ADT=4.88 hrs.\Jars=112.59 hrs. Total ADT=7.89 hrs. Total Jar=112.59 hrs. 13:00 14:00 1.00 14.00 DRILL E 7 P Circulate bottoms-up 2X.)Rack back one stand after each CBU f/3233'-1230551 Reciprocate and rotated string.)Pump rate 900 gpm @ 1350 psi.)120 rpm @ 6-7K torque. 14:00 15:00 1.00 15.00 DRILL E 4 'P Monitor well-static(blow down equipment))POOH f13055'-1/2865'-detected+20K over pull and RIH back 122960'. 15:00 16:00 1.00 16.00 DRILL E 4 'P POOH back reaming f/2960'-1/2600'into 13 3/8"csg.1 Pump rate 900 gpm(g 1350 psi.120 rpm @ 5K torque. 16:00 17:00 1.00 17.00 DRILL E 7 P Circulate bottoms-up.)Reciprocate and rotated string.)900 gpm @ 1350 psi.)120 rpm @ 5K torque.\Monitor well-static.) Pump dry job. 17:00 19:00 2.00 19.00 DRILL E 4 'P POOH on elevators(/2600'-t/BHA#4.Down bad data f/ARC 825 and UD Telescope and reprogram.)UD PD Flex Receiver and Power Drive. 19:00 21:30 2.50 21.50'DRILL E 4 P POOH working BHA#4-Down load data f/ARC 825 and L/D Telescope and reprogram.)UD PD Flex Receiver and Power Drive. 21:30 00:00 2.50 24.00-DRILL E 4 P P/U and M/U BHA#5 with mud motor(change AKO to 1.50°)-dress new 12 1/4"bit)P/U NM pony collars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Mike Ross ENI Co Rep michael.ross@enipetroleum.com '907-685-0715 Eni representative David F Smith ENI Co Rep david.i.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleuin 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 133/8 12.415 L80 369 2.669.0 10/26/2011 Last Leakoff Test Depth(ftKB) TVD(868) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,669.0 2.478-97 LSND 9.20 500.0 13.08 1.6848 rif* Eni E&P Division (Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ Date:10/30/2011 - Report#: 17 API/UWI:50-629-23453-00-00 page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 8.31 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 4,096.0 3,551.3 863.00 11.42 75.6 106.0 13.5 Partly Cloudy,WC- 219°SW @ 14.6 2° • MPH,Gusts to 20 MPH Daily summary operation 24h Summary Finished P/U BHA#5 to 277'-shallow test\Service rig/RIH f/277'-113143'\Wash/ream f/3143'-113233'\Drill slide/rotating 1/3233'-114099.1 155 joints 9 5/8"csg(40#L-80 Hydril 563)load in pipe shed. Operation at 07.00 Drilling ahead. 24h Forecast Drilling 12 1/4"intermediate ahead with mud motor assembly./Finish prep 9 5/8"csg Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 "01:30 1.50' 1.50 DRILL E 4 P PJSM-Finished P/U BHA#5 mud motor assembly 0277'and perform shallow test 625 gpm @ 750 psi.-good. 01:30 02:00 0.50 2.00 DRILL E 25 P Service equipment and perform top drive inspection. 02:00 "04:00 2.00 4.00 DRILL E 4 P RIH f/277'-1/2667'/Break circulate and Schlumberger MWD check shot.\Continue RIH 1/2667'-113143'.1 Up wt.=154K-Dn wt.=142K. 04:00 04:30 0.50' 4.50'DRILL E 6 P Wash and ream 1/3143'-113233'-pumping 750 gpm @ 900 psi.\60 rpm @ 5K torque. 04:30 12:00 7.50 12.00'DRILL -E 3 P Drill Slide/Rotating(/3233'-113620'(3285'TVD)-Pump rate 750 gpm @ 1390 psi./65 rpm @ 4-10K torque.\WOB=8-25K\ Up wt.=169K-Dn wt.=145K-Rot wt.=155K\MW=9.5 ppg\ECD 9.72 ppg./ADT=4.27 hrs.-AST=3.38 hrs.-ART=0.89 hrs.\Jars=116.86 hrs. 1200 '18:00 6.00 18.00 DRILL E 3 P Drill Slide/Rotating f/3620'-1/3972'(3508'TVD)-Pump rate 900 gpm @ 1620 psi./70 rpm @ 5-20K torque-back stands as hole required./WOB=10-20K1 Up wt.=170K-Dn wt.=140K-Rot wt.=150K1 MW=94 ppg\ECD 9.6 ppg./ADT=3.55 hrs: - AST=2.94 hrs.-ART=0.61 hrs./Jars=120.41 hrs. 18:00 '00:00 6.00 24.00'DRILL E 3 P Drill Slide/Rotating f/3972'-114096'[(3564'TVD)drilling L Ugnu]-Pump rate 900 gpm @ 1600 psi.\70-100 rpm @ 8-20K torque-back stands as hole required./WOB=10-20K1 Up wt.=180K-Dn wt.=140K-Rot wt.=150K\MW=9.3 ppg\ECD 9.6 ppg./ADT=3.60 hrs.-AST=2.64 hrs.-ART=0.96 hrs./Jars=124.01 hrs. Total ADT=11.42 hrs. Total AST=8.96 hrs. Total ART=2.46 hrs. Total Jar=124.01 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 36.9 2,669.0 10/26/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(Iblgal) •P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,669.0 2,478.97 LSND 920 500.0 13.08 1,684.8 iii _iis Eni E&P Division I well Name: SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO e Date:10/31/2011 - Report#: 18 (� API/UWI:50-629-23453-00-00"-I • r'� page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13.628.0 11,953.00 145.08 82.4 9.31 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5.152.0 3.872.2 1,056.00 12.87 82 1 108.0 2.8 Partly Cloudy,WC- 202°SSW 01)13.5 14.8° MPH,Gusts to 13.8 MPH Daily summary operation 24h Summary Drill slide/rotating(/4096'-05152'(3876'TVD))Work on Mud plant suit case system(east side)to rig-prep to test line. Operation at 07.00 Drilling ahead to TD(proposed+/-6200'). 2411 Forecast Drilling 12 1/4"hole section to TD(proposed+/-6200'MD))Circulate 14-5 to 7X or until clean-rack back one stand after each CBU.\POOH back reaming to 13 3/8"csg shoe @ 2669'per well plan and hole condition dictates.)Circulate until shakers clean(CBU+/-3 to 7X))POOH and LID BHA#5)Change rams t/9 5/8"csg.)Pull wear bushing and test.)Perform dummy run with 9 5/8"landing joinVcsg hanger.)R/U Tesco equipment. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 600 DRILL E 3 P Drill Slide/Rotating f/4096'-04262'(3606'TVD)-Pump rate 900 gpm @ 1700 psi.\80 rpm @ 6-10K torque-back ream stand.)WOB=10-30K\Up wt.=172K-Dn wt.=140K-Rot wt.=152K)MW=9.3 ppg\ECD 9.7 ppg.)ADT=3.99 hrs.-AST= 1.80 hrs.-ART=2.19 hrs.)Jars=128.0 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Slide/Rotating f/4262'-84578'(3708'TVD)-Pump rate 900 gpm(§1800 psi.)100 rpm @ 7-12K torque-back ream stand.)WOB=10-30K)Up wt.=176K-Dn wt.=142K-Rot wt.=154K)MW=9.4 ppg1 ECD 9.9 ppg.)ADT=2.88 hrs.-AST= 1.89 hm.-ART=0.99 km.)Jam=130.88 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Slide/Rotating0 f/4578'-84858'(3797'ND)-Pump rate 900 gpm @ 1820 psi.)70 rpm(§5-10K torque-back ream stand as required.)WOB=15-25K\Up wt.=175K-Dn wt.=140K-Rot wt.=148K)MW=9.4 ppg\ECD 9.6 ppg.)ADT=295 hrs.-AST=2.47 hrs.-ART=0.48 hrs.)Jars=133.83 hrs. 18:00 00:00 ' 6.00 24.00 DRILL E 3 P Drill Slide/Rotating(/4858'-V5152'(3876'TVD)-Pump rate 900 gpm @ 1820 psi.)70-80 rpm @ 7-10K torque-back ream stand.)WOB=15-25K)Up wt=178K-Dn wt=140K-Rot wt.=153K)MW=94 ppg)ECD 9.7 ppg.)ADT=3.05 hrs.-AST= 2.75 hrs.-ART=0.30 hrs.)Jars=136.88 hrs. Total ADT=24.29 hrs. Total AST=17.87 hrs. Total ART=6.42 hrs. ✓ Total Jar=136.88 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com '907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(MKS) Run Date CASING 13 3/8 12.415 L80 36.9 2.669.0 10/26/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,669.0 2,478.97 LSND 9.20 500.0 13.08 1.684.8 Eni E&P Division (Well Name: SP18-N5 Pi* ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO �,�.. e Date:11/1/2011 - Report#: 19 APIIUWI:50-629-23453-00-00 " " page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 10.31 Daily Information End Depth(ftKB) End Depth(TVD)(I...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 6.117.0 3,999.2 965.00 35.75 27.0 108.0 22.5 Clear,WC 11.3° 270°W @ 4.8 MPH, Gusts to MPH Daily summary operation 24h Summary Drill from 5152'MD to 6117'MD.TD this section of hole at 23:00 hrs.Total ADT 35.75 hrs,Total AST 23.78 hrs and total rotate time 11.97 hrs. Operation at 07.00 Backreaming out of the hole.having no problems. 24h Forecast Circulate bottoms up and back ream out of the hole as/per K&Ms instructions.Rig up and run 9 5/8"casing. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 3 P Drill from 5152 MD to 5410'MD,AST=1.76,ART=1.23 and ADT=2.99 hrs.Pick up weight=175K,slack off weight= 142k and rotating weight=152K. 04:00 05:00 1.00 5.00 DRILL E 20 U At 5410'MD,trouble shoot MWD rig floor display,not working.Reciprocate and rotate pipe from 5410'MD to 5342'MD while working on problem.GPM=600 and Rotate at 70 RPM. 05:00 05:30 0.50 5.50 DRILL E 20 U POOH one stand of drill pipe and continue to trouble shoot MWD rig floor display,not working.Reciprocate and rotate pipe from 5342'MD to 5248'MD while working on problem.GPM=600 and Rotate at 70 RPM. 05:30 06:00 0.50 6.00 DRILL E 7 U Wash and ream back to bottom from 5248'MD to 5410'MD. 06:00 23:00 17.00 23.00 DRILL E 3 P Drill from 5410'MD to 6117'MD.Reach casing point at 6117'MD.GPM=900 @ 1950 PSI,Rotary Torque=8k Off,10k On,WOB=25k,Drag up=178k,Drag down=140k and Rotate weight=153k, Mud weight=9 ppg,ECD=10 ppg, Maximun gas observed=5349 units @ 6048'MD.Total Jar hours=148.40,Total Bit hours=35.75,Total ADT=35.75 hrs, Total AST=23.78 hrs and Total ART=11.97 hrs. 23:00 00:00 1.00 24.00 DRILL E 7 P Circulate and reciprocate drill pipe to clean hole from 6117'MD to 6022'MD.GPM=900,RPM=120. Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Mike Ross ENI Co Rep 'michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smdh@enipetroleum.com 907-685-0715 632-3058 , Eni representative Geoff Ackerman ENI HSE geoff.ackennan@enipetroleum.co 907-685.0721 it Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 36.9 2,669.0 10/26/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,669.0 2,478.97 LSND 9.20 500.0 13.08 1.684.8 II 0_-- Eni E&P Division I Well Name:SP18-N5 I ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • Date:11/212011 - Report 20 AFIIUWI'50-629-23453-00-00 2 r' I iipage 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11.953.00 145.08 82.4 11.31 Daily Information End Depth(RKB) End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature("F) Weather Wind 6 117 0 3,999.2 0.00 110.0 20.1 Clear,WC 8.8°F 231°WSW,10.6 MPH,Gusts to 10.6 MPH Daily summary operation 24h Summary Circulate bottoms up and back ream out of the hole as/per K&Ms instructions.Lay down directional BHA,Pull wear bushing,make dummy run with landing joint,Rig up Tesco equipment,pick up test joint, change out upper rams to 9 5/8",test rams to 250/3,500 psi. Operation at 07.00 Running 9 5/8"casing. 24h Forecast Rig up and run 95/8"casing,circulate,cement,displace„test BOP's. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 960 Time Log Start End I Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50' 2.50 DRILL E '7 P PJSM continue circulate hole clean,rack back one stand every 745 bbls circulated from 6022'to 5632'with 900 gpm,2000 psi.120 rpms. 02:30 10:30 8.00' 10.50 DRILL E 4 P Backream from 5632'to to 2661'with 900 gpm.2000 psi.and 125 rpms. 10:30 12:30 2.00 12.50 DRILL E 7 P Circulate and condition mud with 900 gpm,1500 psi.and 20 rpms.recip from 2661'to 2567'. 12:30 18:30 6.00' 18.50 DRILL E 4 P Continue to pull out of hole,lay out BHA. Clean clay build up and flush all tools with water. 18:30 19:00 0.50 19.00 DRILL E 19 P Make up wear bushing retrieving tool and retrieve wear bushing. 19:00 20:30 1.50 20.50 DRILL G 20 P Pick up landing joint,make dummy run,break out hanger from landing joint and lay down same. 20:30 21:30 1.00' 21.50 DRILL G '20 P 'Pick up and rig up Tesco casing running equipment. 21:30 22:30 1.00 22.50 DRILL G 20 P Pick up 9 5/8"test joint,make up test plug,run and seat test plug. 22:30 23:30 1.00 23.50 DRILL G 20 P Change out upper rams to 9 5/8". 23:30 00:00 0.50 2400 DRILL G 12 P Test 95/8"rams to 250/3,500 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross 'ENI Co Rep 'michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk .john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.669.0 2,478.97 LSND 9.20 500.0 13.08 1,684.8 Eni E&P Division n rt �Weu Name:5P18 Ns ENI Petroleum Co.Inc. Daily Repo Well Code:25788 Field Name:NIKAITCHUO • e Date:11/3/2011 - Report#: 21 APIIUWI:50-629-23453-00-00 " iii page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concesslon N' Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(8) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13.628.0 11,953.00 145.08 82.4 12.31 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6.117.0 3.9991 2 0-00 110.0 16.0 Clear.WC 6' 16°NNE,5.4 MPH, Gusts to 6 MPH Daily summary operation 24h Summary Rig down test equipment,rig up Tesco casing running equipment,service top drive„run 9 5/8"casing,circulate,cement,displace,remove landing joint,run seal assembly,test to 5k,remove 9 5/8" casing rams from BOP's,freeze protect with Little Red, Operation at 07.00 Testing BOP's 24h Forecast Finish testing BOP's,pick up new drilling assembly,run in hole,wait on cement,drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 960 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL G 12 P PJSM,Rig down BOP test equipment. 00:30 02:00 1.50 2.00-DRILL G 1 P PJSM,Rig up Tesco casing running tools and other equipment. 02:00 02:30 0.50 2.50'DRILL G 19 P Service Top Drive 02:30 03:00 0.50 3.00 DRILL G 12 P Calibrate Tesco casing tool. 03:00 03:30 0.50 3.50'DRILL G 4 P Make up shoe track and test,test OK. 03:30 13:00 9.50 13.00'DRILL G 4 P Run 9 5/8"L-80,408 casing to 6,100'. Maintain torque and drag as per KW Rep. P/U 280k and S/O at 180k. 13:00 13:30 0.50 13.50 DRILL G 7 P Circulate and reciprocate pumping at 4 bpm,180 psi. 13:30 15:30 2.00 15.50'DRILL G 20 P Rig down Tesco equipment,change out bales,and rig up cement head. J 15:30 18:00 2.50 18.00 DRILL G 7 P Circulate and reciprocate casing,pumping at 4bpm and increasing to 7 bpm with 380 psi. Pump 80 bbls of Mudpush. C 53, 18:00 19:00 1.00 19.00 DRILL H 9 P Schlumberger pump 10 bbls of water,test lines to 3,500 psi. Drop bottom plug,pump 192 bbic n1 neepCrete at 12.5 ppg. ✓ pumping at 6 bpm,1,000 psi. Drop top plug,launch with 10 bbls water. G^ 19:00 20:30 1.50 20.50 DRILL H 9 P Displace with 446 bbls of 9.4 ppg mud. Bump plug with 4461 stks pumped with 260 psi and increase to 760 psi. Hold for 5 min,bleed off,Boats holding. 20:30 21:30 1.00 21.50'DRILL H 20 P Rig down cement head,pull landing joint,and lay down 350 ton slips. 21:30 22:00 0.50 22.00 DRILL C 5 P Run and set 9 5/8"packoff and test to 5,000 psi.for 10 min. Good test. • 22:00 23:00 1.00 23.00'DRILL G 20 P Lay down casing running equipment,install test plug,cleaning pits. ✓ 23:00 00:00 1.00 24.00'DRILL C 20 P Change upper rams from 9 5/8"to 4.5107". Change out bales,rig up Little Red and freeze protect 9 5/8"x 13 3/8"casing. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.Spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6.103.3 11/3/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,669.0 2,478.97 LSND 9.20 500.0 13.08 1,684.8 iivoiiiis Eni E&P Division (Well Name:SP18-N5 I ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO eDate:11/4/2011 - Report#: 22 APIIUWI:50-629-23453-00-00 2 i "A page 1 of 1 Wellbore name: SP18-N5 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOVON 15 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) SP18-N5 DRILLING 10/22/2011 15628.0 11,953.00 145.08 82.4 13.31 Daily Information End Depth(ftKB) End Depth(TVD)(f.,,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ff/hr) P06 Temperature("F) Weather Wind 6.117.0 3,999.2 0.00 106.0 15.1 Clear,WC 7.7° 227°W,5.8 MPH, _ Gusts 5.8 MPH Daily summary operation 24h Summary Freeze protect,test BOP's rig down Tesco equipment,change out saver sub and hang bell guide,service rig,cllean drill floor,pick up BHA#6,shallow test,run in hole to 4980',filling pipe every ten(10) stands. Operation at 07.00 Drilling shoe track. 246 Forecast Test casing,change over mud to LVLT,drill float collar,drill 20'new hole,perform LOT/FIT,drill ahead as per program. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E '19 P Little Red Services pump 160 bbls of diesel to freeze protect between the 13 3/8"and 9 5/8"casing. Final pumping pressure 900 psi.rig up to test BOP's. 01:30 07:30 6.00 7.50 DRILL C 12 P Test BOP's as procedure with 4 1/2"and 5 1/2"pipe. Annulars to 250/2,500 psi. Rams to 250/3.500 psi. All test for 5 min each. Test accumulator. 07:30 08:00 0.50 8.00 DRILL C 20 P Pull test plug,rig down,and blow down test equipment. 08:00 08:30 0.50 8.50 DRILL E -19 P Run and seat wear bushing. 08:30 10:00 1.50 10.00 DRILL E '20 P Rig down Tesco service lines and equipment. Move BHA tools to rig floor. 10:00 11:30 1.50 11.50'DRILL E 20 P Change Out saver sub and hang bell guide. 11:30 12:30 1.00 12.50'DRILL E '20 P Service top drive,clear and clean drillfloor. 12:30 13:00 0.50 13.00 DRILL E '20 P Move BHA tools to rig floor. 13:00 17:00 4.00 17.00 DRILL E 4 P Pick up BHA#6. Make up bit,pick up directional tools,load source, finish picking up BHA. 17:00 18:00 1.00 18.00 DRILL E '7 P Shallow test MWD,record BHA weight for KAM support base line. 18:00 00:00 6.00 24.00 DRILL E 4 P Run in hole to 4,980',filling pipe every 10 stands as per directional driller. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 ✓ Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P Suri Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,669.0 2,478.97 LSND 9 20 500 0 13.08 1,684.8 ff.i* Eni E&P Division 1 (Well Name:SP18-N5 - I ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO n• en II Date:11/5/2011 - Report#: 23 APIIUWI:50-629-23453-00-00 page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 14.31 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,117.0 3,999.2 0.00 102.0 4.3 Cloudy,WC-5.1° 107°ESE,3.9 MPH, Calm Daily summary operation 24h Summary Run in hole 6012",attempt to test 9 5/8"casing,no success,test packoff-good,pull out of hole,attempt to test casing shoe with blind rams-no good,pick RTTS run in hole,get good casing test,pull out of hole Operation at 07.00 Run in hole with dnlling assembly to drill out. 24h Forecast Run in hole to 6,012',drill float collar,shoe track,and shoe,clean out old hole to 6,317',doll new hole to 6,330',circulate and condition mud,perform LOT,it good,charge out mud to SBM,drill ahead if approval is granted by the State. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 4 'F. Continue tnp in hole to5,938',wash down to 6,012',tag up with 5k down. 01:00 02:00 1.00 2.00 DRILL E 7 t. Circulate and condition mud with 500 gpm.and 1300 psi. 02:00 02:30 0.50 2.50 DRILL E 20 P Lay down single,rig up to test 9 5/8"casing. 02:30 04:30 2.00 4.50 DRILL E 12 P Pressure up on casing,pumping at 1.5 bpm to 3,000 psi.bled off 1,000 psi in 10 minutes. Made several attempts to test the casing,isolating,and troubleshooting with no success. 04:30 05:00 0.50 5.00 DRILL E 12 P Test 9 5/8"x 13 3/8"paskoff to 5,000 psi for 10 min. Good Test. 05:00 06:00 1.00 600 DRILL E 12 'P Continue to troubleshoot casing test. Pressure would drop from 3,000 psi and stabilize around 750-800 psi. (Conference call with ENI Anchorage). 0600 1200 6.00 12.00 DRILL E 4 P Pull out of hole,download source from downhole tools. 12:00 1400 2.00 14.00 DRILL E 12 P Rig up and test casing with blind rams. Pressure up to 3,000 psi.after 15 minutes,pressure down to 2,700 psi. 14:00 17:30 3.50 17.50 DRILL E 4 'P Pick up and make up Howco RTTS,run in hole to 5.946'. 17:30 18:00 0.50 18.00 DRILL E 19 P Rig up to circulate and fill pipe. 18:00 20:00 2.00 20.00 DRILL E 12 'P Ste RTTS at 5,946',pressure up on casing to 3,000 psi.for 30 minutes. Good test. Pumped 47 stks with 4.5 bbls pumped. 20:00 00:00 4.00 24.00 DRILL E 4 'P Bleed pressure,release RTTS,pull out of hole. Daily Contacts • Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 EN representative Geoff Ackerman ENI HSE geoff.ackennan@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 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) 6,117.0 3,999.24 LSND 12.80 750.0 16.41 3,4092 / Y iiiii* Eni E&P Division Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO 2' Date:11/6/2011 - Report#: 24 APUUWI:50-629-23453-00-00 " �� page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31 70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 15.31 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature CO •Weather Wind 6.117.0 3.999.2 (100 102.0 4.9 Partly Cloudy,WC- 232'SW.4.9 MPH, 9.6 Calm Daily summary operation 24h Summary Clean drill floor,trip in hole,slip and cut drilling line,service rig,drill out shoe track,make new hole.circulate for leak off test,perform test,prepare to change out mud systemchange out mud system to oil base mud,clean surface equipment and prepare to drill. Operation at 07.00 Drilling 8 3/4"hole. 24h Forecast Finish cleaning surface equipment&drilling 8 3/4"hole. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P Clear and clean drillfloor. 00:30 04:30 4.00 4.50 DRILL E 4 P Pick up BHA.load downhole tools,shallow test downhole tools,trip in hole to 5,935'. 04:30 08:00 3.50 8.00 DRILL E 20 P Slip and cut drilling line,service ng,monitor well while inspect top drive and drawworks. 08:00 08:30 0.50 8.50 DRILL E 20 P 'Calibrate Schlumberger block height. 08:30 13:30 5.00 13.50 DRILL E 19 P Drill out Float collar,shoe track,and shoe from 6012'to 6,103'. Clean out to 6,117',drill new hole to 6,137',with 480 gpm, 60 rpm,10-20k weight on bit. 13:30 15:00 1.50 15.00 DRILL E 7 P Pull into shoe,circulate and condition for leak off test. 15:00 16:00 1.00 16.00 DRILL E 19 P Perform leak off test,pumped 1.8 bbls to 750 psi for a 12.8 ppg.EMW,held test for 10 minutes,bled down to 640 psi,bled back 1.5 bbls. 16:00 17:00 1.00 17.00 DRILL E 20 P Rig down test equipment,blow down cement hose and kill line,pick up single for displacement. 17:00 19:30 2.50 19.50 DRILL E 20 P Clean and prepare surface equipment and stage trucks for displacement of oil base mud. -- 1930 21:00 1.50 21.00 DRILL E 7 P Displace hole with oil base mud. 21 00 0000 3 00 24.00 DRILL E 20 P Monitor well,clean and prepare surface equipment for drilling. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener -ENI •Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING95/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 6,117.0 3,999.24 LSND 12.80 750.0 16.41 3.409.2 Eni E&P Division I Well Name: SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO 11* • APIIU WI:50-629-23453-00-00 2^n Date:111712011 - Report#: 25 'I II II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) • 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 16.31 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 9.481 0 3.9636 1.716.00 110.0 10.8 Cloudy,WC 2.3 286"WNW,4.7 MPH,6.8 MPH Gust Daily summary operation 24h Summary Prepare surface equipment for drilling with OBM. Drilling from 6,137'to 7,855'. Operation at 07.00 Drilling 8 3/4"hole. 24h Forecast Drilling Ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9 45 Time Log Start End Cum Time Time Dor(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 04:00 4.00 4.00 DRILL E 20 P Prepare surface equipment for drilling with OBM. 04.00 00.00 20.00' 24.00 DRILL E 3 P -Drill from 6,13T to 7,855'with 550 gpm,150 rpms,10k web, 10.77 ECD,and max gas 1300 units. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener 'ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.corn 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoffackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 En:representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 9 5/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 6.117.0 3,999.24 LSND 12.80 750.0 16.41 3.405.2 * Eni E&P Division [Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • API/UWI:50-629-23453-00-00 2^ Date:1118/2011 - Report#: 26 If II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31 70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N// DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 17.31 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9.860.0 3.958.4 2,100.00 22.50 93.3 107.0 9.0 Cloudy,WC-9' 83-E,6.3 MPH Daily summary operation 24h Summary Drill to 9,481',circulate,backream to 7,765',side tracking to 7,814'. Operation at 07.00 Drilling 8 3/4"hole. 24h Forecast Drilling ahead front 7,814.0 Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 13:30 13.50 13.50 DRILL 'E 3 P Drilling 8 3/4"hole from 7,855'to 9,481'with 5/12k weight on bit,130 rpms.550 gpm.and 2,160 psi. Max ECD 10.95 ppg. and max gas 1600 units. 13:30 114:00 0.50 14.00 DRILL E 7 P Circulate and condition mud prior to backreaming. 14:00 I 20:00 6.00 20.00 DRILL E 6 P Backream from 9,481'to 7,814'while circulate one btms up for each of first two stands. 20:00 i 00:00 4.00 24.00 DRILL I E 3 P Drill from 7,765'to 7,814',side tracking with 0-2k weight on bit.130 rpm,533 gpm.with 1,750 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep 'jack.keener@enipetroleum '907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Milling Tool Pusher 907-685-0716 En:representative John Spaulding ENI Rig Clerk John spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 6,117.0 3,99924 LSND 12.80 750.0 10 41 3,409 2 sfokiks Eni E&P Division I Well Name:SP18-N5 EN/Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • API/UWI:50-629-23453-00-00 Date:1119/2011 - Report#: 27 eIf II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) 0018-NO DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 18.31 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9.865.0 3.958 4 384.00 22.50 17.1 108.0 9.0 Cloudy,WC-10.8- 87 E.21.1 MPH. Gusts 21.1 MPH Daily summary operation 24h Summary Side tracking from 7,795'to 7,8141 Drill ahead from 7,814'to 9,8651 Operation at 07.00 Drilling 8 3/4"hole©10235'MD 24h Forecast Continue drilling 8 3/4"hole. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01 30 - 1.50- 1 50 DRILL E 19 P Continue to time drill for open hole side track from 7,795'to 7,814'with 530 gpm,1,900 psi,130 rpm,1-2k weight on bit. . After side track established,pull back to 7,790'and slide to bottom with no rotation, pull back to 7,765'and re-enter side track to confirm re-entry into new hole. 01 30 '00.00 22.50' 24.00 DRILL E 3 P Drill from 7,814'to 9,865'with 550 gpm,2,120 psi,130 rpm,12-15k weight on bit. ECD=10.73 ppg,1,200 units max gas. Torque 13-14k,P/U=190k,S/0=105k.and Rotate=144k. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jackpotter@enipetroleum com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dnlling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk torn.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95,/8 8.835 L80 35.9 6.103.3 11/3/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 0.117.0 3.99924 LSND 12-80 750.0 1641 3.409.2 Eni E&P Division I Well Name: SP18-N5 10* ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • APIIU WI:50-629-23453-00-00 2^n Date:1111012011 - Report#: 28 'I ')II page 1 of 1 Wellbore name: SP18-N5 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) •RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31 70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOVON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 19.31 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12.2820 3.9050 2,417.00 24.00 100.7 109.0 7.9 Cloudy,WC-8.7- 51-NE 13.6 MPH, Gusts 14.1 MPH Daily summary operation 24h Summary Drilling from 9,865'to 12,282'. Operation at 07.00 Drilling 8 3/4"hole at 12834'MD. 24h Forecast Drill ahead,TD the hole.circulate. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00 00 24.00' 24.00 DRILL -E 3 P Drilling 8 3/4"hole from 9.865'to 12,282'with 550 gpm,2,640 psi.130 rpm,2-20k weight on bit,11.56 ppg ECD, 1,950 units max gas. P/U 205k,S/O 85k.and ROT 141k. (Note)Bob Noble,AOGCC,granted extension for testing the BOP's after TD the hole. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715.6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.corn 907-6850721 Tool Push Dave Evans Doyon Dulling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.corn 907-685-0722 229-6100 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 6,117.0 3,999.24 LSND 12.80 750.0 16.41 3,409.2 V Eni E&P Division IWell Name:SP18-N5 I Tririn ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • 2^ Date:11/11/2011 - Report#: 29 APIIUWI:50-629-23453-00-00 tf 'I page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) ' 0618-N5 DRILLING 10/22/2011 13,628.0_ 11,953.00 145.08 82.4 20 31 Daily Information End Depth(ftKB) End Depth(TVD)(f_,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 13.601 0 3.872.0 1,319.00 11.50 114.7 106.0 0.3 Partly Cloudy,WC- 76'ENE @ 212 21.5mph Daily summary operation 24h Summary Drill ahead,TD the hole,circulate,backreaming out of hole. Operation at 07.00 Continue pull out of hole. 24h Forecast Pull out of hole,lay down bottom hole assembly,test GOP's,rig up and run 5 1/2"liner. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 0.08 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '11:30 11.50 11.50 DRILL E 3 -P Drill from 12,282'to 13,601'with 550 gpm,2,660 psi.130 rpm,16k wob.11.64 ppg ECD,and max gas 1250 units. P/U=200k,S/0=75k,and rotate=138k. 11:30 -12:00 0.50 12.00 DRILL E 7 P Circulate with 550 gpm,2,650 psi,130 rpms. 12:00 '16:00 - 4.00 16.00 DRILL E 6 'P Backream out of hale from 13,601'10 13,220'with 550 gpm,2440 psi.130 rpm. Backream first four stands off bottom at one btms up per stand pulled. 16:00 20:00 4.00 20.00 DRILL E 6 P Backream from 13,220'10 12,644',six stands at one btms up per two stands pulled. 20:00 '00.00 ' 4.00 24.00 DRILL E 6 'P Backream from 12,644'to 11,700'with 550 gpm,2,350 psi.130 rpm. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Jack Keener ENI Senior Co Rep lack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvg@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 6.117 0 3,999.24 LSND 12.80 750.0 16.41 3.409 2 L- Joilik Eni E&P Division I Well Name:SP18-N5 ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • APIIU WI:50-629-23453-00-00 2 I( II�, Date:11/12/2011 - Report#: 30 page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13.628.0 11,953.00 145.08 82.4 21.31 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(SF) Weather Wind 13.601 0 3,872.0 0.00 110.0 -1.3 Partly Cloudy,WC- 72 ENE @ 9.2 mph 16.8` Daily summary operation 24h Summary Backream out of hole,troubleshoot top drive,continue to backream out of hole. Make adjustments to top drive. Operation at 07.00 Backreaming out of hole. 24h Forecast Complete troubleshoot of top drive.pull out of hole,lay down BHA,pull wear bushing,test BOP'S,rig up and run 5 1/2"liner. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 940 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 DRILL E 6 P 'Backream out of hole from 11,700'to 7,945'with 550 gpm.2,100 psi.130 rpm.22 units gas,rotate weight 142k. 10.00 '22:00 - 12.00 22.00 DRILL E 20 TRO4 Troubleshoot problems with top drive,circulating at 3 bpm.200 psi. Remove shot pin housing from top drive and replace seals. Replace shot pin housing back on top drive. 22.00 '00-00 2.00 24.00 DRILL E 6 P Backream from 8,042'to 7,945'while circulate bottoms up with 550 gpm,2,050 psi,130 rpm. Make more adjustments on the top dove. (Note)Bob Noble,AOGCC,waived the witness on the BOP test. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum -907-685-0715 715-6431 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum corn 907-6850721 Tool Push Dave Evans Doyon Drillmg Tool Pusher 907-685-0716 Tool Push Chad Johnson Dovon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6,103.3 11/3/2011 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) 6.117.0 3,999.24 LSND 12.80 750.0 16.41 3.405.2 V Ad. Eni E&P Division I Well Name: SP18-I.o I ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ eDate:11/13/2011 - Report#: 31 API/UWI:50-629-23453-00-00 e "Ft page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOVON DRILLING DOVON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(FRB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 22.31 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13 601 0 3.872.0 0.00 106.0 -0.9 Partly Cloudy,WC- 238'WSW©12 6 15.5` mph Daily summary operation 24h Summary Change out hydraulic hose on top dove,backream out of hole to 4,975',circulate btms up,slug pipe,pull out of hole,lay down BHA,download source,work on top drive,function BOP's and clean, retrieve wear ring and prepare to test BOP's. Operation at 07.00 Running 5 1/2"liner. 24h Forecast Test BOP's,rig up and run 5 1/2"liner,set liner hanger,release from hanger,displace SBM with Brine. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9 40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00-DRILL E 20 TRO4 PJSM,change out hydraulic hose on top drive rotating head. 01:00 08:00 7.00 8.00 DRILL E 6 P Backream out of hole from 7,945'to 4,975'with 550 gpm,1,450 psi,130 rpm.Rotate weight 148k. 08:00 09:00 1.00 9.00 DRILL E 7 P Circulate bottoms up as per KW with 550 gpm,1,450 psi,130 rpm. 09:00 10:00 1.00 10.00 DRILL E 19 P Observe well,static. Pump slug. 10:00 14:00 4.00 14.00 DRILL E 4 P Drop 2 3/8"drift down drillpipe,pull out of hole from 4,975 to 289'. 14:00 '18:00 4.00 18.00 DRILL E 4 P Monitor well,static,pull out of hole laying down BHA,download source. 18:00 20:00 2.00 20.00 DRILL E 20 U Work on top drive,replaced IBOP actuator and actuator selonoid valve. 20:00 21:30 1.50 21.50'DRILL E 19 P PJSM,function test BOP rams and clean stack with Johnny Wacker. 21:30 00:00 2.50 24.00 DRILL E 20 P Drain BOP's,pick up test joint.retrieve wear ring,install test plug,rig up test manifold,bleed air from stack and choke manifold,prepare to test. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 '715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.corn 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Dulling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 35.9 6.103.3 11/3/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 6.117.0 3,999.24 LSND 12.80 750.0 16.41 3.409.2 > -_� Eni E&P Division Well Name:SP18-wa EN/Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • API/U W I:50-629-23453-00-00 2^ Date:11/14/2011 - Report#: 32 f� I' page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,628.0 11,953.00 145.08 82.4 23.31 Daily Information End Depth(RKB) End Depth(ND)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature Cr) Weather Wind 13 601.0 3,872.0 0.00 109.0 5.4 Partly Cloudy,WC- 315°NW @ 9.8 mph 94° Daily summary operation 24h Summary Test BOP's,rig down test equipment,install wear bushing,rig up and run 5 1/2"liner. Operation at 07.00 Displace hole with brine. 24h Forecast Run 5 1/2"liner,set liner hanger,test and release from hanger,displace hole with brine,clean surface equipment,pull out of hole laying down drillpipe. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 12 P Test BOP's with 5 1/2"and 4 1/2"pipe,annulars to 250/2,500 psi.rams and all related equipment to 250/3,500 psi.all test for 5 min.each. Accumulator draw-down test O.K. 06:00 07:00 1.00 7.00 DRILL E 20 P Rig down test equipment,clear and clean drillfloor. 07:00 08:00 1.00 8.00 DRILL E 5 P Install wear bushing. 08:00 10:30 2.50 10.50 DRILL E 20 P PJSM,rig up GBR casing equipment for running 5 1/2"liner. 10.30 00.00 13.50 24.00 DRILL E 4 P Run 5 1/2"liner as per program. Run a total of 187 joints of L-80, 17 lb/ft.length of 7,653'95'. X-over,seal bore,x-over, and hanger all total of 7,682.46'. P/U=145k,S/0=115k,R/W=130k,and torque at 5k ft/lbs Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685.0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobbywalls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.corn 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvg@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8 835 L80 35.9 6,103.3 11/3/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 6.117.0 3,999.24 LSND 12.80 750.0 16.41 3,4092 Eni E&P Division (Well Name:SP18-ND ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO •2n Date:11/15/2011 - Report#: 33 APuuwl:50-629-23453-00-00 I' II II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type -_ 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RIB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 DRILLING 10/22/2011 13,6280 11,953.00 145.08 82.4 24.31 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 13,601.0 3,872.0 0.00 106.0 2.8 Clear,WC-7.8° 271°W @ 5.5 mph Daily summary operation 24h Summary Baker rep.put PAL MIX in SLZXP liner packer.\Run 5 1/2"liner on 5"drill pipe to depth @ 13,5331 Dropped setting ball-pumped down and landed the ball with 210 psi.-pressure-up to 3000 psi to inflate the packer hold for 10 mins.continue staging pressure in 500 psi.increments to 4000 psi.hold for 5 min.each-bleed off./Test liner packer 1/1500 psi.f/10 mins.(chart record)/Checked HRD tool released from liner.P/U 1/5830'.1 R/U pits to displace OBM with 9 ppg brine.Pumped two spacers-20 bbls LVT-100 bbls.citric acid spacer followed by the 9.00 ppg 3%KCL brine.OBM shipped to the WIF for disposal.Clean 9.0 ppg brine to the surface shut down and clean surface equipment./POOH UD 5"DP to liner running tool-Baker rep.inspect(good)and L/D.\RIH with 5"DP from derrick 1/3325'. Operation at 07.00 L/D 5"drill pipe and cleaning active 8 rock washer pits. 24h Forecast Finish laying down 5"doll pipe./Pull wear ring./Slip and cut drilling./Spot Baker Centrilift equipment and reel building.\R/U GBR tubing tongs and Centnlift equipment./Call HOWCO slick line stand by./ PJSM P/U Centrilift ESP assembly. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL G 4 P Mix PAL MIX and pour into SLZXP liner packer hanger as per Baker rep. 01:00 08:00 7.00 8.00 DRILL G 4 P RIH with 5 1/2"liner on 5"drill pipe(/7693'-013,533'/Up wt.=190K-On wt.=115K-Rot wt.=150K\20 rpm @ 4-5K torque.\ Fill pipe every 20 stds.and obtain K&M data. 08:00 10:00 2.00 10.00 DRILL G 4 P Dropped ball-started pumping 2 bpm @ 130 psi.with 1/2 DP volume and slowed rate to 1 bpm @ 90 psi.-ball landed on seat w/210 psi.Pressure-up as Baker rep.to 3000 psi.f/10 mins.-3500 psi.f/5 mins.-4000 psi f/5 mins.to set liner packer,bleed off./R/U test liner packer to 1500 psi for 10 mins.(chart record).Hydraulic released running tool from liner (lost 20K from Up wt.)and set 60K down twice on liner top.\Liner shoe @ 13,533'and Liner top @ 5850'MD. 10:00 12:00 2.00 12.00 DRILL E 7 P Displace OBM mud with 9.0 ppg brine @ 58301 Pump 20 bbls LVT and 100 bbls.citric acid spacers-followed by 9.0 ppg 3%KCL brine.Up wt.=175K-Dn wt.135K. 12:00 13:00 1.00 13.00 DRILL E 1 P Shut down pumps when clean 9.0 ppg brine to the shakers./Clean surface equipment(shakers and flush lines).Monitor well-static. 13:00 20:00 7.00 20.00 DRILL E 4 P PJSM-POOH lay down S-135 5"drill pipe f/5830'-t/Baker liner running tool/(vac out fluids). 20:00 21:00 1.00 21.00 DRILL E 4 P Lay down running tool as per Baker rep-tool inspected and ball recovered. 21:00 00:00 3.00 24.00 DRILL E 4 P RIH with 5"doll pipe out of derrick 03325'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 '715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvg@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L-80 5,848.5 13,531.0 11/15/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 6,117.0 3.999.24 LSND 12.80 750.0 16.41 3,409.2 # Eni E&P Division LllName:SP18-nn EN/Petroleum Co.Inc. Daily Report. Well Code:25788 Field Name:NIKAITCHUO e Date:11116/2011 - Report#: 1 APIIUWI:50-629-23453-00-00 2" " page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOVON 15 LAND RIG Job information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP18-N5 COMPLETION 25.35 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 102.0 1.8 Mostly Clear,WC- 251"WSW @ 5.6 9.2" mph Daily summary operation 24h Summary RIH with 5"DP from derrick 1/3325'-1/4800'.1 POOH 1/4800'-1/990'L/D 5"DP.\RIH 1/990'-829001 Replace hydraulic hose on iron rough neck.\Continue POOH 1/2900'-1)2200'L/D pipe\Service rig.1 .% POOH L/D 5"DP 1/2200'-1/surface.\Slip and cut drilling.\Pull wear ring.\R/U GBR tubing tongs and load rig floor with Centrilift equipment,tools and clamps.\Spot ESP reel building(load with new ESP cable reel)and lug up generator.\Load pipe shed with Centrilift ESP pump and motor assemblies. Operation at 07.00 P/U ESP motor/seals section assembly and service same. 24h Forecast Hang Centrilift ESP sheaves in derrick and change components on motor assembly and dress new pump assembly.\Hold PJSM-P/U ESP motor assembly and service-Halliburton set pump in TTC.\ Install motor lead and RIH P/U 41/2"trig.(12.6F L-80 Hydnl 563)as per tally. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 900 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00'COMP K 4 'P RIH with 5"drill pipe out of derrick 1/3325'-848001 Clean active pits and rock washer cutting pit\Transfer fluids from production upright to WIF for disposal. 02:00 08:00 6.00 8.00 COMP K 4 -P PJSM-POOH lay down S-135 5"drill pipe(14800'-11990'/(vac out fluids).\Continue cleaning pits and transferring fluids to WIF for disposal. 08:00 10:00 2.00 10.00 COMP K 4 •P RIH with 5"drill pipe out of derrick 1/990-t/2900'. 10:00 11:00 1.00 11.00 COMP K 25 U Change out hose on hydraulic rough neck. 11:00 12:00 1.00 12.00 COMP K 4 P Continue POOH lay down S-135 5"drill pipe(/2900'-t\2200'\(vac out fluids). 12:00 13:00 1.00 13.00 COMP K 25 P Service rig:inspect and lubricate blocks and draw-works. 13:00 17:30 4.50 17.50'COMP K 4 P POOH and L/D 5"drill pipe f/2200'-1)surface.\(vac out fluids). 17:30 20:00 2.50 20.00'COMP 'K 25 P Cut drilling line and service rig components.\Spot ESP reel building. 20:00 21:00 1.00 21.00 COMP K 5 P 'Pull wear ring with Vetco Gray rep.\Spot generator by ESP reel building. 21:00 00:00 300 24.00'COMP K 1 *P PJSM:R/U GBR tongs and load floor with Centrilift equipment,tools and clamps.\Load pipe shed with Centrilift ESP pump and motor assembly.\Load new ESP cable reel into building./Lug electrical wires from generator to ESP reel building. Daily Contacts Position Contact Name Company Title • E-mall Office Mobile Eni representative Jack Keener 'ENI Senior Co Rep -jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.t.smitn@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.corn 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date LINER 5 1/2 L-80 5.848.5 13.531.0 11/15/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 6,117.0 3,999.24 LSND 12.80 750.0 16 41 3,409.2 iiiiii* Eni E&P Division (Well Name:SP16-.. ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • APIIUWI:50-629-23453-00-00 2^ Date:11/17/2011 - Report#: 2 'f II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(55) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) •Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 COMPLETION 26.35 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 0 105.0 -8.0 Partly Cloudy,WC- 247'WSW @ 3.1 16.1° mph Daily summary operation 24h Summary Finished loading ESP equipment on floor.\Hang Centring sheaves in derrick and string ESP cable/cap tube to rig Floor,while dressing new pump assembly and changing components on motor assembly.\ PJSM-P/U TTC,pups and first 4 1/2"tbg joint-R/U HES and set pump in TTC-R/D HES.)P/U motor/seal assembly and service-install Cap tube,1/4"TEC line and MLE to pot head-RIH t/1261 Gator splice MLE to ESP cable and SwageLok 1/4"to 3/8"cap tube-install cannon splice clamp. , Operation at 07.00 RIH with ESP completion assembly installing cannon clamps as well plan. 24h Forecast Perform electrical inspection/test on ESP cable and gauge reads.\RIH with 4 1/2"tbg.(12.6#,L-80,Hydril 563)as per well plan and tally.)Centrilift to perform electncal checks every 1000'. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 900 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 COMP K 1 P Finished loading Centrilift equipment on floor.\Hang ESP and cap sheaves in derrick and string ESP cable and cap through sheaves from reel building.)Dress pump bottom with pump eye and remove gauge sensor from 126 HP motor to install on 150 HP motor(electrical connection broke on gauge sensor),send Centring rep.to Prudhoe Bay shop for new gauge sensor. 06:00 13:00 7.00 13.00 COMP K 4 P PJSM with Halliburton,Baker and GBR to install pump assembly in TTC.)P/U TTC-two XO pups-4 1/2"tbg joint(12.68, L-80,Hydril 563)-R/U Halliburton slick line and install pump assembly as per well plan-test to 1000 psi.1/10 mins.) • Remove test tool and install tbg.stop.)R/D Halliburton. 13:00 18:00 5.00 18.00 COMP K 4 P PJSM-P/U motor assembly-check rotation and service motor and seal section.)Install cap tube on motor centralizers, 1/4"TEC line on WellLift gauge and MLE cable to pot head terminal,phase(0.9 and 42.26 G ohms).\Installed Christolizer as per well plan. 18:00 19:00 1.00 19.00 COMP K 25 U Trouble shoot Centrilift equipment for installing cannon clamps. 19:00 21:30 2.50 21.50 COMP K 4 P Continue RIH with ESP assembly to pressure discharge sub and connect 1/4"TEC line to same-RIH @ 126'-install cannon clamps as per well plan. 21:30 00:00 2.50 24.00 COMP K 19 P Perform gator splice on MLE to ESP cable.)SwageLok connection 1/4"to 3/8"cap tube.\Install cannon splice clamp. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Dnlling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvg@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 5 1/2 L-80 5.848.5 13.531.0 11/15/2011 Last Leakoff Test Depth OMB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 6,117.0 3,999.24 LSND 12.80 750.0 16.41 3,409.2 Eni E&P Division (Well Name:SP18-ND rifi* EN!Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUQ • Date:11/18/2011 - Report#: 3 API/uwl:50-629-23453-00-00 2 n It page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 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) SP18-N5 COMPLETION 27.35 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature("F) Weather Wind 0.0 99.0 -13.2 Mostly Clear,WC- 232°SW @ 9.1 mph 31.4° Daily summary operation 24h Summary Perform electrical test on ESP cable/gauge reads/RIH with 4 1/2"tbg.(12.68,L-80,Hydril 563)1/126-5750'as per well plan/P/U tbg.hanger and landing joint\Dress hanger with chemical line and penetrator-Centrilift spliced pig tail and installed in penetrator-perform electrical test\Land tbg.hanger(P/U re-orientate)-screwing lock downs/Test tbg.hanger seals(upper&lower)to 5000 psi.1/10 mins.each\Pull landing joint and install BPV\Prep to N/D BOPE and remove completion fluids from active pits. Operation at 07.00 Dress tbg.hanger and N/U tree. 24h Forecast N/D BOPE\N/U tree-Centrilift perform electrical test\Test tbg.hanger void/pack-off and tree components 115000 psi.f/10 mins.each\Freeze protect tbg./annulus with Little Red\Secure well and move rig off. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 900 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 COMP K 4 P Performed electrical test[Baseline readings:Phase to Phase 32 ohms/Pressures:intake=75.4 psi;discharge=24.5 psi./ Temperatures:intake=43.46°;discharge=56.9°;motor-44.1°;electrical=43.44°/Vibration:X=0.045;Y=0.044/System current=11.807 System voltage=156.0/Meg:1.53 gig Ohms].\RIH with ESP completion assembly on 4 1/2'tbg.(12.6#,L- 80,Hydril 563)1/126'-1/1992/GBR torque turn connection.\Install cannon clamps on every connection.)Centrilift perform electrical checks every 1000'. 06:00 1200 6.00 12.00 COMP K 4 P P/U 4 1/2"tbg.(12.6#,L-80,Hydril 563)(/1992'-114424'with ESP completion assembly./GBR torque tum connection.\ Install cannon clamps as per well plan.\Centrilift to perform electrical checks every 1000'. 12:00 17:30 5.50 17.50 COMP K '4 P RIH with ESP completion assembly on 4 112"tbg.(12.6#,L-80,Hydril 563)1/4424'-05750'-GBR torque tum connection.\ Install cannon clamps on every connection./Centrilift to perform electrical checks every 1000'. 17:30 20:00 250 20.00 COMP K -20 P P/U Vetco Gray tbg.hanger and landing joint.\Vetco Gray dress tbg.hanger with penetrator&chemical injection line.\ Centrilift splice ESP cable to penetrator pigtail&installed to penetrator-Performed electrical test[Final readings:Phase to Phase 2.9 ohms/Pressures:intake=1866.1 psi;discharge=1860.8 psi./Temperatures:intake=84";discharge=85"; motor=84.3";electrical=84.1°/Vibration:X=0.040;Y=0049/System cunent=11.8/System voltage=162/Meg:2.35 gig Ohms]. 2000 23:30 3.50 23.50 COMP 'K 19 P Land tbg.hanger-ESP assembly @ 5778'-Up wt,135K-Dn wt.=112K\Pick hanger back to rig floor and re-orientate- land and confirm-run all lock-down screws in./Test hanger body seals(upper&lower)5000 psi t/10 mins.each.\Pull landing joint./Install BPV. 23:30 00:00 0.50 24.00 COMP K 5 P Prep to N/D BOPE and remove remaining 9.0 ppg completion fluids from active pits. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jackpotter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date LINER 5 1/2 L-80 5,848.5 13,531.0 11/15/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 6,117.0 3,999.24 LSND 12.80 750.0 16.41 3,409.2 Eni E&P Division I Well Name:SP16 I ENI Petroleum Co.Inc. Daily Report Well Code:25788 Field Name:NIKAITCHUO • API/UWI:50-629-23453-00-00 2^n II Date:11/19/2011 - Report#: 4 II II page 1 of 1 Wellbore name: SP18-N5 Well Header Permit/Concession N" Operator ENI Share)%) Well Configuration type 211-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 32.28 31.70 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP)ft/hr) DFS(days) SP18-N5 COMPLETION 28.35 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 0 0 03.0 Mostly Cloudy,WC- 300°WNW @ 3.1 6.5° mph Daily summary operation 24h Summary R/D GBR and Centrilift from rig floor.\N/D BOP.\Centrilift performed electrical test.\Vetco Gray N/U tree-test hanger void/pack-off and tree to 5000 psi.f/10 mins.each-SIMOPS: construction/production installed choke and flow line components.\WU Little Red on tbg.and returns on IA to rig choke.\Displace with 36 bbls.and pressure increased and reducing pump rate-shut down.\Switch lines-Little Red on IA and returns from tbg.to rig choke/Trouble shoot Little Red boiler.\Freeze protect well pump rate 1.48 bpm @ 550 psi.(650 psi max.)70-80°-FCP 450 psi.@ rate 1.27 bpm.\Pumped 169 bbls.with 1:1 returns\Shut well in-OA @ 300 psi.-IA @ 195 psi.-Tbg.@ 200 psi.\R/D Little Red and lines.\Prep to skid rig floor\Released rig from SP18-N5 @ 2400 hrs. Operation at 07.00 Rig move. 24h Forecast Demob and move rig. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 COMP K 5 P R/D and clear floor of GBR tongs and Centrilift equipment-clean drip pan and remove fluids from active pits. 02:30 06:00 3.50 600 COMP K 5 P N/D BOP-Set BOP stack and user on back on stumps in sub-base cellar\Clean active pits\Remove 4 1/2"tbg.from pipe shed and prep#3 pump house for move. 06:00 06:30 0.50 6.50 COMP K 20 P Centrilift performed electrical integrity test and gauge reading @ penetrator[Phase to Phase 2.9 ohms/Pressures:intake= 1855 psi;discharge=1850 psi./Temperatures:intake=84.1";discharge=84.97";motor-84.67°;electrical=84.49°/ Vibration:X=0.064;Y=0.055/System current=11.8/System voltage=161/Meg:2.39 G Ohms]. 06:30 14:00 7.50 14.00 COMP K 5 P Vetco Gray prep tbg.hanger(chemical injection line))N/U tree adapter&tree valve-test hanger/pack-off to 5000 psi.for 10 mins.\Pull BPV&install TWC-test tree&components t/5000 psi.10 mins.\Pulled TWC\Construction/Productlon install choke and flow line during tree test process-also R/U to freeze protect well\Continue cleaning active pits.\Centrilift checked ESP cable/motor integrity and confirm balance conductivity after test 14:00 16:00 2.00 16.00 COMP K 5 P R/U Little Red on tree to pump down tbg.with returns from IA to rig choke\Transfer diesel to Little Red and reload fuel truck\Test lines to 3200 psi. 16:00 18:00 2.00 18.00 COMP K 7 P PJSM-Little Red sheared upper GLM @ 2450 psi.\Continue to pump 2 bpm @ 1200 psi.with 36 bbls.(2 bbls.over tbg. volume @ GLM)away which pressure gradually increase and rate was decreased to 112 bpm @ 2000 psi.- shut down- pressure bleed off slow.)Decision was made to bleed off pressure and switch lines to pump down IA with retums thru tbg. 18:00 20:00 2.00 20.00 COMP K 20 P Trouble shoot Little Red heating coil for pre heating diesel-could not circulate thru heating coil-keeping cycling and attempting to pump and final broke through and preheated diesel.\Disconnect#3 pump house and move pad. 20.00 22:00 2.00 22.00 COMP K 7 P Pump down IA with diesel 1.48 bpm @ 550 increasing to 650 psi.(max)-Temp @ 70-80°with returns out tbg.to ng choke with 1:1 returns.\Final rate 1.27 bpm @ 450 psi.\Pumped 169 bbls.\Shut well in-OA @ 300 psi-IA @ 195 psi.-Tbg.@ 200 psi. 22.00 23:00 1.00 23.00 COMP K 5 P R/D Little Red from freeze protect and lines to rig choke.\Install roof hatch cover on well bay. 23.00 00:00 1.00 24.00 COMP K 2 P PJSM-Prep to skid rig floor and transfer displaced fluid to rock washer.\Released rig from SP18-N5 @ 2400 hrs. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile • • Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.cor 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 L-80 5.848.5 13,531.0 11/15/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 6,117.0 3,999.24 LSND 12.80 750.0 10.41 3,409.2 HALLIBURTON eno IPk. tIr )IkIuIIrir1I PACKING LIST Spy Island Drillsite Nikaitchuq SP18-N5&SP18-N5 PB1 Shipping Date: 17-Nov-2011 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 301 East 92nd Avenue;Suite 2 Anchorage,AK 99501 Anchorage,AK 99515 Attn: Howard Oakland 907-739-1235 Item Description Interval Packaging Box Descriptio,. SP18-N5 Washed and Dried Samples-50' 2,684'to 5,100' Paper envelopes 1 of 5 Washed and Dried Samples-50' 5,100'to 7,500' Paper envelopes 2 of 5 Washed and Dried Samples-50' 7,500'to 10,400' Paper envelopes 3 of 5 Washed and Dried Samples-50' 10,400'to 13,601'TD Paper envelopes 4 of 5 SP18-N5 PB1 Washed and Dried Samples-50' 7,750'to 9,481'TD Paper envelopes 5 of 5 One(1)Bundle Contains all Five(5)Boxes Notes: Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Andrew Buchanan 907-865-3388 Received by Expediter: � Date: 2\ kck.,0 RECEIVED- NOV ECEIV NOV 2 1 2011 Alaska Oil&Gas Cons.Commission Anchorage oZll — � c0l SEAN PARNELL,GOVERNOR ALASKA OIL AND 333W.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, Schrader Bluff Oil Pool, SP18-N5 ENI US Operating, Co. Inc. Permit No: 211-101 Surface Location: 4458.9' FSL, 1327' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 506' FSL, 2078' FEL, SEC. 12, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service 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. Si er- // /o f I Norm. • ioner DATED this 'fiiday of August, 2011. cc: Department of Fish 85 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED' 1. )KA OIL AND GAS CONSERVATION CON, SION AUG 19 2011 PERMIT TO DRILL 20 AAC 25.005 jj��r==ff rr pFb la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj 2Single Zone ❑ ii'A�A15' o»ston Drill ❑ Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas glIONK 1OBates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 2 Single Well ❑ 11.Well Name and Number: ENI US Operating Co. Inc. Bond No. RLB0008627 SP18-N5 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 13628' . TVD: 3987' 1,r� Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): >c `��' Q7 �' f /-10( Surface: 4458.9 FSL 1327.0 FEL S19 T14N R9E UM ADL 391283,388583,388574,388571 J a i= r° Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 857 FSL 1498 FEL 18 T14N R9EUM ADL 417493 9/22/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 506 FSL 2078 FEL 12 T14N R8EUM 1280 11208'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: ' 53.4 feet 15.Distance to Nearest Well Open Surface:x- 511582 . y- 6053640 . Zone- 4 GL Elevation above MSL: ' 12.4 feet to Same Pool: OP10-09 16.Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1837 psig . Surface: 1389 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven _ 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2302 35 35 2337 2173 1118 sx 10.7#ASL,271 sx 12.5#Deeperete r 12.25" 9-5/8" 40 L-80 Hydril 563 6136 33 33 6169 4084 719 sx 12.5#Deeperete .r 8.75" 5.5" 15.5 L-80 Hydril 521 7659 5969 4084 13628 3987 uncemented liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing yength Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch❑I Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑I Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maurizio GGrrandii �,� Title Well Operation Project Manager (1A4. 1/1-At Signature 't . 1t_LL Phone 907-865-3320 Date 12/21/2010 ( Commission Use Only Permit to Drill - / API Number: fl``kll Permit Approval n See cover letter for other Number: .1-1 f ' 50-vz?-2,3c/51.11 vv Date: �eC7� `1 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: Q Other: 'ii`' 350) PSi- S o f la S f"� / r , Samples req'd: Yes EI No No Mud log req'd: Yes ❑ 2' .ss �dd �I3 4 h K� � -�--. ... i 'r (.1.4-42s�2S measures: Yes❑ No[I/ Directional svy req'd: Yes ['No ❑ Noii �l.rtS�t./�►r 4JiT"keSS �i✓Gv'T�r 1JO1 eS � �4-50.4,6- 5✓S o 4 i +'+ a ro r.61 Z o M a s. 0 XZ) R � pr � / _- APPROVED BY THE COMMISSION DATE:g•Z5.r If a /Or ,COMMISSIONER OR1G1 ' L / .zs.I1 .f,,_ . ;i ,..„0.a ,r„ Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(9)) Submit in Duplicate .... 11004, tir ni . Iu _ernReCElV AUG 1 9 2011, Maks Oil&Cae Cep. cemassion Anchorage 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com August 17,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill producer SP18-N5 Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore producer well SP18-N5.The well will be drilled and completed using Doyon rig 15. The planned spud date is 9/22/2011. 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, /jLi Maurizio randi Well Operation Project Manager IRS Oliktok Point Nikaitchuq Field • P n 0 p rro�eLm SP18-N5 (P3) Alaska DIR 1 LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" X-65 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res Surface Csq Dir -0 13-3/8" ID Base Permafrost 1,900' 1,783' > 68 lbs/ft MW(ppg) Wellbore Stability cn Mud Motor 1— L-80,BTC 9.2-9.5 Lost Circulation Hole Cleaning a• c ID 0 Va a 13-3/8"Casing Point 2,337' 2,173' ' . 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation 40 lbs/ft MW(ppg) Hole Cleaning mi CI L-80,Hydril 563 9.4 Torque&Drag TOC 3,949' 1111-1 i N N "N"Sand Top 4,949' o C..7.11.7., . C, TOL 5,969' tD S 9-5/8"Casing Point 6,169' 4,084' 12-1/4" 85 F LSND GR/RES Periscope/PWD Wellbore Stability Neutron/Density Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 15.5 lbs/ft MW(ppg) Xceed 675 L-80,Hydril 521 9.4 (Geo-Steering) 5-1/2"Slotted Liner TDI 5-1/2"Lnr 13,628' 3,986' 8.3/4" 85`F FazePro EnD Petirolleuim 2n0 Application for Permit to Drill Saved: 17-Aug-11 Application for Permit to Drill Document Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(f) 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(6) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Lateral Mud Program(MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25.005(c)(9) 6 10. Seismic Analysis 7 Requirements of 20 MC 25.005(c)(10) 7 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed:17-Aug-11 *tit • • Eno Petrolleuim ena Application for Permit to Drill Saved: 17-Aug-11 12. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 MC 25.005(c)(14) 8 15. Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed: 17-Aug-11 tot. , En troleum ,.?...m. Application for Permit to Drill Saved: 17-Aug-11 1. Well Name Requirements of 20 MC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SP18-N5 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 at Surface 4458.9 FSL 1327.0 FEL S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.4'AMSL Northing 6053640.670' Easting: 511582.790' Pad Elevation 12.4'AMSL • Location at Top of Productive Interval 857 FSL 1498 FEL 18 T14N R9EUM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 6169' Northing: 6055318.400' Easting:511402.800' Total Vertical Depth, RKB: 4084' Total Vertical Depth, 55: 4031' Location at Total Depth 506 FSL 2078 FEL 12 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13628' • Northing:6060240.500' Easting: 505743.900' Total Vertical Depth, RKB: 3987' • Total Vertical Depth, 55: 3933' • Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); 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 wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and AOGCC PERMIT Document.doc Page 3 of 9 Printed: 17-Aug-11 ...... Toit Enil =, Nu Riii- Application for Permit to Drill Saved: 17-Aug-11 (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration ---, Di'e. ''^ Q 4. Drilling Hazards Information y4. yrs•¢ 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; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent . mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (4084'TVD)(0.45 - 0.11 psi/ft) = 1389 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 25005(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 MC 25.030(!); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed:17-Aug-11 folos ' * Eno --' ' roleum pin Application for Permit to Drill Saved: 17-Aug-11 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 AAC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2302 35 35 2337 2173 1118 sx 10.7#ASL,271 sx 12.5# Deeperete 12.25" 9-5/8" 40 L-80 563il 6136 33 33 6169 4084 719 sx 12.5#Deeperete 8.75" 5.5" 15.5 L-80 H521il 7659 5969 4084 13628 3987 uncemented 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 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. bt ✓t✓ J a`4'et. J. AOGCC PERMIT Document.doc Page 5 of 9 Printed:17-Aug-11 .... • 10#1 En ' troIe Application for Permit to Drill Saved: 17-Aug-11 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 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) './ Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value _ Initial Value _ Final Value Density(ppg) 8.8 9.2 9.2 9.5 • Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH _ 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program✓ Lateral Mud Program ./ (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.4 • Density(ppg) 8.8 - 9.5 • Plastic Viscostiy 15 - 25 Funnel Viscosity (CP) 45 - 60 - (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 - 18 (lb/100 s!) (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 st) 200psi&100°F API FiltrateOil/Water (cc/30 min)) 4 - 6 Ratio 60/ 40 Chlorides(mg/l) <500 Electrical >600 pH 9.0 - 10.0 _ Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. 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 MC 25.033(1); AOGCC PERMIT Document.doc Page 6 of 9 Printed:17-Aug-11 ..... lot • Enii qtr,.; Nevi Application for Permit to Drill Saved: 17-Aug-11 Not applicable: Application is not for an exploratory or stratigraphic test well. 9. 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 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. 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 MC 25.061(b); Not applicable: Application is not for an offshore well. 11. 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 application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. 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 9oyon 15. 4.410 a�, v-�'ev� i -1•s It- 2. Spud and directionally drill 16" ole tocasing point as per directional plan. Run Gyro and MWD tools as • required for directional monitoring. 3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. Install and test wellhead to 5000 PSI. • 5. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. • 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. ' 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. 11. RU casing drive system. , AOGCC PERMIT Document.doc Page 7 of 9 Printed: 17-Aug-11 tir . Ieum • EnH � Application for Permit to Drill Saved: 17-Aug-11 12. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 13. Install 9-5/8"Emergency Slips. 14. Install 9-5/8"packoff and test to 5000 psi. 15. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 16. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 17. PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, • clean out cement to top of float equipment. 18. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 19. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 20. PU and run 5-1/2"slotted liner to TD. 21. Land liner, set liner hanger with 200'Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 22. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 23. Nipple down BOP, nipple up tree and test. Pull BPV. • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). (1). ofr- • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 24. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 25. Move rig off. 13. 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 an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. AOGCC PERMIT Document.doc Page 8 of 9 Printed: 17-Aug-11 If* • El PtiroIIeuim Application for Permit to Drill Saved: 17-Aug-11 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 AOGCC PERMIT Document.doc Page 9 of 9 Printed: 17-Aug-11 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. 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II Z i i i i R. i i' i iiii i E N I' $ u u i i i 5 + i i iii i >< I 1 1. i 1 iiiiI _ I a 1 i iN i 8 i iiii i Y : : ' ::•:' �S ! 0 .... 1 1 ...e 1 .1 I LI....+......5..!ti:., O C 1 1 1 1 1 1 i 'g V 1 11 i i i W O 1 1 i L 1 8 1 1 I W i 11 i l i d 1 1 1 U • 1 1 1 1 'i 1 1 1 1 1 • 1 1 1 11:1 i o i I i 1 i i i 1 ii:.i O pO O o O 0 > i0 0 CDV N O N f0 '7 (8)008:(0l=eIeoS aAl Ili,* 1 2n I• ISchlumberger WELL FIELD STRUCTURE SP18-N5(P3) Nikaitchuq Spy Island Magneto Parameters Surface Louten NAD27 AR.Slats Rare,Zone 04,US Feat Mtscellansous Model BOOM2011 06: 810581 Date: October 20,2011 Lit N 7033279/9 NodNrg: 6053640.678U5 God Com:006856397' Slot: SP18 NO Rc. Rotary TablelS346stow MSL/ Meg Dec: 20.866' FS 576521n Lon'. W 1495417.9% fasting: 511582.TORUS Scale Fact 099890015 Plan'. SP18-615(P3) Sny Date.August 10,2011 -6000 -4800 -3600 -2400 -1200 0 7200 • < 7200 SP18-N5(P3) End Cry TD SI-N5 Tgt 14 Cry 2/106 N 6000 End C,v 'Al.._ 6000 SI-N5 Tgt 12 End Cry Cry 2/100 SI-NE Tgt 13 Cry 2/100 End Cry SI-NI Tgt 11 Cry 2/100 End Cry 4800 SI-N5 Tat 10 End Crya 4600 Fault 19 SI-N6 Tgt S End Cry - Cry 2.5/100 Cry 2.5/100 A A A Cry End Cry End SUNS Tgt 6 Z SI-NO Tgt 7 Civ 2/100 = 3600 Cry 21100 3600 0 0 N End Cry End Cry SI•N6 rgt4 C SI-N5TQ16 Ct02/100 Cry 2/100 II 01 End Cry End Cry SI-N5 Tgt 2 u) 2400 4d.N5 gt•S••••• •••••• • Crysrteo 2400 u) CIV 2/100 v v V End Cry Cry 2.5/100 Cry 2.5/100 9-5/S••Csg End Cry 1200 31#5.bael 1200 RTE Cry 4.6/100 KOP Cry 1.5/100 0 ..,_End Cry 0 Cry 2.5/100 Cry 2.5/100 Cry 0.5/100 Cry 4.5/180 1343/S"Csg -1200 -1200 -6000 -4800 -3600 -2400 -1200 0 «< W Scale=1(in):1200(ft) E >>> Schlumberger SP18-N5 (P3) Anti-Collision Summary Report Analysis Date-24hr Time: August 11,2011-13:14 Analysis Method: Normal Plane Client: Eni Petroleum Reference Trajectory: SP18-N5(P3)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Spy Island Rule Set: D&M AntiCollision Standard S002 v5.1 Slot: SP18 Min Pts: All local minima indicated. Well: SP18-N5 Borehole: SP18-N5 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major S117-SE2(P2)(Def Plan) Warning Alert 8.04 6.82 1.36 5.57 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7.17 4.78 0.50 2.49 319.92 319.90 MinPts 7.21 4,77 0.53 2.45 329.88 329.85 MinPt-O-EOU 7.28 4.79 0.581 2.441 334.85 334.82 MinPt-0SF 47.64 43.57 40.97 11.39 547.43 548.51 CtCt<=151n>15.00 Exit Alert 2694.55 2666.94 2653.67 101.5 4735.99 3859.31 MinPt-O-SF 2687.96L 2660.74 2647 86 102.73 4870.79 3905.77 MinPts I 2687.941 2660.76 2647.71 102.90 4880.38 3908.82 MinPt-C1Ct 1871.98 1823.36 1799.54 39.28 6749.96 4075.19 TD 2631.88 2625.36 202.84 2929.59 2732.89 MinPt-CtCt 2645.98 1; 2625.20 200.43 2981.97 2780.76 MinPt-O-EOU 2646.21 2631.:'MMEE 197.68 3032.75 2826.57 MinPt-O-ADP ' 781.93 743.21 724.33 20.69 3872.30 3439.03 MinPt-CICI 782.10 743.1 724.12 20.56 3877.55 3441.94 MinPt-0-EOU 782.21 743.11 7241020.51 3879.30 3442.90 MinPt-O-ADP 803.46 762.01 74178 19.8 3940.84 3478.76 MinPt-O-SF 1280.92 1201.45 1172.20 21. 5419.04 4019.05 MinPt-0-SF SP16-F143(P2)(Def Plan) Warning Alert 15.96 14.74 2.95 12.04 0.00 0.00 CtCt<=15m<15.00 Enter Alert 14,45 11.98 1.43 5.36 354.79 354.73 MinPts 14.45 11.96 1.44 5.32 359.75 359.69 MinPt-O-EDU 14.84 12.22 1.83 illrl 384.49 384.39 MinPt-O-SF 48.81 44.67 35.79 11.50 567.21 566.10 CtCt<=15m>15.00 Exit Alert 2428.49 2400.89 2387 91.49 4712.92 3850.71 MinPt-0SF 2422.21 2394.821 238166 92.00 4819.21 3888.79 MinPts 2422.1 2394.83 2381.68 92.06 4825.22 3890.82 MinPt-CtCt 1572. 1366.33 1263.96 7.67 12878.90 3980.34 MinPt-CtCt 1578.26 1347.64 1232.82 6.87 13628.82 3987,35 TD 2653.90 2632.27 2621.95 128.481 3808.24 3403.68 MinPt-O-SF 16730.84 16708.04 16697.14` 766.901 714,17 710.82 MinPt-OSF 16676.92 16654.20 16643.32 766.911 715.53 712.15 MinPt-O-SF 14277.47 14257.89 14248.601: 768.001 785.21 780.13 MinPt-O-SF 10889.32 10870.16 10861.07- 598.971 2817.41 2628.61 MinPt-OSF SI19-FN2(P2)(Def Plan) Warning Alert 15.99 14.77 2.95 12.07 0.00 0.00 CtCt<=15m<15.00 Enter Alert 15.99 13.98 2.95 7.32 200.00 200.00 MinPts 16.01 13.96 2,97 7.24 209.99 209.99 MinPt-O-EOU 16.68 14.46 3.64 274.93 274.92 MinPt-O-SF 48.38 44.65 35.34 12.65 519.72 519.02 CtCt<r15m>15.00 Exit Alert 2506.35 2477.59 2463.7'�tS;S, 4744.63 3862.49 MinPt-O-SF 2491. > _'�"- 1 91.46 4891.98 3912.45 MinPts =:8 2463.09 2449.49 91.54 4897.20 3914.07 MinPt-CtCt 2220 7, 2154.19 2121.41 33.86 7913.80 4031.47 MinPt-CtCt 2228. • 2109.02 28.19 8457.86 4030.46 MinPt-O-EOU 2232.66 2148.96�MillX11 26.98 8594.82 4030.80 MinPt-O-ADP 2266.88 2166.77.® 22.86 9239.35 4048.63 MinPt-O-ADP 2285.84 2174.5 ®J 20.71 9628.43 4044.98 MinPt-O-ADP 2317,2.1=0ff 2113.42 17.13 10512.87 3980.40 MinPt-O-EOU 2319.67 2181.5.MGM 16.90 10562.30 3973.51 MinPt-0-ADP 2737.12 2504.59 2388.81 11.82 13628.82 3987.35 TD 10985,43 10965.36 10955.821 575.561 2931.48 2734.63 MinPt-0-SF 12010.34 11988.69 11978.361 581.091 2939.04 2741.57 MinPl-OSF 15147.31 15120.00 15106 831 575.271 2959.12 2759.96 MinPt-0-SF 5114-N6(P2)(Def Plan) Warning Alert 31.94 30.72 6.14 25.10 0.00 0.00 CtCt<=15m<15.00 Enter Alert 31.94 29.91 6.1 15.11 200.00 200.00 MinPts 31.98 29.8 6.18 14.66 260.08 260.08 MinPt-O-EOU ( 31.32 24.57 5.521 4.46 960.95 949.25 MinPts 31.44 24.47 5.64 4.34 1010.68 996.40 MinP1-0-EOU 32.00 24.79 6.21 mum 1075.21 1057.04 MinPt-OSF 49.13 41.14 23.33 6.00 1444.77 1390.73 CtCtc=15m>15.00 Exit Alert 71.8 57.9 46.0 5.09 3180.34 2955.67 MinPts 72.31 57.56 48.51 4.84 3210.77 2981.43 MinPt-O-E0U 73.70 58.09 47.90 4.66 3241.05 3006.73 05F<5.00 Enter Alert Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 1 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 78.68 61.58 52.88 4. 3296.14 3051.89 MinPt-O-SF 90.23 71.37 62.43 4.99 3370.40 3110.84 OSF>5.00 Exit Alert 1062.17 989.63 8.32 10200.72 4027.59 MinPt-CtCt 1201.29 969.09 853.48 519 13628.82 3987.35 TO 5125.98 5089.53 5071.8.® 2148.23 1999.22 MinPt-O-SF 5175.62 5138.82 5120.92 14450 2158.42 2008.39 MinPt-O-SF 5120-N4(P3)(Def Plan) -c z,u x. =i.g, . a, Warning Alert 24.03' 22.80 4.56 10.63 0.00 0.00 CtCt<=15m<15.00 Enter Alert 23.92 21,8 4.4 1097 299.90 299.89 MinPts 1 22.20 19.09 2.74 6.74 634.02 632.09 MinPts 22.93 18.40 3.46 4.79 793.43 788.12 MinPt-O-EOU 23.071 18 40 3.61 4.67 808.37 802.62 MinPt-O-EOU 42.42 29.08 22.95 MIKE 1460.87 1404.79 MinPt-O-SF 67.51 45.22 34.61 IIIMER 1978.08 1850.32 MinPt-0SF 97.69 77.12 67.45 4.99 2279.33 2119.04 OSF>5.00 Exit Alert 1139.51 1087.63 1062.1.�l 5364.88 4013.66 MinPt-O-SF MIME 1112.42 1069.04 13.82 7542.36 4036.64 MinPt-CtCt 1108.39 1063.02 13.22 7778.10 4032.68MInPt-CtCt NEM 1087.77 1032.09 10.77 8781.00 4037.20 MinPt-CtCt NEM 1042.60 964.02 7.63 10793.58 3955.36 MinPt-CtCt 1203.98 975.48 861.72 5.29 13628.04 3987.34 TO 7452.00 7429.76 7419.13 milic, 1160.65 1136.35 MinPt-0SF 7669.86 7649.65 7640.03 398.801 2662.04 2481.51 MinPt-O-SF SP12-SE3(P2)(Def Plan) - Wamlrtg:Aletl 63.09 61.86 30.28 50.54 0.00 0.00 Surface 58. 55.51 25.67 19.24 453.49 453.18 MinPte 58. 55.45 25.69 18.77 463.17 462.81 MinPt-O-EOU 67.87 63.54 35..:Maga 572.09 570.93 MinPt-O-SF 2441.85 2416.89 2404.r tel" 4501.43 3763.54 MinPt-O-SF 2456.34 2431.17 2419.11=r1Eij 466258 3831.29 MInPt-O-SF 1488.10 1448.21 1429.76 40.24 6683.67 4079.81 TD 2601.95 2588.82 2569.1' 2335.15 2171.06 MinPt-O-SF 2426.80 2404.65 2393.91 MI=, 3993.18 3505.76 MinPt-O-SF 148.90 126.86 116.1.MIER 4972.77 3936.33 MinPt-O-SF 131,62 104.02 90.72 4.91 5021.62 3949.51 OSF<5.00 Enter Alert 125.2 87.12 68.57 3.35 5077.55 3963.39 MinPt-CtCt 128. 83.21 61.21 2.89 5119.67 3972.99 MinPt-O-EOU 130.93 83.6 60.5412.81 5137.03 3976.73 MinPt-O-ADP 137.29 86.89 62.18 2.761 5188.13 3983.10 MinPt-0SF 27403 218.15 190.70 4.97 565263 403941 05F>5.00 Exit Alert S113-FN4(P2)(Def Plan) Warning Alert 39.94 38.72 7.74 31.63 0.00 0.00 CICt<=15m<15.00 Enter Alert 36.57 33.82 4.37 12.85 424,10 423.90 MinPts 36.59 33.80 4.39 12.69 429.00 428.78 MinPt-O-EOU 40.01 36,62 7.82 11111111111310 496.86 496.32 MinPt-0SF 4906 45.18 16.87 12.33 553.80 552.82 CtCt<=15m>15.00 Exit Alen 2375.12 2348.39 2335.5', EEE 4683.50 3839.48 MinPt-0SF ®mum m3ME 92.71 4763.31 3869.27 MinPls 755.06 603.25 527.83 5.00 12212.08 3971.03 OSF<5.00 Enter Alert 506.14 291.81 185.13 2.37 13628.82 3987.35 OSF>5.00 Exit Alert 2544.94 2523.16 2512.7 =En 3871.35 3438.51 MinPt-OSF 17875.18 17850.26 17838.2.="'I 681.81 679.10 MinPt-O-SF 17840.86 17815.98 17804.0 =EKE 682.57 679.84 MinPt-O-SF 15605.78 15583.99 15573.5:N' I 738.32 734.44 MinPt-O-SF 13995.70 13976.18 13963.5.® 788.04 78289 MinPt-O-SF 10930.23 10911.72 10898.0 1 590.46 2729.83 2545.96 MinPt-0-SF SP10-FN5(P2)(Def Plan) Warning Alert 79.19 77.97 46.38 63.70 0.00 0.00 Surface 74.93 71.86 42.12 24.06 468.45 468.06 MinPts 74.97 71 83 42 16 23.53 478.12 477.68 MinPt-O-EOU 88.37 83.61 55.56 18.331 619.42 617.70 MinPt-OSF 1 2273.300 2248.731 2236.97 96.68 466029 3830.38 MinPts 2273.32 2248,75 2237.00- 96.671 4668.91 3833.77 MinPt-O-SF 604.60 482.81 422.41 5.00 11780.07 3955.39 OSF<5.00 Enter Alert IL 596.13 438.71 360.50 3.80 12284.40 3972.01 MinPt-CtCt 611.21 421.4 327.088��' 3.23 12750.11 3978.47 MinPt-0SOU 625.42 424.21 324.1u� 3.12 12937.49 3981.19 MinPt-O-ADP 674.49 450.46 338.941 3.021 13381.05 3985.68 MinPt-0SF 71065 476.50 359.92 3.04 13628.82 3987.35 OSF>5.00 Exit Alert 229282 2273.00 2260.01 miEEE 3842.50 3422.59 MinPt-0SF 14030.58 14008.38 13997. ®1 783.78 778.74 MinPt-OSF 13596.87 13574.67 13564.06 2729.37 2545.52 MinPt-0SF 19481.72 19447.46 19430.8.=OM 2820.43 2631.44 MinPt-OSF SP23-N3(P3)(Def Plan) Warning Alert 48.05 46.83 15.24 38.26 0.00 0.00 CICI<=156<15.00 Enter Alert 1 48.051 45.99 15.24u 22.721 299.80 299.79 MinPts 48.270 4647 15.46 26.14 439.30 439.05 MinPt-O-EOU 49.14 46.72 16.33 19.79 553.43 552.45 CtCt<=15m>15.00 Exit Alert 79.34 72.44 46.531 11.3 1078.44 1060.07 MinPt-O-SF 80.86 73.82 48.05 11 3 1092.98 1073.64 MinPt-O-SF 83,47 76.20 50.66 11 31 1117,17 1096.14 MinPt-OSF 258.96 239.71 226.15 13 391 2241.67 2084.26 MinPt-O-SF 267.00 24727 234.19 13.481 2278.09 2117.89 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 2 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MDIft)_I TVD(ft) Alert I Minor I Major 571.31 549.12 538. 25.71 2632.53 2453.39 MinPt-O-SF 2481.98 2453.96 2440. 91.76 3153.28 2932.51 MinPt-O-SF 3828.05 3792.38 3775.0 110.31 3799.48 3398.83 MinPt-O-SF 3011.81 2960.51 2935.35 59.84 5201.79 3989.53 MInPt-O-SF 3001.51 2950.811 2925.96 60.36 5369.03 4014.12 MInPt-O-ADP 3001.412950.81 2925.97 60.39 5374.14 4014.68 MinPt-O-EOU 1 3001.4 2950.82 2925.99 60.42 5379.25 4015.22 MinPt-CtCt 2407.45 2179.48 2065.99 10.60 13627.38 3987.34 TD SP22-FN1(P2)(Def Plan) Warning Alert 39.96 38.74 7.75 31.65 0.00 0.00 CtCt<=15m<15.00 Enter Alert 39.96 37.95 7.75 19.21 200.00 200.00 MinPts 39.97 37.93 7.76 18.98 209.98 209.98 MinPt-O-EOU 43.66 41.22 11. ®. 354.36 354.31 MinPt-O-SF 49.04 46.29 16.82 17.42 413.42 413.25 CtCt<=15m>15.00 Exit Alert 50.90 48.04 18.69 Ti 428.07 427.85 MinPt-O-SF 2559.12 2529.64 2515.. 90.04 4776.12 3873.84 MinPt-O-SF 2537.70 2508.9.WERIn 91.50 4936,81 3926.02 MInPt-O-ADP 2537.66 2495.05 91.59 4941.57 3927.42 MInPt-O-EOU 2508.92 2495.09 91.67 4946.33 3928.80 MinPt-CtCt 2327.70 2306.19 55.09 6697.44 4077.62 MinPt-CtCt 2371.8-MIME 2305.98 54.83 6705.05 4077.19 MinPt-O-EOU 2371.98 2327.6.MEM 54.67 6710.13 4076.92 MinPt-O-ADP 3781.89 3549.90 3434.39 16.37 13828.82 3987.35 TD 20030.10 19982.05 19958.52` 425.61 3034.98 2828.57 MinPt-O-SF 11288.94 11267.25 11256.72, 520.45 3103.65 2889.41 MinPt-O-SF 3952.65 3930.85 3920.44 181.26 3664.56 3318.99 MinPt-O-SF 12803.04 12781.25 12770.83 587.40 879.68 871.49 MinPt-OSF I1848.221 1837.53) 1816.01 172.85 1405.25 1356.18 MinPts SP24-SE1(P2)(Def Plan) Pass 56.00 54.78 23.19 44 75 0.00 0.00 Surface 56.00 53.98 23.19 27.17 200.00 200.00 MinPts 56.01 53.97 23.20 26.84 209.98 209.98 MinPt-O-EOU 73.67 70.54 40.86 23.13 461,42 461,07 MinPt-O-SF 2964.12 2941.97 2931.31 133.7 3500.72 3208.38 MinPt-O-SF 2920.57 2891.54 2877.56 104.3 4735.18 3859.02 MinPt-O-SF 2864.26 2836.96 2823.84 109.14 5039.23 3954.02 MinPt-O-ADP 2864.2 2836.9 2823.85 109.27 5043.33 3955.05 MinPt-O-EOU I 2864.2 2836.99 2823.92 109.53 5051.55 3957.10 MinPt-CtCt 2335.60 2275.75 2246.31 39.66 7026.28 4066.00 TD 1615.21 1561.08 1534.5. 3315.63 3067.58 MinPt-O-SF =61.ln 30.37 3316.26 3068.09 MinPts 2403.04 2337.97 2305.9 6l 5497.92 4025.93 MinPt-O-SF 2403.22 2338.16 2306.1 1=EIM 5586.55 4033.65 MinPt-O-SF 2403.28 2338.22 ® 5608.88 4035.60 MinPt-O-SF 2306.31 2239.31 2206.31 MIME i 6721.43 4076.36 MinPt-O-SF 2298.00 2231.29 2198421 •- 6773.41 4074.41 MinPt-O-SF 2288.34 2220.53( 6 35.26 6907.65 4069.94 MinPt-O-ADP 2286.26 MSI 2188.14 35.29 6912.04 4069.80 MinPt-O-EOU .' 2220.59 2188.27 35.36 6920.59 4069.51 MinPt-CtCt SI25-N2(P2)(Def Plan) Pass 79.11 77.88 46.30 63.63 0.00 0.00 Surface 79. 77.01 46.2 37.8 299.67 299.66 MinPts I 77.85 74.58 44.84 24.94 587.48 586.16 MinPts 77.79 74.42 44.98 22.77 636.95 634.98 MinPt-O-EOU 116.90 107.79 84.09® 1229.25 1199.14 MinPt-O-SF 3500.34 3277.23 3166.17 15.75 13563.01 3986.91 TD 7549.34 7504,90 7483.17 173.7 1245,68 1214.05 MinPt-O-SF 7489.02 7425.03 7403.52 173.6 1256.33 1223.69 MinPt-O-SF 7410.02 7366.35 7345.011 173.58 1264.31 1230.90 MinPt-O-SF 7330.21 7287.00 7265.891 173.57 1275.34 1240.84 MinPt-O-SF 7267.41 7224,57 7203.64 173.58 1284.20 1248.81 MInPt-O-SF 6299.28 6262.27 6244.26 174.86 1500.67 1439.49 MinPt-O-SF 5283.14 5250.41 5234 541 166 401 1999,92 1868.94 MinPt-O-SF 4464.79 4431.52 4415.39 38 30 2644.91 2465.19 MinPt-O-0F I 1994.791 1969.111 1956.77 80 75 2902.52 2707.93 MinPts SP11-N7(P2)(Def Nen) Pass 71.12 69.89 38.31 57.11 0.00 0.00 Surface 7112 69.10 38.31 34.67 200.00 200.00 MinPts 71.12 69.10 38.31 34.55 210.03 210.03 MinPt-O-EOU 71 55 69.45 38.7 MEM 300.29 300.28 MinPt-O-SF 175.50 154.13 142.69 1:3 1992.82 1862.87 MinPt-O-SF 2400.13 2332.12 2298.61 35.80 6183.95 4085.72 MinPt-CtCt Minn 2318.58 2278.48 29.91 7155.88 4060.97 MinPt-CtCt IMEMe 2301.23 2252.20 24.47 8121.64 4029.75 Mi6Pt-C1Ct 2400.01 2278.82 2218.72 19.96 9121.94 4049.60 MinPl-CtCt 2401.76 2168.92 2052.99 10.35 13628.82 3987.35 TD 6600.57 6545,72 6518 79® 1303.64 1286.26 MinPt-O-SF 6564.77 6510.22 6483.43 1aw69 1309.37 1271.38 MinPt-0SF 5274.95 5232.12 5211.19=KEE 1822.20 1717.30 MinPt-O-SF 5225.80 5183.38 5162.66�''I 1853.79 1744.35 MinPt-O-SF 6295.82 6241.95 6215.51 11111= 2244.95 2087.27 MinPt-0SF 6340.14 6285.90 6259.27 MEy 2251.07 2092.92 MinPt-O-SF 5131-S4(P2)(Def Plan) Pass Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 3 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 135.10 133.88 102.30 109.38 0.00 0.00 Surface 135.10 133.09 102.30 66.40 200.00 200.00 MinPts 135.12 133.08 102.31 65.66 209.94 209.94 MinPt-O-EOU 181.64 177.77 148.83 46.60 585.56 584.26 MinPt-O-SF 3459.79 3440.91 3426.9.0000000 ;, 1554.42 1486.25 MinPt-O-SF 3505.38 3486.24 3472.5 MMEI 1557.70 1489.09 MinPt-O-SF 7373.63 7342.82 7327.9 0000000M 1980.90 1852.72 MinPt-O-SF ,IMI2M. 6388.10 6334.42 60.51 2621.37 2442.74 MinPt-CICt 6497.6 6386.99 6332.16 59.24 2627.63 2448.71 MinPt-0-EOU 6498.91 6387.26 mmEEE. 58.71 2630.35 2451.30 MinPt-O-ADP 7175.19 7025.58 6951.2 mog 2729.67 2545.81 MinPt-O-SF 2904.66 2873.14 2857.91.mm m; 4888.78 3911.46 MinPt-0SF 2817. 80000 �l 99.12 5091.55 3966.67 MinPts 8800 2787.78 2773.59 99.23 5094.73 3967.40 MinPt-CtCt ® 2718.01 2700.44 78.35 5928.50 4063.46 MinPt-CtCt 2754.39 BBBBF3 2700.08 77.58 5942.53 4064.68 MinPt-O-EOU 2754.61 2717.8 2700.0 77.20 5949.51 4065.29 MinPt-O-ADP 3086.76 3035.27 3010.0 =BE 6693.16 4077.87 MinPt-O-SF 3412.26 3355.78 3328.03i6839.14 4072.22 MinPt-O-SF 3553.14 3494.45 3465.59jj)�- 6919.97 4069.54 MinPt-O-SF 3585.36 3526.11 3496.98 8000800EM 8938.15 4088.93 MinPt-O-SF 3920.33 3855.55 382365 0000080 ' 7182.37 4059.37 MinPt-O-SF 7058.76 6961.03 691266 72.96 8500.64 4030.55 TD n 8341.47 8252.86 8209.05® 6609.37 4084.38 MinPt-O-SF V 7063.451 6965.720 6917.351 73.001 8500.64 4030.55 MinPts SP27-N1(P3)(Def Plan) Pass 95.12 93.90 62.32 76.72 0.00 0.00 Surface 95.12 93.09 62.32 46.09 200.00 200.00 MinPts 95.13 93.09 62,32 45 45 97 224.90 224.90 MinPt-O-EOU 95.17 93.11 62.36�mrir"I 299.61 299.60 MinPt-0SF 225.31 207.13 192.50 000000000 1897.18 1781.43 MinPt-0SF 8382.56 8325.80 8297.94029.77 3525.95 MinPt-0SF 7522.28 7472.02 7447.3.NENE 4130.97 3580.87 MinPt-OSF 6716.24 6672.56 6651. .0.0000001 4269.63 3653.02 MinPt-0SF 0000.. 4906.84 4863.53 57 64 7503.44 4038.66 MinPt-CtCt 4807.26 4591.72 4484.45 22 42 13626.87 3987.34 TD 9391.37 9332.48 9303.5 00000001 1115.80 1094.87 MinPt-OSF 9361.09 9302.38 9273.5 M 1118.74 1097.60 MinPt-O-SF 8978.71 8922.27 8894.5 BBBBBBBBBB I 1158.57 1134.44 MinPt-OSF 6055.45 6022.16 6006.01 NEM 1959.05 1834.14 MinPt-OSF 6004.63 5971.60 5955.5 MEM 1986.04 1857.09 MinPt-O-SF 5404.99 5375.04 5360. 00000000000 2329.76 2166.02 MinPt-0SF _MMES 000EEME, 0000 '® 2800.5o 2612.72 MinPts SP01-SE7(P2)(Def Plan) Pass 159.18 157.95 125.37 129.05 0.00 0.00 Surface 158.83 156.29 126.02 62.10 366.20 366.13 MinPts 158.90 156.21 126.10 58.60 406.40 406.25 MinPt-O-EOU 204.61 198.59 171.''0000000 779.43 774.51 MinP1-0SF 215.62 209.24 182.81000000 9 809.65 803.86 MinPt-0SF 6188.23 6164.04 6153.4. 278.69 2077.95 1936.68 MinPt-O-SF 3224.85 3209.82 3192.'-.ME111 2337.05 2172.84 M1nPt-OSF 1841.70 1827.18 1808.9'000000 8 3094.46 2881.34 M1nPt-OSF 1823.23 1808.79 1790.4.0000001 3162.14 2940.12 MinPt-OSF MIME V88145.00000] 129.45 3672.24 3323.83 MinPts 1767.79 1754.15 1734.9'=153A 3723.72 3355.32 MinPt-O-SF 1754.35 1738.02 1721. '=BM 4192.18 3613.20 M1nPt-OSF 1746.70 1730.19 1713.9' 105.68 4498.60 3762.28 MinPt-OSF 1878.48 1658.30 1645.6 IE.= 5441.98 4021.05 M1nPt-OSF 1674.5 1650.53 1639.00 72.55 5503.71 4026.43 MinPt-CtCt 1674.8 1650.281 1638.48 70.90 5520.33 4027.88 MinPt-O-EOU 1675.17 1650.''""11 1638.4 70.21 5527.45 4028.50 MinPt-0-ADP 2379.44 2318.08 2287.8 39.391 6609.44 4084.37 MinPt-OSF 3252.29 3184.21 3150.66 48.46 6921.78 4069.48 TD 6226.89 6204.67 6194.0' 280.26 1746.13 1651.99 MinPt-OSF 5985.11 5903.37 5863.0'IME111. 4727.85 3856.30 MinPt-OSF 5273.94 5202.93 5167.9.00000000 4991.90 3941.61 M1nPt-OSF 5262.79 5191.92 5156.9:00000000 6 4997.77 3943.20 MinPt-O-SF 5099.18 5030.83 4997.1 1MEG 5096.25 3967.75 MinPt-O-SF 5059.39 4991.60 4958.1'BBBBBBBBB-BBOT 5124.83 3974.11 MinPt-O-SF 4864.78 4798.53 4765.'+MEM 5288.64 4003.84 MinPt-0SF 6921.77 4069.48 MinPts SP3O-W1(P2)(Oaf Plan) Pass 119.12 117.89 86.31 96.32 0.00 0.00 Surface 119.12 117.10 86.31 58.47 200.00 200.00 MinPts 119.12 117.10 86.31 58.40 20995 209.95 MinPt-0-EOU 119.23 117.18 86.4.0000000001 299.51 299.50 MinPt-0SF 273.78 255.37 240.98 14.80 1914.64 1796.32 MinPt-0SF 10246.10 10171.28 10134 36 000® 4064.47 3544.97 MinPt-0SF 10208.08 10133.53 10096.75 MEI 4067.42 3546.58 MinP1-0-SF 6670.46 6624.26 6601.66 000000000000 4697.14 3844.71 MinPt-0SF 6377.76 6334.08 6312.7- 149.38 4866.51 3904.40 MinPt-O-SF 4986.43 4940.96 4918.7 '._______ 5477.04 4024.11 MinPt-0SF 5029.72 4983.87 4961.4 BBBBBBB e•5l 5499.83 4026.09 MinPt-O-SF 601513 5935.96 5896.87 76.92 7178.67 4059.60 M1nPt-O-EOU 6010.59 5904,09 5851.33 56.95 8584.75 4030.74 MinPt-CtCt Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 4 of 14 • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6006.23 5838.34 5754.88 35.98 11625.43 3951.55 MinPt-CtCt 6007.64 5791.04 5683.23 27.86 13628.82 3987.35 TD 10418.89 10345.79 10309.83 144.86 1091.98 1072.70 MinP4-0SF 10384.63 10311.97 10276.13 144.86 1095.09 1075.60 MinPt-O-SF 6169.89 6135.12 6118.26 183.01 2261.79 2102.81 MInPt-O-SF 5022.00 4999.19 4988.29 230.1 2458.94 2287.90 MinPt-O-SF M 1428.17 1405.951 1393.36 70.48 2732.51 2548.50 MinPts 5132-W2(P2)(Def Plan) Pass 143.06 141.84 110.26 115.89 0.00 0.00 Surface 143.06 141.0 110.26 70.35 20000 200.00 MinPts 143.06 141. 110.26 70.31 204.97 204.97 MinPt-0-EOU 143.22 141.18 110.41 MDR 299.41 299.40 MinPt-OSF 268.15 256.47 235. MEC, 1366.76 1322.37 MinPt-0SF 277.09 26502 244.281 1396.06 1348.13 MinPt-0SF 303.67 290.55 270.86 MEM 1473.83 1416.10 MinPt-O-SF 11488.08 11396.50 11351 20 MEM 4139.72 3585.53 MinPt-0SF 7578.71 7520.10 7491.29=MEE 4919.47 3920.87 MinPt-0.5F 7313.07 7257.31 7229.9 ® 5138.58 3977.05 MinPt-0SF MEE 7100.13 7044.24 64.52 8600.42 4030.85 MInPI-CICt ! MEM 7032.53 6945.47 41.39 11636.91 3951.56 MInPt-CtCt 7208.51 6984.84 6873.50 32.37 13628.82 3987.35 TD 11483.81 11394.82 11350.8 130.49f 1072.00 1054.04 MinPt-0SF 6864.56 6821.35 6800.2 162 87 2296.64 2135.12 MinPt-0-SF 1987.44 1964.16 1953.01 89.09 2565.08 2389.01 MinPts 5135-W4(P2)(Def Plan) Pass 167.14 165.92 134.33 135.56 0.00 0.00 Surface 111 82.29 200.00 200.00 MinPts 167.57 165.54 134.76 81.981 279.45 279.44 MinPt-0SF 454.14 441.80 421.3 ®1I 1385.47 1338.84 MinPt-O-SF 475.44 462.51 442.63 36.68 1421.97 1370.80 MinPt-O-SF 5918.57 9864.66 9838.20MM 4970.96 3935.83 MinPt-0-SF 8388.15 8336.01 8310.431 5598.31 4034.68 MinPt-0-SF 8477.37 8424.71 8398.87' 164 02 5627.52 4037.22 MinPt-O-SF 9537.77 MIME 9416.26 118.69 7180.42 4059.49 MinPt-0-EOU 9519.81 9418.75 9368.72 95.12 8164.06 4029.83 MInPt-CtCt 9524.10 IMM 9362.96 89.19 8600.49 4030.86 MinPt-0.EOU 9576.92 9359.76 9251.67 44.30 13628.82 3987.35 TD 9094.62 9052.10 9031.331219. 2233.48 2076.73 MinPt-OSF 1; 7229.431 7202.351 7189. 276. 2360.26 2194.62 MinPts SP33-W3(P2)(Def Plan) • Pass 151.15 149.93 118.34 122.49 0.00 0.00 Surface 151.15 149.14 118. 74.36 200.00 200.00 MinPts 151.15 149.14 118.34 74.33 204.97 204.97 MinPt-O-EOU 151.47 149.43 118.66 MEE 299.38 299.37 MinP9-O-SF 494.36 472.86 461.55 4ss66 1982.00 1853.66 MinPt-O-SF 11495.42 11387.24 11333 64 MEM 4319.94 3678.17 MInPI.O-SF 10427.39 10331.46 10283.99 109.82 4470.16 3749.47 MinPt-O-SF 8415.95 8168.66 8045.51 34.16 13628.82 3987.35 TD 11120.36 11017.06 10965.9 108.67 1225.18 1195.44 MinPt-0SF 1743.79 1721.88 1710.9: 79.53 2514.75 2341.01 MinPts SP36-W5(P2)(Def Plan) Pass 8.11 86.29 200.00 200.00 MinPts 175.70 173.67 142.8•Mart 279.42 279.42 MinPt-OSF 488.42 476.32 455.61 jjjjjjjjjjj 7 1366.79 1322.39 MinPt-0SF 513.96 501.22 481.1 1 1406.09 1356.92 MinPt-OSF 10903.83 10847.66 108200 MEM 5017.58 3948.45 MinPt-OSF 10550.50 10471....jjjjj 134.45 7182.97 4059.33 MinPt-0-ADP 10530.86 10314.38 10206.64 48.86 13828.82 3987.35 TD 10017.81 9970.65 9947.61 217.30 2226,21 2070.05 MinPt-0-SF 1 7902.244 7876.76 7864.51 322.57 2351.34 2186.24 MinPts S107-5E4(P2)(Def Plan) Peas 103.08 101.86 70.28 83.22 0.00 0.00 Surface 100.10 97.03 67.29 32.26 458.85 458.51 MinPts 100.13 97.00 67.33 31.52 468.52 468.14 MinPt-0-EOU 124.46 118.94 91.6`jjjjjjjjjjj! 662.74 660.36 MinPt-0SF 696.69 687.67 663.8'IMO 1118.80 1097.65 MinPt-0SF 2330.83 2308.62 2298.0-MOM 4502.18 3763.87 MinPt-0SF MEM 2308. > 2297.6 104.86 4541.19 3781.01 MinPts 2330.4,MIME 2297.6 win 4551.04 3785.26 MinPts 2332.59 2310.26 2299.6 u 109.6 4841.08 3822.73 MinPt-0-SF 2350.39 2328.17 2317.5•MUM 4843.85 3897.03 MinPt-0-SF 2357.84 2335.63 2325.0 5608.85 4035.58 MinPt-OSF 1125.70 1098.98 1086.12 43.71 6719.35 4076.46 TD 689.08 633.59 606.34 12.631 6284.34 4092.51 MinPt-O-SF 673.32 620.561 594.6 12.99 8394.71 4094.92 MinPt-O-ADP 673 01 620 49 594.72 13.04 6401.90 4094.89 MinPt-O-EOU I672.68 620.78 595 32 13.19 6419.77 4094.72 MinPt-C1Ct SD37-05P1(P4b)(Det Plan) Pass 191.82 190.71 159.01 171.10 0.00 0.00 Surface 191.8 189.89 159.01 98.91 200.00 200.00 MinPts 191. 189.73 159.18 84.67 289.27 289.27 MinPI-0-EOU 269.90 262.98 237..•MDEE 1026.56 1011.38 MinPt-OSF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 5 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct MI.1 EOU(ft) Dev.lftFact. MD(ft) I TVD(ft) Alert I Minor I Major 941.73 920.56 908.9 44.44 3461.57 3179.92 MinPts 942.17 920.11 909.36 42.66 3524.44 3225.26 MinPt-O-EOU 942.25 920.12 909. 42. 3529.44 3228.78 MinPt-O-SF 942.55 920.191 909. 44.05 3544.22 3239.12 MinPt-O-ADP 984.05 957.46 944.66 38. 3822.61 3411.60 MinPt-O-SF 1130.22 1101.58 1087.7 40. 4116.75 3573.25 MinPt-O-SF 3201.66 3177.18 3165.43 136.21 5309.16 4006.74 TD S108-FN6(P2)(Def Plan) Pass 92.53 89.28 59.73 28.03 519.42 518.73 MinPts 92.5 89.21 59.78 27.08 534.09 533.28 MinPt-O-EOU 112.58 107.20 79.77 mos716.20 712.81 MinPt-O-SF 2139.63 2117.47 2106.8MMEE; 4257.67 3646.95 MinPt-O-SF MIME 2090.70 2079.38 93.35 4601.10 3806.41 MinPt-CtCt 2114.431 2090.66J=MS 93.12 4624.07 3815.85 MinPts 2115.61 2091.79 2080.42, 4681.78 3838.79 MinPt-O-SF 2247.73 2225.53 2214.9 W11111 5374.39 4014.70 MinPt-O-SF 2250.77 2228.57 2217.96 MEE 5437.73 4020.68 MinPt-O-SF 1097.61 1002.51 955,45 11.65 9909.43 4040.94 MinPt-CtCt millE 957.63 894.89 8.63 10524.94 3978.62 MinPt-CtCt 1086.' 890.10 8.33 10602.84 3968.65 MinPt-O-EOU 1088.98 955.7 889.6. 8.23 10637.28 3965.08 MinPt-O-ADP 1275.33 1099.19 1011.62 3163 11611.81 3951.60 MinPt-O-SF 1428.06 1232.98 1135., mem 12170.31 3970.46 MinPt-O-SF 1878.65 1840.21 1521.48 7.91 13628.82 3987.35 TD 13039.77 13017.57 13006.96=mg 818.72 812.65 MinPt-O-SF 13029.70 13007.51 12996.8'MIESES 2660.82 2480.35 MinPt-O-SF 20345.77 20298.80 20275.81=En 2790.95 2603.73 MinPt-O-SF SP04-SE5(P2)(Def Plan) Pass I 133.87 130.87 101.06 4423 470.76 470.37 MinPts 133.95 130.81 101.14 42.26 495.58 495.04 MinPt-O-EOU 134.0 130.81 101.21 41.38 505.50 504.91 MinPt-O-EOU 172.74 166.48 139.93 27. 787.96 782.80 MinPt-O-SF 1954.5 1934.6 1921.77 97.99 4368.51 3701.87 MinPts 1954.71 1934.51 1921.90 96.74 4430.92 3731.43 MinPt-O-EOU 1961.70 1941.08 1928.8•�" 4740.11 3860.83 MinPt-O-SF 1911.36 1890.71 1878.5 MI01 5561.14 4031.44 MinPt-O-SF 1617.95 1595.77 1585.1 =EC 5992.51 4069.03 MinPt-O-SF MIME 1098.61 1075.14 24.41 6678.71 4078.77 MinPt-CtCt 1146.84 1098.19 1074.36 24.04 6678.83 4078.77 TD 3084.60 3071.08 3051.80 227.98 2335.84 2171.72 MinPt-O-SF 1946.86 1929.00 1914.05 108.95 3956.53 3485.53 MinPt-OSF 2269.72 2213.59 2186.02 41_1 5301.61 4005.70 MinPt-O-SF 1215.76 1158.86 1130.91 21.73 6649.06 4080.92 MinPt-O-SF 1147.55 1098.321 1074.20 23.77 6678.72 4078.77 MinPt-O-ADP L1146.98' 109819 1074.28 23.97 6678.82 4078.77 MinPts SP05-FN7(P2)(Def Plan) Pass 127.19 125 97 94.39 102.92 000 0.00 Surface 124.79 121.74 91.98 40.55 459.41 459.07 MinPts 124.86 121.67 92.05 38.85 478.83 478.40 MinPt-O-EOU 157.98 151.85 125.17 25.54 722.39 718.87 MinPt-O-SF 2135.261 2113.744 2102.45 99.18 4485.51 3756.41 MinPts 2139.63 2117.89 2106.83 98.34 4664.00 3831.84 MinPt-OSF 2077.74 2055.54 2044.94 93.5 5661.84 404021 MinPt-O-SF 1420. 1358.83 1328.73 23.57 8366.25 4030.27 MinPt-CtCt 1423. 1355.09' 1321.18 20.97 8570.12 4030.70 MinPt-O-EOU 1424.66 1355.`'•`,11 1320.99 20.80 8584.94 4030.74 MinPt-O-ADP 1798.01 1648.26 1573.87 12.08 10638.96 3964.92 MinPt-O-SF 2003.53 1837.51 1754. 12.1 11151.48 3954.36 MinPt-O-SF 3074.90 2839.77 2722.69 13.13 13628.82 3987.35 TD 12990.49 12968.31 12957.6'NEE:g.8 826.88 820.55 MinPt-O-SF 13046.38 13024.20 13013.5 1111112111E 2608.53 2430.48 MinPt-O-SF 20331.28 20274.16 20246.1.=me 2754.14 2568.99 MinPt-O-SF S102-5E6(P2)(Def Plan) Pass 151.07 149.84 118.26 122.43 0.00 0.00 Surface 151.07 149.05 118.26 74.32 200.00 200.00 MinPts 151.19 148.83 118.38 63.51 300.56 300.55 MinPt-O-EOU 205.33 199.13 172.5 32.89 742.63 738.65 MinPt-0SF 5087.33 5065.11 5054.5 228.85 2091.69 1948.80 MinPt-O-SF 3970.71 3956.37 3937.91 276.76 2337.25 2173.03 MinPt-O-SF I1932.21 1918.13 1899.41 137.07 3738.02 3363.80 MinPts 1929.16 1913.75 1896. 125.11 3919.04 3464.84 MinPts 1929.24 1913.67 1896.43 123.81 3933.90 3473.04 MinPt-O-EOU 1858 96 1839.19 1826.1'1111112^ 5474.39 4023.88 MinPt-O-SF 1773.18 1751 04 1740. :MMICE 5658.58 4039.93 MinPt-O-SF ® 1664.85 1649.20 54.19 6048.39 4073.90 MinPt-CtCt 1697.71 1664.311648.10 52.35 6081.62 4076.80 MinPt-O-EOU 1698.49 1664. 1647. 51.39 6099.75 4078.38 MinPt-O-ADP 1923.30 1863.24 1833.71 32.54 6849.65 4071.87 MinPt-O-SF 2205.40 214064 2108.75 34.57 6926.24 4069.33 TD 5126.80 5104.58 5094.0 230.65 1771.25 1673.59 MinPt-OSF 3662.59 3597.99 3566.18 57.56 5255.54 3998.78 MinPt-O-SF 3506.99 3448.52 3419.77 60.98 5496.70 4025.82 MinPt-OSF 2208.65 2143.871 2111.971 34.61 8926.23 4069.33 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 6 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor AlertStatus Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP09-S1(Def Survey) ass 17845.11 17843.30 17812.30 9840.75 243.68 243.67 MiePt-O-SF 17258.34 17250.14 17225.53® 2519.84 2345.86 MinPt-O-SF 16681.05 16658.68 16648.24 760.43 2849.77 2489.82 MInPt-O-SF 7258.20 7199.75 7173.70®' 3022.49 2817.37 MinPt-O-SF 4419.63 4185.85 4070.15.'7 5214.76 3891.88 MinPt-O-SF 4593.68 4343.56 4220.22 18.61 6716.07 4076.62 TD 3209.86 3003.29 2901.33 15.731 2880.33 2687.36 MinPt-O-SF 3045.47 2859.94 2769.65 16.84 2928.38 2731.77 MinPt-O-ADP 3044.59 2859.75 2769.84 16.90 2929.76 2733.05 MinPt-O-EOU I 3043.59 2860.90 2772.12 17.11 2933.75 2736.71 MinPt•CtCt 5129-S2(P2)(Def Plan) Pass 111.15 109.92 78.34 89.81 0.00 0.00 Surface 111.15 109.13 78.34 54.52 200.00 200.00 MinPts 111.16 109.12 78.35 53.89 209.95 209.95 MinPt-O£OU 148.28 144.59 115.47=Ea 554.43 553.44 MinPt-O-SF 767.28 758.73 734.471111111M. 1133.79 1111.55 MinPt-O-SF 2861.56 2830.75 281588. 4845.26 3897.49 MInPt-0-SF 2809.50 2780.0561 98.94 5031.73 3952.11 MinPts 2809.48 2780.06 2765.88 99.04 5035.26 3953.01 MinPt-OtCt 2676.15 2657.35 72.18 6069.95 4075.78 MinPt-CtCt 2715.06.�I 2656.88 71.27 6089.77 4077.51 MinPt-O-EOU 2715.31 2675.97 2656.83 70.92 6097.69 4078.20 MinPt-O-ADP 4013.11 3922.53 3877.7'imprE 8342.09 4030.21 MinPt-0SF 4677.24 4578.91 4530.24 48.04 8593.30 4030.79 TD 5039.48 5022.34 5006.6 =OE 1382.72 1336.43 MinPt-O-SF 5605.19 5582.99 5572.3.=MEI 1621.70 1544.60 MinPt-O-SF 4179.56 4130.28 43.41 2777.28 2590.85 MinPt-CtCt 4279. • 4179.06 4129.31 43.00 2780.49 2593.87 MinPt-0-EOU 4280.10 4179.1 NM= 42.81 2781.95 2595.25 MinPt-O-ADP 4538.52 4420.77 4362.38 38.86 2841.45 2651.12 MinPt-O-SF 5838.15 5745.35 5699.44® 6468.01 4093.58 MinPt-O-SF 5855.01 5763.02 5717.52 Man 7219.76 4056.95 MInPt-O-SF 5826.01 5733.83 5688.23 mms. 7547.28 4036.42 MinPt-O-SF �: 4=gm mizEi 48.07 8593.30 4030.79 MinPts OP14-53(Def Survey) Pass ,,:, 17856.16 17854.35 17823.35 9846.72 243.61 243.60 MinPt-O-SF 17270.02 17261.82 17237.22 2154.0 2518.89 2344.96 M1nPt-O-SF 16586.89 16571.43 16554.09 1107.4 2650.89 2470.88 MinPt-O-SF 14591.34 14571.91 14558.53 817.09 2740.54 2556.11 MinPt-O-SF 12382.21 12359.10 12349.40 608.28 2816.11 2627.39 MinPt-0-SF 10181.84 10152.99 10141.0 426.86 2886.13 2692.74 MinPt-O-SF 10125.09 10096.34 10084.49 426.93 2886.29 2692.89 MinPt-O-SF 7056.95 6812.21 6690.60 29.01 5273.88 4001.65 MinPt•O-SF 7136.36 6881.76 6755.57 28.27 6319.53 4093.86 TD 5611.71 5388.46 . 5277.87 25.381 2574.04 2397.57 MinPt-0-SF 5357.19 5160.28 5063.94 27.78 2673.47 2492.40 MinPt-O-ADP 5356.06 5160.08 5064.23 27.92 2675.76 2494.58 MinPt-O•EO1J 1 5354.581 5163.13 5069.66 28.62 2686.22 2504.53 MinPt-CtCt 5353.42 5176.77 5091.041 31.19 2717.55 2534.30 MinPI-0-ADP 5351.45 5176.3,'11 5091.44 31.48 2720.58 2537.18 MinPt-O-EOU 1 5350.25 5177.33 5093.53 31.89 2725.15 2541.52 MinPt-CtCt Nikeilchuq 4(Def Survey) 8148.0 8146.1 8115. 419544 52.20 52.20 MinPts 8148.1 8146.1 8115.29 4081.14 67.14 67.14 MinPt-O-EOU 8153.65 8150.86 8120..' 301.21 301.20 MinPt-O-SF 8154.4 8151... 8121.6. 2421.81 632.45 630.55 MinPts 8154.5 8150.r. 8121.72 2283.56 872.66 670.11 MinPt-O•EOU 8116.65 8100.08 8083.: 489.4 1998.66 1867.86 MinPt-0SF 6215.90 6151.18 6120.24 100.39 4909.40 3917.82 MinPt-CtCt 6216.12 6150.92 6119.73 99.62 4915.85 3919.72 MinPt-O-EOU 8216.52 6151.00 6119.65 99.11 4920.14 3921.07 MInPt-O-ADP 6217.83 6151.5 6119.76 97.86 4930.98 3924.30 MinPt-O-ADP 6221.88 6153.': 6120.67 94.77 4957.47 3932.01 MinPt-O-ADP 6242.53 6169.39 6134.16 88.56 5020.97 3949.34 MinPt-0SF Kigun 1 PB1(Def Survey) Pass 5059.60 5057.12 5026.79 2042.98 168.37 168.37 MinPts 5059.65 5057.05 5026.84 1944.10 198.37 198.37 MinPt-O-EOU 5060.01 5057.34 5027.2."' 296.46 296.45 MinPt-0SF 5060.1 5057.3' 5027.2• 1824.70 488.96 488.47 MinPts 5060.1 5057.2 5027.39 1720.07 518.13 517.44 MinP1-0£OU 5452.88 5434.87 5420.0 MEM 1999.29 1868.40 MinPt-0-SF 6799.52 8753.41 6731.1 152.81 6395.76 4094.91 MinPt•O-SF I 8270.631 6187 561 6146.:-, 76.96 6950.99 4068.50 MinPts 0115-54(P4)(Def Plan) Pass 17857.77 17855.96 17824.96 ..E 243.32 243.32 MinPt-0-SF 17272.27 17264.07 17239.46 MIME 2518.48 2344.57 MinPt-O-SF 16375.24 16356.60 16342.- 906.311 2653.61 2473.49 MinPt-OSF 15733.33 15710.84 15700.5 NM= 2678.00 2496.71 MinPt-O-SF 8309.15 8014.81 7868.40 28.37 6254.40 4090.94 TO 7043.53 6763.19 6623.51 25.211 2466.99 2295.55 MinPt-OSF 6521.86 6291.95 6178.81 28.81 2620.75 2442.14 MinPt-O-ADP 6518.161 6291.19 6179.57 29.18 2626.28 2447.42 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 7 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6515.18 6295.49 6187.64 30.19 2639.02 2459.57 MinPt-CtCt Nikaitchuq 3PB2(Def Survey) """��I Pass 7900.0• 7898.15 7867.2 4067.72 52.20 52.20 MinPts 7900.30 7897.31 7867. 2638.64 309.58 309.56 MinPt-O-SF 7854.73 7838.09 7821.9 472.00 2001.09 1869.94 MinPt-O-SF f 7040.13 7010.62 6997.01 258.51 4387.73 3711.08 MinPt-CtCt 7040.13 7010.62 6997.01 258.47 4388.11 3711.26 MinPt-O-EOU 7040.14 7010.62 6997.01 258.44 4388.50 3711.45 MinPt-O-ADP 7088.06 7058.11 7044.21 254.98 4452.87 3741.58 MinPt-O-SF 7092.64 7062.69 7048.78 254.97 4455.75 3742.90 MinPt-O-SF 8576.21 8546.88 8533.09 310.99 4651.46 3826.88 TD Ir 8580.501 8551.17 8537.381 311 1311 4651.46 3826.88 MinPts Nikeitchuq 3PB3(Def Survey) Pass I 7900.091 7898.15r 7867.28 4067.72 52.20 52.20 MinPts 7900.30 7897.31 7867.5 2638.6 309.58 309.56 MinPt-O-SF 7854.73 7838.09 7821.9 472. 2001.09 1869.94 MinPt-OSF 1 7040.13 7010.62 6997.01 258.51 4387.73 3711.08 MinPt-C1Ct 7040.13 7010.62 6997.01 258.47 4388.11 3711.26 MinPt-O-EOU 7040.14 7010.62 6997.01 258.44 4388.50 3711.45 MinPt-O-ADP 7088.06 7058.11 7044.21 254.98 4452.87 3741.58 MinPt-O-SF 7092.64 7062.69 7048.78 254 97 4455.75 3742.90 MinPt-O-SF 9076.25 9046.34 9032.26 322.32 4652.36 3827.24 TD 1 9081.0 MEM 9037.0:=Ma 4652.36 3827.24 MinPts Nikaitchuq 4PB1(Def Survey) Pass 8148.0 8146.1 8115.26 4195.44 52.20 52.20 MinPts 8148.1 8146.1 8115.29 4081.14 67.14 67.14 MinPt-0-EOU 8153.65 8150.86 8120.84 2926.71 301.21 301.20 MinPt-O-SF 8154. 8151.06 8121.62 2421.81 632.45 630.55 MinPts 8154.5 8150.98 8121.72 2283.56 672.66 670.11 MinPt-O-EOU 8116.65 8100.08 8083.8 489.4 1998.66 1867.86 MinPt-O-SF 1 7378.31 7349.10 7335.61 273.43 4365,39 3700.36 MinPt-CtCt 7378.32 7349.10 7335.61 273.34 4366.15 3700.73 MinPts 7417 881-7364.2 7338.52 144.081 4422.60 3727.55 MinPts OPO4-07(Def Survey) Pass I17834.82 1783360 17802.04 14570.43 0.04 0.04 MinPts 17835.11 17833.34 1780230 10085.69 160.04 160.04 MinPt-O-EOU 17835.14 17833.25 17802 34 9426.71 213.64 213.64 MinPt-O-EOU ll 17835.14 17833.26 17802 33 9514.10 216.38 216.38 MinPts 17835.73 17833.92 17802.931 9836 2.1 243.37 243.37 MinPt-O-SF 17248.92 17240.73 17216 11 2155.271 2520.41 2346.41 MinPt-O-SF 17231.28 17223.10 17198.48 2155.32 2529.90 2355.45 MinPt-O-SF 17201.30 17183.14 17168.49 2162.241 2546.33 2371.13 MinPt-O-SF 16188.30 16176.25 16155.49 1416.31 2663.06 2482.49 MinPt-O-SF 13149.53 13126.63 13116.72 633.52 2776.31 2589.93 MinPt-O-SF 1 7737.881 7675.981 7647.96 138.001 3060.54 2851.37 MinPts Kigun 1(Def Survey) Pass 5059.60 5057.12 5026.79 2042.98 168.37 168.37 MinPts 5059.65 5057.05 5026 84 1944.10 198.37 198.37 MinPt-O-EOU { 5060.01 5057.34 5027.201 1895.7211 296.46 296.45 MinPt-O-SF I 5060.1 5057.3 5027.2 1824.70 488.96 488,47 MinPts I 5060.1 5057.2 5027.39 1720.07 518.13 517.44 MinPt-O-EOU 5456.36 5438.36 5423.55 6• 2000.11 1869.10 MinPt-O-SF 6595.39 6578.32 6562.58 386.28 3319.76 3070.89 MinPt-O-SF i 6735.29 6717.89 6702.49 386.90 3396.65 3131.11 MinPt-O-SF 1 6782.72 6765.19 6749.91 386.90 3420.78 3149.48 MinPt-O-SF 7136.31 7118.00 7103.51, 3572.89 3258.86 MinPt-O-SF 7980.42 7957.96 7947.61 1=11NE 4126.00 3578.21 MinPt-O-SF r. I 6367. 6331.55 6314.51 186.85 4965.84 3934.39 MInPt-C1Ct 6367.3 6331.551 6314.511 186.82 4966.26 3934.51 MinPts ( 6374.99 6338.95 6321.81 185.931I 4988.28 3940.62 MinPt-O-SF 6380.90 6344.84 6327.69 185.981 4995.79 3942.66 MinPt-OSF 6799.52 6753.41 6731 171 152.811 6395.76 4094.91 MinPt-O-SF 6306.19 6248.08 6219.84 111.60 6927.34 4089.29 TD 6142.65 6082.80 6053.69 8868.38 4071.25 MinPt-OSF 6140.68 6080.88 605179 105.52 6874.80 4071.04 MInPt-O-ADP 6140.6 6080.88 6051.79 105.53 6874.99 4071.03 MinPt-O-EOU 6140.6 6080.88 6051.80 105.53 6875.17 4071.02 MinPtCtCt mma msznimmi=z3m 6763.28 4074.74 MinPts Tuvaaq ST 1(Def Survey) Pass 5059.60 5057.12 5026.79 2042.98 168.37 168.37 MinPts 5059.65 5057.05 5026.84 1944.10 198.37 198.37 MinPt-O-EOU 5060.01 5057.34 5027.2 1895.72 296.46 296.45 MinPt-O-SF 5060.1 5057.3 5027.2 1824.70 488.96 488.47 MinPts 5060.1 5057.2 5027.39 1720.06 518.13 517.44 MInPt-O-EOU 5773.43 5750.95 5740.6. 256.68' 2019.25 1885.54 MinPt-0SF 5803.67 5780.97 5770.5,- 2024.93 1890.44 MinPt-O-SF 8278.31 8233.36 8211.76 191.64 4483.18 3755.36 MinPt-OSF 7864.87 7822.13 7801.6.- 4567.53 3792.31 MinPt-O-SF 7531.06 7489.82 7470..,- 4643.66 3823.76 MinPt-O-SF 6717.88 6679.09 6660. ,.111.10E1. 4963.16 3933.63 MinPt-O-SF 6608.25 6571.8, 190.90 5098.51 3968.26 MinPt-O-ADP 6608.2'=MEE 6554.59 190.97 5099.31 3968.44 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 8 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct•Ct Ift)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6608.244 6571.90 6554.60 191.04 5100.10 3968.62 MinPt-CtCt 12495.66 12447.25 12423.9 267.7 3800.56 3399.44 MinPt-OSF 12783.50 12734.01 12710.1 267.7 3906.61 3457.98 MinPt-O-SF 12872.30 12822.47 12798. 267.77 3937.03 3474.77 MinPt-0SF 13051.43 13000.93 12976.56 267.76 3998.15 3508.50 MinPt-0SF 10837.77 10793.14 10771.7 253.71 1890.07 1775.36 MinPt-0SF 10689.20 10645.18 10624.1 253. 1901.34 1784.98 MinPt-0SF 10382.25 1033947 10319. 254. 1919.51 1800.47 MinPt-0SF 9562.30 9522.47 9503.51 252.1 1960.16 1835.09 MinPt-0SF 9421.57 9382.30 9363.6 252.1 1968.76 1842.40 MinPt-0SF 6799.52 6753.41 6731.17 152.81 6395.76 4094.91 MinPt-0SF I6398.011 6332.09 6299.93 99.46 7298.01 4051.89 MinPt.C1Ct 6398.'457 6331.6 8299.12 98.20 7330.89 4049.77 MinPt-0-EOU 6400.86 6332.2 6298.881 95.83 7408.66 4044.74 MinPt-O-ADP 8159.73 7953.65 7851.42 39.90 13628.82 3987.35 TD 19198.90 19150.14 19126.6 MI= 2364.26 2198.38 M1nPt-O-SF OP10-09(Def Survey) Pass MIMI MEM. 17812.96�� 14579.37 0.27 0.27 MinPts 17846 20IMME,. 17813.39 9525.86 168.65 168.65 MinPt-O-EOU 17846.22=EMI 17813 41 9069.40 209.48 209.48 MinPt-0-EOU 7846.19 17844.28 MUM 9323.55 216.30 216.30 MinPts 17259.99 17251.80 17227.18• ,•, 2519.72 2345,75 MinPt-O-SF 17243.53 17235.34 17210.7 =ME 2528.61 2354.23 MinPt-O-SF 17232.39 17224.20 17199.58®' 2534.42 2359.78 MinPt-O-SF 17228.08 17219.88 17195.27.MEIE 2536.48 2361.73 MinPt-O-SF 18208.48 16195.35 16175.67- 2661.34 2480.84 MinPt-O-SF 14324.47 14301.81 14291.67 675 46 2686.96 2505.23 MinPI-0-SF 9865.44 9581.95 9440.71 Man 5242.37 3996.83 MinPt-0SF 9903.82 9611.42 9465.71 33,98 6722.55 4076.31 TD 8349.06 8084.24 7952.321 31.641 2430.47 2260.89 MinPt-0SF 7582.55 7364.74 7257.31 35.28 2577.38 2400.75 MinPt-0-ADP 7581.15 7364.43 7257.57 35.46 2579.89 2403.15 MinPt-O-EOU 7578.59 7365.60 7260.66 36.10 2587.84 2410.74 MinPt-CtCt OP12-01(Def Survey) Pass I 17847.891 17845.55 17815.08 7625 411 200.32 200.32 MinPts 17849.84 17848,03 17817.03 9853.37 243.99 243.99 MinPt-0SF 17263.49 17255.29 17230.68 2154.90 2519.35 2345.39 MinPt-0SF 16356.81 16337.66 16324.01 879.83 2653.80 2473.66 MinPt-0SF 15431.80 15409.24 15398,99 718.87 2701.21 2518.79 MinPt-0SF 14149.00 14115.78 14100.63 466.82 2748.59 256373 TD 0107-04(Def Survey) Pass 17841.96 17840.15 17809.16 9838.55 243.66 243.66 MinPt-0-SF 17254.99 17246.80 17222.18 2154.91 2520.12 2346.13 MinPt-O-SF 16930.52 16915.67 16897.71 1167.83 2673.43 2492.36 MinPt-0SF r 9029.91 8931.48 8884.76 96.59 3061.93 2852.60 MinPts OPO4-07P51(Def Survey) Rams:7i :510• 17802.0 r 14570.43 -0.04 0.04 MinPts 17835.11 MEM 17802.30 10085.69 160.04 160.04 M1nPI-O-EOU 17835.1.Ma= 17802.34 9426.71 213.64 213.64 MinPt-O-EOU NEM 17833.26 IIII817.S1F 9514.10 216.38 216.38 MinPts 17835.73 17833.92 17802.9 9836.29 243.37 243.37 MinPt-0-SF 17248.92 17240.73 17216.11- 2520.41 2346.41 MinPt-O-SF 17231.28 17223.10 17198.4:- 2529.90 2355.45 MinPt-0-SF 17201.30 17193.14 17168.4•- 2548.33 2371.13 MinPt-0-SF 16188.30 16176.26 16155.4: 1416.89, 2663.06 2482.49 MinPt-OSF 13145.21 13122.30 13112.41 imasit 2776.51 2590.12 MinPt-0-SF 9035.48 8986.11 8964.15 Imam 2971.88 2771.59 MinPts OP08-04(Def Survey) Pass 17843.53 17841.72 17810.7. 9840.0• 243.65 243.65 MinPt-0-SF 17256.65 17248.46 17223.: =pm 2519.99 2346.00 MinPI-O-SF 16409.30 16395.75 16376.4'�"i, 2663.51 2482.92 MinPt-0-SF 13657.10 13634.18 13624.2'=MK 2807.53 2619.33 MinPt-OSF 11523.10 11495.42 11483.73 492.30 2849.34 2658.50 TD 11277.36 11249.89 11238.36 488.60 2849.27 2658.44 MinPt-0SF 0111-01(Def Survey) Pass 14580.68 0.15 0.15 MinPts 17845.6. :�, 9234.79 204.05 204.05 MinPts 17848.29 17846.48 17815.4: r:5• •, 243.63 243.63 MinPt-0SF 17261.69 17253.50 17228.8: 2154.60'. 2519.58 2345.61 MinPt-0SF 17228.33 17220.10 17195.5u...1W 2537.89 2363.07 MinPt-0SF 16458.37 16445.24 16425.56 MIMI 2658.79 2478.42 MinPt-0SF 11932.33 11908.82 11899.52® 2788.62 2601.54 MinPt-0SF 11662.35 11638.03 11828.40 605.40 2789.24 2602.12 TD Nikaitchuq 3PB1(Def Survey) Pass 1 7900.091 7898 150 786728 4067.72 52.20 52.20 MinPts 7900.30 7897.31 7867,50 2638.641 309.58 309.56 MinPt-0-SF 7854.73 7838.09 7821.9 472.001, 2001.09 1869.94 MinPt-0SF I 7040.13 7010.62 6997.01 258.51 4387.73 3711,08 MinPt-CtCt 7040.13 7010.62 6997.01 258.47 4388.11 3711.26 M1nPt-O-EOU 7040.14 7010.62 6997.01 258.44 4388.50 3711.45 MinPt-O-ADP 7088.06 7058.11 7044.21 254.981 4452.87 3741,58 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 9 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Den.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 7092.84 7062.69 7048.78 254.97 4455.75 3742.90 MinPt-O-SF 8848.95 8819.58 8805.78 320.53 4853.98 3827.87 TD I 8853.521 8824.151 8810.351 320.681 4653.96 3827.87 MinPts Oliktok Point 1-2(Def Survey) Pass I 17830.47' 17828.44' 17797.66 8781.94 200.07 200.07 MinPts 17832.40 17830.69 17799.59 10465.28 243.38 243.38 MinPt-0SF 17245.39 17237.29 17212.58 2178.15 2520.69 2346.68 MinPt-O-SF 16275.78 16253.40 16242.97 745.38 2633.24 2454.06 MinPt-O-SF 13982.33 13904.62 13867.10 186.32 2693.13 2511.11 TD 17831.50 17830.38 17798.69 15997.35 0.00 0.00 Surface OP03-P05(Def Survey) Pass 0111331111. 17831.9. 17800.5. 13084.84 90.20 90.20 MinPts 17833.4•M•;! 17800.68 9667.42 208.14 208.14 MinPt-O-EOU FNIZEM 17831.6 17800.67 9715.59 210.87 210.87 MinPts 17834.25 17832.44 1780145. 9834.23 243.64 243.64 MinPt-0SF 17248,80 17238.61 17213.99'_® 2520.82 2346.80 MinP60SF 17214.71 17206.53 17181.90 2156 69 2538.42 2363.58 MinPt-O-SF 16897.97 16882.29 16865.16® 2676.16 2494.96 MinPt-O-SF 16866. 16850.6- 1000.48 2695.55 2513.40 MinPts 16883. ' 16866.16 16850.73 991.69 2697,02 2514.81 MinPt-O-EOU 16905.12 16882.83 16872.31 769.97 2725.16 2541.53 MinPt-0SF 16074.70 16036.39 16018.12, 440.0 2834.90 2645.00 MinPt-0-SF 1 1027115 10207.131 10177.21 171.56 3078.65 2867.41 MinPts 0106-05(P9c)(Def Plan) Pess 17838.79 17836.98 17805.9•MIME 243.36 243.36 MinPt-0-SF 17252.17 17243.98 17219.36'.] 2520.13 2346.14 MinPt-0-5F 17216.33 17207.89 17183.5 I 2088.64 2539.63 2364.73 MinPt-0SF �..,�ESIMh. .;,', 2152.96 2557.55 2381.83 MinPts 17634.63 17616.98 17601.82.'..' 2680.35 2498.95 MinPt-O-SF 17721.42 17699.27 17688,61: 2700.23 2517.86 MInPt-O-SF 17829.96' 17781.64 17757.97 376.84 2772.68 2586.51 MInPt-CtCt 17832.64 17778.87 17752.47 337.77 337.77 2785.66 2598.75 MinPt-O-EOU 17836.48 17779.6 17751,71 319.28 2792.93 2605.59 MinPt-0-ADP 1 10472.99( 10354.53 10296.89 90.831 3207.95 2979.05 MinPts Nikaitchuq 1(Def Survey) Pass 803207 8029.40 7999. • 3003.46 297,22 297.21 MinPt-0-SF 7987.60 7970.98 7954.7•ME= 1998,93 1868.09 MinPt-0SF 7328.88 7312.95 231.03 4473.76 3751.11 MinPt-CtCt 7362.86 M2M5 7312.94 230.95 4474.55 3751.47 MinPt-0-EOU 7362.88 7328,87 MEM 230.87 4475.34 3751.82 MinPt-O-ADP 8302.69 8256.33 8234.0-I_ 4959.59 3932.61 MinPt-0SF 8543.07 8495,07 8471.! 5W' 5012.23 3947.05 MinPt-0SF 8893.02 8843.55 8819.7. 186.381 5079.09 3963.76 MinPt-O-SF 10584.28 1050768 1047026 NM= 5247.21 3997.43 MinPt-0-SF OP17-02(Def Survey) Pass 17859.98 17858.57 17827.17 12596.73 114.12 114.12 MinPts 17860.01 17858. 17827.20 12174.56 125.15 125.15 MinPt-O-EOU 77860.21 17858. 17827.40 9898.82 219.05 219.05 MinPts 17860.30 17858.49 17827.46 9889.24 225.36 225.36 MinPt-0-SF 17266.92 17258.75 17234.11 2162.03 2522.69 2348.58 MinPt-0SF 17281.59 17253.40 17228.78.. 2156.94 2525.63 2351.38 MinPt-0SF 16989.91 16968.36 16957.11 801.06 2650.79 2470.79 MinPt-0SF 16923.00 16900.69 16890. 2861.08 2480.60 MinPt-0SF 16501.22 16470.08 16455.29 557.95 2682.92 2501.40 TD 11324.93 11059.84 10927.79 42881 2388.59 2221.30 MinPt-0SF 10575.43 10359.11 10251.77 49.25 2516.57 2342.75 MinPt-0-ADP 10574.93 10359.00 10251.86 49.34 2517.34 2343.48 MinPt-0-EOU 1 10574.47 10359.71 10253.17 49.62 2519,64 2345.67 MinPt-CtCt OP05-06(Del Survey) Pass MEIM INIZERIE�.. 14571.68 0,14 0.14 MinPts 17836.5. 7834 80; 17803.71 10388.13 155.14 155.14 MinPt-0-EOU 17836.5• 17834.701 17803.78 9452.99 212.25 212.25 MinPt-O-EOU I8i*0L101 1783471, '®. 9550.20 214.98 214.98 MlnPts 17837.28 17835.47 17804.47 WIME. 243.65 243.65 MinP6OSF 17250.02 17241.83 17217.21 MEM 2520.54 2346.53 MinP1-0SF I .•'.i4 17183.0 .11130 1539.14 2569.14 2392.89 MinPts 17197.21 MUM 17164.40 1108.988'11 2579.47 240275 MinPt-O-EOU 17234.57 17215.68 17201.761 923 2626.97 2448.08 MinPt-O-SF 17314,43 17292.14 17281.621 784.22 2683.11 2501.57 M1nPt-O-SF 17510.86 17429.70 17389.621 218 41 2920.48 2724.51 MinPt-O-SF 16977.68 16898.69 16859.72 27-7-7-1 2943.03 2745.23 MinPt-O-SF 16719.35 16641.75 16603.52® 2950.98 2752.51 MinPt-0-SF 1 15895.55 15821.56 15785.28® 2979.00 2778.07 MinPt-0-SF 15521.92 15449.84 15414 561 215.961 2990.72 2788.71 MInPt-0-SF 15208.98 15137.75 15102 951 218.481 3000.95 2797.96 MinPt-0SF 15080.77 15009.82 14975.181 217.67 3005.20 2801.80 MinPt-O-SF 14883.70 14813.29 14778.971 216 75 3011.65 2807.62 MinPt-0-SF 14387.59 14320.96 14288.61 222 3.4 3031.44 2825.40 MinPt-O-SF 14108.81 14042.98 14011.0 221.16 3044.63 2837.19 MinPt-O-SF • 13816.60 13752.66 13721.76 223.52 3059.76 2850.68 MinPt-0-SF 13535.29 13472.66 13442.44 223.96 3075.89 2864.97 MinPt-0SF 13258.59 13196.71 13166. 3091.22 2878.49 MinPt-0SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 10 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 12810.74 12751.69 12723.3 225.76 3123.87 2907.06 MinPt-O-SF 12323.07 12266.95 12240.07 229.19 3168.51 2945.57 MinPt-O-SF ( 11139.861 11080.321 11051.62 194.03 3327.50 3077.07 MinPts 0113-03(66)(Def Plan) Pass 17854.61 17852.80 17821.8. 9846.251 243.33 243.33 MInPt-O-SF 17268.92 17260.72 17236.11=Eta 2518.76 2344.83 MinPt-O-SF 16781.08 16758.74 16748.27 2602.58 2424.81 MinPt-0SF 12032.70 11699.71 11533.7 MEER 4969.02 3935.28 MinPt-0SF 11978.41 11644.87 11479.5.MEM 4995.81 3942.67 MinPt-0SF 11823.91 11497.02 11334.06=EC 5077.86 3963.47 MinPt-0SF 11654.94 11332.93 11172.4.. 'r, 5159.85 3981.45 MinPt-O-SF 11533.25 11152.51 10962.64 30.37 9432.71 4046.83 TD 9844.03 9551.67 9405.99 33.781 2399.11 2231.23 MinPt-0SF 9109.36 8867.12 8747.22 37.98 2544.44 2369.32 MinPt-O-ADP 9107.351 8866.80 8747.77 38.25 2547.33 2372.08 M1nPt-O-EOU 1 9104.99 8869.28 8752 75 39.06 2555.31 2379.69 MInPt-CtCt OP08-04PB1(Def Survey) Pass 17843.53 17841.72 17810.72 9840 04 243.65 243.65 MinPt-0-SF 17256.65 17248.46 17223.8,MEM 2519.99 2346.00 MinPt-O-SF 16409.30 16395.75 16376.4-''MEM 2863.51 2482.92 MinPt-0-SF 13657.10 13634.18 13624.2.)jjjjjjj I 2807.53 2619.33 MinPt-0-SF 11523.10 11495.42 11483.72 492.25 2849.34 2658.50 TD 11281.63 11254.23 11242 73 489.97 2848.75 2657.95 MinPt-O-SF Oliktok Point I-2PB2(Def Survey) Pass 1 17830.471 17828.521 17797.6 917713 200.07 20007 MinPts 17832.40 17830.69 17799.5 10479.13 243.38 243.38 MinPt-0SF 17239.80 17231.50 17206.7 2179.1 2523.67 2349.52 MinPt-0-SF 16275.78 16253.42 18242.97 745.68 2633.24 2454.06 MinPt-0-SF 13982.33 13904.64 13867.13 186.34 2693.13 2511.11 TD 17831.50 17830.51 17798.69 18115.80 0.00 0.00 Surface OP17-02PB1(Def Survey) Pass 17859.9: 17858.4:.V81M' 11896.03 114.12 114.12 MinPts 17860.01• '5l t 17827.20 11608.55 125.15 125.15 MinPt-O-E0U 17860.30 17858.46 17827.49 9669. 213.60 213.60 MinPt-O-SF 1 17860.211 17858.311 17827.40 9709.74 219.05 219.05 MinPts 17860.30 17858.46 17827.49k 9699.66 225.36 225.36 MinPt-O-SF 17861.00 17859.18 17828.19 9848.98 243.60 243.60 MinPt-O-SF 17275.14 17266.94 17242.3= 2518.48 2344.56 MinPt-0SF 17266.92 17258.72 17234.11 2154.36 2522.69 2348.58 MinPt-O-SF 16989.91 16968.32 16957.11 799.52 2650.79 2470.79 MinPt-0SF 18926.47 16904.17 16893.67 2660.64 2480.18 MinPt-0SF 12934.56 12846.07 12502.32 44.99 6045.47 4073.65 TD 11632.93 11360.92 11225.41 42.921 2356,55 2191.13 MinPt-0SF 10624.60 10411.94 10306.48 50.37 2521.71 2347.64 MinPt-O-ADP 10624.12 10411.85 10306.60 50.46 2522.45 2348.35 MinPt-0-EOU 10623.77 10412.19 10307.30 50.63 2523.74 2349.58 MinP1-01C1 Oliktok Point I-1A-106(P5)(Def Plan) Pass 17830.78 17828.27 17797.971 243.60 243.60 MinPt-0SF 17243.66 17234.78 17210.8 MEM 2520.84 2346.81 MinPt-O-SF 17083.01 17060.51 17050.2.=an 2669.80 2488.90 MinP1-0SF MEM 17033.95 17020.86 651.84 2690.16 2508.28 MinPt-CtCt 17062. ' '� 17020.45 642.21 2691.75 2509.79 MinPt-0-EOU 17062.59 17033.7,.MIME 637.50 2692.53 2510.54 MinPt-O-ADP 13164.27 13018.49 12946.3 MIME 3241.99 3007.52 MinPt-O-SF MIIMES11930.64 11842.80 68.91 3418.31 3147.61 MlnPts Nlkeitchuq 3(Def Survey) Pass I 7900.09 7898.15 7867.28 4067.72 52.20 52.20 MinPts 7900.30 7897.31 7867.50 2638.64 309.58 309.56 MinPt-O-SF 7854.73 7838.09 7821.92 472.00. 2001.09 1869.94 M1nPt-0-SF 1 7040.13 7010.62 6997.01 258.51 4387.73 3711.08 MinPt-CtCt 7040.13 7010.62 6997.01 258.47 4388.11 3711.26 MinPt-0-EOU 7040.14 7010.62 6997.01 258.44 4388.50 3711.45 MinPt-0-ADP 7088.06 7058.11 7044.21 254.981 4452.87 3741.58 MinPt-0SF 7092.64 706269 7048.78 254.971 4455.75 3742.90 MinPt-0SF 9076.25 9046.34 9032.26 322.32 4652.36 3827.24 TD 9081.07WrillE 9037.0:�'I 4652.36 382724 MinPts 0119-08(P6)(Def Plan) Pass 17865.84 17864.02 17833.0 9852.47 243.30 243.30 MinPt-O-SF 17280.81 17272,60 17248...MIlMj1 2517.80 2343.91 MinPt-0SF 16748.49 16726.17 16715.68 764.29 2638.62 2459.19 MinPt-0SF 16414.46 16378.55 16361.36 477,47 2653.87 2473.73 TD 11736.35 11512.57 11401.201 52,69 2496.34 2323.47 MinPt-0-ADP 11736.04 11512.50 11401.27 52.75 2496.82 2323.93 MinPt-O-EOU 1 11735.76 11512.82 11401.89 52.89 2497.97 2325.02 MInPt-CtCt OP03-P05PB2(Def Survey) Paas 17833.31 17831. 17800. 13084.843 90.20 90.20 MinPts 17833.4 17831. 17800.68 9667.42 208.14 208.14 MioP1-0-EOU 17833. 17831. 17800.6 9715.59 210.87 21087 MinPts 17834.25 17832.44 17801. 9834.231 243.64 243.64 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 11 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17246.80 17238.61 17213.99 2155.38 2520.82 2346.80 MinPt-O-SF 17214.71 17206.53 17181.90 2156.89 2538.42 2363.58 MinPt-O-SF 16897,97 16882.29 16865.16 1102.29 2676.16 2494.96 Min%-O-SF 16883. 16866.22 16850.64 1000.46 2695.55 2513.40 MinPts 16883. 16866.16; 16850.73 991.67 2697.02 2514,81 MinPt-O-EOU 16905.12 16882.83 16872.31 769.9 2725.16 2541.53 MinPt-O-SF 16074.70 16036.38 16018.1. 440.. 2834.90 2645.00 MinPt-O-SF 1 12077.941 12027.551 12004.16 258.16 2971.27 2771.03 MinPts 0111-01PB1(Def Survey) Pass MMMT 17814.56 14580.68 0.15 0.15 MinPts MODE 17845 62MERE: 9234.79 204.05 204.05 MinPts 17848.29 17846.48 17815.': 9843. 3 243.63 243.63 MinPt-O-SF 17261.69 17253.50 17228.8,0-1HW 2519.58 2345.61 Min%ASF 17228.33 17220.10 17195.5.Inilli 2537.89 2363.07 MinPt-O-SF 16458.37 16445.24 16425.56- 2658.79 2478.42 Min%-O-SF 0000 12161.091MM 2787.16 2600.16 MinPts OP18-08 current(Non-Def Survey) Pass I 17861.04 17858.94 17828.23' 8517.33 200,09 200.09 MinPts 17276.90 17268.71 17244.09 2158.39 2518.31 2344.40 MinPt-O-SF 17078.21 17067.59 17045.40 1642.63 2573.94 2397.48 MinPt-O-SF 16305.20 16282.83 16272.39 747.29 2630.81 2451.75 MinPt-O-SF 15890.15 15857.78 15842.44 517.91 2637.74 2458.35 TD 12945.34 12741.99 12640.83 63.98 2517.09 2343.24 MinPt-O-SF 12938.75 12735.35 12634.25 63.9 2524.55 2350.35 MinPt-O-SF 12938.33 12735.13 12634.14 6405 2525.08 2350.86 Min%-0-ADP 12938.18 12735.09 12634.16 64.09 2525.38 2351.13 MinPt-O-EOU 1 12938.05 12735.29 12634.53 64.20 2526.01 2351.74 MinPt-CtCt OP23-W W 02(Def Survey) Pass 17872.36 17870.54 17839.55 MEMEM 243.56 243.56 MinP1-0-SF 17287.16 17278.95 17254.35=EC 2517.52 2343.65 MinPt-O-SF 17261.35 17253.14 17228.54 11.11111202530.98 2356.48 MInPt-OSF 17201.67 17193.52 17168.87 2168.98 2569.32 2393.06 MinPt-O-SF 17186.89 17178.76 17154.09 MMMT 2580.43 2403.67 MinPt-O-SF 17095.29 17086.89 17062.49 2104.4• 2614.64 2436.31 Min%-OSF 15279.35 15263.23 15246.55 MI= 2796.20 2608.67 Min%-OSF 13976.57 13953.49 13943.76 684.9 2924.10 2727.84 MinPt-O-SF 4 12394.65 12356.53 12339.94 373.56 3202.92 2974.81 MinPt-CtCt 12394.66 12356.531 12339.93 373.40 3203.38 2975.21 MinPts 13001.69 12963.13 12944.74 353.391 3384.01 3121.39 MinPt-O-SF 13028.50 12990.01 12971.58 353.44 3389.22 3125.40 TD 0P18-08(P11)(Def Plan) Pass Nimo M "rf M00oMi UMW 200.09 200.09 MinPts 17276.90 17268.71 17244.09 IMIEM 2518.31 2344.40 MinPt-O-SF 16339.03 16316.64 16306 22 MEME1 2633.99 2454.78 MinPt-O-SF 14640.75 14341.5'• 14192.42 49.09 5392.77 4016.60 MinPt-O-ADP 14638.8 MMM®'] 14192.72 49.33 5409.46 4018.20 MinPt-O-EOU 14637.89 14315.29 14154 49 45.51 6735.03 4075.76 TD 13310.86 13036.991 1290054d 48.77 2397.99 2230.17 MinPt-O-ADP 13309.6 13036.73 12900 78 48.95 2400.87 2232.89 MinPt-O-EOU 13308.61 13037.49 12902.43 49.28 2405.85 2237.59 MinPt-CtCt 12911.75 12689.07 12578.244 58.25 2515.80 2342.01 Min%-O-ADP 12908.98 12688.50 12578.81 58.83 2518.27 2344.37 MinPt-O-EOU 4 12906.79 12890.77 12583.36 60.08 2523.16 2349.03 MinPt-CtCt OP26-DSPO2(Det Survey) Peas 18062.96 18061.84 18030.151 16205.02 0.19 0.19 MinPts 18063.12 188061.34 18030.31 10152.89 202.64 202.64 MinPt-O-EOU 18061.3' 18030.30 10211.31 205.33 205.33 MiePte 18063.86 18062.16 18031.05 10602.9. 243.01 243.01 MInPt-O-SF 17478.97 17470.83 17446.16 MOMMO' '-.e' 2516.57 2342.75 MinPt-O-SF 17457.71 17449.57 17424.91 00000l' 12527.92 2353.57 MinPt-O-SF 17049.28 17039.46 17016.47 MOB 2812.91 2434.67 MinPt-O-SF 13407.42 13384.23 13374.61,M000000 2933.49 2736.48 MinPt-O-SF 4 13393.83 13370.08 13360.18 676.69 2953.33 2754.66 MinPt-CtCt 13393.83 13370.07 13360.17 676.27 2953.74 2755.04 MinPt-O-EOU 13393.85 13370.08 13360.17 675.84 2954.15 2755.42 MinPt-O-ADP 13502.89 13477.70 13466.85 621.994 3021.91 2816.85 MinPt-O-SF 13547.01 13522.01 13511.18 625.36 3034.54 2828.18 TD Oliktok Point I-2PB1(Def Survey) Pass 4 17830.471 17828.4.4 17797.66 8781.94 200.07 200.07 MinPts 17832.40 17830.69 17799.59 10465.28 243.38 243.38 MinPt-O-SF 17245.39 17237.29 17212.58 2178.151 2520.89 2346.68 MinPt-O-SF 16275.78 16253.40 16242.97 745.371 2633.24 2454.06 MinPt-O-SF 13700.38 13614.07 13572.33 164.08 2699.35 2517.02 TD 17831.50 17830.38 17798.69 15997.35 0.00 0.00 Surface 1 17830.470 17828.44 17797.661 8785 104 199.74 199.74 MinPts OP16-03(Def Survey) Pass 17859.40 17857.59 17826.5•, 9848.7• 243.56 243.56 MinPt-O-SF 17273.44 17265.23 17240.6 IMMO 2518.63 2344.70 MinPt-O-SF 17253.87 17245.63 17221.06 2144.68 2528.91 2354.51 Min%-OSF 16914.02 16891.69 16881.21 MIEN 2632.19 2453.06 Min%-0SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 12 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MDSft) I TVD(ft) Alert I Minor I Major 15483.48 15194.12 15049.93 15049.93 53.69 5935.74 4064.09 TD 14189.77 13923.93N 13791.501 53.57 2349.02 2184.06 MInPt-O-ADP 14189.6 13923 91 13791.53 53.59 2349.46 2184.47 MinPt-O-EOU I 14189. 13924.01 13791.73 53.63 2350.35 2185.31 MinPt-CtCt 13586.11 13383.28 13282.361 67.31 2505.68 2332.36 MinPt-O-ADP 13585.89 13383.23 13282.40 67.36 2505.97 2332.64 MinPt-0-EOU 1 13585.65 13383.43 13282.81 67.50 2506.68 2333.32 MinPt-CtCt OP05-06PB2(Def Survey) Pass 17836.36',�=Mg 14571.68 0.14 0.14 MinPts 17836.52 17834.80f- L 17803.71 10368.13 155.14 155.14 MInPt-O-EOU 17836.59 MI= 17803.78 9452.99 212.25 212.25 MinPt-O-EOU 17836 58 17834.71' '®r 9550.20 214.98 214.98 MinPts 17837.28 17835.47 17804.47 MIMI 243.65 243.65 MinPt-O-SF 17250.02 17241.83 17217,21e 17217.21.WIEM 2520.54 2346.53 MinPt-O-SF 17194.45' 17183.0 1539.14 2569.14 2392.89 MinPts 17197.21 EMU 17164.40 1108.98 2579.47 2402.75 MinPt-O-EOU 17234.57 17215.68 17201.7696 2626.97 2448.08 MinPt-OSF 17314.43 17292.14 17281.6 784.16' 2683.11 2501.57 MinPt-OSF 17510.86 17429.67 17389.5 (' 2920.48 2724.51 MinPt-O-SF 16977.68 16898.66 16859.66'- 2943.03 2745.23 MinPt-O-SF { 16719.35 16641.72 16603.47.- 2950.98 2752.51 MinPt-OSF 15895.55 15821.53 15785.22979.00 2778.07 MinPt-O-SF 15521.92 15449,80 15414.5*j 2990.72 2788.71 MinPt-0SF 15208.98 15137.71 15102.8'((((((( 4 3000.95 2797.96 MinPt-OSF 15080.77 15009.76 14975.1*IMMO 3005.20 2801.80 MinPt-O-SF 14883.70 14813.26 14778.91 MIMI 3011.65 2807.62 MinPt-O-SF 14387.59 14320.92 14288. ® 3031.44 2825.40 MinPt-0SF 14108.81 14042.94 14011.0 "MEE 3044.63 2837.19 MinPt-0-SF 13816.60 13752.62 13721.7.INS& 3059.76 2850.68 MinPt-OSF 13535.29 13472.62 13442.3,'Man 3075.89 2864.97 MinPt-0SF 13258.59 13196.88 13166.84 MEM 3091.22 2878.49 MinPt-O-SF 12810.74 12751.66 12723.27 an 3123.87 2907.06 MinPt-O-SF 12504.71 12447.99 12420.80® 3151.10 2930.63 MinPt-O-SF *11 11963.90® 3207.56 2978.72 MinPts OP22-W WO1(P2)(Def Plan) Pass 17870.73 17868.92 17837.9 '- 243.29 243.29 MinPt-O-SF 17285.99 17277.78 17253.1:- 2517.39 2343.52 MinPt-0SF 17235.85 17226.95 17203.. 1980.2. 2545.31 2370.15 MinPt-0SF MEM E:.MEM. 2129.11 2563.71 2387.71 MinPts 17505.22 17493.18 17472.4. 1470.0 2639.70 2460.22 MinPt-0SF 17668.62 17654.69 17635.81 2767,88 2581.97 MinPt-0SF 16996.20 16973.81 16963.3'11.1111G. 2865.41 2673.49 MinPt-O-SF 1 15174.93 15105.74 15072.19 226.10 3287.33 3044.75 MinPt-CtCt 15175.35 15105.36 15071.37 223.19 3296.70 3052.34 MInPt-0-EOU 15175.99 15105.50 15071.23 221.39 3302,40 3056.95 MinPt-O-ADP 15196.54 15120.71 15083.49 204.131 3355.93 3099.53 MinPt-0SF OP03-P05PB1(Def Survey) Pass MEM 17831.'' 17800. * 13084.84 90.20 90.20 MinPts 17833.4'MIUME. 17800.68 9667.42 208.14 208.14 MinPt-O-EOU MIM.: 17831.6' 17800.67 9715.59 210.87 210.87 MinPts 17834.25 17832.44 17801.451 9834.23 243.84 243.64 MinPt-0SF 17246.80 17238.61 17213.9'I- 2520.82 2346.80 MinPt-O-SF 17214.71 17206.53 17181.9* 215669 2538.42 2363.58 MinPt-O-SF 16897.97 16882.29 16865.16111111870 2676.16 2494.96 MinPt-O-SF j 16866.2. 16850.6' 1000.62 2695.55 2513.40 MinPts 16883. , 16866.1 16850.73 991.83 2697.02 2514.81 MinPt-O-EOU 16905.12 16882.84 16872.31 770.11 2725.16 2541.53 MinPt-0SF 16023.97 15985.57 15967.27 437.98 2837.88 2647.79 MinPt-0SF 1 15538.511 15498.761 15479.97 413 36 2869.34 2677.14 MinPts 0120-07(P12)(Def Plan) Pass 17867.47 17865.66 17834.67 9853.37 243.30 243.30 MinPt-O-SF 17282.54 17274.33 17249.73 2153.26 2517,66 2343.78 MinPt-OSF 17255.74 17247.38 17222.93 2113.2 2531.96 2357.42 MinPt-O-SF 17238.6 17230.4 17205.83 2163.00 2550.47 2375.08 MinPts 17238.6 17230,46 17205.83 2162.58 2550.81 2375.40 MInPt-0-EOU 17433.21 17413.52 17400.4* 892.812646.12 2466.34 MinPts 17424.56 17402.31 17391.7 788.831 2653.20 2473.09 MinPt-OSF .11=11 16425.80 1631154 72.88 6628.40 4082.63 MinP8-CtCt 16655.33 16425.45 16311 00 72.76 6647.46 4081.04 TD 15049.25 14853.7 77.36 2439.26 2269.22 MinPt-O-ADP 15049.2' 14756.49 77.36 2439.40 2269.35 MinPt-O-EOU MEM. 14853.75 14756.50 77.37 2439.67 2269.61 MinPt-CtCt 15069.78 14875.13 14778.3*01MR 2500,70 2327.62 MinPt-0SF !MEMSECOMM. 14760.76 77.67 2504.58 2331.32 MinPts 15053.68 14858.88 14761.97 MM= 2505.58 2332.27 MinPt-OSF 15015.26 14819.96 14722.80® 2517.10 2343.25 M1nPt-OSF 14226.07 14075.28 14000.70 95.36 2571.66 2395.30 MinPt-O-ADP 14225.62 '®'E 14000.80 95.60 2572.06 2395.68 MinPt-O-EOU IMMEM 14075.47 14001.35 95.95 2572.65 2396.24 MinPt-CtCt Nikaitchuq 2(Def Survey) Pass I15940.811 15938.901 15908.001 8315.95 13.45 13.45 MvnPts 15399.12 15376.65 15366.311 689.731 3830.25 3415.82 MinPt-0-SF 15111.18 15074.05 15056 581 432.371 4269.18 3652.79 MinPt-0SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 13 of 14 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft), Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15110.56 15073.61 15056.24 434.50 4276.12 3656.30 MinPt-O-ADP I 15110.521 15073.57 15056.18 434.46 4278.39 3857.44 MlnPts 15114.97 15077.44 15059.76_ 42T27 4304.82 3670.67 MinPt-O-SF 15147.42 15109.47 15091.53422.11 4344.08 3690.02 MinPt-O-SF 15161.72 15123.76 15105.75_ 421.79 4357.53 3696.56 MinPt-O-SF 15247.66 15208.82 15190.32 411.98 4397.88 3715.91 MinPt-O-SF 15930.09 15884.62 15862.77 364.45 4587.18 3800.61 MInPt-OSF 1621686 16169.89 16147.29 358.65 4634.67 3820.15 MinPt-O-SF 16314.68 16267.39 16244.6 358.2 4649.39 3826.05 MinPt-O-SF 16414.96 16367.39 16344.49 358.3 4663.60 3831.69 MinPt-O-SF 16581.481 16495.721 16453.73 197.38 4684.01 3839.66 MinPts 0018-08PB1(Def Survey) Pass U 17861 041 17858 94 17828 23 8517.33 200.09 200.09 MinPts 17276.90 17268.7' 17244.09 2158.39 2518.31 2344.40 MinPt-O-SF 16862.70 16848.47 16829.89 1215.35 2596.66 2419.16 TD I 17861.0411 17858.941 17828 2311 8521 4811 199,66 199.66 MinPts 011ktok Point I-1(Del Survey) Pass 17830.78 17828.27 17797.9711111118110351' 243.60 243.60 MinPt-O-SF 17243.66 17234.78 17210.8 1983.6 , 2520.84 2346.81 MinPt-O-SF 17080.33 17057.86 17047.5 769.42 2671.24 2490.28 MinPt-O-SF .15IMM 17034.41 17021.56 663.72 2690.16 2508.28 MinPt-CtCt 17062. -MEEMEE. 17021.17 654.09 2691.75 2509.79 MinPt-O-EOU 17062.59 17034.2 MEM. 649.37 2692.53 2510.54 MinPt-O-ADP 17695.45 17614.•'® 224 69 2878.69 2685.84 MinPt-O-ADP 17153.34 17064.44 17020.8:®. 2972.76 2772.39 MinPt-O-SF 16929.31=I= 2978.99 2778.06 MinPts 0P25-DSP01(61)(Del Plan) Pass 18067.35 18065.77 18034.54 11483.10 242.73 242.73 MinPt-O•SF 17483.19 17475.04 17450.38 2194.36 2516.03 2342.23 MinPt-O-SF 17320.63 17306.70 17287.82 1269.25 2681.44 2499.98 MinPts 17320.77 17306,57 17287.96 1245.45 2886.12 2504.44 MinPt-O-EOU 17444.79 17422.57 17411.9:MOM 2823.22 2634.06 MinPt-O-SF 17733.52 17704.17 17689.99 2936.77 2739.49 MinPt-O-SF OP05-06PB1(Del Survey) Pass 17836.361�mem= 14571.68 0.14 0.14 MinPts 17836.5.NEM 17803.71 10368.13 155.14 155.14 MinPt-O-EOU 17836.5' 17803.78 9452.99 212.25 212.25 MinP1-0-EOU BEM 17834.71 ME=5 9550.20 214,98 214.98 MinPts 17837.28 17835.47 17804.4 MIME 243.65 243.65 MinPt-O-SF 17250.02 17241.83 17217.21 MOE 2520.54 2346.53 MinPt-OSF 17183.07 1539.14 2569.14 2392.89 MinPts 17197.21 ME= 17164.40 1108.98 2579.47 2402.75 MinPt-O-EOU 17234,57 17215.68 17201.76''® 2626.97 2448.08 MinPt-O-SF 17314.43 17292.14 17281.62 2683.11 2501.57 MinPt-O-SF 18173.50 18092.98 18053.21 EMEM 2874.06 2681.54 MinPt-OSF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP18-N5\SP18-N5\SP18-N5(P3) 8/11/2011 1:15 PM Page 14 of 14 • Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP 18-N5 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule ®, = Date: August 10,2011 used:Minor Risk-Separation Factor !-u •:" North 0-800'md 350 0 10 34020 330`P1• - ; N4(30' i_ 40 320 SI -SE2(P.,, A „Agrees_40 35 .♦Ik. ,� - ,..... 1A11‘ gr 30 , ��• , �// ,'N1I•71lTiIra:4A P.'k.\-71No-4Iti,1l1lk*,,i11k.i04fl.f\_/4ip.. 50 ♦i t,1l"4ki,-‘4-s°-0' '''4.97.,l,%c.f.1'ii;.A,,t,k 'io,k\ir\IH4wn ,1).,..C ,...__l„iI.',','. 300 Z �\�'k / ' (‘‘\i 60 Q ,�� 290 N ,`.��` v 6 70 At41i. , t: 1114-N6('2 3 280 ` ►P.' kI _4\ ‘ 1ov,• ,,.► 80 270 /7O* `\ , \ 90 260 '\ fo1 \` 100 Il APA* I,.,fhpsr 250 , AIL \ -�_- 1,0 Wen Io 240 , i _ , 41iiø 120 230 fj4/.111109* 130 220 r 140 11.4/811111111111114#40 ,0 150 200 .1111 160 190 180 170 Well Ticks Type: MD on SP18-N5(P3) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=15.00 ft Schlumberger 1 TAYE,>NG CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP 18-NS Oriented EOU Dimension N Field: Nikaitchug Structure: Spy Island NoGo Region Anti-Collision rule . IP'' Date: August 10,2011 used:Minor Risk-Separation Factor h• North 0-800'md 350 0 10 340 VIIIISP:)2) 330 r. 30 , �■" `� •'��FN7(P2) 320 �� 108 40 .13-FN A r`l l .� a• -04-SE5(P2) . 17 - :'i:FN3(- ;,�'1,-Z, 0 %Pk,040 be° �- 310 , , ,; _ p• _�• ,50 ,r5, 9 N2(- saA •iii. 300 P22 F, (P2)' i ��,' e ` s�',`�A4111�.� �`��Oir �'�60 i "*.% 1111% `,: •Vl• �~� 's :�• •102-SE6 P2 290 i `.4 "i11.6...,..4,0114111,416. �� . •�� iitlAt� AIM *19. k . *- yam. ,,i ,-„ `�t1 �, 280 k. ' \ Silh�r ao �,�� i 7y'�/ ` \�.. �•` �`/i/� 1i I ,. ln.. .:fin\�,��`..'t'� �, y kV Me.r _ i ', 270 ..--,-,_..-_,-.,:„. .0. ,, ,,,,,,,,..„,k...,. '�, ,, i (;�. it �� ..441 ''�---*,•--c itt,,, I div i,.. watt. .11, .like:::., ; ,i •"wi,*.`+ia` iltIbv rrielW�'I//; 260 t 1 �.`4,Mt -:' Wi 4.-Wi i;,►// • .` 100 '< ' ,� 4!'i� . �mojr_ 250Ff ►� - f_ _ a 110 1p 'low : 411111111010+ 7 240 120 230 dit 414,..,,,o,0 130 220 140 210 150 204111111111111110160 190 180 170 Well Ticks Type: MD on SP18-N5(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum Well: SP 18-N5 NoGo Region EOU's based on: Oriented EOU Dimension N' Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rut: Date: August 10,2011 used:Minor Risk-Separation —marI Factor North 800- 13-3/8" 350 0 10 340 MOW20 330 30 140 320 !� 40 ��J III 120 1111rraPP. 310 �� . 50 tioif--0,,,. 1Wik ,...-4, 300Nok ,k 14' �144* "WWW ' - I„I' logrilt"!611P wi7iti • tlti‘‘..*V � P11 N7(P2) Millk‘Nk\ :ILO I 280 .�:..== � I �. /" • V , 410:1"-ii - 80 r.1a� �� , . . I,' ., • ��1,,� �� • e\ �� iii 270 ' , Jf��\��.�`��► �.'j�� \�ii4P 90 ilimillIlim '. :- I, r py. 260 1,��„�e iii ;ki �:��` . .. , , 11 � 100 411,90. , 250\ ‘‘*,4‘'s,' Ft.,- ►4 , •*ils 1,0 ��:I = ' J4 0. 11/ 240 �'w ,�� 120 230 4• j�, 130 224441111 140 210 150 200 i / 160 190 180 170 Well Ticks Type: MD on SP18-N5(P3) Calculation Method: Nominal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP 18-NS Oriented EOU Dimension N Field Nikaitchuq Structure: Spy Island oGo Region Anti-Collision rul: '- Date: August 10,2011 used:Minor Risk-Separation --mour' Factor North 13-3/8"-9-5/8" 350 0 10 340 VI Ill 20 330AI 30 140 320 �'� 40 (.- �s -.4901111i_ 120 310 2977 IT � 50 AN 300 44Ap _ 60 - a ' .4* .41V 10P1 290 ,4 �60 • 41111Pti, i ilk* 40tolipeo 280 80 elaraltb,S '*, 114-N6(P2) lainkli 2U270 ��.�` �-® ®- 90 11111.1PIS A,.11111141.01111111111111111 01.# 260 ° MWzt1‘111i..6m--1/4I ojel.b.h 1 0 °owe l.1 ��rg-- -.d1Weiicilinn1l1 � 04E, A4,A1lpwl o� i,04 250 .„ , t • 110 240 ,,4 .. r0d120 III* 11112111.P . 230 411**,130 41114! 220 k1/4414411 8 IV$ftj2-SE3(P2) 210 .... 150 200 160 190 180 170 Well Ticks Type: MD on SP18-N5(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP 18-N5 Oriented EOU Dimension Tf Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule Date: August 10,2011 - used:Minor Risk-Separation Factor 9-5/8"-TD North 350 0 10 340 20 330 30 0 140 of 320 �, iii 4 40 120 310 461 Ali 50 10 300 60 4 i 11110701 111 al 11114 1044 290 aPat 1pZIIIWINriqrlOdi 70 r 4(*h 280 L4)41118514illtatiW1147404‘04111111.11111111 ,414 41a 80 270 aimiregookr000saill 260OW ii.11111111PAISIVAIKVasihftleliall i ii* 4111701 lir I r 100 % Ifittill14 II la 250 s ,*At 0 4 0 110 oaIIII � Otiv 2404i610k 120 6. ...,,,,,„,„aiiiiii,„.. 230 ., 130 ., *tis 220 1111 140 210all 150 200 060 190 180 170 Well Ticks Type: MD on SP18-N5(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft sg N P C N \ _ ee w 0.. =O T. T. z !ID Wiz§ � Q ,.., m Lin o � � maiai. aa O K z a z \. . O? ;,°., :0,7 O., za F poc,> a m Y O m m 1- a N M a In l0 h Cg O z 0 1 !0 L, .g 0 . . n ea' io - W o a c\ F Fo o❑ N 2' JN m z �' J N .L7W am�/ OON W - I+, t 0 M O z e‘ N II g oo ra • m w d 16' a� - _ z 3 Em k La 1 s g s s P 2 Ido w R ik m 25 $ N j$ a SI', Dm LQ 0 8 ? �� w �o o o it 2 gRg gg x g�g R ' €� MIN) 1i__{.) _,_ --I—Ir - v/I of a 1 _ 1 E a ...._. it_ - k. ..'— t 1 a V 101-1 VI El SE 6 ; j " I O ;, . I, i -- 011111"11--- IS L e Icc ' e :j u .8/S S,fl I < 1 fr 1 8 0f% 4 So w k 5 t7, 8 h NNNN N A NI-NI,NIN-•-<D�� ID•-<O tD ID �(D In 01(1Q ONONOU)ONOU) € b LI 1- 6 3ItN MVVNIA(O(p h oD aD O(0)00�-�NNMMV V IA I0(O�h h co 00@ TO O•-,-NNMMV VIA IA ¢>.� rc a (o 00000tC0(Dt0(D00 h hI-rhrr r r r rr r A I`r r r r--r--00 a 000 cd 0000000000000000 42 � O 2pm o.co g g CI k E 0,g g C tl 61 p oK�x mE V��, UFNM V h NM(D 0O 0) - V h NM(D OO O) •- V (Dh aO O) •-NM V (D h N OO OA - M Hg m 12,;, :512 12 O N MM "2MM co MMMMa NiNi �IA(A IA IA V V V pa V V vj IA IA IA IA� l0 6 (O(0.510(D6 tO_hr-:r-: ` N N o= 3� IT 0 N 1 I m A y IC t C7 I i N —IA O NO M O 4 Oa OA V 03 Vh O)oOV rn g 00�V O V NMV W q NM WM W MhM 00 g DW MNM� NNNM LO 72.0. V V V V V V V V V V V 4 V V V V O V IA IAN v)IA IA 6 LO(A 666 N NNNdi N 66666 666 0 p N E i V 4(DN00m .-NM V IA(O N W 0)C 7 NI^').V Li?Lc:h 00 CA 7 N M'V IA t0h NO NM VIA(D h M. 3 � O O.O O O O O�O O 7 N N N N N N N N 2.�F co N00000000�Om O)O)O)��O)O)� I � • P3D 4 .N -- - — — --- cu < 1,.. o a n a a ww of yo • a u. Nm n g c,'= A 3 a 3 'o 1 Z O _I f- Q w J- W cc u..1`... N n m N Q O /1) t ww > C 1'4 r CO\ r .rte (f) tit 1111, th 0 . '1% 2 0 LL m co "mil earrellbk. 411\ o 8 V 0 @ • m ,_ z cu 0. 14 1 I 1 k 40[' 0 . 4 Lill 0 111_, • (-! 1 Okii,„„ ipm � _ a\ du viiiinire 4? 0 DO rk 4, 0 r_ Or ow' Z ai ty > d > d 76 co ci) L C >2 x in > 41 r • O00 2 t� v 0Xial Q j 0 d JQ � Y3 c z co � v o ectU � o u � � � � � fC = (0 N CCF 0 = E io R = io - m W O w O LU _ 0 � z � z N F- J To Q M = N M Cr ,■ 0 MI .CU Q m CD ca oo M �,- d - Schlumberger CemCADE*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : SP18-N5 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : Spy Island-Alaska Proposal No. : Draft v1 (P3) Service Point : Prudhoe Bay,Alaska Date Prepared : 08/16/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1©slb.com G ATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment.experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GNEN CONCERNING ACCURACY DR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. .Mark of Schlumberger Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2337.4 ft BHST : 36 degF Bit Size : 16 in ft (x 1000) psi Frac — — — -- Pore —Siltstone__ 1 o •••••Sandstone••••• o— - —Siltstone=_ i , , III . Mr — — cp o- ME - IIH ' Ii . H 0 0 ,_ Well Lithology Formation Press. Page 2 sp18-n5 cade v1 8-16-11.ctw:08-16-2011, LoadCase Surface Casing:Version wcs-cem462-12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 178.9 18.250 Landing Collar MD : 2257.4 ft Casing/liner Shoe MD : 2337.4 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2337.4 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16:000 in Mean Annular Excess : 206.8 % Mean OH Equivalent Diameter: 20.383 in Total OH Volume : 878.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1900.0 16.000 250.0 21.184 2337.4 16.000 35.0 16.822 Page 3 sp18-n5 cade v1 8-16-11 cfw,08-16-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Saili g' String : 13.375 District : Prudhoe Bay,Alaska Sailing' Country : USA Loadcase : Surface Casing Max. Deviation Angle : 32 deg Max. DLS : 4.517 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 160.0 0.000 100.0 100.0 0.0 160.0 0.000 200.0 200.0 0.0 160.0 0.000 300.0 300.0 1.5 160.0 1.500 400.0 399.9 4.0 160.0 2.500 480.0 479.6 6.0 160.0 2.500 500.0 499.4 6.5 159.0 2.510 600.0 598.5 8.9 155.7 2.500 700.0 696.9 11.4 153.8 2.503 800.0 794.5 13.9 152.5 2.494 900.0 891.0 16.4 151.6 2.500 1000.0 986.3 18.9 151.0 2.498 1100.0 1080.2 21.4 150.5 2.506 1200.0 1172.5 23.9 150.1 2.495 1300.0 1263.0 26.4 149.8 2.504 1400.0 1351.6 28.9 149.5 2.503 1402.1 1353.4 28.9 149.5 2.416 1500.0 1438.9 29.4 149.5 0.500 1600.0 1525.8 29.9 149.5 0.500 1700.0 1612.2 30.4 149.5 0.500 1800.0 1698.3 30.9 149.5 0.500 1900.0 1783.8 31.4 149.5 0.500 1981.7 1853.4 31.8 149.5 0.502 2000.0 1869.0 31.1 148.6 -4.517 2100.0 1956.1 27.6 143.0 -4.504 2200.0 2046.0 24.3 135.9 -4.500 2300.0 2138.2 21.4 127.0 -4.496 2337.6 2173.3 20.5 123.0 -4.509 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 755.0 11.32 8.43 SV-4 Siltstone 1144.0 11.40 8.43 SV-3 Sandstone 1430.0 11.50 8.43 SV-2 Siltstone 1900.0 11.80 8.43 Permafrost Base Shale 2003.0 12.00 8.43 SV-1 Sandstone 2338.0 12.50 8.43 TD Shale Page 4 sp18-n5 cade v1 8-16-11 cfw:08-16-2011, LoadCase Surface Casing:Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Scilimerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1783.8 32 -1.6 2338.0 2173.7 36 -1.1 • ft degF OII 30 35 40 4`5 50 55 60 65 70 7I I I \ I5 80 8I5 - Geoth.Profile -Tubular Fluids -Annulus -O O- en O_ 0 O O_ U) O O_ 0 N O 0 to N— Temp. Profile At 193 min Page 5 sp18-n5 cade v1 8-16-11.cfw;08-16-2011. LoadCase Surface Casing.Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Original fluid Mud 9.50 lb/gal k: 8.28E-2 Ibf.s^n/ft2 n :0.262 Ty: 0.48 Ibf/100ft2 Displacement Volume 338.0 bbl Total Volume 974.3 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 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Lead Slurry 463.7 1837.4 0.0 10.70 k:1.83E-1 lbf.s^n/ft2 n:0.216 Ty:12.28 Ibf/100ft2 12.5 DeepCRETE 72.6 500.0 1837.4 12.50 k:1.58E-2 Ibf.s^n/ft2 n:0.788 Ty:7.69 Ibf/100ft2 Mud 338.0 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48Ibf/100ft2 Static Security Checks: Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2030 psi at 2257.4 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton Float Valve Diff Press 165 psi Page 6 sp18-n5 cede v1 8-16-11 cfw,OB-16-2011; LoadCase Surface Casing,Version wcs-cenr462_12 Client : Eni Petroleum Well : SP18-N5 scil��r��r String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well :SP18-N5 String : 13.375"Surface Casing District : Prudhoe Bay,Alaska Country : USA lb/gal ft o 8 9 10 11 12 13 -Hydrostatic -Mn.Hydrostatic —Max.Dynamic —Mn.Dynamic —Frac o —Pore O— In o N 0 O_ Y � U r O R ! Q Fluid Sequence Dynamic Well Security ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 lbf/100ft2 3 Lead Slurry 463.7 bbl 10.70 lb/gal Herschel:k=1.83E-1 Ibf.s^n/ft2 n=0.216 Ty=12.28 lbf/100ft2 ■12.5 DeepCRErE 72.6 bbl 12.50 lb/gal Herschel:k=1.58E-2 Ibf.s^n/ft2 n=0.788 Ty=7.69 lbf/100ft2 ■Mud 338.0 bbl 9.50 lb/gal Herschel:k=8.28E-2 Ibf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 2337.4 ft Top of Cement= 0.0 ft *Mark of Schlumberger S r Page 7 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 2.0 0.0 80 Line Up Cement Unit Lead Slurry 5.0 463.7 92.7 463.7 80 Mix&Pump Lead Slurry(3-7 BPM) 12.5 DeepCRETE 4.0 72.6 18.2 72.6 80 Mix&Pump Tail Slurry(2-6 BPM) Pause 0.0 0.0 1.0 0.0 80 Shut Down Pumping Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Kick Out Plug w/Cement Unit Pause 0.0 0.0 3.0 0.0 80 Line Up Rig Pumps Mud 8.5 310.0 36.5 320.0 80 Displace Casing Mud 5.0 13.0 2.6 333.0 80 Start Slowing Rate Mud 2.0 5.0 2.5 338.0 80 Bump Plug Shut-In 0.0 0.0 5.0 0.0 80 Bleed Off&Check Floats Total 03:07 hr:mn 974.3 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 0 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2030 psi at 2257.4 ft Burst 4798 psi at 0.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 77 degF Simulated BHCT 76 degF Max HCT Depth 2337.4 ft CT at TOC 71 degF Max HCT Time 02:47:54 hr:mn:sc Static temperatures : At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 71 degF 60 degF Bottom Hole (degF) 76 degF 36 degF Page 8 sp18-n5 cade v1 8-16-11.cfw:08-16-2011: LoadCase Surface Casing:Version wcs-cem462_12 • Client : Eni Petroleum Well : SP18-N5 Sallie" String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD Modeled at Shoe: o Depth= 2337 ft cd u N rOHydrostatic Dy narnic -Frac L� Pore r 1q in d �- O eq O Li u) of 0 o) to cid' O cd O 20 40 60 80 100 120 140 160 180 200 Time (min) ECD Modeled at Conductor Shoe: Depth= 160 ft o � -Hydrostatic -Dynamic in Frac Ci- Pore iffO 0O- y of O w- inc O cd O 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 ScIimberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing BHCT Model: R I o First Sack Temp. _Kl Ea- -Last Sack Temp. (S W- -8 0 if A O ife- _8 --( r_ _8 N N F- -8 N R M 0 30 60 90 120 150 180 210 Time(min) Surface Pressure: Calc.Pump Press. g Cala CemHP §D _/1r - 8- —— /- 0 iI I T 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 10 sp18-n5 cade v1 8-16-11.cfw,08-16-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schilling String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 2337 ft 0 Out Q h r- co- \-----r...."-Vy- \- -- v- m- N1 — .1111 O 20 40 60 80 100 120 140 160 180 200 Time (min) Annular Velocity: --- Depth= 2337 ft_-- p Annular Velocity W- I- 8- lq I 0 0 L I -T I I 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 11 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; loadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 lb/gal Rheo. Model : HERSCHEL_B. k : 8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n : 0.262 Ty : 0.481bf/100ft2 Gel Strength : 6.40 lbf/100ft2 MUD Mud Type :WBM Job volume : 338.0 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water : 96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 lbf.s^n/ft2 At temp. :65 degF n : 0.420 Ty : 13.04 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 : 1.83E-1 Ibf.s^n/ft2 At temp. : 72 degF n : 0.216 Ty : 12.28 lbf/100ft2 Gel Strength : 13.78 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 10.367 gal/sk Job volume :463.7 bbl Dry Density : 106.26 lb/ft3 Yield : 2.33 ft3/sk Quantity : 1118.88 sk Sack Weight : 100 lb Solid Fractioff T 4U % BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.367 gal/sk Page 12 sp18-n5 cade v1 8-16-11.cfw,08-16-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing 12.5 DeepCRETE DESIGN Fluid No: 6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.58E-2 lbf.s^n/ft2 At temp. : 70 degF n :0.788 Ty : 7.69 lbf/100ft2 Gel Strength : 36.82 lbf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :4.736 gal/sk Job volume : 72.6 bbl Dry Density : 116.59 lb/ft3 Yield : 1.50 ft3/sk Quantity :271.94 sk Sack Weight : 100 lb Solid Fraction : 57yo BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :4.736 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Annulus ID : 13.375 in-OD : 16.000 in O --- 12.5 DeepCRETE Lead Slurry — MUDPUSHII O—— Mud O r O IE O I I 1 1 1 1 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 (bbl/min) Page 13 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2317.4 ft Casing Shoe :2337.4 ft NB of Cent. Used :33 NB of Floating Cent. :33 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 2017.4 25 1/2 NW-TR-13 3/8-8-TR 3 W304 13.1 357.4 2337.4 8 1/1 NW-TR-13 3/8-8-TR 3 W304 75.7 2017.4 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 ft 0 20 40 60 80 100 f u Betw een Cent. +At Cent. L O +t LoO H ++ 1+ i+ 8 O t t O O ++ � 1F t O — [ + + o is _ q O Well Pipe Standoff Page 14 sp18-n5 cads v1 8-16-11.cfw;08-16-2011; loadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: WeIICLEAN II 0,0 cyoft 0 50 100 0 20 40 60 80 100 c) -1 K - - - Std Betw.Cent. Mud Contarrmation _ _ — Cement Coverage Uncontaminated Slurry s, g 1 `1 §- . ___v‘? N- Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° g g 0 g a G 200- 200 200 200 400- T 400 400 400 BOG- 800 BOG Boo 800- 800800 800 4. 100G- 1000 . 1000 1000 Z, O. 1200- 1200 a a 1200 1200 a c 1400- 1400 0 a 1400 1400 8 1600- 1600 1604 1600 1600- 1800 1600 -- 1800 2000— 2000 2000 2000 2200-*' 2200 2200 2200 6 'f m 6 # a 2 a a p a 0 0 2 11111 Mud = Lead Slurry I I High <4 Low 12.5 DeepCRETE MUDPUSH II I I Mechun-i I I None Page 15 sp18-n5 cede v1 8-16-11.cfw,08-16-2011: LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schloberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name B809 1118881b 1119 sack 100lb D972 27194 lb 272 sack 100 lb D182 552 lb 23 sack 251b D047 20.0 gal 5 can 5.0 gal D031 9537 lb 87 sack 110 lb D046 54 lb 9 sack 50 lb D065 68 lb 2 sack 50 lb D167 68 Ib 3 sack 251b D153 271b 2 sack 251b Mix Water Requirements : Fresh water 399 bbls MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer Lead Slurry Volume :463.7 bbl Density : 10.70 lb/gal Yield : 2.33 ft3/sk Dry Phase Liquid Phase Blend: 111888 lb Design Mix Water 276.2 bbl 10.0 bbl LAS Design B809(100 lb 111888.125 lb Fresh water 276.187 bbl 10.001 bbl 12.5 DeepCRETE Volume : 72.6 bbl Density : 12.50 lb/gal Yield : 1.50 ft3/sk Dry Phase Liquid Phase Blend: 27411 lb Design Mix Water 30.7 bbl 10.0 bbl LAS Design D972 27193.779 lb Fresh water 30.662 bbl 10.001 bbl D046 54.388 lb 0.200%BWOB D065 67.984 lb 0.250%BWOB D167 67.984 lb 0.250%BWOB D153 27.194 lb 0.100%BWOB Page 16 sp18-n5 cade v1 8-16-11.cfw;06-16-2011; LoadCase Surface Casing;Version wcs-cem462_12 Schlumberger CemCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : SP18-N5 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : Spy Island Proposal No. : Draft v1 (P3) Service Point : Prudhoe Bay,Alaska Date Prepared : 08/16/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1@slb.com �S�G,N 4 n ` � I F 117L -9�URi'E Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 6171.0 ft BHST : 73 degF Bit Size : 12 1/4 in ft (x 1000) psi 0 2 3 - — — - - - ,—Poae SIItStone —Pore o _ ■ o— •Sandstone ' ' 'Sandstone• EMIG • ' ■ o - Coal M 11111101111111 - Coal IIII o o- O - IMIIRO O_ 1. O - O -4 O— U? - • • 'Sandstone. • o II 0 0 o - 0 o - t~- Well Lithology Formation Press. Page 2 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 ScSIolirpr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2337.0 13 3/8 68.0 12.415 Landing Collar MD : 6089.0 ft Casing/liner Shoe MD : 6169.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 6169.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 HYD 563 Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.370 in Total OH Volume : 594.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 6169.0 12.250 50.0 13.371 617t0 12.250 0.0 12.250 Page 3 sp18-n5 cade v1 8-16-11.cOw:08-16-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 String : 9-5/8 District : Prudhoe Bay,Alaska Sahli" Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Max. Deviation Angle : 85 deg Max. DLS : 4.519 deg/100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 160.0 0.000 100.0 100.0 0.0 160.0 0.000 200.0 200.0 0.0 160.0 0.000 300.0 300.0 1.5 160.0 1.500 400.0 399.9 4.0 160.0 2.500 480.0 479.6 6.0 160.0 2.500 500.0 499.4 6.5 159.0 2.510 600.0 598.5 8.9 155.7 2.500 700.0 696.9 11.4 153.8 2.503 800.0 794.5 13.9 152.5 2.494 900.0 891.0 16.4 151.6 2.500 1000.0 986.3 18.9 151.0 2.498 1100.0 1080.2 21.4 150.5 2.506 1200.0 1172.5 23.9 150.1 2.495 1300.0 1263.0 26.4 149.8 2.504 1400.0 1351.6 28.9 149.5 2.503 1402.1 1353.4 28.9 149.5 2.416 1500.0 1438.9 29.4 149.5 0.500 1600.0 1525.8 29.9 149.5 0.500 1700.0 1612.2 30.4 149.5 0.500 1800.0 1698.3 30.9 149.5 0.500 1900.0 1783.8 31.4 149.5 0.500 1981.7 1853.4 31.8 149.5 0.502 2000.0 1869.0 31.1 148.6 -4.517 2100.0 1956.1 27.6 143.0 -4.504 2200.0 2046.0 24.3 135.9 -4.500 2300.0 2138.2 21.4 127.0 -4.496 2337.6 2173.3 20.5 123.0 -4.509 2400.0 2232.0 19.2 115.8 -4.493 2500.0 2326.8 17.8 102.2 -4.503 2600.0 2422.2 17.4 87.3 -4.500 2700.0 2517.4 18.1 72.7 4.498 2800.0 2612.0 19.8 59.9 4.501 2900.0 2705.3 22.3 49.4 4.500 3000.0 2796.8 25.3 41.1 4.501 3100.0 2885.9 28.7 34.6 4.498 3200.0 2972.0 32.3 29.3 4.503 3300.0 3054.6 36.2 25.1 4.496 3400.0 3133.3 40.1 21.5 4.501 3500.0 3207.5 44.1 18.5 4.503 3600.0 3276.7 48.2 16.0 4.493 3700.0 3340.6 52.4 13.7 4.502 3798.8 3398.0 56.5 11.7 4.505 3800.0 3398.7 56.5 11.7 0.000 3900.0 3453.9 56.5 11.7 0.000 4000.0 3509.1 56.5 11.7 0.000 4020.6 3520.5 56.5 11.7 0.000 4100.0 3563.8 57.3 7.5 4.496 4200.0 3616.8 58.6 2.5 4.498 4300.0 3667.8 60.1 357.5 4.505 4400.0 3716.4 61.7 352.7 4.503 4500.0 3762.4 63.5 348.1 4.496 4600.0 3805.4 65.5 343.6 4.497 Page 4 sp18-n5 cede v1 8-16-11.cfw;08-16-2011; LoadCase 9-5/8 Intermediate Casing lal;Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4700.0 3845.3 67.6 339.2 4.499 4800.0 3881.6 69.8 335.0 4.504 4900.0 3914.4 72.1 330.9 4.500 5000.0 3943.2 74.4 326.9 4.504 5100.0 3968.0 76.9 323.0 4.497 5200.0 3988.6 79.4 319.2 4.502 5300.0 4004.9 81.9 315.4 4.496 5400.0 4016.7 84.5 311.7 4.497 5419.5 4018.5 85.0 311.0 4.519 5500.0 4025.5 85.0 311.0 0.000 5600.0 4034.2 85.0 311.0 0.000 5700.0 4042.9 85.0 311.0 0.000 5800.0 4051.6 85.0 311.0 0.000 5900.0 4060.4 85.0 311.0 0.000 6000.0 4069.1 85.0 311.0 0.000 6100.0 4077.8 85.0 311.0 0.000 6119.5 4079.5 85.0 311.0 0.000 6169.5 4083.8 85.0 311.0 0.000 6171.0 4084.0 85.0 311.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 755.0 11.00 8.43 SV-4 Siltstone 1144.0 11.20 8.43 SV-3 Sandstone 1430.0 11.50 8.43 SV-2 Siltstone 1900.0 11.80 8.43 Permafrost Base Sandstone 2003.0 12.00 8.43 SV-1 Shale 2347.0 12.30 8.43 Ugnu Top(UG4) Coal 2972.0 12.50 8.43 UG-2 Coal 3845.0 12.50 8.43 Lower Ugnu Shale 4663.0 12.50 8.43 Schrader Bluff Coal 4805.0 12.50 8.43 N Seq Top Sandstone 4949.0 12.50 8.43 N Sand Top Sandstone 5082.0 12.50 8.43 N Sand Bottom Sandstone 5502.0 12.50 8.43 N Seq Base Sandstone 6036.0 12.50 8.43 OA Sand Top Shale 6126.0 12.50 8.43 OA Sbl 2 Sandstone 6171.0 12.50 8.43 TD Sandstone Page 5 sp18-n5 cade v1 8-16-11.cfw,08-16-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 ScIimberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1783.8 32 -1.6 6171.0 4084.0 73 0.3 ft degF 30 35 40 45 50 55 60 65 70 75 80 85 - Geoth.Ftofile -Tubular Fluids -Annulus O - O O r- O - O_ N pO - O- M O - O_ O - - O - O O Lo - O - O a- ce LO O - O _ O Temp. Profile At 125 min Page 6 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 3949'(1,000' above the"N"Top) Original fluid Mud 9.30 Ib/gal k : 5.97E-3 Ibf.s^n/ft2 n :0.616 Ty: 8.86 lbf/100ft2 Displacement Volume 461.7 bbl Total Volume 723.7 bbl TOC 3946.8 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 3110.2 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 DeepCRETE 192.0 2222.2 3946.8 12.50 k:8.96E-3 lbf.s^n/ft2 n:0.903 Ty:19.28 Ibf/100ft2 Mud 461.7 0.0 9.30 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 418 psi at 2748.0 ft Pore 116 psi at 2748.0 ft Collapse 2483 psi at 6089.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 65 ton Float Valve Diff Press 136 psi Page 7 sp18-n5 cade v1 8-16-11.cfw,08-16-2011: LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 ScI��r�ir String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client : Eni Petroleum Well :SP18-N5 String :9-5/8" Intermediate Casing District :Prudhoe Bay,Alaska Country :USA ft lb/gal 0 8 9 10 11 12 13 - -Hydrostatic -Mn.Hydrostatic -Max.Dynamc §_ -Mn.Dynamic -Frac -Pore O - „1 _ $ N E - m • O M - r, O O g_ \ \ 5%) ^z • o_ N 54, O O r_ td Fluid Sequence Dynamic Well Security 7:3 ■MUDPUSH II 70.0 bbl 10.50 b/gal Herschel:k=5.23E-2 Ibf.s^n/ft2 n=0.324 Ty=12.92 bf/100ft2 ■DeepCRErE 192.0 bbl 12.50 lb/gal Herschel:k=8.96E-3 Ibf.s^n/ft2 n=0.903 Ty=19.28 Ibf/100ft2 ■Mud 461.7 bbl 9.30 lb/gal Herschel:k=5.97E-3 Ibf.s^n/ft2 n=0.616 Ty=8.86 Ibf/100ft2 Total Depth = 6171.0 ft Top of Cement= 3946.8 ft *Mark of Schlumberger Sdimlirpr Page 8 sp18-n5cadev18-16-11.cfw;08-16-2011: LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA 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 Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Line-up Cement Unit DeepCRETE 5.0 192.0 38.4 192.0 80 Mix&Pump Cement Slurry(3 to 7 BPM) Pause 0.0 0.0 2.0 0.0 80 Shut down pumping Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Mud 8.0 10.0 1.3 10.0 80 Kick-Out Plug w/Cement Unit Pause 0.0 0.0 3.0 0.0 80 Line Up Rig Pumps Mud 8.5 431.7 50.8 441.7 80 Displace Casing Mud 5.0 10.0 2.0 451.7 80 Begin Slowing Rate Mud 3.0 10.0 3.3 461.7 80 Bump Plug Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 02:03 hr:mn 723.7 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 327 psi at 6171.0 ft Pore 116 psi at 2748.0 ft Collapse 2367 psi at 673.2 ft Burst 4536 psi at 0.0 ft Temperature Results BHCT 76 degF Simulated Max HCT 73 degF Simulated BHCT 65 degF Max HCT Depth 0.0 ft CT at TOC 66 degF Max HCT Time 01:58:26 hr:mn:sc Static temperatures At Time (hr:mn) 00:01 hr:mn Geo.Temp. Top of Cement (degF) 66 degF 63 degF Bottom Hole (degF) 65 degF 73 degF Page 9 sp18-n5 cade v1 8-16-11.cfw,08-16-2011: LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD Modeled at the Shoe: Depth= 6169 ft c4 O_ Hydrostatic -Dynamic -Frac O Fore - O O cd- 0 � cd- • I O 20 40 60 80 100 120 140 Time(min) ECD Modeled at the Surface Shoe: Depth= 2338 ft Fluids at 6169 ft 0 N- Hydrostatic - Dynamic Frac Fore O rn O 03- 0 of In od O cd O 20 40 60 80 100 120 140 Time(min) Page 10 sp18-n5 cade v1 8-16-11 cfw;08-16-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcscem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : LISA Loadcase : 9-5/8 Intermediate Casing(a) BHCT Temperature Model: - O First Sack Temp. IF Last Sack Temp. I CS 0 Ii IP- -8 vs F- r rg- OD OD- 8 8 _ - o 20 40 60 80 100 120 140 Time (min) Surface Pressure: v ' Calc.Pump Press. Calc.CemHP CV O g CO - d / i i°3- r C3- CV Cr /11---: O 0 20 40 60 80 100 120 140 Time (min) Page 11 sp18-n5 cade v1 8-16-11.cfw,08-16-2011. LoadCase 9-5/8 Intermediate Casing(al.Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 kindlier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Returns Rate: Fluids at 6169 ftco -0 Out -0 In t`- (0- ia1 i 1� _ i M- — N- N \I 0 - i 0 20 40 60 80 100 120 140 Time (min) Annular Velocity: Depth= 6169 ft Annular Velocity 8- C� i i --., Ir- 1 0 I 0 20 40 60 80 100 120 140 Time(min) Page 12 sp18-n5 cade v1 8-16-11.cfw;08-16-2011, LoadCase 9-5/8 Intermediate Casing Cal:Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :6149.0 ft Casing Shoe :6169.0 ft NB of Cent. Used :27 NB of Floating Cent. :27 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 4449.0 0 0/0 0.0 4419.2 5329.0 22 1/1 HYDROFORM HFD 0.0 5311.3 5969.0 0 0/0 0.0 5329.0 6169.0 5 1/1 HYDROFORM HFD 0.0 5986.7 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) (Ibf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford i'I N.A. N.A. N.A. ft 0 20 40 60 80 100 • < D Q Between Cent. + +At Cent. O -O_ O O - ' O O N O - ' O M - O - O O O - O O O - O (C - O - O O Well Pipe Standoff Page 13 sp18-n5 cade v18-16-11.cfw;08-16-2011; Loadcase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k : 5.97E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.616 Ty : 8.861bf/100ft2 Gel Strength : 32.02 Ibf/100ft2 MUD Mud Type :WBM Job volume :461.7 bbl Water Type : Fresh VOLUME FRACTION Solids : 6.0% Oil : 1.0 % Water : 93.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 lbf.s^n/ft2 At temp. : 65 degF n : 0.324 Ty : 12.92 lbf/100ft2 Gel Strength : 40.56 Ibf/100ft2 Job volume : 70.0 bbl DeepCRETE DESIGN Fluid No: 7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 8.96E-3 lbf.s^n/ft2 At temp. : 50 degF n : 0.903 Ty : 19.28 lbf/100ft2 y Gel Strength : 58.20 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :4.735 gal/sk Job volume : 192.0 bbl Dry Density : 116.59 lb/ft3 Yield : 1.50 ft3/sk Quantity : 718.98 sk Sack Weight : 100 lb Solid Fraction : 57.8% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 4.735 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Page 14 sp18-n5 cade v1 8-16-11.ctw:08-16-2011, LoadCase 9-5/8 Intermediate Casing(a).Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 SChIinkerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Fluid Rheology Profiles: Annulus ID: 9.625 in Flow Rate : 8.5 bbl/min DeepCRE1E - MUDPUSH I -Mud r g 8 8— g— I I I I I I I 12.2 12.3 12.4 12.5 12.6 12.7 12.8 12.9 13.0 13.1 13.2 13.3 Annulus OD (in) Annulus ID: 9.625 in-OD: 12.250 in - DeepCRETE - MUDPUSHII - Mud — 8— W— I I I I I I I I I I I I I 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bbbmin) Page 15 sp18-n5 cade v1 8-16-11.cfw;08-16-2011; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 IT . Client : Eni Petroleum Well : SP18-N5 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: WeIICLEAN II R I _ 0 50 Cement .Cent.100 0 UMncontamna O 6080 100 d1 Slurry } I Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall I 1 4000- III. -4000 4000- -4000 4200- -4200 4200- •j ! -4200 4400- -4400 4400- `.,., ,..R,�"1 -4400 4800- -4500 4600- -4600 4800- -4800 + t 4500- -4800 5000- -5000 s s 5000- -5000 r 0 5200= -5200 0 5200_ -5200 0 5400 54005440 -544G 5600- -5600 5600- ? -5500 5500- -5800 5500- -5800 6000- 76000 6000- -6000 • i2 0 0 0 2 2 MI Mud I I High = Low Ii DeepCRETE I I Medium II I None (--1 MUDPUSH II Page 16 sp18-n5 ode v1 8-16-11.ciw,08-16-2011, LoadCase 9-5/8 Intermediate Casing(al.Version wcs-cem462_12 Client : Eni Petroleum Well : SP18-N5 Schlobergcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 718991b 719 sack 1001b D182 382 lb 16 sack 251b D046 157 lb 4 sack 50 lb D031 8199 lb 75 sack 110 lb D065 180 lb 4 sack 50 lb D167 180 lb 8 sack 251b D153 721b 3 sack 251b Mix Water Requirements : Fresh water 145 bbls MIXING PREPARATION MUDPUSH II Volume :70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.747 bbl D182 382.481 lb 6.000 lb/bbl of base fluid D046 12.749 lb 0.200 lb/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer DeepCRETE Volume : 192.0 bbl Density : 12.50 lb/gal Yield : 1.50 ft3/sk Dry Phase Liquid Phase Blend: 72474 lb Design Mix Water 81.1 bbl 10.0 bbl LAS Design D972 71898.484 lb Fresh water 81.062 bbl 10.001 bbl D046 143.797 lb 0.200%BWOB D065 179.746 lb 0.250%BWOB D167 179.746 lb 0.250%BWOB D153 71.898 lb 0.100%BWOB Page 17 sp18-n5 cade v1 8-16-11.cfw.08-16-2011. LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem462_12 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Enit E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of`Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW = Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 Emmm E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 Eno E&P Division REVISION STAP-P-1-M-6140 0 1 bliti LEAK-OFF TEST REPORT Report N' Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rig tlpe: J.UPs Hole()wooer(in): 12"114 Weight(Kg.): 1.3 R.K.B.eleswtion(m): 26 Last Csg.Shoe(m): 797 Marsh Mscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter(in): 131/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: .155 Y.P.1b/100 Ra): 5 Liners(in): 6.5" Weight tb/t): 61 Gelstb/100 t). 2/8 Flow Rate(bpi): 0.25 - Max.Burst pres(psi): 3103 W.L(ccRO min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm/10 m Time Vol une Pressure Time Volume Pressure Time Vdume Pressure (min) (bd) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 100 300 10.5 2 463 5 125 400 11 2 455 8 150 500 11.5 2 460 7 1.75 570 12 2 445 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Nd e: Pumped with a constant low rate of(bbl): 'ablume pumped(bbl): Lblume retum ed(bbl): (ps) 1000 900 - 800 stop pump F 700 -----,, e 600 / - shut in curve S 500 / S —�� U 400 r - 8 minutes e 300 200 100 0 , 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbl) 41 O. Time mins RESULTS: (Press.m,n+Press.,-o.)x10/D epth=[(1.3 x 797 110)+(430 x 0.07)]x10/797=1.68(Kg/cm2/10 m) Note: Comp any Representative Figure 15-1 - Leak-Off Test Report REv DATE BY CK APP DE,SCRIPTIOt REVS DATE BY CK APP DESCRIPTION C 10/07:0 DHS CC CC Tht cl Drawing VICINITY 11A1' SCALE: 2 Wes IE ( I,, °6 I 1 ° x b 1 z � Or 0 THIS I16 rS 30 �-, f SURVEY �4 30 29 S 21 A.S.P N.AD41, 74 35 to c4 ,31 37 35 int , 1y 'tib 'E E 31 3.. ..S 34 114NT14N Ti3N 4 1 T13N y 2 =Limb< Dal=PAD4 LDI K :, �. 10 it �� I; , il _ - ....__________-. -.....-. 41 �`''S-3R „ , !, • it�# 51 ,) b s. L 4 --,.�_._,P4 ,.roc .,.. -' :U ' , - -- ,F 15 ,r 14 `{ DS..30abs.w►.a'. PAD ,y 21 22 2,' + +r -f l ri t1 1 Mi S ) � taa � rr DS-3VA 1 I • COO PAD ( V x 28 27 n P. tit's ` DS 3Nn, , 4V� a� +o pykDU a.t.. ' J rr Elf .. 1 a " ,�y 1+ r I 2-. G P'. ,�] .� » x E I.t "i (11-"Al„ o r. A _ .0 re DRAWING NOTES: V ri ' "� 1 111 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NADB3. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NADB3. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH, RANGE 9 EAST. UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCEC IN THIS DRAWING ARE PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 =OR COORDINATE VALUES IN NAD27. 40.,:c,,,.............,94: Art SURVEYOR'S CERTIFICATE 4:. 49th -'t' +*/ •I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND j ." -0 't LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF , �` :::•1z"' 4.:(imp l....•- ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY I . FRANCIS J. CORNING DONE BY ME OR UNDER MY DIRECT SUPERVISION AND I �3 �; 1 's LS-10695 .► THAT NI DIMENSIONS AND OTHER DETAILS ARE CORRECT 1 'F':, .. AS OF OCTOBER 01, 2010 '1 •�f ••...!)!d-t1A1fr• .jr __ 1 *"'($4oe SPY ISLAND DRILL SITE so• i WELL CONDUCTORS • AS—BUILT LOCATIONS 2�II • .�,, CAD FILE:ENI3543@9 US op rahn DATE,a/o,,2D'D DRAWNO NO: Eni-3543—d9 PART: REV: 3 REO REV DATE BY CCK ' &PP DESCRIPTION REV DATE BY CK APP DESCRIPTION U 10/0 110 )IIS CC CC 1"1:'C D'cw 'g N . Gid (l- NY ___. r" �P Seti.. '9 �y Ssr; 7p ---1v W ASL NAUb3, Ti. ! i0 _ J (7' � 0 010 7°v 1J t.,..) d, N cD W W [resa9, J 0 °I"'‘-""—__, c> A �r—l CA j© ) toa o °IW '()L#17-1-..1 co DETAIL A. SCALE: 1"-80' i SAHOE ER oci.5N9J� /7 l \ i I o �° ' Q coaan a• C oZYe 1'I C.SUv w • ari DETAL A 1- C, C SPY ISLAND DRILL SITE (SID) 1 t iz,r_____-------- Y G p,r109ADE LEGENC SCALE 20C c ,00 200 0 - WELL CONDUCTOR AS—BUILT THIS SURVEY 1" 200' r11145 �a�* &any SPY ISLAND DRILL SITE WELL CONDUCTORS �• 8, AS—BUILT LOCATIONS 0211 II n • �►r.t y�� CAD FILE:EN 3543D9 11S op( r1t11(ril OA1E: /Dt/zolo DRAWING NO: Eni-3543—d9 PART: 3 REV: REV DATE BY CK APP DESCRIPTION RVQ/ DAZE BY CK APP DESCRIPTION 0 Vi r.oy n `1. s c0 cc nit c DrcJ1'1r Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. ' 'Y' 'X' _atitude (N) Longitude(W) F.N.L F.E.L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70°33'27.209" 149°54'24.765" 797 1171 12.4 2 6053421.65 165176187 70033127.194" 149'54'25.000" 798 1179 12.4 3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 12.4 4 6053418.56 1651746.17 70'33'27.164" 149'54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70033127.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149054125.925" 804 1210 12.4 7 6053412.44 1651714.77 70033427.104" 149'54'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70'33'27.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70°33'27.074" 149°54'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70'33'27.060" 149"54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149054'27,318" 813 1257 12.4 12 6053404.80 1651675.51 70°33'27.029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 _ 70033'26.986" 149°54'28.221" 819 . 1288 12.4 14 6053398.83 1651644.95 70'33'26.971" 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637.12 70°33'26.956" 149054'28.685" 822 1304 _ 12.4 16 6053395.82 1651629.26 70°33'26.942" 149054'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70°33'26.927" 149°54'29.147" 825 1319 12.4 18 6053392.78 1651613.58 70°33'26.912" 149054'29.380" 827 1327 12.4 . 19 6053389.63 1651597.90 70'33'26.881" 149054129.843" 830 1343 12.4 20 6053388.17 1651590.00 70033'26.867" 149'54'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70033'26.852" 149054'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70°33'26.838" 14914'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70033126.823" 149'54'30.773" 836 1374 12.4 24 6053382.12 1651558.61 70033'26.808" 149054131.003" 837 1382 12.4 25 6053377.65 1651535.94 70033'26.764" 149'5431.673" 842 1405 , 12.4 26 6053376.14 1651.528.13 70°33'26.750" 149°54'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70033126.7341 149°54'32.137" 845 1421 12.4 28 6053373.11 1651.512.46 70033'26.720" 149'54'32.366" 846 1428 12,4 29 6053371.56 1651504.49 70'33'26.705" 149054432.602" 848 1436 12.4 30 6053370.06 1651496.66 70'33'26.690" 149054'32,833" 849 1444 12.4 31 6053367.05 1651480.97 70033'26.661" 149°54'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70033'26.646" 14905433.527" 854 1468 12.4 33 6053363.93 1651465.22 70033'26.631" 149°54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70'33126.616" 149°54'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'26.601" 149054'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70033'26.586" 149054134.459" 860 1499 12.4 37 6053356.19 1651425.30 70°33'26.555" 149054434.941" 863 1516 12.4 38 6053354.74 1651417.32 70033'26.541" 149054135.177" 864 1524 12.4 iiix,,,01 a4. 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TRANSMITTAL LETTER CHECKLIST WELL NAME �a , . ,11 ' = �) r A7A PTD# ( / �L J Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 4/ r 106-?5 POOL:At/ f T c'�c t( V . J r 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. 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CD CD = (Q 7 -1 7 CD x (° = a e 0 0 0 3 m r co co O 3 co O a (n 0 n C)) cn 77 Ca 0 c (n c 3 (o n) a 3 p 3 n to • Q o- D C0 - 0 o (u N (0 o (Q 0) ' yell History File AP ' E ND IX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpltfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: November 19, 2011 Surface Data Logging End of Well Report SP18-N5 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Show Reports 8. Survey Report 9. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Doyon 15 Well: SP18-N5 SP18-N5 PB1 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23453-00-00 50-629-23453-60-00 (PB1) Sperry Job Number: AK-AM-0009010095 Job Start Date: 22 Oct 2011 Spud Date: 22 Oct 2011 Total Depth: SP18-N5 13601’ MD, 3872.00’ TVD SP18-N5 PB1 9481' MD, 3919.81’ TVD North Reference: True Declination: 20.842° Dip Angle: 81.060° Total Field Strength: 57651.965 nT Date Of Magnetic Data: 05 November 2011 Wellhead Coordinates N: North 70° 30’ 39.32” Wellhead Coordinates W: West 149° 51’ 50.42“ Drill Floor Elevation 53.87’ Ground Elevation: 13.1’ Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Nicholas Istre, Zachary Beekman Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SP18-N5 10/22/2011 Sperry arrives on location at 1300 hrs. Get the rock washer, pits, shaker, air lines, and transfer pumps ready. Work on containment for the line from the rock washer to WIF. Pre spud meeting in doghouse at 1700 hrs. Clean out the conductor to 166’ MD. Pump while pulling out of the hole to 60’. Pull out of the hole on elevators. Make up bottom hole assembly number two. Run in the hole with wire line, gyro, and prepare to run in the hole. 10/23/2011 Begin drilling ahead taking Gyro surveys per directional driller to 277’ MD. Pull out of the hole and make up bottom hole assembly number two. Pump while pulling out due to 5 thousand pound over pull. Run in the hole with bottom hole assembly number two and drill ahead taking Gyro surveys per direction driller to 923’ MD. 10/24/2011 Continue drilling ahead from 923’ to 1436’ MD. An MWD failure with Schlumberger tool occurred. Stopped to trouble shoot the tool. Observe well and back ream out of the hole from 1400’ to 185’ MD. Lay down bottom hole assembly number two. Make up bottom whole assembly number three with back up MWD tool, other wise it is a similar bottom hole assembly makeup. Run in the hole and continue drilling to 1724’ MD as of midnight. Sperry replaced malfunctioning Gas Chromatograph with a new unit and calibrated both the THA and Gas Chromatograph. 10/25/2011 Continue drilling ahead from 1724’ to 2684’ MD. Surface casing point reached at a depth of 2684’ MD at 1345 hours. Circulated 4 bottoms ups then back reamed out of hole from 2356’ to 820’ MD. Hole circulated clean at 830’ MD. Pull out of the hole on elevators and lay down bottom hole assembly number three. Max gas observed within the surface hole section was 1238 units at a depth of 1688’ MD. 10/26/2011 Finish laying down bottom hole assembly number three. Rig up to run 13 3/8” casing. Run 13 3/8” casing while topping off every ten joints. Circulate and reciprocate casing. Max gas observed while running casing was 105 units. Rig up and cement casing in place. Casing shoe set at 2669’ MD. Rig down cementing equipment. 10/27/2011 Nipple down the BOP stack. Test wellhead seals to 5000psi for 10 minutes. Test successful. Nipple up the BOP stack and test BOPs. 10/28/2011 Finish testing BOPs and rig down BOP testing equipment. Pull the test plug and pick up bottom hole assembly number four. Attempt to clean out MWD tool was unsuccessful. Lay down ARC and lay down MWD. Pick up the new MWD and ARC. Continue to make up bottom hole assembly number four. Run in the hole and successfully shallow test MWD tool. Run in the hole to 2389’ MD and fill pipe. Circulate one bottoms up and pressure test casing to 2500psi. Wash and ream to 2583’ MD. Drill out the plug and cement. 10/29/2011 Drill 26’ of new formation to 2710’ MD. Perform Formation Integrity Test to 13.08 PPG EMW. Begin to drill ahead. At 3233’ MD, circulate the hole clean. Flow check the well and find it to be static. Back ream out of the hole from 2980’ to 2600’ MD. Circulate one bottoms up and flow check the well again. Well is static. Pull out of the hole on elevators. Lay down bottom hole assembly number four. Make up and pick up bottom hole assembly number five. Decision was made to pull out of the hole because the bit was unable to build proper angle with the powerdrive. The new bottom hole assembly will have a 1.5° mudmotor instead of rotary steerable. 10/30/2011 Finish making up bottom hole assembly number five and run in the hole to shallow test MWD. Successful shallow test for MWD tool. Trip in the hole to 3143’ MD. Wash and ream from 3143’ to 3233’ MD. Begin to drill ahead from 3233’ MD. Currently we have been showing much lower than usual gas reading this intermediate section. Multiple tests have been done on every component of the gas detection equipment with no failures occurring and all calibrations correct. To be completely sure that we are monitoring the total gas, we are in the process of installing a second gas trap in a different location further down the possum belly. The area is much less turbulent than where the trap is currently situated, however it is not as close to the flow line. 10/31/2011 Continue drilling ahead. We successfully installed the second gas trap downstream further from the flow line in the lower possum belly, where the mud flow is less turbulent. Instantly our gas readings increased from an average of ~3 units to a max of 30 units, then leveling out to an average of 14-17 units. We can conclude that although there may be some break out of gas from the drilling fluid prior to where the gas trap is now situated, we must use the current placement to be able to effectively monitor Total Gas. The extreme amount of flow and turbulence occurring where the first gas trap was located resulted in the drilling fluid being forced through the gas trap before the agitator blades could break the gas out of the drilling fluid. 11/01/2011 Continue drilling ahead to TD of intermediate section at 6117’ MD. Casing point reached at 2255 hours. Circulate one bottoms up and back ream out of the hole. Max gas observed during the day was 5349 units at a depth of 6047’ MD. Average gas for the day was 762 units and background gas was 344 units. 11/02/2011 Back ream out of the hole to 2661’ MD. Circulate at the casing shoe. Flow check well and observed it to be static. Pull out of the hole and lay down the bottom hole assembly. Make up a dummy run with 9 5/8” hanger. Rig up Tesco. Change out the rams and test. 11/03/2011 Run in hole with 9 5/8” casing and set the shoe at 6096’ MD. Rig up the cement head. Cement casing and chase the plug. Bump the plug at 6141 strokes. Successfully check the floats. Lay down the landing joint and change the upper rams. Rig up for freeze protect. 11/4/2011 Finish freeze protect. Test the BOP stack. Service the top drive. Make up bottom hole assembly number six and begin running in the hole. 11/5/2011 Continue running in the hole with bottom hole assembly number six. Test the casing with a result of failure. Troubleshoot the testing equipment. Test 13 3/8” and 9 5/8” pack off – OK. Pull out of the hole and pump a dry job. Lay down bottom hole assembly number six. Run in the hole with RTTS to 5946’ MD, fill pipe, and test 9 5/8” casing to surface at 3000psi for 30 minutes. 9 5/8” casing test successful. Pull out of the hole and lay down RTTS. 11/6/2011 Make up bottom hole assembly number seven. Run in the hole and successfully shallow test the MWD. Trip in the hole to 5953’ MD. Cut and slip drilling line and calibrate the blocks. Clean out the shoe track. Drill 20’ of new formation to 6137’ MD. Perform a successful Formation Integrity Test to 12.85 PPG EMW. Prep for and displace to oil based mud. 11/7/2011 Finishing cleaning pits and changing over to oil based mud. Drill ahead from 6137’ MD. Maximum gas observed for the day was 1561 units at a depth of 7800’ MD. Average gas for the day was 450 units and background gas was 142 units. 11/8/2011 Continue to drill ahead to 9481’ MD. A decision was made to pull back and perform an open hole sidetrack. Circulated one bottoms up, then back reamed from 9481’ to 7759’ MD. Began making a ledge to sidetrack at 7765’ MD. Open hole sidetrack was successful at 7795’ MD. Drill ahead. Maximum gas for the day was 1831 units at a depth of 7904’. Average gas was 445 units and the background gas was 33 units. 11/9/2011 Successfully performed open hole sidetrack at 7795’ MD. Continue to drill ahead. Testing gas data between the two gas trap locations yielded the following results; using the upper gas trap, closest to the flow line, is more accurate. Using the lower gas trap showed 20-25% less gas. 62 units vs. 50 units when this experiment was conducted. We will of course use the upper location whenever at all practical, but during high flow rates it is not possible due to the extreme turbulence created at the higher gas trap location, rendering the readings useless. Therefore, we will continue forward with our interim plan set out a few weeks ago as these findings further support our earlier beliefs. We will use the higher gas trap in surface sections and other low flow situations, and use the lower gas trap in high flow situations only. Maximum gas observed for the day was 1271 units at 8135’ MD. The average for the day was 501 units and the background gas was 56 units. 11/10/2011 Continue drilling ahead to a depth of 12315’ MD as of midnight. Maximum gas for the day was 1981 units at a depth of 11998’ MD. The average gas for the day was 620 units and the background gas was 59 units. 11/11/2011 Continue drilling ahead to TD depth of 13601’ MD reached at 1100 hours. Back ream out of the hole as per K&M representative. Maximum gas for the day was 1491 units at a depth of 12370’ MD. The average gas was 726 units and the background was 76 units. 11/12/2011 Continue to back ream out of the hole as per K&M representative. Top drive problems occurred at a depth of 7945’ MD. Stopped to troubleshoot and repair. Continue to back ream out of hole once top drive issues were repaired. 11/13/2011 Continue to back ream out of the hole to a depth of 4975’ MD. Stopped to circulate two bottoms up. Pumped a dry job, then began to pull out of the hole. Lay down the bottom hole assembly, pull wear ring, and rig up to test the BOP stack. 11/14/2011 Finish testing BOPs. Rig up GBR casing equipment. Begin running in the hole with the 5 ½” slotted liner. 11/15/2011 Land and set 5 ½” slotted liner. Displace oil based mud to KCl NaCl Brine. Lay down drill pipe. ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air 0 0 Units*C-4i C-4n C-5i 0 0 0 Depth C-1 C-2 C-3 0 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: to Tools Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 0 MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition Depth in Drilling All Circ WIF. Pre Spud meeting in doghouse. Clean out conductor to 166' MD. Pump while POOH to 60'. POOH on elevators. M/U BHA #2. R/U wireline, gyro, prepare to RIH. Get rock washer pits, shakers, air lines, and transfer pumps ready. Work on containment for line from rock washer to % - md Max @ ft Current ROP (ft/hr) 160' 160' 0' Flow In (gpm) Current Pump & Flow Data: - RIHRig Activity: Flow In (spm) $3,285.00 $3,285.00 Report For:Keener/Smith/BuchananTotal Charges: - AvgMin Max Max 2.0 Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n 16 Size Hughes MX-1 Milltooth 160' (ppb Eq)cP PV PWD MBT ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 Customer: Well: Avg 1 22-Oct-2011 24:00:00Time: Report #: Date: Sh 8.70 20.0 36 1.170 Gas Summary 00 17 ClystCly 160' 8.70 Chromatograph (ppm) Ss 5.6 Lst 1 Cht Silt Siltst YP Cor Solids (lb/100ft2) 3,4009.30 mg/lml/30min API FL Trip 0 24 hr Recap: ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air Trip 0 24 hr Recap: YP Cor Solids (lb/100ft2) 3,6009.00 mg/lml/30min API FL 1 Cht Silt Siltst 9.00 Chromatograph (ppm) Ss 4.5 Lst 160' 23 ClystCly Gas Summary 1936 0 Sh 9.00 20.0 36 1.170 2 23-Oct-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 Customer: Well: Avg (ppb Eq)cP PV PWD MBT 80 922' 16 Size Hughes MX-1 Milltooth 923' TuffGvlCoal C-5n 3.0 Bit Type TFA - pH Chlorides -Min - Avg - AvgMin Max Max Drilling AheadRig Activity: Flow In (spm) 451.0 $3,285.00 $6,570.00 Report For:Keener/Smith/BuchananTotal Charges: 160' 923' 763' Flow In (gpm) Current Pump & Flow Data: - 176.0 Max @ ft Current ROP (ft/hr)869'247.6 md in Drilling All Circ overpull. RIH with BHA #2 and drill ahead taking Gyro surveys per DD to 923' MD. Drilling ahead taking Gyro surveys per DD to 277' MD. POOH and M/U BHA #2. Pump while pulling out due to 5k % -MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition Depth 6 3 17 0 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 160' 923' to Tools ARC 825, PowerPulse 825 Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 640 152 SPP (psi) Gallons/stroke 1189 @ Yesterday's Depth: 0 0 0 0 0 0 Background Maximum Minimum Average 0 00 0 0 00 Depth C-1 C-2 C-3 0 0 0 0 Units*C-4i C-4n C-5i 0 0 ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air Trip 0 24 hr Recap: YP Cor Solids (lb/100ft2) 2,7008.90 mg/lml/30min API FL 1 1RR Hughes MX-1 Milltooth Cht Silt Siltst 9.30 10.0 Chromatograph (ppm) Ss 4.8 Lst 160' 1436' 1276' 1436' 19 ClystCly Gas Summary 46896 0 Sh 9.30 20.0 31 1.170 3 24-Oct-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg (ppb Eq)cP PV PWD MBT 78 1688' 952' 16 1.170 16 Size Hughes MX-1 Milltooth 1500' TuffGvlCoal C-5n 4.5 Bit Type TFA - pH Chlorides -Min - Avg - AvgMin Max Max Drilling AheadRig Activity: Flow In (spm) 295.8 $3,285.00 $9,855.00 Report For:Keener/Smith/BuchananTotal Charges: 923' 1724' 801' Flow In (gpm) Current Pump & Flow Data: - 160.0 Max @ ft Current ROP (ft/hr)1690'176.0 md Sperry replaced malfunctioning Gas Chromatograph with a new unit and calibrated both THA and GC. in Drilling All Circ L/D BHA. M/U BHA #3 with backup MWD tool, otherwise similar BHA makeup. RIH and continue drilling to 1724' as of midnight. Continue drilling from 923' to 1436' MD. MWD failure, troubleshoot tool. Observe well, BROOH from 1400' to 185' MD. % -MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition Depth 101 45 339 10 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 923' 1724' to Tools ARC 825, PowerPulse 825 Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 640 152 SPP (psi) Gallons/stroke 1189 @ Yesterday's Depth: 1312 15034 0 0 0 0 Background Maximum Minimum Average 0 00 0 0 00 Depth C-1 C-2 C-3 0 0 0 0 Units*C-4i C-4n C-5i 0 0 ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air Trip 271 24 hr Recap: YP Cor Solids (lb/100ft2) 1,3008.90 mg/lml/30min API FL 1RR Cht Silt Siltst 9.40 Chromatograph (ppm) Ss 4.7 Lst 1436' 2684' 1248' 22 ClystCly Gas Summary 162874 0 Sh 9.40 22.5 27 1.170 4 25-Oct-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg (ppb Eq)cP PV PWD MBT 64 1688' 2680' 16 Size Hughes MX-1 Milltooth 2684' TuffGvlCoal C-5n 5.0 Bit Type TFA - pH Chlorides -Min - Avg - AvgMin Max Max L/D BHARig Activity: Flow In (spm) 543.5 $3,285.00 $13,140.00 Report For:Keener/Smith/BuchananTotal Charges: 1724' 2684' 960' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)2166'203.4 md in Drilling All Circ clean @ 830' MD. POOH on elevators. L/D BHA. Continue drilling from 1724' to 2684' MD, Surface casing point. CBU 4x. BROOH from 2356' to 820' MD. Circulate hole % -MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition Depth 222 1238 45 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 1724' 2684' to Tools ARC 825, PowerPulse 825 Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 6293 28401 0 0 0 0 Background Maximum Minimum Average 0 00 0 0 00 Depth C-1 C-2 C-3 0 0 0 0 Units*C-4i C-4n C-5i 0 0 ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air 0 0 Units*C-4i C-4n C-5i 0 0 0 Depth C-1 C-2 C-3 0 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: 2684' 2684' to Tools Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition Depth in Drilling All Circ GAS 105 units. R/U and cement casing; casing set at 2669' MD. R/D cementing gear. Finish L/D BHA #3. R/U to run casing. Run casing topping off every 10 joints. Circulate and reciprocate casing, MAX % - md Max @ ft Current ROP (ft/hr) 2684' 2684' 0' Flow In (gpm) Current Pump & Flow Data: - R/D CementingRig Activity: Flow In (spm) $3,285.00 $16,425.00 Report For:Keener/Smith/BuchananTotal Charges: - AvgMin Max Max 5.0 Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n 45 16 Size Hughes MX-1 Milltooth 2684' (ppb Eq)cP PV PWD MBT ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 5 26-Oct-2011 24:00:00Time: Report #: Date: Sh 9.30 8.56 20.0 16 1.170 Gas Summary 00 19 ClystCly 1436' 2684' 1248' 9.30 Chromatograph (ppm) Ss 5.4 Lst 1RR Cht Silt Siltst YP 1-2-WT-G-0-I-NO-TD Cor Solids (lb/100ft2) 1,2008.80 mg/lml/30min API FL Trip 105 24 hr Recap: ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air 0 0 Units*C-4i C-4n C-5i 0 0 0 Depth C-1 C-2 C-3 0 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: 2684' 2684' to Tools Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition Depth in Drilling All Circ N/D BOPs. Test wellhead seals to 5000psi for 10 min - OK. N/U BOPs. Test BOPs. % - md Max @ ft Current ROP (ft/hr) 2684' 2684' 0' Flow In (gpm) Current Pump & Flow Data: - Test BOPsRig Activity: Flow In (spm) $3,285.00 $19,710.00 Report For:Keener/Smith/BuchananTotal Charges: - AvgMin Max Max 4.0 Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n Size 2669' (ppb Eq)cP PV PWD MBT ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 6 27-Oct-2011 24:00:00Time: Report #: Date: Sh 9.20 5.0 21 Gas Summary 00 10 ClystCly 9.20 Chromatograph (ppm) Ss LstCht Silt Siltst YP Cor Solids (lb/100ft2) 7009.80 mg/lml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air 0 0 Units*C-4i C-4n C-5i 0 0 0 Depth C-1 C-2 C-3 0 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% 758 181 SPP (psi) Gallons/stroke 1089 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: to 2684' Depth Daily Charges: Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre MWD Summary 4.23 Hours Depth in / out Footage WOB RPM Condition 2684' in Drilling All Circ ARC, L/D MWD. P/U new MWD, P/U ARC. Continue to M/U BHA#4. Shallow hole test MWD - OK. RIH to 2389' MD and fill pipe. CBU. Pressure test casing to 2500psi. Wash and ream to 2583' MD. Drill out plug and cement. Finish testing BOPs. R/D for testing BOPs. Pull test plug. P/U BHA#4. Attempt to clean out MWD tool. No good. L/D % - md Max @ ft Current ROP (ft/hr) 2684' 2684' 0' Flow In (gpm) Current Pump & Flow Data: - Drill out plug/cementRig Activity: Flow In (spm) $3,285.00 $22,995.00 Report For:Ross/Smith/BuchananTotal Charges: - AvgMin Max Max 4.0 Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n 54 12 1/4" Size Smith GF20B 2711' (ppb Eq)cP PV PWD MBT Tools Powerdrive 900X6; Telescope 825; Arc 825 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 7 28-Oct-2011 24:00:00Time: Report #: Date: Sh 9.30 5.0 19 1.116 Gas Summary 00 11 ClystCly 2684' 9.30 Chromatograph (ppm) Ss 5.8 Lst 2 Cht Silt Siltst YP Cor Solids (lb/100ft2) 7009.70 mg/lml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air 0 0 Units*C-4i C-4n C-5i 0 0 0 Depth C-1 C-2 C-3 0 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 289 676 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 3233' Depth Daily Charges: Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 40 3 6 2 4.23 Hours Depth in / out Footage WOB RPM Condition 2684' to in Drilling All Circ check well - static. BROOH from 2980' to 2600' MD. CBU and flow check well again - static. POOH on elevators. L/D BHA #4. M/U and P/U BHA #5. Pulled out of hole because unable to build proper angle with powerdrive. New BHA will have 1.5* Mudmotor Dill 26' new hole to 2710' MD. Perform FIT to 13.08 PPG EMW. Drill ahead. At 3233' MD, circulate hole clean. Flow % - md instead of rotary steerable. Max @ ft Current ROP (ft/hr)3032'113.2 MWD Summary 2684' 3233' 549' Flow In (gpm) Current Pump & Flow Data: - M/U BHA #5Rig Activity: Flow In (spm) 229.3 $3,285.00 $26,280.00 Report For:Ross/Smith/BuchananTotal Charges: - AvgMin Max Max 4.0 Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n 2796' 3100' 12 1/4" Size Smith GF20B 3233' (ppb Eq)cP PV PWD MBT Tools Powerdrive 900X6; Telescope 825; Arc 825 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 8 29-Oct-2011 24:00:00Time: Report #: Date: Sh 9.30 7.89 7.5 24 1.116 60 Gas Summary 4985 0 12 ClystCly 40 2684' 3233' 549' 9.30 Chromatograph (ppm) Ss 5.2 Lst 2 Cht Silt Siltst YP 1-1-WT-T-1-1/16-PN-CD Cor Solids (lb/100ft2) 8009.90 mg/lml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air component of the gas detection equipment with no failures occuring and all calibrations correct. To be completely sure that we are monitoring the Total Gas, we are in the process of installing a second gas trap in a different location further down the possum belly. This area is much less turbulent than where the trap is currently situated, however it is not as close to the flow line. Trip 24 hr Recap: YP Cor Solids (lb/100ft2) 1,1009.60 mg/lml/30min API FL 3 10 Cht Silt Siltst 9.35 Chromatograph (ppm) Ss 4.5 Lst 3233' 11 ClystCly 90 Gas Summary 2746 0 Sh 9.35 10.0 25 1.116 9 30-Oct-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools SP Motor 1.83*; Telescope 825; ARC 825 54 3965' 3100' 12 1/4" Size Smith GF20B 4055' TuffGvlCoal C-5n 5.0 Bit Type TFA - pH Chlorides -Min - Avg - AvgMin Max Max Drill AheadRig Activity: Flow In (spm) 451.0 $3,285.00 $29,565.00 Report For:Ross/Smith/BuchananTotal Charges: 3233' 4100' 867' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)3798'145.3 MWD Summary md NOTE: We have been showing much lower than usual gas readings this intermediate section. Multiple tests have been done on every in Drilling All Circ drill ahead from 3233' MD. Finish M/U & RIH w/BHA #5. Shallow test MWD - OK. TIH to 3143' MD. Wash & ream from 3143' to 3233' MD. Begin to % - 4.23 Hours Depth in / out Footage WOB RPM Condition 3233' to 4 <2 22 2 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 4100' Depth Daily Charges: 19.0 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 791 190 SPP (psi) Gallons/stroke 1330 @ Yesterday's Depth: 189 347 0 0 0 0 Background Maximum Minimum Average 0 00 0 0 00 Depth C-1 C-2 C-3 0 0 0 0 Units*C-4i C-4n C-5i 0 0 ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air NOTE: We successfully installed the second gas trap downstream further from the flow line in the lower possum belly, where the mud flow is less turbulent. Instantly our gas readings increased from an average of ~3 units to a max of 30 units, then leveling out to an average of 14-17 units. We can conclude that although there may be some break out of gas from the drilling fluid prior to where the gas trap is now situated, we must use the current placement to be able to effectively monitor Total Gas. The extreme amount of flow and turbulence occuring where the first gas trap was located resulted in the drilling fluid being forced through the gas trap 0 0 Units*C-4i C-4n C-5i 0 0 0 Depth C-1 C-2 C-3 1 0 0 0 0 00 Background Maximum Minimum Average 0 1 0 22 25 344 11912 Area: Location: 96% 892 213 SPP (psi) Gallons/stroke 1926 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 5197' Depth Daily Charges: 172.3 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 1689 4 62 4.23 Hours Depth in / out Footage WOB RPM Condition 4100' to in Drilling All Circ Continue drilling ahead. % - 132 md before the agitator blades could break the gas out of the drilling fluid. Max @ ft Current ROP (ft/hr)4444'161.1 MWD Summary 4100' 5197' 1097' Flow In (gpm) Current Pump & Flow Data: - Drill AheadRig Activity: Flow In (spm) 513.5 $3,285.00 $32,850.00 Report For:Ross/Smith/BuchananTotal Charges: - AvgMin Max Max 6.0 Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n 55 5138' 4126' 12 1/4" Size Smith GF20B 5034' (ppb Eq)cP PV PWD MBT Tools SP Motor 1.83*; Telescope 825; ARC 825 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 10 31-Oct-2011 24:00:00Time: Report #: Date: Sh 9.40 12.5 27 1.116 100 Gas Summary 203862 476 13 ClystCly 3233' 9.40 Chromatograph (ppm) Ss 3.6 Lst 3 Cht Silt Siltst YP Cor Solids (lb/100ft2) 1,3009.10 mg/lml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air Trip 24 hr Recap: YP Cor Solids (lb/100ft2) 1,4009.20 mg/lml/30min API FL 3 Cht Silt Siltst 9.50 Chromatograph (ppm) Ss 3.6 Lst 3233' 12 ClystCly 100 Gas Summary 407103 3199 Sh 9.50 17.5 27 1.116 11 1-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools SP Motor 1.83*; Telescope 825; ARC 825 54 6047' 5538' 12 1/4" Size Smith GF20B 6080' TuffGvlCoal C-5n 7.0 Bit Type TFA - pH Chlorides -Min - Avg AvgMin Max Max BROOHRig Activity: Flow In (spm) 442.2 $3,285.00 $36,135.00 Report For:Ross/Walls/BuchananTotal Charges: 5197' 6117' 920' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)5240'128.1 MWD Summary md in Drilling All Circ Continue drilling ahead to Intermediate Casing Point TD of 6117' MD, reached at 2255 hrs. CBU. BROOH. % - 762 - 4.23 Hours Depth in / out Footage WOB RPM Condition 5197' to 344 5349 40 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 6117' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 891 214 SPP (psi) Gallons/stroke 1931 @ Yesterday's Depth: 4189 63695 0 278 2471 181 Background Maximum Minimum Average 0 189 6 244 1880 24 171 C-4i C-4n C-5iC-1 C-2 C-3 1037 0 Units* 2321 6 92 Depth 3062 ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air Trip 373 24 hr Recap: YP 1-3-LT-G-0-8-SD-TD Cor Solids (lb/100ft2) 1,3009.20 mg/lml/30min API FL 3 Cht Silt Siltst 9.60 Chromatograph (ppm) Ss 3.8 Lst 3233' 6117' 2884' 13 ClystCly 100 Gas Summary 00 Sh 9.60 35.75 20.0 24 1.116 12 2-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools 55 12 1/4" Size Smith GF20B 6117' TuffGvlCoal C-5n 7.2 Bit Type TFA - pH Chlorides -Min - Avg AvgMin Max Max R/U CasingRig Activity: Flow In (spm) $3,285.00 $39,420.00 Report For:Ross/Walls/BuchananTotal Charges: 6117' 6117' 0' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr) MWD Summary md in Drilling All Circ hanger. R/U Tesco. Change upper rams and test. BROOH to 2661' MD. Circulate at casing shoe. Flow check - Static. POOH. L/D BHA. M/U dummy run w/ 9 5/8" % -- 4.23 Hours Depth in / out Footage WOB RPM Condition 6117' to Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 6117' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0 0 0 0 0 Background Maximum Minimum Average 0 0 0 0 0 0 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 Units* 0 0 0 Depth 0 ROP . . Mud Data:Density (ppg) Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) * 10000 units = 100% Gas In Air 0 0 Units* 0 0 0 Depth 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 6117' Depth Daily Charges: Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 4.23 Hours Depth in / out Footage WOB RPM Condition 6117' to in Drilling All Circ OK. L/D landing joint. Change upper rams. R/U for freeze protect. Run casing to 6096' MD. R/U cement head. Cement casing and chase plug. Bump plug at 6141 strokes. Check floats - % -- md Max @ ft Current ROP (ft/hr) MWD Summary 6117' 6117' 0' Flow In (gpm) Current Pump & Flow Data: - Freeze ProtectRig Activity: Flow In (spm) $3,285.00 $42,705.00 Report For:Ross/Walls/BuchananTotal Charges: AvgMin Max Max Bit Type TFA - pH Chlorides -Min - Avg TuffGvlCoal C-5n 47 Size 6117' (ppb Eq)cP PV PWD MBT Tools ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 13 3-Nov-2011 24:00:00Time: Report #: Date: Sh 9.60 17 Gas Summary 00 13 ClystCly 9.60 Chromatograph (ppm) Ss LstCht Silt Siltst YP Cor Solids (lb/100ft2) mg/lml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air 0 0 Units* 0 0 0 Depth 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% 507 121 SPP (psi) Gallons/stroke 1124 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 6117' Depth Daily Charges: Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 4.23 Hours Depth in / out Footage W OB RPM Condition 6117' to in Drilling All Circ Finish freeze protect. Test BOPs. Service Top Drive. M/U BHA #6. RIH with BHA #6. % -- md. Max @ ft Current ROP (ft/hr) MWD Summary 6117' 6117' 0' Flow In (gpm) Current Pump & Flow Data: - RIH w/ BHA #6Rig Activity: Flow In (spm) $3,285.00 $45,990.00 Report For:Keener/W alls/BuchananTotal Charges: AvgMin Max Max 6.7 Bit Type TFA - Alkal Lime -Min -Avg TuffGvlCoal C-5n 48 8 3/4" Size Smith MDSi616-BPX 6117' Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 14 4-Nov-2011 24:00:00Time: Report #: Date: Sh 1.9 15 0.902 Gas Summary 0 0 13 ClystCly 6117' 9.40 Chromatograph (ppm) Ss Lst 4 Cht Silt Siltst YP Cor Solids (lb/100ft2) 42.90 Mud (lb/bbl)ml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air Trip 24 hr Recap: YP Cor Solids (lb/100ft2) 3.772.90 Mud (lb/bbl)ml/30min API FL 4 Cht Silt Siltst 9.50 Chromatograph (ppm) Ss Lst 6117' 13 ClystCly Gas Summary 0 0 Sh 1.9 15 0.902 15 5-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 57 8 3/4" Size Smith MDSi616-BPX 6117' TuffGvlCoal C-5n 6.7 Bit Type TFA - Alkal Lime -Min -Avg AvgMin Max Max RIH w/ BHA #7Rig Activity: Flow In (spm) $3,285.00 $49,275.00 Report For:Keener/W alls/BuchananTotal Charges: 6117' 6117' 0' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr) MWD Summary md. in Drilling All Circ RIH w/ BHA #6. Test casing - FAIL. Trouble shoot test equipment. Test 13 3/8" & 9 5/8" packoff - OK. POOH. Pump dry % -- 4.23 Hours Depth in / out Footage W OB RPM Condition 6117' to Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 6117' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0 0 0 0 0 Background Maximum Minimum Average 0 0 0 0 0 0 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 Units* 0 0 0 Depth 0 ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air 0 0 Units* 0 0 0 Depth 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 6137' Depth Daily Charges: Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 98 1466 0 4.23 Hours Depth in / out Footage W OB RPM Condition 6117' to in Drilling All Circ M/U BHA #7, RIH. Shallow test MWD - OK. TIH to 5953' MD. Cut and slip drilling line. Calibrate blocks. Clean out % -- md. Max @ ft Current ROP (ft/hr) MWD Summary 6117' 6137' 20' Flow In (gpm) Current Pump & Flow Data: - Displace to OBMRig Activity: Flow In (spm) $3,285.00 $52,560.00 Report For:Keener/W alls/BuchananTotal Charges: AvgMin Max Max 6.7 Bit Type TFA - Alkal Lime -Min -Avg TuffGvlCoal C-5n 47 3127' 8 3/4" Size Smith MDSi616-BPX 6117' Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 16 6-Nov-2011 24:00:00Time: Report #: Date: Sh 9.45 1.9 15 0.902 Gas Summary 0 0 13 ClystCly 6117' 9.45 Chromatograph (ppm) Ss Lst 4 Cht Silt Siltst YP Cor Solids (lb/100ft2) 3.772.90 Mud (lb/bbl)ml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air Trip 24 hr Recap: YP Cor Solids (lb/100ft2) 3.712.85 Mud (lb/bbl)ml/30min API FL 4 10 Cht Silt Siltst 9.50 Chromatograph (ppm) Ss 4.0 Lst 6117' 16 ClystCly 90 Gas Summary 188274 429 Sh 9.50 1.9 16 0.902 17 7-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 49 7800' 7078' 8 3/4" Size Smith MDSi616-BPX 7851' TuffGvlCoal C-5n 10.0 Bit Type TFA - Alkal Lime -Min -Avg AvgMin Max Max Drill AheadRig Activity: Flow In (spm) 520.9 $3,285.00 $55,845.00 Report For:Keener/W alls/BuchananTotal Charges: 6137' 7853' 1716' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)7701'244.1 MWD Summary md. in Drilling All Circ Finish cleaning pits. Drill ahead from 6137' MD. % - 450 - 4.23 Hours Depth in / out Footage W OB RPM Condition 6137' to 142 1561 116 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 7853' Depth Daily Charges: 263.1 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 544 131 SPP (psi) Gallons/stroke 1952 @ Yesterday's Depth: 5317 47170 62 169 166 86 Background Maximum Minimum Average 64 102 101 108 100 67 61 C-4i C-4n C-5iC-1 C-2 C-3 52 39 Units* 130 71 31 Depth 157 ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air Trip 87 24 hr Recap: YP Cor Solids (lb/100ft2) 2.862.20 Mud (lb/bbl)ml/30min API FL 4 20 Cht Silt Siltst 9.40 Chromatograph (ppm) Ss Lst 6117' 14 ClystCly 80 Gas Summary 214629 533 Sh 9.40 1.8 15 0.902 18 8-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 47 7904' 7856' 8 3/4" Size Smith MDSi616-BPX 7813' TuffGvlCoal C-5n 13.0 Bit Type TFA - Alkal Lime -Min -Avg AvgMin Max Max Drill AheadRig Activity: Flow In (spm) 557.8 $3,285.00 $59,130.00 Report For:Keener/W alls/BuchananTotal Charges: 7853' 7793' -60' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)9428'277.0 MWD Summary md. in Drilling All Circ Drill ahead to 9481' MD. Decision made to pull back and open hole sidetrack. CBU 1x. Backream from 9481' to 7759' % - 445 - 4.23 Hours Depth in / out Footage W OB RPM Condition 7853' to 33 1831 4 Logging Engineers:Emil OpitzReport By:Emil Opitz / Nicholas Istre 7793' Depth Daily Charges: 10.7 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 542 129 SPP (psi) Gallons/stroke 1896 @ Yesterday's Depth: 205 81 40943Average 0 77 0 153 C-4i C-4n C-5iC-1 C-2 C-3Units* 156 0 35 Depth 185 0 92 112 (Current) 60 00 6470 Background Maximum Minimum ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Current) in Surface Sections and other low flow situations, and use the lower gas trap in high flow situations only. 34 010 4662 Background Maximum Minimum Units* 121 15 23 Depth 142 21 78 69 C-4i C-4n C-5iC-1 C-2 C-3 Average 17 78 32 175 172 5479 41839 Area: Location: 96% 548 131 SPP (psi) Gallons/stroke 2203 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 9767' Depth Daily Charges: 235.4 Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman 56 1271 57 4.23 Hours Depth in / out Footage W OB RPM Condition 7793' to in Drilling All Circ Successfully drilled open hole sidetrack @ 7795' MD. Drill ahead. % - 501 - md. Note: Testing gas data between the two gas trap locations yielded the following results; Using the upper gas trap, closest to the flow line, is more accurate. Using the lower gas trap showed 20-25% less gas. 62 units vs. 50 units when this experiment was conducted. W e will of course use the upper location whenever at all practical, but during high flow rates it is not possible due to the extreme turbulence created at the higher gas trap location, rendering the readings useless. Therefore, we will continue forward Max @ ft Current ROP (ft/hr)7841'244.7 MWD Summary 7793' 9767' 1974' Flow In (gpm) Current Pump & Flow Data: - Drill AheadRig Activity: Flow In (spm) 585.1 $3,285.00 $62,415.00 Report For:Keener/W alls/BuchananTotal Charges: AvgMin Max Max 10.6 Bit Type TFA - Alkal Lime -Min -Avg TuffGvlCoal C-5n 48 8135' 8027' 8 3/4" Size Smith MDSi616-BPX 9767' Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 19 9-Nov-2011 24:00:00Time: Report #: Date: Sh 9.40 66 / 34 15 0.902 100 Gas Summary 145374 414 15 ClystCly 6117' 9.40 Chromatograph (ppm) Ss 4.2 Lst 4 Cht Silt Siltst YP Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl)ml/30min API FL with our interim plan set out a few weeks ago as these findings further support our earlier beliefs; W e will use the higher gas trap Trip 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Current) 103 4371 110140 Background Maximum Minimum Units* 299 52 63 Depth 354 80 179 182 C-4i C-4n C-5iC-1 C-2 C-3 Average 38 181 29 325 469 3711 56119 Area: Location: 96% 544 130 SPP (psi) Gallons/stroke 2646 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 12315' Depth Daily Charges: 86.5 Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman 59 1981 49 4.23 Hours Depth in / out Footage W OB RPM Condition 9767' to in Drilling All Circ Continue drilling ahead. % - 620 - md. Max @ ft Current ROP (ft/hr)10731'268.3 MWD Summary 9767' 12315' 2548' Flow In (gpm) Current Pump & Flow Data: - Drill AheadRig Activity: Flow In (spm) 592.4 $4,285.00 $66,700.00 Report For:Keener/W alls/BuchananTotal Charges: AvgMin Max Max 11.7 Bit Type TFA - Alkal Lime -Min -Avg TuffGvlCoal C-5n 52 11998' 11599' 8 3/4" Size Smith MDSi616-BPX 12188' Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 20 10-Nov-2011 24:00:00Time: Report #: Date: Sh 9.55 66 / 34 17 0.902 80 Gas Summary 220452 812 16 ClystCly 6117' 9.50 Chromatograph (ppm) Ss Lst 4 20 Cht Silt Siltst YP Cor Solids (lb/100ft2) 3.122.40 Mud (lb/bbl)ml/30min API FL Trip 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Max) Trip 31 24 hr Recap: YP Cor Solids (lb/100ft2) 3.122.40 Mud (lb/bbl)ml/30min API FL 4 Cht Silt Siltst 9.50 Chromatograph (ppm) Ss Lst 6117' 16 ClystCly Gas Summary 171247 763 Sh 9.55 66 / 34 17 0.902 21 11-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg Ratio cP PV PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 52 12370' 13595' 8 3/4" Size Smith MDSi616-BPX 12188' TuffGvlCoal C-5n 11.7 Bit Type TFA - Alkal Lime -Min -Avg AvgMin Max Max BROOHRig Activity: Flow In (spm) 423.9 $3,285.00 $69,985.00 Report For:Keener/W alls/BuchananTotal Charges: 12315' 13601' 1286' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)12837'273.7 MWD Summary md. in Drilling All Circ Continue drilling ahead to TD depth of 13601' MD. BROOH as per K&M rep. % - 726 - 4.23 Hours Depth in / out Footage W OB RPM Condition 12315 to 76 1491 92 Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman 13601 Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 536 128 SPP (psi) Gallons/stroke 2423 @ Yesterday's Depth: 406 8510 69956Average 102 313 99 489 C-4i C-4n C-5iC-1 C-2 C-3Units* 265 103 93 Depth 327 148 286 168 (Current) 99 65103 159224 Background Maximum Minimum ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Current) 0 00 00 Background Maximum Minimum Units* 0 0 0 Depth 0 0 0 0 C-2 C-3 C-4i C-4n C-5i Average 0 0 0 0 0 0 0 Area: Location: 96% 553 132 SPP (psi) Gallons/stroke 2052 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman W OB RPM Condition 13601 to 13601 Depth in Drilling All Circ Continue BROOH as per K&M Rep. Top Drive problems @ 7945' MD. Troubleshoot and repair. Continue to BROOH. % md. -- MWD Summary Current ROP (ft/hr) 13601' 13601' 0' Flow In (gpm) Current Pump & Flow Data: - $3,285.00 $73,270.00 Report For:Total Charges: Max @ ft Daily Charges: Max Max BROOHRig Activity: Flow In (spm) Keener/W alls/Buchanan 4.23 - Alkal Lime -Min -Avg AvgMin API FL TuffGvlCoal C-5n Sh Size Smith MDSi616-BPX 13601'11.6 Bit Type TFA Hours Depth in / out Footage C-1 PWD Oil / W ater Tools Xceed, Periscope, Telescope, ADN 675 ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 22 12-Nov-2011 24:00:00Time: Report #: Date: 0.902 55 8 3/4" Cly Gas Summary 0 0 Chromatograph (ppm) Ss Lst 6117' 16 ClystChtSiltSiltst 4 9.40 Ratio cP ml/30min 66 / 34 17 PV YP Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl) (Max) Trip 60 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Max) Trip 24 hr Recap: PV YP 1-2-CT-S-X-I-BT-TD Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl)Ratio cP ml/30min 51.20 66 / 34 17 4 9.40 Cht Silt SiltstSs Lst 6117' 13601' 9270' 16 Clyst Gas Summary 0 0 Chromatograph (ppm) 0.902 57 8 3/4" Cly 23 13-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg C-1 PWD Oil / W ater Tools Size Smith MDSi616-BPX 13601'11.6 Bit Type TFA Hours Depth in / out Footage TuffGvlCoal C-5n Sh - Alkal Lime -Min -Avg AvgMin API FL Max @ ft Daily Charges: Max Max Test BOPsRig Activity: Flow In (spm) Keener/W alls/Buchanan 4.23 $3,285.00 $76,555.00 Report For:Total Charges: 13601' 13601' 0' Flow In (gpm) Current Pump & Flow Data: - Current ROP (ft/hr) MWD Summary -- All Circ Continue to BROOH to 4975' MD. 2x CBU. Pump Dry Job. POOH. L/D BHA. Pull wear ring. R/U to test BOPs. % md. W OB RPM Condition 13601 to 13601 Depth in Drilling Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0 0Average 0 0 0 0 C-4i C-4n C-5iC-2 C-3Units* 0 0 0 Depth 0 0 0 0 (Current) 0 00 00 Background Maximum Minimum ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Current) 0 00 00 Background Maximum Minimum Units* 0 0 0 Depth 0 0 0 0 C-2 C-3 C-4i C-4n C-5i Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman W OB RPM Condition 13601 to 13601 Depth in Drilling All Circ Finish testing BOPs. R/U GBR Casing. RIH w/ 5.5" slotted liner. % md. -- MWD Summary Current ROP (ft/hr) 13601' 13601' 0' Flow In (gpm) Current Pump & Flow Data: - $2,685.00 $79,240.00 Report For:Total Charges: Max @ ft Daily Charges: Max Max RIH w/ 5.5" LinerRig Activity: Flow In (spm) Keener/W alls/Buchanan 4.23 - Alkal Lime -Min -Avg AvgMin API FL TuffGvlCoal C-5n Sh Size 13601'11.6 Bit Type TFA Hours Depth in / out Footage C-1 PWD Oil / W ater Tools ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 24 14-Nov-2011 24:00:00Time: Report #: Date: 57 Cly Gas Summary 0 0 Chromatograph (ppm) Ss Lst 16 ClystChtSiltSiltst 9.40 Ratio cP ml/30min 66 / 34 17 PV YP Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl) (Max) Trip 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Max) Trip 24 hr Recap: PV YP Cor Solids (lb/100ft2)Mud (lb/bbl)Ratio cP ml/30min 9.00 Cht Silt SiltstSs LstClyst Gas Summary 0 0 Chromatograph (ppm) Cly 25 15-Nov-2011 24:00:00Time: Report #: Date: ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg C-1 PWD Oil / W ater Tools Size 13601' Bit Type TFA Hours Depth in / out Footage TuffGvlCoal C-5n Sh - Alkal Lime -Min -Avg AvgMin API FL Max @ ft Daily Charges: Max Max L/D DPRig Activity: Flow In (spm) Keener/W alls/Buchanan 4.23 $2,685.00 $81,925.00 Report For:Total Charges: 13601' 13601' 0' Flow In (gpm) Current Pump & Flow Data: - Current ROP (ft/hr) MWD Summary -- All Circ Set 5.5" liner. Displace OBM to KCl NaCl Brine. L/D DP. % md. W OB RPM Condition 13601 to 13601 Depth in Drilling Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0 0Average 0 0 0 0 C-4i C-4n C-5iC-2 C-3Units* 0 0 0 Depth 0 0 0 0 (Current) 0 00 00 Background Maximum Minimum ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air (Current) 2685 Current daily charge 0 00 00 Background Maximum Minimum Units* 0 0 0 Depth 0 0 0 0 C-2 C-3 C-4i C-4n C-5i Average 0 0 0 0 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: Logging Engineers:Emil OpitzReport By:Emil Opitz / Zachary Beekman W OB RPM Condition 13601 to 13601 Depth in Drilling All Circ % md. 4000 Co. Mans W orkstation charge not added to daily charges (10 days @ 400/day) 300 Sample catcher changeout on 11/6/11 for Mewborn/W elch -- Daily Charges include: 8000 Holding charge not yet posted to total charges from last months field ticket MWD Summary Current ROP (ft/hr) 13601' 13601' 0' Flow In (gpm) Current Pump & Flow Data: - $16,832.50 $98,757.50 Report For:Total Charges: Max @ ft Daily Charges: Max Max CompletionRig Activity: Flow In (spm) Keener/Smith/Buchanan 4.23 - Alkal Lime -Min -Avg AvgMin API FL TuffGvlCoal C-5n Sh Size 13601' Bit Type TFA Hours Depth in / out Footage C-1 PWD Oil / W ater Tools ENI Petroleum SP18-N5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009010095 Customer: Well: Avg 26 16-Nov-2011 24:00:00Time: Report #: Date: Cly Gas Summary 0 0 Chromatograph (ppm) Ss LstClystChtSiltSiltst 9.00 Ratio cP ml/30min PV YP Cor Solids (lb/100ft2)Mud (lb/bbl) (Max) 1847.5 Consumables for the well Trip 24 hr Recap: WE L L N A M E : SP 1 8 - N 5 LO C A T I O N : Spy Island OP E R A T O R : EN I P e t r o l e u m AR E A : North Slope MU D C O : MI S w a c o ST A T E : Alaska RI G : Do y o n 1 5 SP U D : 22-Oct-11 SP E R R Y J O B : AK - A M - 0 0 0 9 0 1 0 0 9 5 TD : 11-Nov-11 BI T RE C O R D BH A # S D L RU N # Bi t # B i t T y p e B i t Si z e De p t h In De p t h Ou t Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 2 1 0 0 1 H u g h e s M X - 1 1 6 . 0 0 1 6 0 1 4 3 6 1 2 7 6 9 . 6 0 1 . 1 7 0 1 3 3 . 0 14 43 1 5 1 8 7 3 5 1 - 2 - W T - G - 0 - I - - D T F P O O H f o r M W D t o o l f a i l u r e 3 2 0 0 1 R R H u g h e s M X - 1 1 6 . 0 0 1 4 3 6 2 6 8 4 1 2 4 8 8 . 5 0 1 . 1 7 0 1 5 1 . 0 12 43 1 8 3 1 6 6 3 2- 2 - W T - G - 0 - I - N O - T D TD Surface Section 4 3 0 0 2 S m i t h G F 2 0 B 1 2 . 2 5 2 6 8 4 3 2 3 3 5 4 9 7 . 9 0 1 . 1 1 6 6 9 . 6 20 80 1 5 2 0 9 1 0 1- 1 - W T - T - 1 - 1 / 1 6 - P N - C D POOH for Mud Motor, unable to make build with rotary steerable 5 4 0 0 3 S m i t h G F 2 0 B 1 2 . 2 5 3 2 3 3 6 1 1 7 2 8 8 4 3 5 . 8 0 1 . 1 1 6 8 0 . 7 25 80 2 0 7 0 9 0 0 1 - 3 - L T - G - 0 - 8 - S D - T D T D I n t e r m e d i a t e S e c t i o n 6 6 0 0 4 S m i t h M D S i 6 1 6 - B P X 8 . 7 5 6 1 1 7 1 3 6 0 1 9 2 0 0 5 1 . 2 0 0 . 9 0 2 17 9 . 6 9 1 3 0 2 6 5 0 5 5 0 1 - 2 - C T - S - X - I - B T - T D S t a t i s t i c s i n c l u d e d r illing of PB1 W E L L N A M E : SP 1 8 - N 5 & S P 1 8 - N 5 P B 1 LO C A T I O N : Sp y I s l a n d OP E R A T O R : EN I P e t r o l e u m AR E A : No r t h S l o p e MU D C O : MI S w a c o ST A T E : A la s k a RI G : Do y o n 1 5 SP U D : 22 - O c t - 1 1 SP E R R Y J O B : A K- A M - 0 0 0 9 0 1 0 0 9 5 TD : 11 - N o v - 1 1 Mu d R e c o r d W a t e r B a s e d M u d R e c o r d 16 0 ' t o 2 , 6 8 4 ' 2, 6 8 4 ' t o 6 , 1 1 7 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l m g / l C a + + 22 - O c t 1 6 0 8 . 7 0 1 7 3 6 2 0 / 3 7 / - 5 . 6 7 0 / 5 3 / 4 3 / 3 2 / 1 6 / 1 4 1 / - 2 . 0 1 \ 98 0 . 0 0 0 . 1 4 9 . 3 2 0 . 0 . 1 0 / . 6 0 3 4 0 0 6 0 C l e a n o u t c o n d u c t o r 23 - O c t 9 2 3 9 . 0 0 8 0 2 3 3 6 2 1 / 3 7 / 4 4 4 . 5 8 2 / 5 9 / 4 8 / 3 2 / 1 9 / 1 3 1 / na 3 . 0 1 \ 9 6 0 . 1 0 0 . 0 5 9 . 0 2 0 . 0 .0 5 / . 4 0 3 6 0 0 60 Drilling 24 - O c t 1 5 0 0 9 . 3 0 7 8 1 9 3 1 2 2 / 4 1 / 5 0 4 . 8 6 9 / 5 0 / 4 3 / 3 3 / 1 9 / 1 7 1 / na 4 . 5 1 \ 9 5 0 . 5 0 0 . 0 5 8 . 9 2 0 . 0 .0 5 / . 4 6 2 7 0 0 60 Drilling 25 - O c t 2 6 8 4 9 . 4 0 6 4 2 2 2 7 1 3 / 3 9 / - 4 . 7 7 1 / 4 9 / 4 0 / 3 0 / 1 4 / 1 2 1 / n a 5. 0 1 \ 9 4 0 . 1 0 0 . 0 5 8 . 9 2 2 . 5 . 0 7 / . 4 1 1 3 0 0 4 0 S u r f a c e T D 26 - O c t 2 6 8 4 9 . 3 0 4 5 1 9 1 6 8 / 1 1 / 1 3 5 . 4 5 4 / 3 5 / 2 7 / 1 9 / 7 / 6 1 / n a 5 . 0 - 0 . 1 0 0 . 0 4 8 . 8 2 0 . 0 . 0 3 / . 3 0 1 2 0 0 4 0 R u n C a s i n g 27 - O c t 2 6 6 9 9 . 2 0 - 1 0 2 1 1 1 / 1 4 / - 5 . 7 4 1 / 3 1 / 2 7 / 2 1 / 1 0 / 8 1 / n a 4 . 0 1 \ 9 5 0 . 0 0 0 . 1 5 9 . 8 5 . 0 . 1 0 / 1 . 0 0 7 0 0 8 0 T e s t B O P s 28 - O c t 2 7 1 1 9 . 3 0 5 4 1 1 1 9 1 1 / 1 5 / - 5 . 8 4 1 / 3 0 / 2 5 / 2 0 / 1 0 / 7 1 / n a 4 . 0 - 0 . 0 0 0 . 1 4 9 . 7 5 . 0 . 1 0 / 1 . 1 0 7 0 0 8 0 D r i l l o u t c e m e n t 29 - O c t 3 2 3 3 9 . 3 0 - 1 2 2 4 1 1 / 1 6 / 1 7 5 . 2 4 8 / 3 6 / 3 1 / 2 4 / 1 1 / 9 1 / n a 4 .0 3 \ 9 4 0 . 1 0 0 . 2 7 9 . 9 7 . 5 .1 7 / 1 . 4 0 8 0 0 40 Drilling 30 - O c t 4 0 5 5 9 . 3 5 5 4 1 1 2 5 1 2 / 1 8 / 2 0 4 . 5 4 7 / 3 6 / 3 0 / 2 3 / 1 2 / 1 0 1 / na 5 . 0 3 \ 9 2 0 . 1 0 0 . 1 3 9 . 6 1 0 . 0 1. 1 0 / 1 . 3 0 1 1 0 0 50 Drilling 31 - O c t 5 0 3 4 9 . 4 0 5 5 1 3 2 7 1 3 / 1 9 / 2 2 3 . 6 5 3 / 4 0 / 3 4 / 2 6 / 1 3 / 1 1 1 / na 6 . 0 3 \ 9 1 0 . 1 0 0 . 0 5 9 . 1 1 2 . 5 .0 6 / 1 . 2 5 1 3 0 0 50 Drilling 1- N o v 6 0 8 0 9 . 5 0 5 4 1 2 2 7 1 5 / 2 1 / 2 5 3 . 6 5 1 / 3 9 / 3 4 / 2 6 / 1 3 / 1 1 1 / na 7 . 0 3 \ 9 0 0 . 1 0 0 . 0 3 9 . 2 1 7 . 5 .0 4 / 1 . 0 0 1 4 0 0 50 Drilling 2- N o v 6 1 1 7 9 . 6 0 5 5 1 3 2 4 1 3 / 1 9 / 2 4 3 . 8 5 0 / 3 7 / 3 3 / 2 6 / 1 2 / 1 1 1 / n a 7 . 2 3\ 8 9 . 8 0 . 1 0 0 . 0 4 9 . 2 2 0 . 0 . 0 4 / 1 . 2 0 1 3 0 0 5 0 I n t e r m e d i a t e T D 3N o v 61 1 7 96 0 47 13 17 43 / 3 0 / 2 5 / 2 0 / 8 / 7 Run Casing In t e r m e d i a t e S e c t i o n Su r f a c e S e c t i o n MI S p u d M u d LS N D 3 -No v 61 1 7 9 .60 47 13 17 - - 43 / 3 0 / 2 5 / 2 0 / 8 / 7 -- - - - - - - - - Run Casing 4- N o v 6 1 1 7 9 . 5 0 5 6 1 3 1 7 - - 4 3 / 3 0 / 2 6 / 2 0 / 8 / 7 - - - - - - - - - - F r e e z e P r o t e c t 5- N o v 6 1 1 7 9 . 5 0 5 7 1 3 1 6 - - 4 2 / 2 9 / 2 4 / 1 7 / 8 / 7 - - - - - - - - - - C a s i n g P r e s s u r e T e s t L e a k 6- N o v 6 1 3 7 9 . 2 0 5 2 1 3 1 5 - - 4 1 / 2 8 / 2 3 / 1 6 / 8 / 6 - - - - - - - - - - D r i l l o u t c e m e n t Oi l B a s e d M u d R e c o r d 6, 1 1 7 ' t o 1 3 , 6 0 1 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e C or r . So l i d s Oi l / W a t e r Oi l P m L i m e S a l t C l - Em u l St a b i l i t y S d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l l b / b b l % W t m g / L m g / l % v o l 4- N o v 6 1 1 7 9 . 4 0 4 8 1 3 1 5 7 / 8 / 8 - 4 1 / 2 8 / 2 3 / 1 7 / 8 / 7 n a / 6 . 7 6 6 \ 3 4 5 8 2 . 9 0 2 . 7 7 3 8 . 5 0 1 2 0 0 0 0 7 2 0 - F r e e z e P r o t e c t 5- N o v 6 1 1 7 9 . 4 0 4 8 1 3 1 5 7 / 8 / 8 - 4 1 / 2 8 / 2 3 / 1 7 / 8 / 7 n a / n a 6 . 7 6 6 \ 34 5 8 2 . 9 0 3 . 7 7 3 8 . 5 0 1 2 0 0 0 0 7 2 0 - C a s i n g P r e s s u r e T e s t L e a k 6- N o v 6 1 1 7 9 . 4 5 4 7 1 3 1 5 7 / 8 / 8 - 4 1 / 2 8 / 2 3 / 1 7 / 8 / 7 n a / n a - 6 6 \ 3 4 5 8 2 . 9 0 3 . 7 7 3 8 . 5 0 1 2 0 0 0 0 7 2 0 - D r i l l o u t c e m e n t 7- N o v 7 8 5 1 9 . 5 0 4 9 1 6 1 6 4 / 8 / 8 4 . 0 4 8 / 3 2 / 2 6 / 1 9 / 8 / 7 n a / 1 1 0 . 0 6 5 \ 3 5 5 7 2 . 8 5 3 . 7 1 29 . 3 8 8 0 0 0 0 7 3 0 0.10 Drilling 8- N o v 7 8 1 5 9 . 4 0 4 7 1 4 1 5 6 / 7 / 7 4 . 6 4 3 / 2 9 / 2 2 / 1 6 / 7 / 6 n a / 1 1 0 . 6 64 \ 3 6 5 6 2 . 2 0 2 . 8 6 2 4 . 7 1 6 5 0 0 0 8 0 0 0 . 2 0 O p e n H o l e S i d e t r a c k @ 7 7 9 5 ' 9- N o v 9 7 6 7 9 . 4 0 4 8 1 5 1 5 7 / 8 / 8 4 . 2 4 5 / 3 0 / 2 4 / 1 7 / 8 / 7 n a / 1 1 0 . 6 6 6 \ 3 4 5 7 2 . 0 0 2 . 6 0 24 . 1 4 6 1 0 0 0 8 1 0 0.20 Drilling 10 - N o v 1 2 1 8 8 9 . 5 0 5 2 1 6 1 7 7 / 8 / 8 4 . 4 4 9 / 3 3 / 2 6 / 1 8 / 8 / 7 n a / 1 1 1 . 7 6 6 \ 3 4 5 7 2 . 4 0 3 . 1 2 25 . 5 0 6 3 0 0 0 7 6 0 0.25 Drilling 11 - N o v 1 3 6 0 1 9 . 4 0 5 0 1 5 1 8 7 / 8 / 8 4 . 6 4 8 / 3 3 / 2 7 / 1 9 / 8 / 7 na / 1 1 1 . 8 6 6 \ 3 4 5 7 2 . 1 0 2 . 7 3 2 5 . 2 0 6 2 0 0 0 7 2 0 0 . 2 5 P r o d u c t i o n T D 12 - N o v 1 3 6 0 1 9 . 4 0 5 5 1 6 1 7 4 / 8 / 8 - 4 9 / 3 3 / 2 7 / 1 9 / 8 / 7 - 1 1 . 6 6 6 \ 3 4 5 7 2 . 0 0 2 . 6 0 2 5 . 0 7 6 2 0 0 0 8 5 0 0 . 2 0 B R O O H 13 - N o v 1 3 6 0 1 9 . 4 0 5 7 1 6 1 7 7 / 8 / 8 - 4 9 / 3 3 / 2 6 / 1 9 / 8 / 7 - 1 1 . 6 6 6 \ 3 4 5 7 2 . 0 0 2 . 6 0 2 5 . 0 7 6 2 0 0 0 8 2 0 0 . 1 0 P O O H 14 - N o v 1 3 6 0 1 9 . 4 0 5 7 1 6 1 7 7 / 8 / 8 - 4 9 / 3 3 / 2 6 / 1 9 / 8 / 7 - 1 1 . 6 6 6 \ 3 4 5 7 2. 0 0 2 . 6 0 2 4 . 7 7 6 1 0 0 0 8 2 0 0 . 1 0 R I H w / 5 . 5 " S l o t t e d L i n e r 9 5 / 8 " I n t e r m e d i a t e @ 6 1 0 3 ' Ca s i n g R e c o r d Pr o d u c t i o n S e c t i o n Fa z e P r o 20 " C o n d u c to r @ 1 6 0 ' 13 3 / 8 " S u r f a c e @ 2 , 6 6 9 ' Marker MD INC AZ TVD TVDSS Top of Permafrost 838.00 6.34 296.73 837.27 781.07 Base of Permafrost 1692.00 18.79 298.97 1667.96 1611.76 Top West Sak 2408.00 37.98 290.91 2300.03 2243.83 Tuffaceous Shale 3674.00 70.19 255.89 2959.11 2902.91 Hue_1 3998.00 70.93 257.14 3065.82 3009.62 Hue_2 4340.00 70.48 258.62 3179.04 3122.84 Top of 9 7/8" Liner 4498.00 70.66 258.38 3231.52 3175.32 SCP 4659.80 71.14 259.64 3285.15 3228.95 Brook 2B 7643.00 70.31 258.35 4266.47 4210.27 Torok Top 9797.00 70.95 257.43 4978.08 4921.88 Torok Base 10382.00 70.92 245.48 5168.77 5112.57 Top of 7" Liner Tieback Seal 10829.00 70.75 228.12 5315.31 5259.11 Torok SH_1 10930.00 70.71 223.66 5348.78 5292.58 ICP1 10978.00 71.07 222.82 5364.53 5308.33 Top HRZ 12244.00 74.04 182.90 5750.02 5693.82 Base HRZ 12713.00 74.33 172.43 5877.78 5821.58 Kalubik Marker 13008.00 75.28 162.55 5955.25 5899.05 Top Kup C 13236.00 76.37 154.36 6009.32 5953.12 LCU 13239.00 76.36 154.27 6010.03 5953.83 BCU 13834.00 78.98 142.75 6137.29 6081.09 T1 13991.00 79.90 140.87 6166.08 6109.88 Top Nuiqsut_D1 14061.00 80.24 139.76 6178.14 6121.94 Top Nuiq::Nuiq_1_D1 14080.00 80.34 139.74 6181.35 6125.15 ICP2 14106.00 80.53 139.63 6185.67 6129.47 T2 14425.00 87.03 141.78 6220.09 6163.89 Nuiq_1::Nuiq_2_D1 14460.00 86.99 141.07 6221.91 6165.71 Nuiq_2::Nuiq_3_D1 14573.00 86.08 138.46 6228.41 6172.21 ODSN-17 Interpolated Tops q_ q_ _ Nuiq_3::Nuiq_4_D1 14760.00 86.09 136.94 6240.14 6183.94 Nuiq_4::Nuiq_5_D1 14863.00 85.03 135.86 6248.45 6192.25 T3 15000.00 86.65 136.08 6258.99 6202.79 T4 (Invert #1)15212.87 90.00 139.92 6266.33 6210.13 T5 15400.00 94.40 140.79 6257.82 6201.62 Nuiq_5::Nuiq_4_U2 15400.00 94.40 140.79 6257.82 6201.62 Nuiq_4::Nuiq_3_U2 15493.00 94.11 140.01 6251.08 6194.88 Nuiq_3::Nuiq_2_U2 15601.00 94.38 138.81 6242.75 6186.55 Nuiq_2::Nuiq_1_U2 15677.00 93.95 137.93 6237.38 6181.18 T6 15700.00 94.29 137.49 6235.72 6179.52 T7 (Revert #2)15854.23 90.00 141.21 6228.00 6171.80 T8 16000.00 85.64 144.07 6235.08 6178.88 Nuiq_1::Nuiq_2_D3 16105.00 85.00 143.72 6243.50 6187.30 Nuiq_2::Nuiq_3_D3 16196.00 84.24 140.01 6252.04 6195.84 Nuiq_3::Nuiq_4_D3 16319.00 84.30 138.72 6264.79 6208.59 Nuiq_4::Nuiq_5_D3 16430.00 85.80 139.96 6274.53 6218.33 T9 16500.00 85.94 139.87 6279.50 6223.30 T10 (Invert #2)17098.72 90.00 141.12 6312.80 6256.60 T11 17205.40 94.00 142.93 6308.93 6252.73 Nuiq_5::Nuiq_4_U4 17510.00 94.70 139.62 6287.67 6231.47 Nuiq_4::Nuiq_3_U4 17580.00 94.97 139.42 6281.76 6225.56 Nuiq_3::Nuiq_2_U4 17707.00 94.55 139.67 6271.24 6215.04 Nuiq_2::Nuiq_1_U4 17785.00 94.95 139.38 6264.78 6208.58 T12 17800.00 94.68 139.42 6263.51 6207.31 T13 (Revert #3)18090.59 90.00 141.14 6248.33 6192.13 T14 18310.00 85.91 140.91 6259.03 6202.83 Nuiq_1::Nuiq_2_D5 18475.00 84.67 140.54 6271.26 6215.06 Nuiq_2::Nuiq_3_D5 18557.00 84.45 140.12 6279.03 6222.83 Nuiq_3::Nuiq_4_D5 18715.00 86.58 140.22 6291.15 6234.95 Nuiq_4::Nuiq_5_D5 18861.00 87.03 141.20 6298.87 6242.67 Nuiq_5::Transition Zone 19511.00 86.39 140.03 6346.96 6290.76 Nuiq_5::Nuiq_Base_D5 19775.00 85.00 140.20 6365.91 6309.71 T15 - TD 19947.00 84.88 140.35 6382.31 6326.11 Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: Andrew Buchanan SP18-N5 PB1 Spy Island ENI Petroleum Emil Opitz 7 Nov - 8 Nov 2011 OA Sands 7700 8500 3977 1 3963 1 Dt h ft C1 C1 C1 C1 Oil shows and information produced by this Show Report is severly effected by FazePro OBM; Production Analysis findings within this report do not properly represent actual downhole conditions or producibility of this well. 1352 Interpretation: GU i t7700 Hydrocarbon Ratios Md C h l i d ( / L )80000Depthft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -=102 64 1352 153869 408 166 315 146 178 55 123 425 74 351 2237169 10703 143166 1164 847 Gas Units7700 Mud Chlorides (mg/L) =80000 1000 NPH Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 214629 9315 533 7900 439 1291 Gas Units 205314 468 65 1822 Mud Chlorides (mg/L) =80000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 171 95 76 10818139 46 159 341 129 205 212 968 2702 Gas Units Mud Chlorides (mg/L) =75000 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 4 131564 16752 205 150 355 55 368 182 458 90 114812 138 217 86 96 765 529 1335 312 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 198 108 90 209 97482 8480 377 161 411 81 62 147 88620 330 8862 216 603 410 985 269 797Gas Units Mud Chlorides (mg/L) =75000 10.0 NPH Oil Gas C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 198 108 90 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3906 1 3848 Andrew Buchanan 31 Oct - 1 Nov 2011 N Sands 5050 5300SP18-N5 Spy Island ENI Petroleum Emil Opitz 1 Dt h ft C1 C1 C1 C1 Interpretation: GU i t 7395103 No producible oil within these zones based upon gas and chromatograph data collected. 1300Md C h l i d ( / L ) Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Gas Units 739 11 0 82840 7531 #DIV/0! 93570 448 5103 0 0 0 #DIV/0!0 11 209 24 10730 185 0 0 1300Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = Gas Units 193132 452 10730 476 5138 203862 1689 24 Mud Chlorides (mg/L) =1300 427 7725 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Gas Units 1 1775 193132 0 0 0 25 5233 1 0 Mud Chlorides (mg/L) =1300 25 0 #DIV/0! 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 429 452 193694 26 #DIV/0! 193694 7450 0 0 1 0 206902 13208 4 503 51 30 0 1 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 362 Gas Units #DIV/0! 427 7366 #DIV/0!4 21 154680 0 0 0 413 51 5240 25 1457 0 0 0 167888 13208 Mud Chlorides (mg/L) =1300 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0 0 0 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3998 2 3992 Andrew Buchanan 1-Nov-11 OA Sands 5870 6117SP18-N5 Spy Island ENI Petroleum Emil Opitz 1 Dt h ft C1 C1 C1 C1 Interpretation: GU i t 44445875 No producible oil within these zones based upon gas and chromatograph data collected. Md C h l i d ( / L )1400 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Gas Units 4444 1454 8 368469 255 131 378098 164 5875 1458 2842 20 2562822 1446 2268 17 9629 2251 20 1438 Mud Chlorides (mg/L) =1400 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = Gas Units 351805 2252 19334 2354 5986 371139 4335 102 Mud Chlorides (mg/L) =1400 156 221 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Gas Units 1820 5349 193 98 1529 290 1689 6047 2041 221 Mud Chlorides (mg/L) =1400 1591 1239 284 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 124 2926 361758 2176 263 156 166 948 1373 2316 746 407103 45345 295 3199 273 2471 2321 3062 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 1541 Gas Units 270 187 259 689295 1112 287959 418 1366 948 1814 273 6069 1407 2817 1814 746 1068 333304 45345 Mud Chlorides (mg/L) =1400 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 1814 746 1068 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: Andrew Buchanan SP18-N5 Spy Island ENI Petroleum Emil Opitz 7 Nov - 10 Nov 2011 OA Sands 6117 11235 3952 3 3998 1 Dt h ft C1 C1 C1 C1 Oil shows and information produced by this Show Report is severly effected by FazePro OBM; Production Analysis findings within this report do not properly represent actual downhole conditions or producibility of this well. 6257 Interpretation: GU i t Hydrocarbon Ratios Md C h l i d ( / L )90000876Depthft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -=0 56 6257 126 9 111850 117 238 14 2301 109549 224 1956165 56 183 18 936 664 Gas Units Mud Chlorides (mg/L) =90000 489 876 1000 NPH Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 7701 161020 10181 437 1289 Gas Units 150839 345 72 417 Mud Chlorides (mg/L) =800001350 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 167 102 65 13719864 Mud Chlorides (mg/L) = 52 117 136 143 169 -7 -21548 2321 Gas Units 61000 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 4 233 186 176 47 655 70 585 211 158328 5625 152703 105 3915 137 39 106 1441 821 261 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 450 157 293 519 122515 6068 1091 364 228 856 89 11232 88 431 116447 136 270 856 397 767 Gas Units Mud Chlorides (mg/L) =68000 152 10.0 NPH Oil Gas C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 450 157 293 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: Andrew Buchanan SP18-N5 Spy Island ENI Petroleum Emil Opitz 10 Nov - 11 Nov 2011 OA Sands 11900 13400 3895 4 3897 1 Dt h ft C1 C1 C1 C1 Oil shows and information produced by this Show Report is severly effected by FazePro OBM; Production Analysis findings within this report do not properly represent actual downhole conditions or producibility of this well. 1981 Md C h l i d ( / L )68000 Interpretation: GU i t11998 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -=104 181 1981 Mud Chlorides (mg/L) =68000 220452 289 285 653 142 469 65 404 812 74 738 7497 212955 527 417 1177511 Gas Units11998 1000 NPH Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 =784 12188 201750 9296 273 535 Gas Units 192454 706 78 1741 Mud Chlorides (mg/L) =65000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 275 112 163 135012521 73 360 615 157 433 458 Gas Units Mud Chlorides (mg/L) =63000 420 1181 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 4 154063 11440 481 401 694 80 748 306 842 94 142623 176 518 189 117 356 275 755 191 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 398 166 232 558 117147 13284 865 258 888 103 109 449 112066 785 5081 607 250 185 483 143 Mud Chlorides (mg/L) =1070Gas Units 62000 10.0 NPH Oil Gas C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 398 166 232 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: Andrew Buchanan SP18-N5 PB1 Spy Island ENI Petroleum Emil Opitz 7 Nov - 8 Nov 2011 OA Sands 7700 8500 3977 1 3963 1 Dt h ft C1 C1 C1 C1 Oil shows and information produced by this Show Report is severly effected by FazePro OBM; Production Analysis findings within this report do not properly represent actual downhole conditions or producibility of this well. 1352 Interpretation: GU i t7700 Hydrocarbon Ratios Md C h l i d ( / L )80000Depthft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -=102 64 1352 153869 408 166 315 146 178 55 123 425 74 351 2237169 10703 143166 1164 847 Gas Units7700 Mud Chlorides (mg/L) =80000 1000 NPH Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 214629 9315 533 7900 439 1291 Gas Units 205314 468 65 1822 Mud Chlorides (mg/L) =80000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 171 95 76 10818139 46 159 341 129 205 212 968 2702 Gas Units Mud Chlorides (mg/L) =75000 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 4 131564 16752 205 150 355 55 368 182 458 90 114812 138 217 86 96 765 529 1335 312 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 198 108 90 209 97482 8480 377 161 411 81 62 147 88620 330 8862 216 603 410 985 269 797Gas Units Mud Chlorides (mg/L) =75000 10.0 NPH Oil Gas C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 198 108 90 1.0 NPH DIRECTIONAL SURVEY REPORT ENI Petroleum Nikaitchuq North Slope Borough Alaska USA AK-XX-0009010095 All depths reference the driller's pipe tally. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 40.00 0.10 122.18 40.00 0.02 S 0.03 E -0.02 0.25 130.00 0.37 136.45 130.00 0.27 S 0.30 E -0.27 0.30 220.00 2.03 175.16 219.98 2.07 S 0.63 E -2.07 1.95 310.00 3.40 181.57 309.87 6.33 S 0.69 E -6.33 1.56 400.00 4.88 178.75 399.64 12.82 S 0.70 E -12.82 1.66 490.00 6.96 170.83 489.15 22.03 S 1.66 E -22.03 2.48 580.00 7.50 164.76 578.44 33.08 S 4.07 E -33.08 1.04 670.00 8.20 146.73 667.61 44.12 S 9.13 E -44.12 2.83 760.00 11.66 141.00 756.25 56.56 S 18.38 E -56.56 3.99 851.39 16.43 142.73 844.88 74.03 S 32.03 E -74.03 5.24 946.79 19.49 146.74 935.63 98.08 S 48.93 E -98.08 3.46 1042.45 21.67 148.49 1025.18 126.49 S 66.92 E -126.49 2.37 1136.88 20.61 148.83 1113.25 155.57 S 84.63 E -155.57 1.13 1233.23 21.19 149.93 1203.26 185.15 S 102.13 E -185.15 0.73 1330.66 28.46 151.30 1291.63 220.80 S 122.13 E -220.80 7.48 1519.08 31.46 152.17 1454.85 303.68 S 166.66 E -303.68 1.61 1617.06 30.54 152.81 1538.84 348.44 S 189.97 E -348.44 1.00 1711.04 30.67 153.94 1619.73 391.21 S 211.41 E -391.21 0.63 1807.50 29.32 150.74 1703.27 433.92 S 233.76 E -433.92 2.17 1906.32 29.60 149.92 1789.31 476.15 S 257.82 E -476.15 0.50 1998.39 27.37 146.10 1870.24 513.40 S 281.03 E -513.40 3.13 2097.28 27.53 145.68 1958.00 551.14 S 306.59 E -551.14 0.25 2194.54 25.91 142.13 2044.87 586.48 S 332.31 E -586.48 2.34 2286.82 23.97 135.26 2128.56 615.72 S 357.89 E -615.72 3.78 2380.82 25.14 124.23 2214.10 640.53 S 387.86 E -640.53 5.03 2476.27 22.75 111.74 2301.39 658.78 S 421.79 E -658.78 5.86 2573.51 21.47 97.54 2391.54 668.09 S 456.92 E -668.09 5.64 2612.35 20.76 91.71 2427.78 669.23 S 470.85 E -669.23 5.71 2664.53 20.07 89.22 2476.68 669.38 S 489.05 E -669.38 2.13 2817.51 21.10 68.53 2620.08 658.93 S 540.99 E -658.93 4.78 2915.50 22.62 56.91 2711.07 642.18 S 573.21 E -642.18 4.67 3012.22 23.02 44.81 2800.27 618.60 S 602.14 E -618.60 4.86 3109.71 23.47 35.30 2889.88 589.22 S 626.80 E -589.22 3.87 3264.15 28.49 21.89 3028.78 529.85 S 658.35 E -529.85 4.99 3360.59 33.56 18.81 3111.41 483.24 S 675.53 E -483.24 5.51 3456.86 37.97 14.42 3189.52 429.33 S 691.50 E -429.33 5.30 3550.19 43.13 13.45 3260.41 370.46 S 706.08 E -370.46 5.57 3647.13 48.66 13.37 3327.85 302.77 S 722.21 E -302.77 5.70 3741.71 52.24 12.91 3388.06 231.77 S 738.78 E -231.77 3.80 3837.63 58.09 13.35 3442.83 155.13 S 756.67 E -155.13 6.11 3933.32 63.18 10.53 3489.75 73.57 S 773.86 E -73.57 5.91 4030.60 67.34 9.17 3530.45 13.46 N 788.96 E 13.46 4.46 4126.36 71.74 7.62 3563.92 102.20 N 802.04 E 102.20 4.84 4223.17 72.82 5.61 3593.39 193.79 N 812.65 E 193.79 2.27 4317.10 70.97 2.22 3622.58 282.85 N 818.76 E 282.85 3.96 4411.77 71.67 358.20 3652.91 372.51 N 819.08 E 372.51 4.09 4507.82 71.64 356.07 3683.15 463.55 N 814.53 E 463.55 2.11 4602.65 70.34 350.86 3714.06 552.59 N 804.34 E 552.59 5.37 4699.42 71.32 347.06 3745.84 642.28 N 786.84 E 642.28 3.84 4791.95 73.07 342.03 3774.15 727.15 N 763.35 E 727.15 5.51 4890.57 71.42 335.67 3804.25 814.70 N 729.51 E 814.70 6.37 4985.47 73.95 331.51 3832.51 895.81 N 689.20 E 895.81 4.96 5083.37 76.49 328.24 3857.49 977.66 N 641.69 E 977.66 4.14 5178.75 76.65 323.50 3879.65 1054.42 N 589.65 E 1054.42 4.84 5274.37 76.40 320.30 3901.94 1127.59 N 532.29 E 1127.59 3.26 5371.10 76.93 317.53 3924.25 1198.52 N 470.44 E 1198.52 2.84 5466.32 79.35 313.39 3943.83 1264.91 N 405.08 E 1264.91 4.96 5561.49 82.84 309.77 3958.56 1327.28 N 334.77 E 1327.28 5.25 5656.98 83.35 309.50 3970.04 1387.75 N 261.76 E 1387.75 0.60 5755.80 83.00 310.20 3981.79 1450.62 N 186.43 E 1450.62 0.79 5848.69 84.39 309.44 3991.99 1509.75 N 115.52 E 1509.75 1.70 5944.41 85.77 307.38 4000.20 1568.99 N 40.80 E 1568.99 2.58 6040.66 92.62 308.22 4001.55 1627.94 N 35.20 W 1627.94 7.17 6163.21 89.63 309.24 3999.14 1704.59 N 130.77 W 1704.59 2.58 6259.55 87.63 306.26 4001.45 1763.55 N 206.91 W 1763.55 3.72 6354.85 88.80 305.19 4004.42 1819.16 N 284.24 W 1819.16 1.66 6450.73 91.21 305.78 4004.41 1874.81 N 362.31 W 1874.81 2.59 6546.73 91.74 307.10 4001.94 1931.82 N 439.51 W 1931.82 1.48 6642.49 91.80 308.62 3998.98 1990.56 N 515.08 W 1990.56 1.59 6738.22 93.55 309.65 3994.51 2050.91 N 589.25 W 2050.91 2.12 6833.71 93.87 310.35 3988.33 2112.16 N 662.24 W 2112.16 0.80 6926.63 92.53 308.56 3983.14 2171.11 N 733.87 W 2171.11 2.40 7020.74 91.15 307.39 3980.12 2228.98 N 808.01 W 2228.98 1.92 7113.06 91.37 307.39 3978.09 2285.03 N 881.35 W 2285.03 0.24 7217.12 92.28 306.97 3974.78 2347.88 N 964.21 W 2347.88 0.96 7312.52 94.87 305.90 3968.83 2404.43 N 1040.81 W 2404.43 2.94 7407.89 92.73 306.04 3962.51 2460.32 N 1117.82 W 2460.32 2.25 7504.78 89.45 305.41 3960.67 2516.87 N 1196.45 W 2516.87 3.45 7599.85 88.69 306.18 3962.21 2572.47 N 1273.55 W 2572.47 1.14 7695.64 88.80 306.75 3964.31 2629.39 N 1350.57 W 2629.39 0.61 7791.27 89.49 307.76 3965.73 2687.27 N 1426.68 W 2687.27 1.28 7887.05 90.66 310.83 3965.61 2747.92 N 1500.79 W 2747.92 3.43 7984.00 88.97 311.80 3965.92 2811.92 N 1573.61 W 2811.92 2.01 8079.72 88.73 312.45 3967.84 2876.12 N 1644.58 W 2876.12 0.72 8176.29 88.37 313.73 3970.29 2942.06 N 1715.08 W 2942.06 1.38 8271.55 89.95 321.91 3971.69 3012.59 N 1778.98 W 3012.59 8.74 8367.66 89.09 322.75 3972.49 3088.66 N 1837.71 W 3088.66 1.25 8462.66 89.07 321.31 3974.02 3163.54 N 1896.15 W 3163.54 1.52 8559.41 87.54 318.34 3976.88 3237.42 N 1958.53 W 3237.42 3.45 8654.31 87.13 313.30 3981.29 3305.38 N 2024.58 W 3305.38 5.32 8749.20 86.69 309.56 3986.41 3368.07 N 2095.60 W 3368.07 3.96 8844.66 89.17 309.24 3989.86 3428.62 N 2169.32 W 3428.62 2.62 8938.56 92.33 310.54 3988.63 3488.82 N 2241.35 W 3488.82 3.64 9036.57 94.94 311.45 3982.42 3552.98 N 2315.17 W 3552.98 2.82 9134.83 96.67 311.73 3972.48 3617.87 N 2388.28 W 3617.87 1.78 9229.16 98.67 312.77 3959.89 3680.72 N 2457.47 W 3680.72 2.39 9324.77 98.79 312.16 3945.38 3744.52 N 2527.19 W 3744.52 0.64 9420.69 99.00 310.97 3930.55 3807.39 N 2598.09 W 3807.39 1.25 9481.00 99.00 310.97 3921.11 3846.45 N 2643.07 W 3846.45 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID) A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 9481.00 FEET IS 4667.01 FEET ALONG 325.51 DEGREES (GRID) Date Printed:16 November 2011 DIRECTIONAL SURVEY REPORT ENI Petroleum SP18-N5 Nikaitchu q North Slo pe Borough Alaska USA AK-XX-0009010095 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 40.00 0.10 122.18 40.00 0.02 S 0.03 E -0.02 0.25 130.00 0.37 136.45 130.00 0.27 S 0.30 E -0.27 0.30 220.00 2.03 175.16 219.98 2.07 S 0.63 E -2.07 1.95 310.00 3.40 181.57 309.87 6.33 S 0.69 E -6.33 1.56 400.00 4.88 178.75 399.64 12.82 S 0.70 E -12.82 1.66 490.00 6.96 170.83 489.15 22.03 S 1.66 E -22.03 2.48 580.00 7.50 164.76 578.44 33.08 S 4.07 E -33.08 1.04 670.00 8.20 146.73 667.61 44.12 S 9.13 E -44.12 2.83 760.00 11.66 141.00 756.25 56.56 S 18.38 E -56.56 3.99 851.39 16.43 142.73 844.88 74.03 S 32.03 E -74.03 5.24 946.79 19.49 146.74 935.63 98.08 S 48.93 E -98.08 3.46 1042.45 21.67 148.49 1025.18 126.49 S 66.92 E -126.49 2.37 1136.88 20.61 148.83 1113.25 155.57 S 84.63 E -155.57 1.13 1233.23 21.19 149.93 1203.26 185.15 S 102.13 E -185.15 0.73 1330.66 28.46 151.30 1291.63 220.80 S 122.13 E -220.80 7.48 1422.84 32.21 150.63 1371.17 261.49 S 144.74 E -261.49 4.08 1519.08 31.46 152.17 1452.94 306.05 S 169.04 E -306.05 1.15 1617.06 30.54 152.81 1536.92 350.81 S 192.35 E -350.81 1.00 1711.04 30.67 153.94 1617.81 393.58 S 213.79 E -393.58 0.63 1807.50 29.32 150.74 1701.36 436.29 S 236.15 E -436.29 2.17 1906.32 29.60 149.92 1787.40 478.52 S 260.21 E -478.52 0.50 1998.39 27.37 146.10 1868.32 515.77 S 283.41 E -515.77 3.13 2097.28 27.53 145.68 1956.08 553.51 S 308.98 E -553.51 0.25 2194.54 25.91 142.13 2042.96 588.85 S 334.70 E -588.85 2.34 2286.82 23.97 135.26 2126.65 618.09 S 360.28 E -618.09 3.78 2380.82 25.14 124.23 2212.19 642.90 S 390.24 E -642.90 5.03 2476.27 22.75 111.74 2299.47 661.16 S 424.17 E -661.16 5.86 2573.51 21.47 97.54 2389.63 670.46 S 459.31 E -670.46 5.64 2612.35 20.76 91.71 2425.86 671.60 S 473.24 E -671.60 5.71 2664.53 20.07 89.22 2474.77 671.76 S 491.43 E -671.76 2.13 2725.58 19.87 78.77 2532.16 669.59 S 512.09 E -669.59 5.85 2817.51 21.10 68.53 2618.31 660.49 S 542.82 E -660.49 4.12 2915.50 22.62 56.91 2709.29 643.74 S 575.04 E -643.74 4.67 3012.22 23.02 44.81 2798.49 620.15 S 603.97 E -620.15 4.86 3109.71 23.47 35.30 2888.10 590.77 S 628.63 E -590.77 3.87 3186.97 24.73 28.67 2958.64 564.03 S 645.28 E -564.03 3.86 3264.15 28.49 21.89 3027.64 532.77 S 659.90 E -532.77 6.26 3360.59 33.56 18.81 3110.27 486.16 S 677.08 E -486.16 5.51 3456.86 37.97 14.42 3188.38 432.25 S 693.04 E -432.25 5.30 3550.19 43.13 13.45 3259.27 373.38 S 707.62 E -373.38 5.57 3647.13 48.66 13.37 3326.71 305.69 S 723.76 E -305.69 5.70 3741.71 52.24 12.91 3386.92 234.69 S 740.33 E -234.69 3.80 3837.63 58.09 13.35 3441.69 158.05 S 758.22 E -158.05 6.11 3933.32 63.18 10.53 3488.61 76.49 S 775.41 E -76.49 5.91 4030.60 67.34 9.17 3529.31 10.54 N 790.50 E 10.54 4.46 4126.36 71.74 7.62 3562.78 99.28 N 803.58 E 99.28 4.84 4223.17 72.82 5.61 3592.25 190.88 N 814.20 E 190.88 2.27 4317.10 70.97 2.22 3621.44 279.93 N 820.31 E 279.93 3.96 4411.77 71.67 358.20 3651.77 369.59 N 820.63 E 369.59 4.09 4507.82 71.64 356.07 3682.01 460.63 N 816.07 E 460.63 2.11 4602.65 70.34 350.86 3712.92 549.67 N 805.89 E 549.67 5.37 4699.42 71.32 347.06 3744.70 639.36 N 788.38 E 639.36 3.84 4791.95 73.07 342.03 3773.01 724.23 N 764.90 E 724.23 5.51 4890.57 71.42 335.67 3803.11 811.78 N 731.05 E 811.78 6.37 4985.47 73.95 331.51 3831.37 892.89 N 690.75 E 892.89 4.96 5083.37 76.49 328.24 3856.35 974.74 N 643.24 E 974.74 4.14 5178.75 76.65 323.50 3878.51 1051.51 N 591.20 E 1051.51 4.84 5274.37 76.40 320.30 3900.80 1124.67 N 533.83 E 1124.67 3.26 5371.10 76.93 317.53 3923.11 1195.60 N 471.98 E 1195.60 2.84 5466.32 79.35 313.39 3942.69 1261.99 N 406.63 E 1261.99 4.96 5561.49 82.84 309.77 3957.42 1324.36 N 336.31 E 1324.36 5.25 5656.98 83.35 309.50 3968.90 1384.83 N 263.31 E 1384.83 0.60 5755.80 83.00 310.20 3980.65 1447.70 N 187.98 E 1447.70 0.79 5848.69 84.39 309.45 3990.85 1506.83 N 117.07 E 1506.83 1.70 5944.41 85.77 307.38 3999.06 1566.08 N 42.35 E 1566.08 2.59 6040.66 92.62 308.22 4000.41 1625.03 N 33.65 W 1625.03 7.17 6137.49 90.41 309.20 3997.85 1685.56 N 109.17 W 1685.56 2.50 6163.21 89.63 309.24 3997.84 1701.83 N 129.10 W 1701.83 3.04 6259.55 87.63 306.26 4000.14 1760.78 N 205.24 W 1760.78 3.72 6354.85 88.80 305.19 4003.11 1816.40 N 282.57 W 1816.40 1.66 6450.73 91.21 305.78 4003.10 1872.05 N 360.63 W 1872.05 2.59 6546.73 91.74 307.10 4000.63 1929.05 N 437.83 W 1929.05 1.48 6642.49 91.80 308.62 3997.68 1987.79 N 513.40 W 1987.79 1.59 6738.22 93.55 309.65 3993.21 2048.15 N 587.57 W 2048.15 2.12 6833.71 93.87 310.35 3987.03 2109.40 N 660.57 W 2109.40 0.80 6926.63 92.53 308.56 3981.84 2168.35 N 732.20 W 2168.35 2.40 7020.74 91.15 307.39 3978.82 2226.22 N 806.34 W 2226.22 1.92 7113.06 91.37 307.39 3976.79 2282.27 N 879.67 W 2282.27 0.24 7217.12 92.28 306.97 3973.48 2345.12 N 962.54 W 2345.12 0.96 7312.52 94.87 305.90 3967.53 2401.67 N 1039.13 W 2401.67 2.94 7407.89 92.73 306.04 3961.21 2457.56 N 1116.14 W 2457.56 2.25 7504.78 89.45 305.41 3959.36 2514.11 N 1194.78 W 2514.11 3.45 7599.85 88.69 306.18 3960.91 2569.71 N 1271.88 W 2569.71 1.14 7695.64 88.80 306.75 3963.01 2626.63 N 1348.90 W 2626.63 0.61 7789.90 89.50 308.22 3964.40 2683.98 N 1423.68 W 2683.98 1.73 7881.15 89.40 308.00 3965.28 2740.29 N 1495.48 W 2740.29 0.26 7978.13 87.56 306.05 3967.85 2798.67 N 1572.87 W 2798.67 2.76 8069.74 86.42 307.27 3972.66 2853.29 N 1646.25 W 2853.29 1.82 8175.05 88.83 308.97 3977.03 2918.23 N 1729.02 W 2918.23 2.80 8271.53 88.82 310.16 3979.01 2979.67 N 1803.38 W 2979.67 1.23 8366.40 90.20 313.44 3979.82 3042.89 N 1874.09 W 3042.89 3.75 8462.59 91.51 316.33 3978.38 3110.76 N 1942.23 W 3110.76 3.30 8559.01 94.18 318.04 3973.60 3181.39 N 2007.67 W 3181.39 3.29 8654.73 91.65 317.79 3968.73 3252.33 N 2071.74 W 3252.33 2.66 8751.02 90.10 316.43 3967.26 3322.86 N 2137.26 W 3322.86 2.14 8844.84 92.77 315.33 3964.91 3390.19 N 2202.55 W 3390.19 3.08 8941.26 91.70 314.26 3961.15 3458.07 N 2270.91 W 3458.07 1.57 9037.16 89.91 313.79 3959.80 3524.71 N 2339.86 W 3524.71 1.93 9133.57 88.73 311.79 3960.95 3590.19 N 2410.60 W 3590.19 2.41 9229.82 89.23 312.63 3962.66 3654.85 N 2481.88 W 3654.85 1.02 9325.74 89.87 314.01 3963.41 3720.65 N 2551.66 W 3720.65 1.59 9419.85 89.95 316.10 3963.56 3787.26 N 2618.14 W 3787.26 2.22 9515.35 89.92 317.68 3963.67 3856.97 N 2683.40 W 3856.97 1.65 9612.76 90.08 316.92 3963.67 3928.56 N 2749.46 W 3928.56 0.80 9708.14 90.56 315.31 3963.14 3997.30 N 2815.58 W 3997.30 1.76 9804.14 91.98 311.47 3961.01 4063.22 N 2885.31 W 4063.22 4.26 9900.37 92.73 310.35 3957.05 4126.18 N 2957.97 W 4126.18 1.40 9995.96 91.36 312.88 3953.64 4189.62 N 3029.38 W 4189.62 3.01 10091.66 91.52 311.76 3951.24 4254.03 N 3100.12 W 4254.03 1.18 10185.66 91.46 311.11 3948.79 4316.21 N 3170.56 W 4316.21 0.69 10284.14 89.91 309.90 3947.61 4380.17 N 3245.43 W 4380.17 2.00 10378.71 89.33 309.59 3948.24 4440.63 N 3318.15 W 4440.63 0.70 10475.45 90.28 309.45 3948.57 4502.19 N 3392.77 W 4502.19 0.99 10572.08 89.82 311.61 3948.49 4564.98 N 3466.21 W 4564.98 2.29 10666.33 89.83 311.72 3948.77 4627.64 N 3536.62 W 4627.64 0.12 10762.00 89.83 311.40 3949.06 4691.11 N 3608.21 W 4691.11 0.33 10858.62 89.69 310.58 3949.46 4754.48 N 3681.14 W 4754.48 0.86 10954.53 89.32 310.70 3950.29 4816.95 N 3753.91 W 4816.95 0.41 11049.55 89.52 305.70 3951.25 4875.68 N 3828.56 W 4875.68 5.27 11144.42 89.52 303.72 3952.05 4929.70 N 3906.54 W 4929.70 2.09 11240.86 89.68 303.93 3952.72 4983.38 N 3986.65 W 4983.38 0.27 11336.70 92.96 305.74 3950.52 5038.10 N 4065.28 W 5038.10 3.91 11432.35 95.11 308.30 3943.78 5095.54 N 4141.45 W 5095.54 3.49 11528.97 98.49 310.99 3932.34 5156.73 N 4215.32 W 5156.73 4.46 11624.79 98.19 314.64 3918.44 5221.16 N 4284.85 W 5221.16 3.78 11721.07 95.44 315.46 3907.02 5288.81 N 4352.38 W 5288.81 2.98 11816.67 93.26 314.25 3899.77 5356.04 N 4419.95 W 5356.04 2.61 11912.99 90.16 312.23 3896.89 5421.98 N 4490.08 W 5421.98 3.84 12009.07 90.72 311.96 3896.15 5486.38 N 4561.37 W 5486.38 0.65 12105.13 87.60 311.73 3897.56 5550.45 N 4632.91 W 5550.45 3.26 12200.87 87.67 310.70 3901.51 5613.48 N 4704.87 W 5613.48 1.08 12296.04 87.33 310.91 3905.66 5675.61 N 4776.84 W 5675.61 0.42 12391.71 88.19 312.58 3909.40 5739.26 N 4848.16 W 5739.26 1.96 12487.88 90.10 313.57 3910.84 5804.93 N 4918.40 W 5804.93 2.24 12584.91 90.78 315.20 3910.09 5872.79 N 4987.74 W 5872.79 1.82 12679.61 91.10 315.09 3908.54 5939.92 N 5054.52 W 5939.92 0.36 12774.97 90.52 313.10 3907.19 6006.26 N 5123.00 W 6006.26 2.17 12871.31 89.93 312.07 3906.81 6071.45 N 5193.93 W 6071.45 1.23 12966.31 90.38 312.48 3906.56 6135.36 N 5264.22 W 6135.36 0.64 13062.11 90.38 312.49 3905.92 6200.06 N 5334.87 W 6200.06 0.01 13159.16 90.33 312.25 3905.32 6265.46 N 5406.57 W 6265.46 0.25 13253.63 91.91 311.95 3903.47 6328.78 N 5476.65 W 6328.78 1.70 13349.42 93.65 313.36 3898.83 6393.61 N 5547.01 W 6393.61 2.34 13444.46 96.75 313.30 3890.21 6458.55 N 5615.85 W 6458.55 3.26 13539.91 96.65 312.38 3879.08 6523.01 N 5685.36 W 6523.00 0.96 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID) A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIE D HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE ) AT 13539.91 FEET IS 8652.91 FEET ALONG 318.93 DEGREES (GRID) Date Printed:14 November 2011 0 1000 2000 3000 4000 5000 6000 7000Dep t h Prognosed Actual SP18-N5 Days vs. Depth Successful open hole sidetrack at 7795' TD 16" Hole Section 2684' MD \ 1000' TVD Off bot: 13:45 25-Oct-2011 22-Oct-2011 Pre Spud meeting and prepare to RIH 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 4 8 1 21 62 02 42 83 2 Me a s u r e d D Rig Days Decision made to stop at 9481' MD and pull back for open hole sidetrack Run & Land 5.5" slotted liner TD 8.5" Hole Section 13601' MD \ 3872' TVD Off Bot: 12:00 11-Nov-2011 TD 12.25" Hole Section 6117' MD \ 2000' TVD Off bot: 22:55 1-Nov-2011 Surface Data Logging After Action Review Employee Name: Emil Opitz Date: 16-Nov-2011 Well: SP18-N5 Hole Section: Int. & Prod. What went as, or better than, planned: Most data collection, computer operations, and general drilling operations. Difficulties experienced: We had issues monitoring gas during the intermediate section of the hole. Conducted numerous tests and re-calibrations of every component of our entire gas monitoring system, but to no avail. Problems with data-exchanging machines at camp. Users are unable to scroll/start- stop/change settings/etc due to extremely slow loading times. Recommendations: After reviewing the last well drilled on this site, determined that one other variable was different; and that was the pump rate. After reassessing the gas trap location and the new data, decided to try another gas trap located in a different location in the shaker room. This alternate location was in a less turbulent/lower flow area in the possum belly. Instantly began detecting gas in the drilling fluid. A Gas Trap standard operating procedure (SOP) has been written and discussed with all personnel. After numerous attempts to rectify the slow computer speeds, it was determined to be an issue related to the service provider (GCI) and their data transmission between the rig and the camp. Tested 3 different brand new computers, new connections wherever possible, and different set-ups for transmitting the data before coming to this conclusion. Innovations and/or cost savings: Gas Trap SOP