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Home My WebLink About212-006David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251113 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# OP08-04 50029234247000 210041 06/12/2013 SCHLUMBERGER USIT OP14-S03 50029234470000 211052 09/26/2013 SCHLUMBERGER CBL/USIT SI29-S02 50629234640000 213006 02/29/2012 SCHLUMBERGER SONIC VISION - TOC SP24-SE1 50629235100000 214011 03/19/2014 HALLIBURTON CAST-M/CBL-M/ACE Please include current contact information if different from above. T41096 T41097 T41098 T41099 212-006SI29-S02 50629234640000 213006 02/29/2012 SCHLUMBERGER SONIC VISION -TOC Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.13 13:15:44 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI29-S02 NIKAITCHUQ SI29-S02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 SI29-S02 50-629-23464-00-00 212-006-0 W SPT 3639 2120060 1500 675 675 675 675 130 130 130 130 4YRTST P Austin McLeod 6/21/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI29-S02 Inspection Date: Tubing OA Packer Depth 512 1676 1644 1635IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250621180629 BBL Pumped:2.7 BBL Returned:2.8 Thursday, July 24, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Friday, July 9, 2021 �%� % P.I. Supervisor �l r(��(� SUBJECT: Mechanical Integrity Tests Eni US Operating Company Inc. SI29-S02 FROM: Jeff Jolles NIKAITCHUQ SI29-S02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv.�� NON -CONFIDENTIAL Comm Well Name NIKAITCHUQ S129 -S02 API Well Number 50-629-23464-00-00 Inspector Name: Jeff Jones Permit Number: 212-006-0 Inspection Date: 6/26/2021 Insp Num: mitJJ210628175200 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S129-SO2Type Inj w TVD 3639 Tubing- -- PTD 2120060Type Test SPT Test psi 1500 IA 787 1700 1684- 1680 BBL Pumped: 1.8 ' IBBL Returned: 1.8 OA 255 255 - 255 255 Interval INITAL P/F P Notes: I well inspected, no exceptions noted. yn�fis Tr-- r�s� , e'cuo SttA'1 ' - �-S3 N1, Friday, July 9, 2021 Page 1 of I 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 19,464 feet N/A feet true vertical 3,834 feet N/A feet Effective Depth measured 19,422 feet 8,409' feet true vertical 3,834 feet 3,616 feet Perforation depth Measured depth 8,892-19,422 feet True Vertical depth 3,688-3,834 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 8,400' 3614' Packers and SSSV (type, measured and true vertical depth)HES PHL Injection 8409' 3616' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Senior Engineer:Senior Res. Engineer: ICDs Collapse 2,480 4,490 ICDs Burst 5,210 6,890 160 2,401' 3,688 4,015' 13.375" 9.625" 4.5" 8,892' 19,422' Authorized Signature with date: Authorized Name: Liner Length 160 4,350' 8,892' 10,530' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-253 189 Size Conductor Surface Intermediate Production measuredPlugs Junk measured N/A Casing Structural 20 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-006 50-629-23464-00-00 N/A 5. Permit to Drill Number: Nikaitchuq Schrader Bluff Oil 2. Operator Name 3. Address: 4. Well Class Before Work: N/A Representative Daily Average Production or Injection Data 4964241 Casing Pressure Tubing Pressure ADL 0391283,0390616, Oil-Bbl measured true vertical Packer 3700 Centerpoint Drive Suite 500, Anchorage 99503 SI29-S2 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MD 160 4,350' 4297 577 452N/A TVD 907-865-3379 Eni US Operating Co. Inc. N/A Stefano Pierfelici Well Operations Project Manager Amjad Chaudhry amjad.chaudhry@eni.com WINJ WAG N/A Water-Bbl t Fra O O 212 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 07/13/2021 By Samantha Carlisle at 9:45 am, Jul 14, 2021 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.07.14 08:21:35 -08'00' Stefano Pierfelic i RBDMS HEW 7/14/2021 SFD 7/16/2021VTL 8/9/21 DSR-7/14/21 SFD 9-5/8" 40 ppfIntermediateCasing, 8,892' MD,3,688' TVD, 84º Inc4-½” 12.6 ppfH563 ProductionTubing4-½” 11.6 ppf,H521 Liner,19,422' MD,3,834' TVD90º IncZonal IsolationPackersInjection ControlDevicesPHL Retr. Packer, 8,507'MD, 3,639' TVD,77º IncConfidentialNikaitchuq Field– Spy IslandRWO: As Completed06/12/20218,526' MD3,644' TVD, 3.725" XNSI29-S2 InjectorMonobore with Injection Control8,624' MD, 3661' TVD, SLZXP Liner Hanger/Packer4-½” Ecc-Nose GuideShoe8,542' MD Mirage Plug with Auto-fill valve8,660' MD - Bottom of Entry GuideItemMD (ft)ItemMD (ft)ICD #119063ICD #1013904ICD #218496ICD #1113379ICD #317910ICD #1212765ICD #417293ICD #1312151ICD #516709ICD #1411524ICD #616137ICD #1510909ICD #715595ICD #1610110ICD #815064ICD #179353ICD #914492ItemMD (ft)4-1/2" Swell Pkr #1181844-1/2" Swell Pkr #2170264-1/2" Swell Pkr #3159114-1/2" Swell Pkr #4143104-1/2" Swell Pkr #5120124-1/2" Swell Pkr #6105544-1/2" Swell Pkr #7 96708,349' MD, 3,601' TVD 4-½”Gauge Carrier for P,T, tubing sensor13-3/8" 68 ppfCasing, 4,350' MD,2,401' TVD, 77º Inc8,409' MD, 3,616' TVDHES PHL 4-½” x 9-5/8" Packer8,459' MD3,629' TVD, 4-½” Overshot 8,447' MD 4-½”, 3.81" GX-Nipple8,426' MD,3621' TVD, 3.81" GX-nipple2,063'' MD,1720' 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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: 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 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 19,464 3,834 19,422 3,834 1262 n/a Casing Collapse Structural Conductor Surface 2,480 Intermediate 4,790 Production Liner ICDs Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 COMMISSION USE ONLY Authorized Name: Authorized Title: 5/21/2021 ICDs Tubing Grade:Tubing MD (ft): 3,688-3,834 8,507' MD /3,639' TVD Perforation Depth TVD (ft):Tubing Size: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283,0390616, 212-006 3700 Centerpoint Drive Suite 500, Anchorage 99503 50-629-23464-00-00 Eni US Operating Co. Inc. Length Size SI29-S2 Nikaitchuq Schrader Bluff Oil n/a PRESENT WELL CONDITION SUMMARY L80 TVD Burst 8,500 MD 6,890 5,210 160 2,401 3,688 160 4,350 20 13.375 160 9.6258,892 4,350 Perforation Depth MD (ft): 8,892 8,892-19,422 4.5 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: May 31st, 2021 19,42210,530 4.5" 4,015 Halliburtons PHL Packer Stefano Pierfelici Well Operations project Manager m n P s 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:47 am, May 24, 2021 321-253 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.05.21 17:32:41 -08'00' Stefano Pierfelic i X SFD 5/24/2021 X 10-404 DSR-5/24/21 X X VTL 5/26/21 BOP test to 3500 psig Annular preventer test to 2500 psig VTL 5/27/21JLC 5/27/2021 5/27/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.27 10:43:39 -08'00' RBDMS HEW 6/2/2021 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com May 21, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SI29-S2 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SI29-S2. SI29-S2 was recompleted on Spy Island on March 22, 2012, with an injection packer set at a depth of 8507’ MD as a Schrader bluff water injector. The well was started up for injection march 2012 Well is down since April 2021 because of a suspected tubing leak. The estimated date for beginning this work is May 31st, 2021. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.05.21 17:33:20 - 08'00' Stefano Pierfelic i SI29-S2 was recompleted on Spy Island on March 22, 2012, with an injection packer set at appy depth of 8507’ MD as a Schrader bluff water injector. SI29-S2 Workover – Summary Page PTD#:212-006 Status Well SI29-S2 is currently shut in. in April 2021 it failed a state required MIT, a rig less leak detection logs were performed and confirmed two leaks in the tubing, Owen tubing patches were installed but subsequent MIT failed again. Data acquisition for pressure- actuated sealant were also performed in order to allow an engineering solution. Scope of Work Scope of this workover is pull out existing tubing and injection packer and run new tubing and new packer. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1631 psi (3,688’ TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/VBR/Shear rams/VBR TIFL/MIT-IA/MIT-OA: Attempted to perform state required MIT on May 16, 2021, failed due to suspected tubing leak. Well type: Injector Estimated start date: May 31, 2021 Drilling rig: Doyon Rig 15 Senior Drilling Engineer Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations project Manager Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Scope of this workover is pull out existing tubing and injection packer and run newttp tubing and new packer. Procedure: 1. Pump in bull heading 9.0-ppg KCL/NaCl brine through tree. 2. Ensure well is killed. Set BPV. 3. MIRU Doyon Rig 15. 4. ND tree and NU BOP and test. 5. Set tubing plug in XN nipple below packer 6. Punch tubing 7. Cut tubing above packer 8. Circ through tubing cut location displacing 4-1/2” x 9-5/8” annular fluids with 9.0-ppg KCL/NaCl brine 9. POOH with 4-1/2” injection completion string x Note: 4-1/2” injection completion string below packer well remain in hole 10. Set packer above the original packer and test 9-5/8” casing to 1650 psi. 11. Contingent casing investigation may be performed based on the well condition. 12. MU new 4-1/2” injection completion sting and RIH to setting depth. x Note: New completion will include 4-1/2” x 9-5/8” packer with 4-1/2” tubing overshot below. Overshot will swallow 4-1/2” tubing stub from original completion. 13. Circ freeze protection and corrosion inhibited 9.0 ppg KCL/NaCl brine completion fluid to 4-1/2” x 9-5/8” annulus 14. Land tubing hanger and overshot 15. Set 4-1/2” x 9-5/8” new packer 16. Pressure test 4-1/2” tubing to 3500 psi, charted 17. Pressure test 4-1/2” x 9-5/8” annulus to 2500 psi, charted 18. Pull tubing plug in XN nipple below packer 19. Install BPV and nipple down BOP. 20. NU tubing adapter and tree. 21. Pull BPV, install test plug and test tree. 22. RDMO. Below the current schematic of the well: VTL 5/26/21 State witnessed MIT-IA required after stabilized injection. Wallace, Chris D (CED) From: Lopez Keith <Keith.Lopez@eni.com> Sent: Saturday, April 10, 2021 12:04 PM To: Wallace, Chris D (CED); Regg, lames B (CED) Cc: Burgess Larry; Dibello Mike; Hart David; Lyden Dan; Brown Timothy; Dexheimer Stephen; Smagge Lorne; Pierfelici Stefano; Lopez Keith Subject: SI -29 (PTD# 212-006) Mr. Wallace, ENI noticed the TAA pressures tracking on SI -29 and became concerned about a potential pressure communication. Today (4/10/21) we attempted to pressure test the IA but the annulus would not hold pressure. The injector is shut in and will remain so until further diagnostics can be conducted. Please let me know of any questions or concerns. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3800 Centerpoint Drive, Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.LODez enixom ani Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 TO: P.I.Jm Rpergg 3,(1 I,]�?I it, SUBJECT: Mechanical Integrity Tests PSupervisor Lll �'1 g Y ENI US OPERATING CO INC S129-S02 FROM: Jeff Jones NIKAITCHUQ S129-S02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry LJ - NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI29-S02API Well Number 50-629-23464-00-00 Inspector Name: Jeff Jones Permit Number: 212-006-0 Inspection Date: 12/10/2016 Insp Num: mitJJ161213070811 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Type In' TVD 1I 3639 - Tubing; 476 • 476 476 476 _ I I s129-sot — W YP J ; PTD2120060 ,Type Test SPT!Test psi 1500 - IA 1 939 1648 • 1 1628 - 1622 _ I Interval 4YRTST 1P/F P v OA 220 230 230 . ! 230 Notes: 1.5 barrels diesel pumped. 1 well inspected,no exceptions noted. - SCANNED APR 0 52017, Wednesday,December 28,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .: _1 ca. - 00 47 Well History File Identifier Organizing(done) wo-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Co r Items: ❑ Ma s: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: 411Eb Date: s j /s/ Project Proofing BY: talMDate: q g pit. /s/ ryif 1 Scanning Preparation 7 x 30 = ca /0 + 7 = TOTAL PAGES at 7 (Count does not include cover sheet) i/fl BY: �arja) Date: Production Scanning Q� Stage 1 Page Count from Scanned File: U (Count does include cover sheet) Q, Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: Vcsixt is, ili 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: P Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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J •O y ea v E a E E mo po O. £ (1)i H E E O 2 d d d 2 U EL (9 0 0 QO' G o 10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q WAG ❑ WDSPL p No.of Completions: Service Q Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 3/21/2012 212-006 3.Address: 6.Date Spudded: 13.API Number: fa) 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 2/8/2012 50- 629-23464-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4437.8 FSL 1436.2 FEL S19 T14N R9E UM 3/11/2012 SI29-S2 Top of Productive Horizon: 8.KB(ft above MSL): 54 15.Field/Pool(s): 2156 FSL 837 FEL 24 T14N R8E UM GL(ft above MSL): 13.1 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 1535 FSL 2610 FEL 29 T14N R9E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511473.7 y- 6053619.45 Zone- 4 19464'MD/3833'TVD ADL 0391283,0390616 TPI: x- 506994.11 y- 6051332.5 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 515622.67 y- 6045445.52 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) 13.1 (ft MSL) 2129 MD/1760.6'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/Sonic/USIT N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD 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 36 4350 36 2401 16 10.7 ppg ASL: 498 bbls N/A 12.5 ppg LiteCRETE:63 bbls 9.625 40 L-80 35 8892 35 3688 12.25 12.3 ppg LiteCRETE:221 bbls N/A 4.5 11.6 L-80 8638 19424 3661 3834 8.75 Blank Liner with ICD's 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 8660 8507'MD/3639'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVEDDEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED APR 0 3 2014 27. AOGCC PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -►N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only K 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑Yes a to If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 2129 1760 Top Ugnu 3148 2199 Top Lower Ugnu 7107 3195 Top Schrader Bluff 7796 3441 Top N Sand 8148 3543 Top OA Sand 8995 3699 Formation at total depth: OA sand 19464 3833 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: Giuseppe Maugeri Printed Name: Marc Kuck Title: Production Optimization Coordinator Signature: � Phone: (907)865-3328 Date: 3/27/2014 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 1b: 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. Form 10-407 Revised 12/2009 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday, March 27, 2014 3:06 PM To: 'Maugeri Giuseppe' Cc: Davies, Stephen F (DOA) Subject: Reporting Compliance: Nikaitchuq SI29-S02 Dear Mr. Maugeri: I am completing the final compliance check for Nikaitchuq SI29-S02, PTD 212-006,API 50-629-23464-00-00,completed on 3/21/2012. As submitted,the form 10-407 Well Completion Report is incomplete because it does not include a list of all formations and geologic markers encountered in Box 29.The purpose of form 10-407 is to provide a concise,two-page summary for AOGCC's well records.As required by Regulation 20 AAC 25.071(b)(5)the operator shall file with the Commission (5)a list of the geologic markers encountered and the measured and true vertical depths of each marker. The list should include, at the minimum, Ugnu Top,Schrader Bluff Top, N Top and OA Top. In addition, a .las file from the Schlumberger PeriScope* Resistivity/VISION Service (electric logging acquired between 8 Feb 2012 and 14 Mar 2012) is required.As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071 (6)a sepia and a reproduced copy of all logs run, including common derivative formats such as tadpole plots of dipmeter data and borehole images produced from sonic or resistivity data, and including composite log formats... an electronic image file in a format acceptable to the commission may be substituted for the sepia; Please provide the updated form 10-407 and the .las file for the e-logs by April 27, 2014. If you have any questions, please contact me. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 1 %. RECEIVED ` STATE OF ALASKA NOV 13 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION la.Well StaWELL❑Oil COMGas ❑PLETIOSPLUG ❑N OReRr ❑ECOMPLEAbandoned ❑TION nRE❑PORT lb.Well IANDI% CC ass: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q WAG ❑ WDSPL❑ No.of Completions: Service 0 Stratigraphic Test n 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 3/21/2012 212-006 3.Address: 6.Date Spudded: 13.API Number: 'K>3 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 2/8/2012 SO-629-23464-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4437.8 FSL 1436.2 FEL S19 T14N R9E UM 3/11/2012 SI29-S2 Top of Productive Horizon: 8.KB(ft above MSL): 54 15.Field/Pool(s): 2156 FSL 837 FEL 24 T14N R8E UM GL(ft above MSL): 13.1 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 1535 FSL 2610 FEL 29 T14N R9E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511473.7 y- 6053619.45 Zone- 4 19464'MD/3833'TVD. ADL 0391283,0390616 TPI: x- 506994.11 y- 6051332.5 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: I Total Depth: x- 515622.67 y- 6045445.52 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 2129 MD/1760.6'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/Sonic/USIT N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 36 4350 36 2401 16 10.7 ppg ASL: 498 bblsN/A ,12.5 ooQ LiteCRETE:63 bbls 9.625 40 L-80 35 8892 35 3688 12.25 12.3 ppg LiteCRETE:221 bbls N/A 4.5 11.6 L-80 8638 19424 3661 3834 8.75 Blank Liner with ICD's N/A 24.Open to production or injection? Yes No Ell 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 8660 8507'MD/3639'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 2 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. RBCMS MAY 2 2 2041\-- Form 0 4Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7N3 42_0/7 -° `/ Submit original only icy 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes [Lilo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 2129 1760 Top Ugnu 3148 2199 Top Lower Ugnu 7107 3195 Top Schrader Bluff 7796 3441 Top N Sand 8148 3543 Top OA Sand 8995 3699 Formation at total depth: OA sand 19464 3833 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: Giuseppe Maugeri Printed Name: Marc Kuck Title: Production Optimization Coordinator Signature:i�� Phone: (907)865-3328 Date: 11/11/2013 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 lb: 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. Form 10-407 Revised 12/2009 REC'D OCT 2013 \��,..sv THE STATE Alaska Oil and Gas � � 0fALAS� Conservation Commission ;rip GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Anchorage, Alaska 99501-3572 S�P Main: 907.279.1433 October 30, 2013 Fax: 907.276.7542 CERTIFIED MAIL– RETURN RECEIPT REQUESTED 7012 3050 0001 4812 5665 Davide Simeone Well Operations Project Manager ENI US Operating Co. Inc. 3800 Center Point Drive, Suite 300 Anchorage, AK 99503 Subject: Incomplete 10-407 Well Completion Report for Nikaitchuq SI29-S2 (PTD No.212-006) Dear Mr. Simeone: The Alaska Oil and Gas Conservation Commission (AOGCC) received on May 7, 2012 the Form 10-407 "Well Completion Report" for the Nikaitchuq SI29-S2 well. As submitted, the report is incomplete, see 20 AAC 25.071. The purpose of Form 10-407 is to provide a concise, two-page summary for AOGCC's well records. Entries such as "Not available" or "To be sent under subsequent report" or "N/A" defeat the purpose of the form; they are not acceptable. In order to complete the Form 10-407 for Nikaitchuq SI29-S2, please submit—within 15 days of receipt of this letter—a revised copy of this Form 10-407 that contains the following data: Box 29: A list of all formations and geologic markers encountered and the measured and true vertical depths of each formation and/or geologic marker. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. These requirements can be accessed online at: Statute AS 31.05.030: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwjnu01.legi s.state.ak.us/c gi-bin/folioisa.dll/stattx07/query=31 !2E05!2E030/doc/{t13554}. Regulations 20 AAC 25.070 and 20 AAC 25.071: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwjnu0 l.legi s.state.ak.us/c gi-bin/folioisa.dll/aac/query=[JUMP:'20+aac+25!2E070']/doc/{@ 1J?firsthit. If you have any questions concerning the matter, please do not hesitate to contact me at (907) 793-1238 or at patricia.bettis@alaska.gov. Sincerely, Patricia Bettis Senior Petroleum Geologist U.S. Postal ServiceTM CERTIFIED MAILTM RECEIPT 141 (Domestic Mail Only;No insurance Coverage Provided) For delivery information visit our website at www.usps.com® lr1 ril cLI Postage $ Certified Fee 'r- - Postmark D Return Receipt Fee j Here D (Endorsement Required) l D Restricted Delivery Fee D (Endorsement Required) lr) �..__._. E Total Postagr m Sent To rU r-9 Davide Simeone D Street,Apt.No Well Operation Project Manager N. or PO Box No. Eni US Operating Co.Inc. City,State,ZIP 3800 Centerpoint Dr.,Ste.300 Anchorage,AK 99503 PS Form 3800,. ... - _:• --- -�.Y=ac.r�nryunerrai SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3.Also complete A. Signet - item 4 if Restricted Delivery is desired, X �� 0 Agent ff Print your name and address on the reverse ,�`V ' 0 Address: so that we can return the card to you. B. Receiv-d by(Printed Name) C. Date of Delivery Attach this card to the back of the mailpiece, or on the front if space permits. D. Is delivery address different from item 1? 0 Yes 1. Article Addressed to: If YES,enter delivery address below: 0 No Davide Simeone 3. Se ce Type Well Operation Project Manager Certified Mail 0 Express Mail Eni US Operating Co.Inc. 0 Registered 0 Return Receipt for Merchandise 3800 Centerpoint Dr.,Ste.300 0 Insured Mail 0 C.O.D. Anchorage,AK 99503 4. Restricted Delivery?(Extra Fee) 0 Yes 2. Article Number 7012 3050 0001 4812 5665 (Transfer from service label) . PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended EI lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 0 . WAG ❑ WDSPL❑ No.of Completions: Service Q • Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 3/21/2012 212-006, q1143 3.Address: 6.Date Spudded: 13.API Number:.50_6a,_43y6y^0)'0,) 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 2/8/2012 629-2846400-N. 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4437.8 FSL 1436.2 FEL S19 T14N R9E UM 3/11/2012 SI29-S2 . Top of Productive Horizon: 8.KB(ft above MSL): 54• 15.Field/Pool(s): 2156 FSL 837 FEL 24 T14N R8E UM GL(ft above MSL): 13.1. Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool. 1535 FSL 2610 FEL 29 T14N R9E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: , Surface: x- 511473.7 y- 6053619.45 Zone- 4• 19464'MD/3833'TVD . ADL 0391283,0390616 TPI: x- 506994.11 y- 6051332.5 Zone- 4, 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 515622.67 y-6045445.52 Zone- 4. N/A ADL 417493 18.Directional Survey: Yes U No H 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 2129 MD/1760.6'TVD 21.Logs Obtained(List all logs_he.ke and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic USIT N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD 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 36 4350 36 2401 16 10.7 ppg ASL: 498 bbls N/A 12.5 Doa LiteCRETE: 9.625 40 L-80 35 8892 35 3688 12.25 12.3 ppg LiteCRET •23'(bb N/A 4.5 11.6 L-80 8638 19424 3661 3834 8.75 Blank Liner with IC N/A• Dfr-v.t' 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 8660 8507'MD/3639'TVD RECEIVED26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED vIrl • MAY 0 7 2012 + IF'ti. Y AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date Of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period � .N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q- Sidewall Cores Acquired? Yes ❑ No E- lf 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. R$DMS MAY 0 74/4\12 Form 10-407 Revised 12/2009 CONTINUED ON REVERSEr-- (0 Z! 73 Submit original only 6 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑Yes [Igo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 2129 1760 OA sand top 8995 3699 Formation at total depth: OA sand 19464 3833 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: Michele Cesari Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: Phone: (907)865-3338 Date: 5/2/2012 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 lb: 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. Form 10-407 Revised 12/2009 (gib N C U E3 7 CZ 13 W 0 _C c �, a ❑ ❑ N I in_ QO x-N (0 CO 4:212100co. J N — CD E N Z 020:00r" N M O V N vommow \ LO o M O M I N M O L V:t.c Q U) Y O C0 L nn '' (6 L r9 atr-r-r-rqr; C N V U O 13 re. w a t0 .-, O N O D C O a) .i O 0�1 M O In a--+ V _ 2 _I .^l .moi -I-1 .-1 ^ L a) Ll • -I N M cr V1 tD N Q CO(O N p C CDCD L > C '� YL YL YL Yt Yt It 3R O 0 = a a a 0- a a a N 0 X a"' E a C v a v v n viL. (a (6 z N C C 0 C) a) _c 00 4- 1.3 (12/ ' \ \ \ \ \ \ \ ) 0 a N v C 4-• G Y Iv X mN co c/) C N (6 M I 1D _ '= w N 0 X __. ❑ e Co a \ _ C U i a4•+ 0 - Cri 2 2 N (0 Q ea N COc O N .4='. � a H CON0 cfl co V' ami co ❑ G� •Q- M 2 c -c zl-CO i.O X r- 0 M 00 c a' co � 4-a 2 Lo 0 co to C ch 0 (6 tV V CI- 0 0 I 2 L M o 20 (0 Na A N t N H O = V1 M n .moi VN1 01 O M N in 0 25- M M N N .-i 0 0 m e __-. \ ..: > (gyp '�'�. 0 .1 N M lA tD N C / Y E .-I .-I .--I .-I .-1 .-I .-1 .-1 TCU It It It It It It It It t) V C1 '- 0013000C30� Cl) Q 0 µ. 0 d to CI C 00000000 -o -0 .a®` a - N. ti- M +� M ID 0 M ofo nm Inc r, N �., o ^O .. u,. >. `� O `O a) ❑ 1� 0 og N N � Lfl 0 LL D i to M Ce 2 r-1 -4 .1 r-1 r-1 r-1 4 r-1 .' 7 \ Cr) H - j J •_, Nr 1.0 I M •C - a in .-1 N M a Un ttillN 00 of Z y 0 00 1- = It It It It It It It It It 0 0 0 0 0 0 0 0 0 (p /* 0 0 0 0 0 0 0 0 0 C) N Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq Vos n • APIIUWI:50-629-23464-00-00 eII^n Date:21512012 - Report#: 1 't II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 -2.67 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 103.0 -17.2 Clear,WC-30° 63°ENE @ 15 mph Daily summary operation 24h Summary R/D and move rig to St29-S2. Operation at 07.00 R/U for spud. 24h Forecast Spot#3 pump unit and completely berm up rig perimeters as per ACS.R/U utility lines to modules and test.R/U DS suitcases and pressure test all lines.R/U EXPRO to well SP23-S3 for flow back procedure. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 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 MOB 'A 20 P Secure well and well bay.Remove double block valves from well head and install flanges.Transfer wellhead equipment from well bay#2 to well bay#3. 02:00 05:00 3.00 5.00 MOB -A 2 P Prep.pad for rig move.Disconnect rock washer and move to end of pad.Remove matt boards and lay newhercultie.Place matt boards for rig move. 05:00 07:30 2.50 7.50 MOB A 2 P 'Move Pit complex to end of matt boards.Spot crane and remove diverter line and remove sacrificial tree valve from well SP 27.Remove EXPRO's surface test valve from between complexes. 07:30 08:30 1.00 8.50 MOB 'A 2 P .PJSM,skid rig floor for move. 08:30 12:00 3.50 12.00 MOB A 2 P 'Obtain Hot Work permit from Operations and cut diverter saddles from atop of well bay.C/O BOP work platform in sub complex. 12:00 15:00 3.00 15.00 MOB A 2 P Cut flange from diverter line for spotting complex.PJSM,Move sub from SP23-S2 to S129-S2.Distance for rig move was 63'. 15:00 15:30 0.50 15.50 MOB 'A 2 P PJSM and skid rig floor over well.Begin to hook up utility lines to rig floor. 15:30 16:30 1.00 16.50 MOB A 2 P Spot pit complex and begin to hookup lines. 16:30 18:00 1.50 18.00 MOB A 2 P PJSM and install suitcases f/manifold house to rig to expedite EXPRO hookups. 18:00 00:00 6.00 24.00 MOB A 2 P Spot Rock Washer complex.Hook up choke hose between complexes.Cont.spotting suitcases. Daily Contacts Position Contact Name Company Title E-mail • Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com -907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilting.com 907-685-0716 Tool Push Alec Dunlop Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgllcm') 11 Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 en0 Date:2/6/2012 - Report#: 2 'I " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 -1.67 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 102.0 -17.6 Clear,WC-32.5° 68°ENE @ 16 mph Daily summary operation 24h Summary Spot#3 pump unit and completely berm up rig perimeters as per ACS.R/U utility lines to modules and test.R/U DS suitcases and pressure test all lines.R/U EXPRO to well SP23-S3 for flow back procedure. Operation at 07.00 Weld diverter line for hookup. 24h Forecast Complete R/U and berming.Nipple up Diverter sys.and do tests.Call AOGCC for witness.Bring spud mud to rig.Service hands ready equipment for spud.Spud well. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start - End Gum Time Time Our(hr) Dur(hr) Phase Opr. Act Plan Oper.Dem. 00:00 05:30 5.50 5.50 MOB A 20 P Work on suitcase installations.Build ramp for pump#3 complex spotting.Test suitcase lines f/manifold bldg.to rig with air. Cont.to berm perimeters. 05:30 12:00 6.50 12.00 MOB A 2 P Install pump#3 complex and R/D ramp.Hook up pump power and utility lines.Test water and diesel lines.Load on water and diesel. 12:00 '18:00 6.00 18.00 MOB A 20 P M/U Vetco 13 3/8"hanger and landing jt.Load well bay with Vetco hardware for nipple up.Cont.on rig up. 18:00 00:00 6.00 24.00 MOB A 20 P N/U Vetco starting head and test to 500 psi for 10 min.Install riser and test to 500 psi for 10 min.N/U diverter sys.and test to 500 psi for 10 min.Tests were witnessed by on tour Driller and Co-man.36.80'RKB to load shoulder,40.92'RKB to ground level,54.02'RKB to Sea level. NOTE;Flow back from SP23-N3 279 bbls @ 40 HZ,90%BSW,10%Oil. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Mike Ross -ENI Senior Drilling Supv -SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Data Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P Lea kOff(kgflcm') • • • • • Voil Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name: Nikaitchuq • APIIUWI:50-629-23464-00-00 e^o Date:2/7/2012 - Report#: 3 " II page 1 of 1 Wellbore name: SI29-S2 Well Header Pennit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 -0.67 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 0.00 109.0 -20.0 Clear,WC-29.5 120'ESE©11.5 mph Daily summary operation 24h Summary Berm rig.\Complete N/U diverter system and function test to AOGCC requirements(John Crisp waived witness of test @ 0600 hrs.\Load 216 joints of 5"TT525 drill pipe into shed(strap).\NOV/Quadco installing drill link on rig.\Service top drive(oil).\Test cement lines 1/3500 psi.\Perform 13 3/8"csg hanger dummy run wuVetco Gray.\Calibrate&test rig gas alarm system.\Cut drill line-inspect brake linkage.\Load 5"HWDP in pipe shed-load floor and pipe shed with BHA components-P/U new 5"HWDP(make&brake to factory spec.).\Expro flow back well SP23-N3 @ 40Hz-total 1250 bbls.- 22%cut mud/H2O&88%Oil.\Little Red injected 863.9 bbls. Operation at 07.00 P/U 5"drill pipe. 24h Forecast Finish P/U 5"new HWDP(make&break connection).\P/U 5"drill pipe./Transfer spud mud to active pits./Per-spud meeting.\P/U BHA#1(dean out conductor).\POOH and P/U#2 Schlumberger tools- R/U Gyro Data and Halliburton.\Drill ahead as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 MOB A 20 P Continue N/U diverter(install bell nipple and flow line),center/secure 20"diverter with tum buckles-welder started fabrication work ordveder spool.\Complete berm around ng./Begin loading 5"drill pipe in pipe shed(strap).\Expro continued flow back SP23-N3. 06:00 12:00 6.00 12.00 MOB A 20 P N/U Diverter line(weld spool)./Load 216 joints 5"drill pipe in pipe shed.\Start changing oil in top drive.\NOV/Quadco started installing drill link on rig.\Notified AOGCC of diverter test-John Crisp waived witness of test @ 0600 hrs. 12:00 18:30 6.50 18.50 MOB A 20 P Finished change oil and service top drive./Perform pressure test cement line V3500 psi.for 10 mins./NOV/Quadco continue installing drill link on rig.\Perform dummy run 13 3/8"csg.hanger with Vetco Gray./Calibrated and tested rig gas alarms./Install hydraulic hoses to diverter system and function test.\Tested diverter system to AOGCC requirements. (Closure time:Knife closed 15 sec.and element 60 sec). 18:30 20:30 - 2.00 20.50 MOB A 20 P Held PJSM-slip and cut drilling line-Inspect brake linkage and service drum coolant lines. 20:30 00:00 3.50 24.00 MOB A 20 P Loaded 5"HWDP(20 jts.)in pipe shed and transfer 13 stands to off drillers side./Set mouse hole in rotary table./Bring BHA#1 and BHA#2 components in pipe shed and rig floor.\Held PJSM-P/U 5"HWDP(make&break connection to factory spec)./Note:Expro flow back SP23-N3 with total 1250 bbls.@ 980-1000 bpd.-final cut 22%H2O and 88%oil.\ Little Red injected total of 863.9 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907.685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907.685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipelroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 41•1* Eni E&P Division 'Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq � APIIUWI:50-629-23464-00-00 e^n Date:2/8/2012 - Report#: 4 " II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(V.) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 0.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) FOB Temperature(°C) Weather Wind 88.09 88.04 69.80 1.39 50.2 111.0 -18.8 Clear,WC-31.5° 223°SSW @ 13.8 mph Daily summary operation 24h Summary Finish P/U 5"new HWDP(make&break connection).\P/U 5"drill pipe.\Transfer spud mud to active pits.\P/U BHA#1\Per-spud meeting.\Clean out conductor 11163'(tag ice(g 60').\POOH and P/U#2 Schlumberger tools and R/U Gyro Data and Halliburton.\Drill ahead slide/rotary 1/289'as per well plan-Gyro Data survey as needed. Operation at 07.00 Drilling ahead slide/rotate as per well plan-Gyro Data as required.\Expro continued flow back SP23-N3 and Little Red injecting produced fluid. 24h Forecast Drill ahead Slide/Rotate f/289'as per well plan./Expro continue to flow back SP23-N3 and Little Red to inject flow back fluids in tank farm-Expro(send an oil sample in for testing).\Load 13 3/8'csg.into • . pipe shed(drift&strap)./Continue removal of equipment from island for storage. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1054.5 Time Log Start End Cum • Time Time Dur(hr) Dur(hr), Phase Opr. Act. Plan Oper.Dew. 00:00 04:30 ' 4.50 4.50'DRILL E 4 P P/U new 5"HWDP(make&break connection to factory spec)-P/U jars-stand back in derrick.\Expro continue flow back SP23-N3 and Little Red injected produce fluids. 04:30 09:30 5.00' 9.50'DRILL E 4 'P 'P/U 5"drill pipe and stand back in derrick(drift 2.875")to drill surface hole./Install chute from rock washer and set cutting . box. 09:30 10:30 1.00' 10.50'DRILL E -1 'P L/D mouse hole and clear floor of thread protectors./Held PJSM-Transfer spud from MlSwaco mud plant to active pits. 10:30 13:00 2.50 13.00'DRILL E 4 P 'PJSM-P/U Schlumberger NM Flex DC(3 jts.)and rack back in derrick./P/U BHA#1 mud motor and bo. 13:00 14:30 1.50 14.50 DRILL E 7 P PJSM-fill hole and flow test surface equipment-Pressure test pumps and mud lines to 3500 psi f/5 mins:good.\Bleed off and blow down. 14:30 15:30 1.00 15.50 DRILL E 4 P Finished P/U BHA#1 clean out assembly wlstab and XO. 15:30 16:00 0.50 16.00'DRILL E 1 'P Held Per-Spud meeting with all personnel-Discussed conductor breaching&contingencies,well control and evacuation procedures,drilling parameters and hole cleaning,close approach and survey. 16:00 17:00 1.00 17.00 DRILL E 3 P Clean out conductor V163'-tag @ 60'(ice)/Pump rate 600 gpm @ 450 psi./30 rpm @ 2-6K torque./POOH to P/U BHA • #2. 17:00 19:30 2.50 19.50 DRILL E 4 -P P/U BHA#2-Schlumberger smart tool string 1/98'. 19:30 21:30 2.00 21.50 DRILL E '20 P PJSM-R/U Halliburton and Gyro Data for surface surveys. 21:30 22:00 0.50 22.00 DRILL 'E 4 'P Continue P/U BHA#2 and RIH 1/98'-11163'. 22:00 00:00 2.00 24.00 DRILL E 3 P 'Drill Slide/Rotate f/163'-11289'(289'TVD).\Pump rate 600 gpm @ 650 psi./40rpm @ 4K torque./WOB 18-20k.\Mud wt.= 8.8 ppg\ECD 0.00 ppg.\Up wt.=95K-Dn wt.=90K-Rot wt.=93K./AST=1.14 hrs.-ART=0.05 hrs.-ADT=1.19 hrs.\ Jars=63.39 hrs. Total ADT=1.19 hrs. Total AST=1.14 hrs. Total ART=0.05 hrs. Total Jar=63.39 hrs. Note:Expro flow back SP23-N3(ESP 43 HZ)with total 2346 bbls.@ 1000 bpd.-final cut 1%H2O and 99%oil.last 3 hrs. of day\Little Red injected last 24 hrs=641 bbls./Total of 1504 bbls. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 , Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD('un) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) Vot Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 2^o Date:2/9/2012 - Report#: 5 'I 'I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5129-02 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 1.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 553.21 476.52 465.12 10.29 45.2 106.0 -16.1 Clear,WC-4.6° 61°ENE @ 5.8 mph Daily summary operation 24h Summary POOH(/289'-t/98'.\RIH 1/98-1/289'with NM Flex DC and 5"HWDP with jars.\Drill Slide/Rotate(/289'-1/1815'.1 Expro continue to flow back SP23-N3 until 2125 hrs.-Little Red injected flow back fluids.\ Switched SP23-N3 fowls production header @ 2130 hrs.\Load 13 3/8'csg.into pipe shed(drift 12.259"OD 8 strap). Operation at 07.00 Drilling ahead slide/rotate as per well plan.Note:Doyon hand reported to Tour Pusher @ 0030 hrs about illness and came to camp @ 0100 hrs.which TP took to ENI medic for evaluation-report will , follow. 24h Forecast Slide/Rotate 1/1815'as per well plan.\R/D Expro flow back lines and equipment from SP23-N3.\Little Red will pump flow back fluids from Expro tank farm./Continue loading 13 3/8"csg.into pipe shed and prep. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Staff End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P POOH 1/289'-1/98'-Two stands 5"HWDP-RIH 1/98-1/286'with stand 8"NM Flex DC and stand(2 its.5"HWDP and jars). Break circulation wash down to 289'. 01:30 06:00 4.50 6.00 DRILL E 3 -P Drill Slide/Rotate(/289'-1/620'(616'TVD).\Pump rate 600 gpm @ 950 psi.)40 rpm @ 4-8K torque.\WOB 10-30K.1 Mud wt.=8.8 ppg\ECD 9.5 ppg.\Up wt.=122K-Dn wt=118K-Rot wt.=120K.\AST=1.45 hrs:ART=0.20 hrs:ADT=1.65 hrs.\Jars=65.04 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Slide/Rotate(/620'-1/1060'(1030'TVD).\Pump rate 650 gpm @ 1190 psi.\40 rpm @ 4-6K torque.\WOB 15-30k.\ Mud wt.=9.1 ppg\ECD 9.99 ppg.\Up wt.=133K-Dn wt.=118K-Rot wt=128K.\AST=2.74 hrs:ART=0.37 hrs.-ADT= 3.11 hrs.\Jars=68.15 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Slide/Rotate 1/1060'-1/1494'(1355'TVD).\Pump rate 640 gpm @ 1100 psi.\40 rpm @ 6-8K torque.\WOB 25-30k.\ Mud wt.=9.2 ppg\ECD 9.99 ppg.\Up wt.=138K-Dn wt.=120K-Rot wt.=132K.\AST=2.88 hrs.-ART=0.49 hrs.-ADT= 3.37 hrs.\Jars=71.52 hrs. 18:00 00:00 - 6.00 24.00 DRILL E 3 'P Drill Slide/Rotate f/1494'-1/1815'(1565'TVD).\Pump rate 796 gpm @ 1500 psi.\60 rpm @ 6-8K torque.\WOB 25-30k.\ Mud wt.=9.3 ppg\ECD 10.1 ppg.\Up wt.=138K-Dn wt.=120K-Rot wt.=135K.\AST=1.57 hrs.-ART=0.59 hrs:ADT= 2.16 hrs.\Jam=73.68 hrs.\Note:At 2130 hrs.SP23-N3 was tumed over to production-ESP initial setting of 44 Hz @ 900 bpd rate. Total ADT=11.48 hrs. Total AST=9.78 hrs. Total ART=1.70 hrs. Total Jar=73.68 hrs. Note:Expro flow back SP23-N3(ESP @ 40 HZ)with total 3076 bbls.@ 890 bpd.-final cut 0.25%mud and 99.75%oil.\ Little Red injected total of 1805 bbls Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener ENI -Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com '907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') ilf..... Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq '� APIIUWI:50-629-23464-00-00 2 I"'J) ^• Date:2/10/2012 - Report#: 6 II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM _ 100.00 HORIZONTAL INJECTION ..Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 2.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,053.39 686.12 500.18 11.90 42.0 106.0 -12.4 Ptly Cloudy,WC- 337°WNW @ 5.7 7.3° mph Daily summary operation 24h Summary Drill Slide/Rotate(/1815'-7/3456'.\R/D Expro flow back lines&equipment from SP23-N3.\Little Red pumped flow back fluids.\Load 13 3l8'csg.into pipe shed(drift 12.259"OD&strap). Operation at 07.00 Drilling ahead slide/rotate as per well plan to proposed 13 3/8"csg.TD @ 4576'MD. 24h Forecast Slide/Rotate f/3456'as per well plan.\Finish-up prep work on 13 3/8"csg. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log , Start End I Cum Time Time Dur(hrll Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 . P Drill Slide/Rotate f/1815'-1/2334'(1874'TVD).\Pump rate 750 gpm @ 1380 psi.\45 rpm @ 8-9K torque.\WOB t5-20K.\ Mud wt=9.3 ppg\ECD 10.17 ppg.\Up wt=152K-Dn wt.=120K-Rot wt.=132K.\AST=1.56 hrs.-ART=1.28 hrs.-ADT= 2.84 hrs.\Jars=76.52 hrs. • 06:00 12:00 6.00' 12.00 DRILL E 3 'P Drill Slide/Rotate 1/2234'-1/2708'(2050'TVD).\Pump rate 650 gpm @ 1170 psi.\40 rpm @ 7-10K torque.\WOE 15-20K.\ Mud wt.=9.3 ppg\ECD 9.94 ppg.\Up wt=154K-Dn wt.=114K-Rot wt.=135K.\AST=1.65 hrs:ART=0.86 hrs.-ADT= 2.51 hrs.\Jars=79.03 hrs. 12:00 18:00 6.00' 18.00 DRILL E 3 'P Drill Slide/Rotate f/2708'-1/3037'(2175'TVD).\Pump rate 650-800 gpm @ 1180-1600 psi.\40 rpm @ 7-10K torque.\WOB 15-20K.\Mud wt.=9.4 ppg\ECD 9.99 ppg.\Up wt.=154K-Dn wt=114K-Rot wt.=135K.\AST=2.25 hrs.-ART=0.78 hrs.-ADT=3.03 hrs.\Jars=82.06 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill Slide/Rotate f/3037'-1/3456'(2252'TVD).\Pump rate 650-800 gpm @ 1200-1650 psi.\40-60 rpm @ 7-12K torque.\ WOB 15-20K.\Mud wt.=9.4 ppg\ECD 10.1 ppg.\Up wt=154K-Dn wt.=115K-Rot wt.=130K.\AST=1.93 hrs:ART= 1.59 hrs.-ADT=3.52 hrs.\Jars=85.58 hrs. Total ADT=23.38 hrs. Total AST=17.17 hrs. Total ART=6.21 hrs. Total Jar=85.58 hrs. Daily Contacts Position Contact Name - Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ngt5@doyondntling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Vist Eni E&P Division I Well Name:SI29-S2 EN/Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq Date:2/1112012 - Report#: 7 APIIUW:50-629-23464-00-00 "" " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 3.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 1,332.59 733.28 279.20 6.23 44.8 101.0 -17.6 Lt.Snow,WC-16° 10°N @ 12.7 mph Daily summary operation 24h Summary Drill Slide/Rotate f/3456'-1/4372'(TD surface section)./Circulate bottoms-up until clean(6X)1/4372'-03832'(rack back stand each CBU)./POOH back reaming 1/3832'-1/1776'as per K&M parameters./ Little Red pumped flow back fluids from SP23-N3. Operation at 07.00 Circulating @ 842'(5"HWDP)to K&M parameters 24h Forecast POOH back reaming 1/1776'-1/842'(5"HWDP)as per K&M parameters./Circulate until clean @ 842'per K&M.\POOH on elevator and work BHA#2(UD)./R/U GBR equipment&Franks tool to run casing./P/U 13 3/8"csg.(685;L-80;BTC)as per tally-check float equipment.\Circulate 13 3/8"csg.-condition mud for cement job-Hold PJSM with Schlumberger./R/D GBR Franks tool and R/U cement head./Schlumberger cement 13 3/8"csg.in place-displace with rig mud pump as per well plan./N/D diverter system. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deur. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill Slide/Rotate 1/3456'-V4090'(2348'TVD).\Pump rate 800 gpm @ 1720 psi.\80 rpm @ 10-20K torque./WOB 14-20K./ Mud wt.=9.4 ppg\ECD 10.09 ppg./Up wt.=166K-Dn wt.=92K-Rot wt=128K./AST=0.90 hrs.-ART=2.78 hrs.-ADT= 3.68 hrs.\Jars=89.26 hrs. 06:00 11:30 5.50 11.50 DRILL E 3 P Drill Slide/Rotate 1/4090'-V4372'(2403'TVD)-TD for 13 3/8"csg.point./Pump rate 800 gpm @ 1800 psi./50-80 rpm @ 10- 12K torque./WOB 18-20K.\Mud wt.=9.35 ppg\ECD 10.02 ppg.\Up wt.=168K-Dn wt.=104K-Rot wt.=128K./AST= 1.38 hrs:ART=1.17 hrs:ADT=2.55 hrs.\Jars=91.81 hrs.\Little Red pumped flow back from Expro from tanks. Total ADT=29.61 hrs. Total AST=19.45 hrs. Total ART=10.16 hrs. Total Jar=91.81 hrs. 11:30 16:00 4.50 16.00 DRILL 'E 7 P Circulate bottoms-up until clean(6X)f/4372'-1/3832'(racking back one stand every CBU)./Pump rate 900 gpm @ 2030 psi./80+rpm @ 6-11K torque./Rot wt.=129K\MW=9.35 ppg./ECD 10.24 ppg.\SLM pipe. 16:00 00:00 8.00 24.00'DRILL 'E '4 P POOH back reaming 1/3832'-111776'.\Pumping 800 gpm @ 1420 psi./60.80+rpm @ 8-12K torque./Rot wt=128K.\MW= 9.4 ppg.\ECD 10.03 ppg.\SLM pipe./Hole condition dictated pulling speed and section with high dog legs-reduce speed until cleaned-up. Daily Contacts Position Contact Name Company Title E-mail Office i Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 • Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') If* Eni E&P Division !Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq �II•Q APIIUWI:50-629-23464-00-00 eI� '�II 11 Date:2/12/2012 - Report#: 8 page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 4.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,332.59 733.28 0.00 101.0 -18.6 Clear,WC-20' 47°NE @ 15 mph Daily summary operation 24h Summary POOH back reaming 1/1776'-1/780'-per K&M parameters.\Circulate(2X)until clean @ 780'\Attempt to POOH on elevators 11730'-over 25K over pull-RIH 11780'\POOH circulating(/780-1/280'.\Work BHA#2(LID Schlumberger smart tools).)R/U GBR equipment&Franks tool to run casing.\PJSM-P/U 13 3/8"csg.(68#;L-80;BTC)f/surface-112733'as per well plan.-Tag up @ 1560'break circulation &wash 111616'-Circulate bottoms-up 1/2073'-V2115'above permafrost. Operation at 07.00 Circulating and condition mud for cement job. 24h Forecast Continue P/U 13 3/8"csg.(68#;L-80;BTC)as per tally(/2738'-V4351'\Circulate and condition mud for cement job-Hold PJSM with Schlumberger.\R/D GBR Franks tool and R/U cement head.) Schlumberger mix&pump cement-displace with rig.)N/D diverter system.\N/U Vetco Gray well head./N/U 13 5/8"BOP stack. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 P -POOH back reaming(/1776'-1/930'.\Pumping 800 gpm @ 1120 psi.)80 rpm @ 6-10K torque.)Rot wt=123K.\MW=9.4 ppg.\ECD 10.10 ppg.)SLM pipe.)Hole condition dictated pulling speed and section with high dog legs-reduce speed until cleaned-up. 03:30 05:00 1.50 5.00 DRILL E 7 P Circulate until clean f/930'-V780'(set back one stand))Pumping 800 gpm @ 1080 psi.\Orientated to high side and reciprocate pipe.\MW=9.45 ppg.\ECD=10.12.1 Lot of gravel returns. 05:00 06:00 1.00 6.00 DRILL E 4 P Monitor well-static-blow down top drive.)POOH 1/780'-735'on elevators.\Up wt.=130K-began encountering over pull 25-35K.\RIH V780'and break circulation. 06:00 07:30 1.50 7.50 DRILL E 4 P POOH pumping f/780'-1/280'\Rate 630 gpm @ 730 psi.\Orientated to high side.\Up wt.=110K\MW=9.35 ppg.\ECD 10.20 ppg. 07:30 13:00 5.50 13.00 DRILL E 4 P Work BHA#2 per Schlumberger-set back jars and NM Flex DC-UD remaining Schlumberger tools.)Clean and clear floor of BHA components.)Remove 5"elevators and short bails from top drive. 13:00 15:00 2.00 15.00 DRILL G 20 P PJSM-R/U GBR equipment and Franks tool to run 13 3/8"csg. 15:00 22:00 7.00 22.00 DRILL G 4 P PJSM-P/U shoe track and check float equipment-OK.\Continue P/U 13 3/8"csg.(68#;L-80;BTC)f/80'-1/2073'as per K&M parameters-filling every joint and top off every 10 joints.\Dn wt.=157K.\Monitor displacement-no loses.\Tag @ 1560'attempted to work through-Break circulation pumping 60 gpm @ 160 psi.and continue working-stage rate up 1/205 gpm @ 250 psi.-work&wash t/1616'continue RIH with 13 3/8"csg. 22:00 22:30 0.50 22.50 DRILL G 7 P Circulation bottoms-up washing down 1/2073'-V2115'above permafrost-stage rate f/80 gpm @ 180 psi.to 210 gpm @ 230 psi.)Up wt.220K-Dn wt=150K. 22:30 00:00 1.50 24.00 DRILL G 4 P Continue P/U 13 3/8"csg.(68#;L-80;BTC)12115'-1/2738'as per K&M parameters-filling every joint and top off every 10 joints.\Dn wt.=150K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') ifigitit Eni E&P Division 'Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq n n Date:2/13/2012 - Report#: 9 APIIUWI:50-629-23464-00-00 l�' 'f page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 5.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,332.59 733.28 0.00 97.0 -18.3 Clear,WC-26° 44°NE©27 mph Daily summary operation 24h Summary PJSM-P/U 13 3/8"csg.(68#;L-80;BTC)as per tally(/2738'-t/4314'./Break circulation with Franks tool stage up to 2.5 bpm-wash down f/4314'-114351'-attempted to reciprocate string,stuck 1'from hanger ring./Circulate&condition mud for cement job stage pump rate to 7 bpm./Shut down pumps-UD GBR Franks tool&P/U Schlumberger cement head./Circulate thru cement head-PJSM with Schlumberger for cement job.\Test lines 113500 psi.\Schlumberger cemented 13 3/8"csg.in place @ 1530 hrs.with full returns-230 bbls.retums back to surface./Flush diverter stack.\N/D flow and 16" diverter line-P/U approximately 4'and Vetco Gray installed emergency slips-transfer 246K weight to same./Set diverter stack back down and N/D components.\Transfer fluids to WIF and clean surface equipment and pits./Remove 20'stand pipe section for modification. Operation at 07.00 Vetco Gray installing Muhi-bowl well head. 24h Forecast Vetco Gray cut 13 3/8"csg.-Install Vetco Gray Multi-bowl well head and valves./N/U 13 5/8"BOP stack./P/U 5"DP\Change saver sud on top drive./Test BOPE-Jeff Jones with AOGCC will witness,will update on time line./Clean active pits and rack washer-Mud Plant mixing LSND mud and will transfer to rig.\Reinstall 20'modified section of stand pipe.\Cut drilling line.\Prep to P/U BHA#3. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dozer. 00:00 03:30 3.50 3.50 DRILL G 4 P P/U 13 3/8"csg.(68#;L-80;BTC)f/2738'-P/U landing joint 114350'-as per K&M parameters-install centralizer per well plan -filling every joint and top off every 10 joints.\Break circulation with 64 gpm @ 125 psi.and stage to 85 gpm @ 220 psi./ Dn wt.i.165K.\Attempted to reciprocate,stuck string 1'from landing ring. 03:30 08:00 4.50 8.00 DRILL G 7 P Circulate and condition mud for cement job-stage rate 210 gpm @ 280 psi./Attempt to work 13 3/8"csg.hanger to landing ring-no luck./Continue increasing pump rate 295 gpm @ 350 psi./Notified AOGCC @ 0745 hrs.-Jeff Jones return call© 0800 hrs.and will witness test. 08:00 09:00 1.00 9.00 DRILL H 5 P Set slips and UD GBR Frank's fill-up-blow down top drive-P/U Schlumberger 13 3/8"cement head and install cement lines. 3/$" 09:00 10:30 1.50 10.50 DRILL H 7 P Break circulation through cement head and continue condition mud pump rate 302 gpm @ 250 psi.-PJSM for cementing 13 3/8"csg.with Schlumberger and all parties involved. C>pAcr 10:30 16:00 5.50 16.00 DRILL H 7 P Shut down mud pumps and switch to Schlumberger pump 10 bbls of water-test line to 3500 psi.-good\Switched back to rig pumping 100 bbls.of Mud Push II @ 10.1-rate of 5 bpm @ 140 psi.\Shut-down drop bottom plug./SLB mix&pump Lead slurry 612 bbls.@ 10.7 ppg.\ActicSet Lite 1408 sks.[2.45 Yield,mix water at 11.513 gatisk.]-Pump rate of 5.0 bpm @ 380 psi.\SLB mix and pump Tail slurry 77 bbls.@ 12.5 ppg./DeepCRETE 277 sks.[1.56 Yield.mix H2O at 5.471 gaVsk.]-Pump rate of 2.0 bpm @ 230 psi.\Shut down&drop top plug-SLB pump 10 bbls H20.\Displace with 641 bbls.@ 9.45 ppg mud with rig pump at 7.5 bpm w/380 psi./With 621 bbls away slow pump to 2.0 bpm with 500 psi.FCP with full returns\Bump plug to 500/psi,over FCP to 1000 psi.-Hold for 10 minutes and bleed off-check floats are holding-Good.\ /\\) Cement in place @ 1530 hrs.with a total of 230 bbls.10.7 ppg cement returns to surface.\Pull to 350K. 16:00 20:00 4.00 20.00 DRILL G 5 P Flush stack diverter stack./PJSM-N/D Diverter system-Remove flow and 16"diverter line-disconnect @ conductor-P/U approximately 4'-Vetco Gray install emergency slips-Slack off-246K weight transfer to slips./R/D cement lines,cement head and GBR tongs from rig floor./Transfer surface volume from active pits and rock washer to WIF for injection. 20:00 00:00 4.00 24.00 DRILL G 5 P Set Diverter stack back down on conductor./N/D components of diverter system-UD 20"riser\Vetco Gray Prep to cut 13 3/8"csg.\Work on cleaning surface equipment and pits./Off line active-Work on disconnecting 20'section of stand pipe for fabrication work for WEI sub operation. Daily Contacts Position Contact Name Company TitleE-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(m) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L60 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1f7Eni E&P Division I Well Name:S129-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • 2^ii Date:2/14/2012 - Report#: 10 API/UWI:50-629-23464-00-00 p " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 6.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,332.59 733.28 0.00 99.0 -24.0 Clear,WC-22' 23°NE @ 11.2 mph Daily summary operation 24h Summary Vetco Gray N/D 20"riser adapter and cut 13 3/8"csg.\Install Vetco Gray Muhi-bowl well head and valves-test t/1800 psi 1/10+mins.\N/U 13 5/8"BOP stack.\Clean active pits and rack washer./P/U test plug&joint-Circulate all mud pumps through kill line for NOV/Schlumberger to test drill link./Shell test BOPE 1/3500 psi.\Change saver sud on lop drive.\Welder modified 20'section of stand pipe for WEI subs./P/U 5"DP./Service rig./Doyon hand pulled muscle in back while cleaning rock washer pit-went to medic and report will follow. Operation at 07.00 L/D 5"HWDP not needed in BHA#3\Prep to test BOPE with AOGCC. 24h Forecast P/U 5"drill pipe for intermediate hole section./L/D 5"HWDP-not needed for BHA#3.\Test BOPE with AOGCC Lou Grimaldi to witness.\Install 20'section of stand pipe and pressure test same.\Transfer LSND mud to active pits./P/U BHA#3 with Schlumberger.\RIH above float equipment./Circulate bottom-up.\Test 13 3/8"csg.to 2500 psi.for 30 mins.(charted).\Drill out shoe track and 20-50'new hole.\Displace to LSND mud-circulate until equal mud weights in/out.\Perform LOT/FIT.\Drill ahead 12 1/4"hole section. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum •• Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Dew. 00:00 02:30 2.50 2.50 DRILL C 5 P N/D Vetco Gray 20"riser adapter from conductor.\Vetco Gray cut 13 3/8"csg:prep for Muki-bowl well head./Continue cleaning active pits and rock washer for LSND mud./Continue working on removal of 20'section of stand pipe from derrick. 02:30 04:00 1.50 4.00 DRILL C 5 P Pull BOP level floor plates and well bay top cover to install Multi-bowl./Lower SSV and 4-way block to well bay./Work on 20'section stand pipe removal.\Clean pits. 04:00 07:00 3.00 7.00 DRILL C 5 P Install Multi-bowl well on 13 3/8"csg.and landing ring-orientated valve alignment to conductor.\Vetco Gray tested to 1800 psi.for 10 mins.(ENI Rep witness)./Install double annulus valves.)Send stand pipe to welder for modification.\Clean pits and rock washer. • 07:00 16:30 9.50 16.50 DRILL C 5 P Install well bay cover and BOP level floor plates./N/U 13 5/8"BOP stack and bell nipple-connect lines to choke,kill,flow, fill-up and bleeder.\Secure and center stack.\Install mouse hole and drain lines./L/D long bails and P/U short bails on top drive./P/U work areas.\Clean pits and rock washer pits.\Welder working on modification of stand pipe section for WEI sub.\Called AOGCC @ 0700 hrs.and Lou Grimaldi called back @ 0739 hrs.will update. 16:30 20:00 3.50 20.00 DRILL E 20 P P/U 5"joint and install test plug./Line up on mud pumps#1-3,Circulate through kill line to test drill link for NOV/Schlumberger.\Change TT525 saver on top drive./Shell test BOP stack to 3500 psi.\Pull test plug.)Call Lou Grimaldi AOGCC for BOP test in mowing @ 0600 hrs.\1830 hrs.Doyon hand pulled muscle in back while cleaning rock washer pit- went to medic and report will follow. 20:00 22:00 2.00 22.00 DRILL E 4 P Install long mouse in rotary table.\P/U 5"DP singles(2 7/8"drift)and rack in derrick-45 joints. 22:00 22:30 0.50 22.50 DRILL E 25 P Service and lubricate rig-Draw-works,blocks,top drive. 22:30 00:00 1.50 24.00 DRILL E 4 'P Continue P/U 5"DP singles in mouse and rack back in derrick(2 7/8'drift)-30 joints. Daily Contacts Position _ Contact Name Company Title Email • Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rigt5@doyondrilling.com 907-685-0716 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') volt Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq � APIIUWI:50-629-23464-00-00 2^o Date:211512012 - Report#: 11 n II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 7.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POE Temperature(°C) Weather Wind 1,332.59 733.28 0.00 97.0 -17.2 Clear,WC-16° 43"NE @12 mph Daily summary operation 24h Summary P/U 5"drill pipe to drill intermediate section.\UD 5"HWDP(20 Its.)./Test BOPE to AOGCC requirements,Lou Grimaldi witness.\Hydro-tested modified 20'section 1/7500 psi.f/10 mins./Install 20'section in demck.\Transfer 700 bbls.new LSND mud to active pits.\P/U BHA#3 with Schlumberger. Operation at 07.00 RIH with BHA#3. 24h Forecast Finish P/U BHA#3 with Schlumberger.\RIH above float equipment.\Cut doling line.\Circulate bottom-up.\Test 13 3/8"csg.to 2500 psi.for 30 mins.(chart record)./Drill out shoe track and 254 new hole./ Displace to LSND mud-circulate until equal mud weights in/out./Perform LOT/FIT.\Drill ahead 12 1/4"hole section. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 ' 2.50 2.50 DRILL E 4 P P/U 5"DP singles in mouse and rack back in derrick(2 7/8'drift)-51 joints./Clean pits. 02:30 05:00 2.50 5.00 DRILL E 4 P Move NM Flex DC and jars/HWDP to ODS./UD 5"HWDP(20 its.)not needed in BHA#3 as per Schlumberger./UD long mouse hole. 05:00 07:30 2.50 7.50 DRILL E 20 P R/U to test BOPE-P/U 5"joint and set test plug-R/U manifold&lines./Fill stack,choke manifold with water./Clean pits. 07:30 17:00 9.50 17.00 DRILL E 12 P Test BOP to AOGCC requirements on 5"tubular./Annular @ 250 psi./2500 psi./Pipe rams(upper&lower),blind rams, ad mud cross valves,choke manifold, stand pipe,floor and top drive valves 250 psi./3500 psi.-Chart record all test for 5 mins./Hydraulic and Manual(A&B)choke valves tested to 1500 psi./Koomey draw down test(Recovery times:f/1500- 1/1700 psi.(200 psi.)in 43 seconds with final @ 3000 psi in 216 seconds.Pre-charge in 16 accumulate bottles average 1150 psi./5 Nitrogen bottles @ 2450 psi average./Flow tested gas buster-13 bbls.volume./Test gas sensors./Lou LS r Grimaldi with AOGCC witnessed BOP test. 17:00 17:30 0.50 17.50 DRILL E 20 P R/D test equipment and pull plug-install wear ring(12 5/16")-Vetco Gray rep./Blow down choke manifold,kill line and top drive. 17:30 23:00 5.50 23.00 DRILL E 5 P Test 20'section of modified stand pipe for WEI sub to 7500 psi.for 10 mins./Reinstall 20'section back in derrick./ Transferred 700 bbls.of LSND 9.2+ppg mud from MI Swaco mud plant to ng active pits. 23:00 00:00 1.00 24.00 DRILL E 4 P P/U BHA#3 with Schlumberger as per DD&MWD hands. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher dg15@doyondrilling.com 907-685-0716 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/em') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 .Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name: Nikaitchuq • APIIUWI:50-629-23464-00-00 2^o Date:2/16/2012 - Report#: 12 " ' page 1 of 1 Wellbore name: SI29-S2 Well Header PennitiConcession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 8.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) FOB Temperature(°C) Weather Wind 1,383.79 744.86 51.21 2.43 21.1 92.0 -25.0 Clear,WC-30 7°N @12 mph Daily summary operation 24h Summary Finished P/U BHA#3 with Schlumberger-surface test and record K&M parameters 2 273'.1 Test stand pipe 1/3500 psi.-f/t0 mins.\RIH f/273-t/4193'above float equipment./Slip&cut drilling tine (circulate bottom-up).\Service rig components./R/U-Test 13 3/8"csg.to 2500 psi.for 30 mins.(charted recorded).\Drill out shoe track 54350'and 25'new hole 1/4397'.\Displace to 9.2 ppg LSND mud- circulate until equal mud weights in/out.POOH into shoe.\Perform LOT to 11.6 ppg EMW.\Down time:Change out draw-works oiler pump electrical motor./Drill ahead 12 1/4"hole section with mud motor. Operation at 07.00 Drilling slide/rotating as required. 24h Forecast Drill ahead with mud motor 12 1/4"hole section. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr)i Dur(hr) Phase Opr. Act. Plan . Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P Continue P/U BHA#3 with Schlumberger-orientate tools-RIH 1/273'-Perform swallow test with pump rate 600 gpm @ 547 psi.\K&M record parameters for BHA.\Up wt.=108K-Dn wt.=100K-Rot wt.=102K. 03:00 03:30 0.50 3.50 DRILL E 12 P 'Pressure test new stand pipe section for WEI sub to 3500 psi 5/10 mins. 03:30 06:30 3.00 6.50 DRILL E 4 P RIH(/273'-V4009'-fill pipe every 20 stands./Wash f/4009'-1/4193'pumping 100 gpm @ 260 psi.\Up wt.=165K-Dn wt.= 92K. 06:30 08:00 1.50 8.00 DRILL E 25 'P PJSM-Slip 120'and cut drilling line.\Circulate hole pumping 84 gpm @ 240 psi.for 13 3/8"csg.test. 08:00 09:00 1.00 9.00 DRILL E 25 P Service rig components-Adjust brakes,draw-works,top drive,blocks,rough neck. 09:00 11:00 2.00 11.00 DRILL E 20 P R/U test equipment and fluid pack./Perform 13 3/8'csg.test to 2500 for 30 mins.(chart record).\R/D test equipment lines. 11:00 14:00 3.00 14.00 DRILL E 3 'P Break circulate wash/ream f/4193'-1/4367'(tag plugs).\Drill shoe track(plugs/cement)f/4267.-V4350'.\Clean rat hole section f/4350'-514372'.1 Pump rate 600 gpm @ 980 psi.\40 rpm @ 6-8K torque.\WOO=9-18K.\Up wt.=170K-On wt.= 90K.-Rot wt.=123K. 14:00 15:30 1.50 15.50 DRILL E 3 P Drill slide/rotate f/4372'-5/4397'(25'new hole-2410'TVD)\Pump rate 600 gpm @ 975 psi.\45 rpm @ 6-10K torque.\ WOB=15-20K.\Up wt=170K-Dn wt.=92K-Rot wt=125K.\Mud wt.=9.5 ppg.\ECD=10.07 ppg.\ART=0.92 hrs.\AST= 0.0 hrs.\ADT=0.92 hrs.\Jars=92.73 hrs. 15:30 18:30 3.00 18.50 DRILL E 7 P Displace well to 9.2 ppg LSND mud.\Pumped 40 bbs.LSND viscosities spacer.\Reciprocate and rotate pipe./Pumping • 500 gpm @ 570 psi.\40 rpm @ 6-8K torque.Up wt.=160K-Dn wt.=95K.-Rot wl.=125K.\ECD=9.6 ppg.\Balance mud 11,.....weight in/out.\POOH into shoe @ 4250'. 18:30 19:30 1.00 19.50 DRILL E 12 P R/U and perform LOT with 9.2 ppg.new LSND mud-EMW=11.6 ppg.\R/D and blow down lines.\Trouble shoot electrical problems with draw-works motors,would not stay moiling. n 19:30 21:30 2.00 21.50 DRILL E 25 'XR99 Down time:Continue trouble shooting draw-works-change out electrical drive motor on draw-works oiler pump. 21:30 00:00 2.50 24.00 DRILL E 3 P Drill Slide/Rotate(/4397'-1/4540'(2442'TVD)./Pump rate 600 gpm @ 780 psi.\40 rpm @ 8-11K torque.\WOB 10-15K.\ Mud wt.=9.2 ppg\ECD 9.70 ppg.\Up wt.=165K-Dn wt.=90K-Rot wt.=128K.\AST=0.0 hrs.-ART=1.51 hrs:ADT= 2.43 hrs.\Jars=94.24 hrs. Total ADT=2.43 hrs. Total AST=0.0 hrs. Total ART=2.43 hrs. Total Jar=94.24 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm) 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 if;iiiiil Eni E&P Division I Well Name:5129-S2 EN/Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • e n il Date:2117/2012 - Report#: 13 APIIUWI:50-629.23464-00-00 " 'I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 9.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,757.78 828.50 373.99 12.95 28.9 92.0 -27.2 Clear,WC-50 39°NNE @ 23 mph Daily summary operation 24h Summary Drill slide/rotate f/4540'-115641'\Check out pumps and surface equipment for drill pipe pressure loss-OK.Schlumberger checks down hole tool parameters.)Circulated-ream 1/5641'-115504'(clean-up coal seams)-drop carbide package to check for wash-out in string-back @ calculated strokes.Decision to drill ahead.)Drill slide/rotate 05641'-115767'. Operation at 07.00 Drilling slide/rotating as required @ 6000'. 24h Forecast Drill ahead 12 1/4"intermediate hole section with mud motor as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time 'rime Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 - 6.00 6.00 DRILL E '3 P Drill slide/rotate 1/4540'-114791'(2499'TVD).)Pump rate 700 gpm @ 1060 psi.)80 rpm @ 11-12K torque./WOB 30K.\Mud wt.=9.2 ppg\ECD 9.93 ppg.\Up wt.=150K-Dn wt.=110K-Rot wt.=128K.\AST=2.47 hrs.-ART=1.19 hrs:ADT=6.09 hrs.)Jars=97.90 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill slide/rotate(/4761'-115423'(2634'TVD)./Pump rate 900 gpm @ 1580 psi.)60 rpm @ 10-12K torque.)WOB 8.10K.\ Mud wt.=9.25 ppg\ECD 9.95 ppg.\Up wt.=155K-Dn wt.=105K-Rot wt.=130K./AST=1.30 hrs.-ART=2.34 hrs.-ADT =9.73 hrs.\Jars=101.54 hrs. 12:00 '18:00 6.00 18.00 DRILL E 3 P Drill slide/rotate f/5423'-1/5641'(2686'TVD).)Pump rate 900 gpm @ 1420 psi.)60 rpm @ 10-12K torque.)WOB 20K.\Mud wt=9.3 ppg\ECD 9.93 ppg.\Up wt.=160K-Dn wt.=102K-Rot wt=130K.\AST=2.75 hrs.-ART=0.98 hrs:ADT= 13.46 hrs.\Jars=105.27 hrs. 18:00 19:00 1.00 19.00 DRILL E -7 P Trouble shoot surface equipment for drill pipe pressure loss(200 psi.)-change pumps,check and clean suction screen pots.)Schlumberger checks down hole tool parameters.\Rig components good. 19:00 20:00 1.00 20.00 DRILL E -7 P Ream 1/5641'-1/5495'pumping 900 gpm @ 1450 psi.)60 rpm @ 10-22K torque(Possible coal seams 1/5430'-115460'& f/5560'-5600')\Drop carbide package to check for possible wash out-(Back to surface @ correct stokes)-Wash&ream I back to bottoms(/5504'-t/5641'pumping 450 gpm @ 1100 psi.)60 rpm @ 8-9K torque.Decision to drill ahead and continue monitoring trends. 20:00 00:00 4.00 24.00 DRILL E '3 P Drill slide/rotate 1/5641'-115767'(2718'ND)./Pump rate 900 gpm @ 1610 psi.\80 rpm @ 8-12K torque.)WOB 15-20K./ Mud wt.=9.3 ppg\ECD 10.04 ppg.\Up wt=165K-Dn wt=105K-Rot wt.=130K.\AST=1.71 hrs:ART=0.21 hrs:ADT =15.38 hrs.\Jars=107.19 hrs. Total ADT=15.38 hrs. Total AST=8.23 hrs. Total ART=7.15 hrs. Total Jar=107.19 hrs. Daily Contacts Position Contact Name Company Title E-mail • Office Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDnlling@enipetroleum.com '907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon156enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91.2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(giL) P LeakOff(kgflcm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Eni E&P Division I Well Name:SI29-S2 EN!Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • API/t1Wl:50-629-23464-00-00 2^n Date:2/18/2012 - Report#: 14 " 'I'I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12_ 1,176.69 5,914.34 172.37 34.3 10.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,101.60 949.45 343.81 12.00 28.7 92.0 -22.2.Clear,WC-28 50°NNE @ 18 mph Daily summary operation 24h Summary Drills slide/rotate(/5767'-t/6895'as per directional well plan-Time break down:slide 776.3%and rotate-22.7%.\Finished loading pipe shed with 9 5/8"csg.-(strap S.drift 1/8.750). Operation at 07.00 -_ Drilling ahead projected to sliding 84%/rotating 16%as directional required. 24h Forecast Drill intermediate hole section with mud motor to proposed 9 5/8'csg TD @ 8992'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 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 3 "P Drill slide/rotate(/5767'-t/6102'(2821'TVD).\Pump rate 900 gpm @ 1704 psi.\80 rpm @ 9-10K torque./WOB 10-30K.\ Mud wt.=9.3 ppg\ECD 10.06 ppg.\Up wt.=160K-Dn wt.=112K-Rot wt.=134K.\AST=2.25 hrs:ART=0.78 hrs:ADT =18.41 hrs.\Jars=110.22 hrs. 06:00 12:00 ' 6.00 12.00'DRILL 'E 3 P Drill slide/rotate f/6102'-1/6380'(2919'TVD).\Pump rate 900 gpm @ 1704 psi.\60 rpm @ 8-9K torque./WOB 10-20K.1 Mud wt.=9.3 ppg\ECD 9.93 ppg.\Up wt.=160K-Dn wt.=118K-Rot wt.=138K.1 AST=3.03 hrs.-ART=0.67 hrs.-ADT= 22.11 hrs./Jars=113.92 hrs. 12:00 18:00 6.00 18.00'DRILL E 3 P Drill slide/rotate 1/6380'-U6719'(3048'TVD)./Pump rate 900 gpm @ 1750 psi.\80 rpm @ 10-15K torque./WOB 10-30K.\ Mud wt=9.3 ppg\ECD 10.02 ppg.\Up wt=180K-Dn wt.=115K-Rot wt=142K.\AST=1.95 hrs:ART=0.81 hrs:ADT =24.87 hrs.\Jars=116.68 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill slide/rotate 1/6719'-1/6895'(3125'TVD).\Pump rate 900 gpm @ 1790 psi.\80 rpm @ 10-15K torque./WOB 10-30K.\ Mud wt.=9.3 ppg\ECD 9.98 ppg.\Up wt.=180K-Dn wt.=115K-Rot wt.=142K.1 AST=2.05 hrs.-ART=0.46 hrs.-ADT= 27.38 hrs./Jars=119.19 hrs. Total ADT=27.38 hrs. Total AST=17.51 hrs. • Total ART=9.87 hrs. Total Jar=119.19 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com -907-685-0715 -715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 • Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 • Last Casing seat • Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8' 12.415'L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 litiiiis Eni E&P Division 'Well Name:SI29-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq Date:2/19/2012 - Report#: 15 APIIUWI:50-629-23464-00-00 page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 11.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,215.29 992.34 113.69 6.18 18.4 92.0 -23.3 Fog,WC-25 49°NNE @ 17 mph Daily summary operation 24h Summary Drill slide/rotate 1/6895'-1/7268'.1 Had a pressure loss(200 psi.)and found 5"DP connection lose 20'below rotary table-set back stand 1/7181'-decision to P001-1.1 Circulated bottoms-up 1/7181'- 116810'(rack stand each CBU)-Observed a 750 psi.of pressure-shut down rotary and pump.\POOH 1/6810'-113916'as per K&M swab model- monitoring for swabbing and calculate fill. Operation at 07.00 POOH with BHA#3 looking for washout in string. 24h Forecast Continue POOH f/3916'to BHA#3-looking for wash out and monitoring for swabbing.\Inspect BHA#3 for possible wash-out in tools string or bad motor-L/D.\P/U BHA#4 RIH to 5"HWDP-surface test./Continue RIH with BHA#4-checking all 5"drill pipe connection. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill slide/rotate 1/6895'-18089'(3188'TVD).\Pump rate 900 gpm(g 1850 psi.\80 rpm @ 10K torque.\WOB 20-30K.\Mud wt.=9.2 ppg\ECD 9.90 ppg.\Up wt.=180K-Dn wt.=120K-Rot wt.=143K.\AST=2.53 hrs.-ART=0.21 hrs:ADT= 30.12 hrs.\Jars=121.93 hrs. 06:00 12:30 6.50 12.50 DRILL E '3 P Drill slide/rotate(/7089'-1/7268'(3256'TVD).\Pump rate 900 gpm @ 1900 psi.\80 rpm @ 10K torque.\WOB 20-30K.\Mud wt=9.3 ppg\ECD 9.94 ppg.\Up wt=180K-Dn wt.=120K-Rot wt.=143K.\AST=3.13 hrs.-ART=.31 hrs.-ADT=33.56 hrs.\Jars=125.37 hrs.\Lost 200 psi.pressure. Total ADT=33.56 hrs. Total AST=23.17 hrs. Total ART=10.39 hrs. Total Jar=125.37 hrs. 12:30 13:30 ' 1.00 13.50 DRILL E 7 P Pick-up off bottom @ 7268'circulating 900 gpm @ 1790 psi.found first connection(20'down)spraying-shut down pump and set back stand#75 in derrick-bit @ 7181'.1 Decision to POOH and check pipe. 13:30 18:00 4.50 18.00 DRILL E 7 P Circulate bottoms-up(4X)f/7181'-1/6810'(racking back one stand every CBU).\Pump rate 900 gpm @ 1790 psi.\120 rpm @ 10K torque.\Rot wt.=140K\MW=9.25 ppg.\ECD 9.94 ppg.\Observed 750 psi.loss in stand pipe pressure-shut down pump and rotary-check SPR on#1&#2 indicated 30 psi.loss on both pumps. 18:00 00:00 6.00 24.00 DRILL E 4 P POOH 1/6810'-1/4350'(casing shoe)on elevators looking for wash out.\Monitor annulus for swabbing and calculated fill each stand.-started @ 9 mins.and increased to 4 mins.a stand-as per K&M swab model.\Continue POOH 1/4350'- 1/3916'increasing speed to 2 mins a stand and monitor for swabbing. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflem') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Vol Eni E&P Division [Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUW I:50-629-23464-00-00 e^II Date:2/20/2012 - Report#: 16 " II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 12.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(•C) Weather Wind 2,215.29 992.34 0.00 _ 94.0 -23.3 Clear,WC-32 37°NE @ 21 mph Daily summary operation 24h Summary POOH(/3916'-V183'per K&M swab model./Jar body failure and recovered 24.93'(with 4.75'of intemal lower mandrel)-Remaining BHA#3 fish in hole 183.76'@ 6625'.\LID jar.\Load 5"HWDP and 8" DC in pipe shed-P/U 5"HWDP./P/U Baker Hughes fishing assembly(BHA#4)and 8"DC 11419'.\RIH f/419'-113781'-break every connection-cleaning and inspecting for dry/washed threads-Dope and torque to spec @ 43K:UD 4 joints-stand#17&#34. Operation at 07.00 RIH with BHA#4 Baker fishing assembly-checking/inspecting every 5"DP connection. 24h Forecast Continue RIH f/3916'-114894'check/inspecting every connection-M/U to spec.@43K-Overshot packing off and string taking weight 20K-will have to pump and possible rotate in hole./POOH 84894'- 82745'(23 stands)./RIH t/2745'-V4893'checking/inspecting connection./Continue RIH washing to top of BHA#3 fish./Engage fish and POOH. Lithology Shows MAASP(kgf/cm°) Mud Weight(g/L) 1108.4 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 4 P POOH 1/3916'-11334'on elevators @ 2 mins a stand-watch for swabbing and calculated fill each stand.\Monitor annulus for 15 mins.\P/U single and set back stand 1/273'. 04:30 06:30 2.00 6.50 DRILL E 4 XDO1 Continue POOH 5"HWDP and jars-found jars body had failed,recovered 24.93'(also recovered lower mandrel 4.75 attached to jars).\Remaining BHA#3 fish in hole 183.76-top of fish approximately @ 6625'.\WU stand of 5"HWDP with single and set./L/D jars. 06:30 09:00 2.50 9.00 DRILL E 4 P Clean and clear floor-Load Doyon 8"drill collars(3)and 5"HWDP(9)into pipe shed. 09:00 10:00 1.00 10.00 DRILL E 4 P PJSM-P/U 5"HWDP(9 jts.)and stand back in derrick. 10:00 12:00 2.00 12.00 DRILL E 1 P Load Baker Hughes fishing tools on rig floor and pipe shed. 12:00 15:30 3.50 15.50 DRILL E 4 P PJSM-P/U and M/U BHA#4 Fishing Assembly(10 3/4"Bowen overshot, 7 3/4"bumper sub,7 3/4"jars and pump out sub)as per Baker rep.and 8"Drill collar t/419'. 15:30 00:00 8.50 24.00 DRILL E 4 P RIH with BHA#4 8419'-11 3781'-Break out(clean&inspect every connection)make up to torque spec of 43K.\BHA weight 60K.\UD 4 joints of 5"drill pipe form string with dry/washed connection and replaced same./Stands#17&#34. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener ENI Senior Drilling Supv SIDDnliing@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1.325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 %I* Eni E&P Division I Well Name:SI29-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq � APIIIAM:50-629-23464-00-00 ,yam^ii Date:2/21/2012 - Report#: 17 lIIpage 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) •RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date •Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 13.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,215.29 992.34 0.00 93.0 -21.7 Clear,WC-23 12°N @ 12mph Daily summary operation 24h Summary RIH checking and inspecting all connections.Take parameters for fishing job.Tag fish @ 7087'and work tool over fish.POOH with Fished BHA to 4808'. Operation at 07.00 POOH to LD fished BHA. 24h Forecast Bring fish to surface and LD.Pick up new BHA and RIH checking DP makeup.Cleanup bottom of hole and proceed to drill to casing depth. Lithology Shows MAASP(kgfIcm) Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E -13 P RIH with Baker fishing assy.1/3781'-4339'checking and inspecting all connections.Fill pipe and break circ.@ 3.5 bpm,300 psi.142k puw,109k sow,127k rotw,5-8k iq. 02:00 02:30 0.50 2.50 DRILL E 13 P RIH f/4339'-4794'.String taking weight so break circ.@ 3 bpm.720-220 psi,overshot packed off and cleaned up. 02:30 03:00 0.50 3.00 DRILL E 13 P RIH f/4794'-4894'.Break circ.and establish rotary @ 20 rpm,5-7k tg,and ream to 4899'. 03:00 04:30 1.50 4.50 DRILL E 13 P Decision was made to POOH f/4899'-2751',150k puw,rack pipe on drlg side. 04:30 08:00 3.50 8.00 DRILL E 13 P RIH(/2751'-4889'with DP from off dug.side and check and inspect connections.110k sow. 08:00 12:00 4.00 12.00 DRILL E 13 P Wash and ream 1/4899'-6582'@ 3 bpm,260 psi,20 rpm,5-6k tq.Est.fishing flow rates,1 bpm,190 psi/3 bpm,260 psi/6 bpm,330 psi,180k puw,112k sow,135k rotw. 12:00 14:00 2.00 14.00 DRILL E 13 P Wash and ream 1/6582'-7087'(TOFish),190k puw.122k sow.PU 10'and circ.@ 1 bpm and rotate and wash down over fish.Stop rotation and PU off bottom 220k puw. 14:00 16:30 2.50 16.50 DRILL E 13 P Flow check-Static.POOH on elevators f/7268'-6150',220k puw. 16:30 00:00 7.50 24.00 DRILL E 13 P Pump out of hole f/6150'-4808',@ 2 bpm,290 psi,170k puw.6 bbls loss during trip. SPR @ 7142'MD(3221'TVD)#1 MP,20 spm=290 psi.#2 MP,20 spm=290 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobil. Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Mauinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat _ Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 iiiiiot Eni E&P Division I Well Name:SI29S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • Date:2/22/2012 - Report#: 18 APIIUWI:50-629-23464-00-00 2" " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5129-62 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 14.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,215.29 992.34 0.00 95.0 -27.8 Lt.Snow,WC-39 10°N @ 10 mph Daily summary operation 24h Summary POOH and UD Fish.M/U BHA#4 and RIH to 1588'. Operation at 07.00 RIH with BHA#4 to 4000'14- 24h /- 24h Forecast Drill ahead to 12.25"TD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 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 13 P Pump out of hole f/4808'-0360'@ 2 bpm,200-350 psi.143k puw. 01:30 i 02:30 1.00 2.50 DRILL E 13 P Orient fish and pull into shoe.150k puw,pump @ 2 bpm,230 psi and come up to 4058'.Blow down top drive and monitor well-static. 02:30 06:00 3.50 6.00 DRILL E 13 P POOH on elevators f/4058'-695'.160k puw.Monitor well-static.8 bbls losses. 06:00 08:30 2.50 8.50 DRILL E 13 P 'PJSM,rack back 8"DC's and HWDP,UD fishing BHA,pull fish to floor and lay down. 08:30 10:00 1.50 10.00 DRILL E 13 P UD Schlumberger BHA. 10:00 10:30 0.50 10.50 DRILL E 13 P Clean ng floor. 10:30 11:00 0.50 11.00'DRILL E 20 P -WEI Reps.plan out WEI manifold project with Doyon. 11:00 12:00 1.00 12.00 DRILL E 13 P P/U overshot and bumper sub.Release fish and L/D. 12:00 15:00 3.00 15.00 DRILL E 13 P PJSM,breakout and UD Baker fishing tools.RIH with 8"DC's and 2-stds HWDP.POOH L/D same. 15:00 16:00 1.00 16.00'DRILL E 20 P -P/U long mouse hole and install in table.P/U stand of 5"DP with washout and break down and L/D. 16:00 19:30 3.50 19.50 DRILL E 4 P PJSM,P/U and M/U BHA#4 as per Schlumberger Directional Driller and RIH to 282'. 19:30 20:00 0.50 20.00'DRILL E 19 P Perform shallow hole test @ 282',669 gpm,670 psi. Blow down top-drive and choke kine. 20:00 20:30 0.50 20.50 DRILL E '19 P K&M rotate @ 30 rpm,2k tq,98k puw,101k sow,100k rotw. 20:30 00:00 3.50 24.00 DRILL E 4 P RIH 5/282'-1588'Check and clean every connection and torque to specs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907.685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.cow 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Voil Eni E&P Division 'Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • e^o Date:2123/2012 - Report#: 19 APIIUWI:50-629-23464-00-00 II II page 1 of 1 Wellbore name: SI29-S2 Well Header Pennit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 15.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,362.81 1,044.42 147.52 8.72 16.9 95.0 -30.0 FOG,WC-35 18°NNE @ 7mph Daily summary operation 24h Summary Wash and ream to TD @ 7268'.Drill ahead to 7752'MD(3426'TVD). Operation at 07.00 Drilling 12.25"intermediate hole to 8000'+/-. 24h Forecast Drill 12.25"intermediate hole to TD+/-8992'MD.CBU as per K&M. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P RIH 1/1588'-4293'checking and MU 5"DP to Specs. 03:00 04:30 1.50 4.50'DRILL E 7 P CBU @ 500 gpm,700 psi,140k puw,110k sow,127k rotw with pumps off,6-8k tq.Monitor well-static. 04:30 05:00 0.50 5.00'DRILL E 4 P RIH on elevators 5 4293'-4443'string taking weight 80-90k sow.Worked through tight spot to 5044'. 05:00 '06:30 1.50 6.50 DRILL E 4 P Wash and ream f/5044'-5604',600 gpm,900 psi,100 rpm,10-14k tq,75-90k sow. 06:30 10:00 3.50 10.00'DRILL E 4 P Wash and ream f/5604'-7192',350 gpm,510 psi.70 rpm,10k tq.Establish drilling rate @ 850 gpm,1850 psi,120 rpm.10k tq and wash and ream to bottom @ 7268' 10:00 12:00 2.00 12.00 DRILL E -3 P Ddg.f/7268'-7311'MD(3272'ND),850 gpm,1850 psi,120 rpm,12k tq on,8-13k tq off,190k puw,115k sow,145k rotw, max gas=11.1-ART,1-ADT,1-Bit/Jars.SPR @ 7260'MD(3252'TVD),9.4 ppg.#1 @ 30=240 psi,@ 40=270 #2 @ 30=240,@ 40=270 psi 12:00 '18:00 6.00 18.00 DRILL E 3 P Ddg.f/7311'-7592'MD(3372'ND),900 gpm.1950 psi,120 rpm.10-12k tq on,12k tq off,10-20k wob,190k puw.119k sow,140k rotw,10.5 ECD,Max gas=28 @ 7311'. 18:00 '00:00 6.00 24.00 DRILL E '3 P Ddg.1/7592'-7752'MD,(3426'TVD),700 gpm,1350 psi,60 rpm,10-12k tq on,12k tq off,20-30k wob,197k puw,122k sow,150k rotw,9.9 ECD,Max gas=4,7.72 ADT,7.72 ART,8.72 Bit/Jars. SPR @ 7653'MD,9.2 ppg,#1 @ 30=190 psi,@ 40=230,#2 @ 30=190,@ 40=230 psi. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig 15@doyondrilhng.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade • Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 %lilt Eni E&P Division I Well Name:SI29-S2 EN!Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 en 1 Date:2/24/2012 - Report 4: 20 page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 16.33 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 2,663.95 1,120.51 301.14 15.90 18.9 95.0 -39.4 Clear,WC-65 10°N @ 10 mph Daily summary operation 24h Summary Drlg.intermediate section f/7752'-8740'MD. Operation at 07.00 Circulate and back-ream out of hole. 24h Forecast TD intermediate section©8900'+/-.Circulate and back-ream out of hole as per OM schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00:00 01:30 1.50 1.50 DRILL E 3 P DrIg.f/7752'-7843'MD(3455'ND)700 gpm,1320 psi,50 rpm,11k tq on,9k tq off,10-30k wob,190k puw,122k sow, 150k rotw,9.92 ECD,Max gas 15.1.62 ADT,10.34 Bit/Jars. 01:30 03:00 1.50 3.00 DRILL E 7 P Circulate and condition mud while reciprocating 1/7811'-7744',900 gpm,2000 psi,120 rpm,10k lq. 03:00 06:00 3.00 6.00 DRILL E 3 P Drlg.f/7843'-7950'MD(3487'ND)600 gpm,1060 psi,45 rpm,10-40k web,10k tq on,8k tq off,195 puw,122k sow,150k rotw,10.04 ECD,Max gas 10.2.28 ADT,12.62 Bit/Jars. 06:00 '12:00 6.00 12.00 DRILL E 3 P Ddg.f/7950'-8316'MD(3591'ND),600 gpm,1070 psi.45 rpm,10-40k wob,13k tq on,9k tq off,184k puw,122k sow, 150k rotw,10.20 ECD,Max gas 363.3.84 ADT,16.46 Bit/Jars.SPR @ 8029'MD(3510'ND)9.4 ppm MW. #1 @ 30=210 psi,@ 40=250 #2 @ 30=200,@ 40=240 psi. 12:00 '18:00 6.00 18.00 DRILL E 3 P Ddg.f/83168550'MD(3648'ND),600-900 gpm,1080-2050 psi,45-120 rpm,4ok wob,13k tq on,9k tq off,190k puw. 125k sow,152k rotw,10.27 ECD,Max gas 118. 18:00 '00:00 6.00 24.00 DRILL E 3 P 04g.f/8550'-8740'MD(3679'ND),600 gpm,1100 psi.45 rpm,39k wob,12k tq on.9k tq off,190k puw,125k sow,152k rotw,10.15 ECD,Max gas 40.8.16 ADT,24.62 Bit/Jars. SPR @ 8346'MD(3596'ND)9.4 ppg MW #1 @ 30=220 psi,@ 40=260 #2 @ 30=230,@ 40=270 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Tom Klein ENI Mats Coordinator 907-685-0718 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 0.10* Eni 1:177Eni E&P Division (Well Name:SI29-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq e APIIWN:50-629-23464-00-00 2^n Date:2/25/2012 - Report#: 21 II II II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 17.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,715.16 1,124.74 51.21 3.23 15.9 96.0 -37.2 Clear,WC-64 18°NNE @ 16 mph Daily summary operation 24h Summary TD intermediate hole @ 8908'MD as per Geologist.Perform cleanup cycle and BROOH to 5508'. Operation at 07.00 BROOH 24h Forecast BROOH to inside of casing.POOH and LD BHA.Change rams to 9 5/8"and test.RU to run 9 5/8"casing. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 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 3 P Complete intermediate section.Ddg.f/8740'-8908'MD(3688'TVD),900 gpm,2020 psi,120 rpm,40 k wob,13k tq on,9k to off,185k puw,122 sow.149k rotw,10.25 ECD,Max gas 25.3.53 ADT,27.94 Bit/Jars.SPR @ 8908'MD(3688'TVD) 9.5 ppg MW #1 @ 30=250 psi,@ 40=300 #2 @ 30=270,@ 40=310 psi 04:30 05:00 0.50 5.00 DRILL E 19 'P Monitor well-Static 05:00 12:00 7.00 12.00 DRILL E 4 P BROOH cleanup cycle f/8908'-8312'MD @ 1 std per btms up,900 gpm,2020 psi,120 rpm,10k tq 149k pow. 12:00 18:00 6.00 18.00 DRILL E 4 P BROOH f/8312'-6920'.900 gpm,1850 psi,120 rpm,10k tq,140k puw,130 sow,140 rotw. 18:00 00:00 6.00 24.00 DRILL E 4 P BROOH f/6920'-5508',900 gpm,1750 psi,120 rpm,8-9k tq,125 puw,130k sow.125k rotw.Total fluid losses for tour-61 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDriliing@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 iiiiiiil Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIt1WI:50-629-23464-00-00 2^II Date:2/26/2012 - Report#: 22 'I " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5129-02 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 18.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,715.16 1,124.74 0.00 97.0 -37.8 Clear,WC-64 11°N@ 15 mph Daily summary operation 24h Summary BROOH,LD BHA. Operation at 07.00 Running 9 5/8"Casing. 24h Forecast Pull wear bushing,set test plug,chg.rams to 9 5/8"and test to 350/3500 psi.RD same.RU and run 9 5/8"casing. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 4 'P BROOH f/5508'-4293',900 gpm,1650 psi,120 rpm,8-10k tq.Cont.to BROOH f/4293'-2612'do to large amount of cuttings retums,900 gpm,1380 psi,120k rpm,3-5k tq. 12:00 19:00 7.00 19.00 DRILL E 4 P BROOH f/2612'-281',900 gpm,1100 psi,120 rpm,2-3k tq,95k puw,95k sow,95k rotw.Monitor well-Static.Daily total losses for trip-25 bbls. 19:00 22:00 3.00 22.00 DRILL E 4 P PJSM,L/D BHA#4. 22:00 '00:00 2.00 24.00 DRILL E 20 P Clear and clean floor.Drain stack and prep.to pull wear bushing. Daily Contacts Position _ Contact Name Company Tide E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv .SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Tom Klein ENI Mails Coordinator 907.685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 11.05 1,325.91 2/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Vitil Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq eDate:2/27/2012 - Report#: 23 APIIUWI:50 629-23464-00-00 2 r' rr ii page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 19.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,715.16 1,124.74 0.00 98.0 -46.1 Clear,WC-82 17°NNE @ 15 mph Daily summary operation 24h Summary Pull wear bushing,set test plug,chg.rams to 9 5/8"and test.R/U Tesco and run/float 9 5/8"400 Hydril 563 casing to Csg.Pt.@ 8892'. Operation at 07.00 Filling 9 5/8"casing as per schedule. 24h Forecast R/D Tesco equipment and R/U cement head.Fill casing as per schedule,circulate hole and perform cementing operations. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 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 Pull wear bushing and set test plug. 00:30 01:30 1.00 1.50 DRILL E 20 P - Change too rams to 91/8". 01:30 03:00 1.50 3.00 DRILL E 12 P R/U and test 9 5/8"rams to 250/3500 psi for 5 min.Charted.R/D test equipment,L/D test jt,and install short wear bushing as per Vetco. 03:00 05:30 2.50 5.50 DRILL E 20 P R/D elevators,top drive bell guide and mobilize Tesco casing equipment to rig floor..Makeup Tesco equipment. 05:30 06:30 1.00 6.50 DRILL E 4 P PJSM,P/U and M/U 9 5/8"shoe track and RIH U 166',fill with mud and check floats-Good. 06:30 12:00 5.50 12.00 DRILL E 4 P RIH w/9 5/8"40#Hydril 563 casi_ng1L-]¢6'-2764'70-77k sow.(<&M perform torque and drag readings. 12:00 18:00 6.00 18.00 DRILL E 4 P Cont.RIH w/9 5/8"casing 6 2764'-5679',75k sow.w$tile rotating.Started rotaing in @ 3373'. 18:00 00:00 6.00 24.00 DRILL E 4 P Cont.RIH w/9 5/8"casing f/5679'-8892'(Csg Pt.).75-85k sow while rotating,130k puw no rotate.Correct displacment observed. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907.685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1.325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Vol Eni E&P Division I Well Name:SI29-S2 EN!Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 2 f"I^o Date:2/28/2012 - Report#: 24 page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 20.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,715.16 1,124.74 0.00 95.0 -42.8 Lt Ice Fog WC-72° 32°NNE @ 12 mph Daily summary operation 24h Summary R/D Tesco equip.,R/U cement head and fill csg.as per schedule.Break circ.and stage rates to 6 bpm.Hold PJSM for cement job. Pump 70 bbls 10.5 Mud Push.Test Schlumberger cement lines to , 3500 psi.Bleed oft pressure and blow down.Batch cement. Operation at 07.00 , N/D stack. 24h Forecast Mix cement and pump 152 bbls LiteCrete slurry 12.5 ppg w/1 Ib/bbl.cemnet in the first 100 bbls.Spot cement in place.Check floats,R/D cmt.equip.N/D BOPS and raise stack.Set emergency slips and cut casing.N/U stack and prep.for BOP test. Lithology Shows MAASP(kgflcm°) Mud Weight(giL) 1114.4 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 P R/D&VD Tesco equipment. 01:00 02:00 1.00 2.00 DRILL E 20 P R/U long bails and cement head. 02:00 07:30 5.50 7.50 DRILL E 19 P Fill casing in stages,1/2,3/4,and full w/676 bbls.Intial casing wt.=85k,full=135k. 07:30 12:00 4.50 12.00 DRILL E 7 P Break circulation @ 1/2 bpm,260 psi.stage up to 2 bpm,260 psi. 12:00 22:00 10.00 22.00 DRILL E 7 P Cont.to circulate staging pumps up to 6 bpm. Notes on circulating rates/losses; 1-3 bpm/0 losses 3.5 bpm/2 bph,circ.until 0 losses 4 bpm/3/4/0 bph losses 4.5 bpm/3/4/1/2 bph losses 5 bpm/2/3/1/2 bph losses 5.5 bpm/1/1/2 bph losses 6 bpm/0 lossses Total losses for circ.cycles=34 bbls. 22:00 22:30 0.50 22.50 DRILL E 7 P Hold PJSM for cementing. 22:30 23:00 0.50 23.00 DRILL H 7 P Pump 70 bbls,10.5 ppg Mud Push @ 5 bpm.,230 psi. i 23:00 23:30 0.50 23.50 DRILL H 12 P Schlumberger pump 10 bbls water and test lines to 3500 psi.Bleed off pressure and blown down lines. 23:30 00:00 0.50 24.00 DRILL H 20 P Schlumberger batch mix cement for job. ' Daily Contacts Position Contact Name Company Title E-mail Office Mobile I Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 • Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date . CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 • • 1 1 Vos Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • n II Date:2129/2012 - Report#: 25 Aplluwl:50-629-23464-00-00 lir(I II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 21.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,715.16 1,124.74 0.00 95.0 -37.2 Clear,WC-59° 12°N@ 10 mph Daily summary operation 24h Summary Pump 155 bbls cement as per plan and displace w/9.4 ppg mud.Bumped plug and had full returns throughout job.CIP @ 0230.Floats held,R/D cmt.equip.Perform 13 3/8"X 9 5/8"Annular infectivity with 55 bbls.9.4 ppg mud.Drain stack and evacuate 9 5/8"csg.N/D BOPE.Set Vetco emergency slips w/100,000 over,set packoff.N/U BOPs.Test 9 5/8"packoff.Chg.rams and complete R/U. Perform freeze protect of 13 3/8"X 9 5/8"annulus wl 260 bbls diesel.R/U for testing BOPE. Operation at 07.00 Testing BOPE. 24h Forecast Test BOPE,P/U and rack back 100 stds of 4.5"DP. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum �� Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. moi-' 00:00 00:30 0.50 0.50 DRILL H 7 P Perform cement operations,pump out btm.piny/156_bbls.Lititecrete 12.5_ w/ ppg 1,ppb m CeNet in the first.100 bbls 4 ' •!� bpm,290 psi initial-180 psi final.Pump out top plug w/10 bbls water. 00:30 02:30 2.00 2.50 DRILL H 7 P Displace cmt.w/9.4 ppg LSND mud @ 6 bpm,230 psi,@ 480 bbls,pump @ 3 bpm,160-500 psi.Bumped plug @ 660 bbls.,pressure up to 1000 psi for 5 min,bleed pressure and floats held okay.CIP @ 0230 hrs.Full returns. 02:30 03:00 0.50 3.00 DRILL H 20 P Blow down cement equipment and R/U to perform injectivity operation. /� .^� 03:00 04:30 1.50 4.50 DRILL E 9 P Pump 20 bbls 9.4 ppg mud down 13 3/8"X 9 5/8"annulus @ 2 bpm,640 psi.Bleed down to 300 psi and back flowed 2 V bbls.Redo;@ 2.2bpm,700 psi pumped 35 bbls.allow formation to bleed down to 80 psi.0 returns.R/D equipment. 04:30 05:30 1.00 5.50 DRILL E 20 P Drain and wash stack.Evacuate 9 5/8"casing for casing cut. 05:30 07:00 1.50 7.00 DRILL E 20 P N/D stack. 07:00 08:00 1.00 8.00 DRILL E 20 P Vetco set emergency slips with 100,000k overpull. 08:00 10:30 2.50 10.50 DRILL E 20 P R/U and cut 9 5/8"casing as per Vetco.Pull landing jt.w/csg.cut off and L/D.Pull wear bushing. 10:30 11:30 1.00 11.50 DRILL E 20 P Run and set 9 5/8"pack off. 11:30 14:00 2.50 14.00 DRILL E 12 P N/U BOPs.Vetco test 9 5/8"pack off to 2470 psi for 10 min.Witnessed by Driller.Clean and clear floor. 14:00 18:00 4.00 18.00 DRILL E 20 P Change upper rams back to 4 1/2"X 7"variables.Complete BOP nipple up. 18:00 23:00 5.00 23.00 DRILL E 9 P Lil Red freeze protect 13 3/8"X 9 5/8"annulus with 260 bbls of diesel @ 2 bpm max pressure of 1050 psi,final pressure of 850 psi. 23:00 00:00 1.00 24.00 DRILL E 20 P Prep.for BOPE testing.Witness waived by Jeff Jones. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2.710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 %jot Eni E&P Division i Well Name:SI29-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq 0• API/UWI:50-629-23464-00-00 n 2 g 11 I) Date:31112012 - Report#: 26 page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) •Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 22.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) ROB Temperature(°C) Weather •Wind 2,715.16 1,124.74 0.00 95.0 -46.1 Clear,WC-84° 186°SSW @ 10 mph Daily summary operation 24h Summary Test BOPE as per requirements.Witness waived by Jeff Jones.P/U 33 jts.5"DP and rack back.P/U 4.5"DP and rack back. Operation at 07.00 P/U 4.5"DP and rack back. 24h Forecast Complete P/U 4.5"DP and rack back.Cut/slip Drlg line.Chg.saver sub.M/U BHA and RIH logging cement bond f/4300'to TO float collar. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:30 10.50 10.50 DRILL E 12 P PJSM.Test BOPE with 5'and 4.5"test jts.@ 250 psi low,3500 psi high for 5 min.charted.Annular @ 250/2500 psi.1 failure on top ram-replaced packers on rams and tested good.1 failure on choke line leak-hammer up and tested good. Draw down;Initial Pressures,Manifold/1550,Sys./3000,Annular/750.After draw down pressures;Man/1450,Sys/1450. 200 psi build up in 33 sec,Total sys.in 189 sec.5-bottles avg @ 2350 psi.Flow tested chokes A,B and Super Choke Test Good.13 bbls to fill Poor Boy Degasser.Witness waived by Jeff Jones. 10:30 11:00 0.50 11.00 DRILL E 12 P Pull test plug and install wear bushing. 11:00 12:00 1.00 12.00 DRILL E 20 P Blow down test equipment and R/D. 12:00 13:00 1.00 13.00 DRILL E 20 P Work on Drill-Link system with NOV&Schlumberger reps.while R/U 5"handling tools. 13:00 16:00 3.00 16.00 DRILL E 4 P Single in hole with 33 jts.of 5"DP and POOH stand back in derrick. 16:00 17:00 1.00 17.00 DRILL E 20 'P Work on Drill-Link system with NOV&Schlumberger reps.while changing handling tools from 5"to 4.5". 17:00 22:30 5.50 22.50 DRILL E 4 P PJSM,P/U 4.5"singles and RIH to 4000'. 22:30 23:00 0.50 23.00 DRILL E 7 P Circulate drill string Gear of thick mud @ 9 bpm,460 psi. 23:00 00:00 1.00 24.00 DRILL E 4 POOH 1/4000'-2500'racking back in derrick. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Writit Eni E&P Division .,} 'Well Name:S129-S2 I ENI Petroleum Co.Inc. Daily Repo)` Well Code:26210 • Field Name:Nikaitchuq e^I' Date:3/212012 - Report#: 27 API/OWL 50-629-23464-00-00 'I II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 23.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) FOB Temperature(°C) Weather Wind 2,715.16 1,124.74 0.00 95.0 -37.0 Clear,WC-67.1° 213°SSW @ 11.5 mph Daily summary operation 24h Summary Complete P/U 4.5"DP and rack back.CuUslip Ddg line.Chg.saver sub.M/U BHA. Operation at 07.00 RIH w/8.75"drilling assy.on 4.5"DP. 24h Forecast Complete M/U of BHA&RIH with 8.75"drill assy.Log cement bond wl SLB sonic from 4350'-TO float collar.Perform casing test.Drill out shoe track plus 20'+of new hole and perform LOT.Drill ahead in the production hole. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P POOH w/4.5"DP f/2510'racking back in derrick. 01:30 07:30 6.00 7.50 DRILL E 4 P Single in hole w/4.5"DP to 5200'. 07:30 09:00 1.50 9.00 DRILL E 20 P Work on Drill-Link w/NOV/Schlumberger reps. 09:00 13:30 4.50 13.50 DRILL E 4 P POOH w/4.5"DP,rack back. 13:30 14:00 0.50 14.00 DRILL E 20 P Clean and clear rig floor.Prep.for cutting drlg.line. 14:00 16:00 2.00' 16.00 DRILL E 20 P Slip&cut ddg.line. 16:00 16:30 0.50 16.50 DRILL E 20 P Work on Drill-Link w/NOV/SLBJElecirician. 16:30 17:00 0.50 17.00 DRILL E 19 P Close blind rams and test casing to 1000 psi 1/15 min. 17:00 20:00 3.00 20.00 DRILL E 20 P R/U and change out saver sub. 20:00 21:30 1.50 21.50 DRILL E 20 P Change out hydraulic hose on Top-Drive. 21:30 22:00 0.50 22.00 DRILL E 20 P PJSM on picking up BHA. 22:00 00:00 2.00 24.00 DRILL E 20 P P/U 8 3/4"BHA as per SLB consisting of Bit,Xceed675,PeriScope675,TeleScope675,NM In-Line STB. Daily Contacts Position I Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross IENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcnt) 1,325.88 731.88 LSND 1102.4 20.7 1385.8 101.4 Eni E&P Division 'Well Name:SI29-S2 ii EN!Petroleum Co.Inc. Daily Repo),,}L Well Code:26210 Field Name:Nikaitchuq • API/UWI:50-629-23464-00-00 e^II Date:3/3/2012 - Report If: 28 I' II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 24.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POE Temperature(°C) Weather Wind 2,715.16 1,124.74 0.00 99.0 -36.7 Ptly Cloudy,WC-64° 211°SSW @17 mph Daily summary operation 24h Summary M/U BHA and RIH and tag Float collar @ 8802'.Log from 4325'-8800'with SonicVision at 900fpm.CBU Operation at 07.00 Drilling shoe track. 24h Forecast CBU and perform casing integrity test to 3000 psi for 30 min.Displace LSND mud with FazePro.Drill shoe track and 20'of new hole.Perform FIT/LOT.Drill ahead. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum • Time Time Dur(hr)•Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 20 P M/U BHA,SonicVision,ADNVision and RIH.M/U 6"Flex collar and STB and lay on skate. r 01:30 03:00 1.50 3.00 DRILL E 20 P PJSM.Load nuclear source with SLB. 03:00 03:30 0.50' 3.50 DRILL E 20 P M/U STB/Flex and jars and RIH. 03:30 04:30 1.00 4.50 DRILL E 12 P Check torque on HWDP,gauges,ng tongs,iron roughneck and Top-Drive as per K&M.Note:60k MU,35k Break out. 04:30 06:00 1.50 6.00 DRILL E 12 P Perform shallow hole test with SLB @ 260',350 gpm.390 psi.Send down link and collect data.Obtain 91k rotw as per K&M.Blow down Top-Drive. 06:00 06:30 0.50 6.50 DRILL E 20 P M/U XO to 4.5"DP and change elevators. I 06:30 10:00 3.50 10.00 DRILL E 4 -P RIH with 4.5"DP to 4325'filling every 20 stds. 10:00 11:00 1.00 11.00 DRILL E 12 P Fill pipe and test MWD tools. 11:00 21:00 10.00 21.00 DRILL E 4 P RIH @ 900 fph logging cement bond w/SonicVision to 8670'.150k puw,105 sow. 21:00 22:00 1.00' 22.00 DRILL E 20 U Mechanic work on leak on Top-Drive. 22:00 23:30 1.50 23.50 DRILL E 4 P Wash to top of float collar @ 8802'while logging. 23:30 00:00 0.50' 24.00 DRILL E 7 P Circulate bottoms up. Daily Contacts ` Position Contact Name Company Title E-mail Office - Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Matls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 .4.* Eni E&P Division I Well Name:SI29-S2 1 EN/Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 en11 Date:314/2012 - Report#: 29 'I " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 25.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 2,897.73 1,136.31 182.58 4.56 40.0 97.0 -36.4 Clear,WC-60° 216°SSW @ 17.3 mph Daily summary operation 24h Summary CBU and perform casing integrity test to 3000 psi for 30 min.Displace LSND mud with FazePro.Drill shoe track and 20'of new hole.Perform FIT/LOT.Drill ahead to 9507'. Operation at 07.00 Drig.ahead in production formation. 24h Forecast Drill ahead in production formation as per Geologist/Directional Driller. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 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 7 P Circ.bottoms up @ 400 gpm,1100 psi. 01:00 02:00 1.00 2.00 DRILL E 20 P PJSM,Blow down Top-Drve.R/U for casing test and purge lines. 02:00 03:30 1.50 3.50 DRILL E 12 P Pressure test 9 5/8"casing to 3000 psi for 30 min.charted.R/D and blow down test lines.PJSM for mud displacement with all involved. 03:30 05:30 2.00 5.50 DRILL E 7 P Displace LSND mud from well with 40 bbls LVT followed with 587 bbls 9.2 ppg FazePro @ 8 bpm,1175 psi. 05:30 07:30 2.00 7.50 DRILL E 20 P Blow down Top-Drive,clean mud pit surface equipment and transfer mud to the WIF. 07:30 11:00 3.50 11.00 DRILL E 3 P Obtain SPR @ 8800'MD(3685'ND),9.2ppg MW #1 @ 30 spm=210 psi,@ 40=300 #2 @ 30=210,@ 40=300 psi. Establish drilling parameters and drill shoe track f/8802'-8855',400 gpm,1560 psi,60-70 rpm,10-11k tq,185k puw,123k sow,140k rotw. 11:00 12:00 1.00 12.00 DRILL E 20 P Lubricate rig and mechanic check presures. 12:00 15:00 3.00 15.00 DRILL E 3 P Ddg.shoe track plus 20'of new hole f/8855'-8928',400 gpm,1590 psi,60-70 rpm,11-12 wob,11-12k tq, 155 puw,120k sow,135k rotw.CBU 15:00 15:30 0.50 15.50 DRILL E 19 P PJSM and perform FIT/LOT with 9.2 ppg MW,22 strokes,750 psi,Equiv.13.1 ppg FIT,2 bbl bleed back. 15:30 18:00 2.50 18.00 DRILL E 3 P Dug 1/8928'-9041'(3701'ND),444 gpm,1940 psi,80-120 rpm,12-15 wob,10-11k tq on,10-11k tq off,155k puw.120k sow,135k rotw,10.41 ECD,Max gas 400.SPR @ 8941'(3691'ND),9.2 MW #1 @ 30=260,@ 40=360 #2 @ 30=270,@ 40=360 #3 @ 30=260,@ 40=360 18:00 00:00 6.00 24.00 DRILL E 3 P Dig.f/9041'-9507'(3728'ND),500 gpm,2400 psi,125 rpm,15-18k wob,16k tq on,13-14k tq off,185k puw,105k sow, 135k rotw,10.83 ECD,Max gas 526,4.56 ADT,4.56 Bit,60.46 Jars.SPR @ 9321'(3711'ND)9.2 ppg MW #1 @ 30=310,@ 40=390 #2 @ 30=310,@ 40=400 #3 @ 30=320,@ 40=410 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI 'Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 I � Eni E&P Division I Well Name:SI29-S2 I f; ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 2^a Date:3/5/2012 - Report#: 30 " II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 26.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 3,206.50 1,146.50 308.76 10.66 29.0 95.0 -32.6 Clear,WC-47 312°NNW @ 8.1 mph Daily summary operation 24h Summary Pump OOH and P/U and RIH the rest of the 4.5"DP.Dig.ahead f/9507'to 10,520'. Operation at 07.00 Ddg.ahead in production hole. 24h Forecast Drill ahead in production hole f/10,520'.TD est.@ 19,505'. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan i Open Descr. 00:00 01:00 1.00 1.00 DRILL E 7 P Take MWD survey,SPR's and grease swivel packing.SPR @ 9507'(3728'TVD)9.2 ppg MW #1 @ 30=300,@ 40=380 #2 @ 30=300,@ 40=380 01:00 02:00 1.00 2.00 DRILL E 4 P BROOH to 9414'circulating 1.5 BU's,500 gpm,2260 psi,125 rpm. 02:00 05:00 3.00 5.00 DRILL E 4 -P Pump OOH 1/9414'-8292'to 4.5"DP,2.5 bpm,260 psi,178k puw. 05:00 05:30 0.50 5.50 DRILL E 20 P Blow down Top-Drive,break out XO and change elevators to 4.5". 05:30 07:30 2.00 7.50 DRILL E 4 P RIH to 9495'with 4.5"DP,fill pipe and establish parameters as per OD and KBM.125k puw,98k sow.Change elevators to 5".Wash to 9507'. 07:30 12:00 4.50 12.00 DRILL E 3 P Drlg.f/9507'-9774'(3738'TVD),550 gpm,2890 psi,130 rpm,16-17 wob,13-15k tq on,10-11k tq off,192k puw,92k sow, 133k rotw,10.70 ECD,Max gas 142,2.18 ADT,6.74 Bit,66.64 Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P DrIg.f/9774'-10.071(3741'TVD).550 gpm,2720 psi,80-130 rpm,17-20 wob,12-14k tq on,8-16k tq off,185k puw,95k sow.135k rotw,10.71 ECD,Max gas 141.SPR @ 10,054'(3741TVD),9.15 MW #1 @ 30=320,@ 40=420 #2 @ 30=310,@ 40=420 #3 @ 30=320,@ 40=420 18:00 00:00 6.00 24.00 DRILL E 3 P DrIg.f/10,071-10,520'(3760'TVD),550 gpm,2820 psi,100-120 rpm,8-10 k wob,14-16k tq on,11-12k tq off,190k puw, 95k sow,135k rotw,10.68 ECD,Max gas 1053,8.48 ADT.15.22 Bit,71.12 Jars. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Ross ENI 'Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907.685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Mails Coordinator 907.685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 V#1 Eni E&P Division 'Well Name:SI29-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • enInI Date:3/6/2012 - Report#: 31 APIIl1NA:50-629-23464-00-00 " II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 27.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,861.21 1,164.68 654.71 12.74 51.4 93.0 -33.5 Partly Cloudy,WC- 229°SSW @ 19.6 78. mph Daily summary operation 24h Summary Drill ahead rotary steerable as to formation(/10520'-1112668'. Operation at 07.00 Drilling ahead 8 3/4"production section as per well plan. 24h Forecast Continue drilling Geo-steering 8 3/4"production hole section as per well plan f/12668'to proposed TD @ 19505'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1096.4 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 3 P Drill rotary steerable(/10520'-1/10885'(3778'TVD).\Pump rate 550 gpm @ 2780 psi.\80/135 rpm @ 15-16K torque.\WOB 16-1810 Mud wt.=9.2 ppg\ECD 10.40 ppg.\Up wt.=212K-Dn wt.=86K-Rot wt.=142K.\ART=3.82hrs:ADT=19.04 hrs.\Jars=74.94 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable 1/10885'-1111455'(3787'TVD).\Pump rate 550 gpm @ 2860 psi.\135 rpm @ 15.16K torque.\WOB 8- 12K./Mud wt.=9.2 ppg\ECD 10.91 ppg.\Up wt.=206K-Dn wt=78K-Rot wt=140K.\ART=2.85 hrs.-ADT=21.89 hrs.\ Jars=77.79 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary steerable f/11455'-1112108'(3791'TVD).\Pump rate 548 gpm @ 2960 psi.\80-135 rpm @ 14-15K torque./WOB 6-12K./Mud wt.=9.2 ppg\ECD 10.96 ppg.\Up wt.=200K-Last Dn wt.=90K @ 11921'w/pumps-Rot wt.=140K.\ART= 3.25 hrs.-ADT=25.14 hrs.\Jars=81.04 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable(/12108'-1112668'(3821'TVD).\Pump rate 550 gpm @ 3030 psi.\135 rpm @ 16-18K torque.\WOB 8- 12K.\Mud wt.=9.2 ppg\ECD 11.05 ppg./Up wt.=205K-Dn wt.=N/A-Rot wt=141\ART=2.82 hrs:ADT=27.96 hrs./ Jam=83.86 hrs. Total ADT=27.96 hrs. Total Jar=83.86 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2.710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 Viol Eni E&P Division 'Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq e^n Date:3/7/2012 - Report#: 32 APIIl1Wl:50-629-23464-00-00 � 'f'I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5I29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 28.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 4,402.23 1,175.77 541.02 10.53 51.4 95.0 -31.7 Partly Cloudy.WC- 231°SSW @ 15 65' mph Daily summary operation 24h Summary Drill ahead rotary steerable as to formation Ill 2668.-1/13975.1 Circulate bottoms-up to clean hole up-monitor for loss-well bore occurring ballooning effect./Drill rotary steerable(/13975'-1/14443'.\Jet flow line,search drip pan POOH pumping 1/1444T-1/14165'looking for rubber hole cover and could not find-Decision to go back to bottom and drill ahead.\Ream f/14165'-1/14443'.1 Schlumberger down link to tool prior to drilling. Operation at 07.00 Drilling ahead 8 3/4"production section as per well plan. 24h Forecast • Drilling 8 3/4"production hole section 614443'to proposed TD @ 19505'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 • Time Log StagEnd Cum Time I Time Dur(hr) Dur(hr), Phase Opr. Act. Plan Oper.Diner. • 00:00 06:00 6.00 6.00 DRILL E 3 .P Drill rotary steerable f/12668'-613310'(3840'TVD).\Pump rate 550 gpm @ 3090 psi.\135 rpm @ 17-18K torque on bottom/13-14K off bottom.\WOB 8-12K.\Mud wt.=9.2 ppg\ECD 11.16 ppg.\Up wt.=210K-Dn wt.=N/A-Rot wt.=142K\ ART=2.46 hrs.-ADT=30.42 hrs.\Jars=86.32 hrs. . 06:00 -12:00 ' 6.00 12.00 DRILL 'E 3 P Drill rotary steerable f/13310'-613975'(3873'TVD).\Pump rate 550 gpm @ 3100 psi.\135 rpm @ 17-18K torque on bottom/12-15K off bottom.\WOB 8-12K.\Mud wt=9.2 ppg\ECD 10.94 ppg.\Up wt.=210K-Dn wt=N/A-Rot wt.= 142K.\ART=2.77 hrs:ADT=33.19 hrs.\Jam=89.09 hrs.\Well bore started ballooning around 0730 hrs.after drilling fault early @13170'. 12:00 '14:00 2.00 14.00'DRILL E -7 P Monitor well and observed the hole was flowing on the connection @13,975.\Circulate bosoms-up to clean up the hole- while circulating hole was taking mud,shut pumps down and gained all the mud back.With hole clean,mud weight drop f/9.2-119.1 ppg and ECD went down from 11.2 to 10.8.1 BU gas went from 1000 units to 400 units.\Determined hole was ballooning and lost were accruing. 14:00 18:00 4.00 18.00 DRILL E 3 P Drill rotary steerable(/13975'-V14069'(3871'TVD).\Pump rate 550 gpm @ 3100 psi.\60-135 rpm @ 17-18K torque on • bottom/12-15K off bottom.\WOB 8.20K.\Mud wt.=9.2 ppg\ECD 10.95 ppg.\Up wt=205K-Rot wt=148K./ART=2.93 hrs.-ADT=36.12 hrs.\Jars=92.02 hrs.\Monitor ballooning effect of well bore and track loses. • • 18:00 22:00 4.00 22.00 DRILL E -3 P Drill rotary steerable f/14069'-1/14443'(3857'TVD).\Pump rate 520 gpm @ 3050 psi.\135 rpm @ 17-18K torque on bottom/12-15K off bottom.\WOB 8-12K.\Mud wt.=9.2 ppg\ECD 11.01 ppg.\Up wt.=200K-Dn wt.=N/A-Rot wt.=145\ ART=2.37 hrs.-ADT=38.49 hrs.\Jars=94.39 hrs.\Continue monitor ballooning effect and loses decreased to none. • Total ADT=38.49 hrs. Total Jar=94.39 hrs. 22:00 '23:30 1.50 23.50 DRILL E 7 XS03 After drilling stand down V14,443'found 3'x 3'x 1/2"rubber hole cover was missing-inspected drip pan and jetted flow line with luck.\Pump out hole f/14443'-1/14165'looking for rubber-drain stack and could not see rubber hole in BOP stack,also removed flow sensor and inspect flow line no luck./Wash/ream f/14145'-1/14443'pumping 400 gpm @ 1800 psi.\135 rpm @ 15K torque.\Up wt.=200K-Rot wt.=155.1 Decision to go back to bottom and drill ahead. • 23:30 '00:00 0.50 24.00 DRILL E 7 P Circulating-Schlumberger down link to tools off bottoms prior to resuming drilling operation./Continue monitor/record for • mud loses-Total loss for day 90 bbls. Daily Contacts I Position ' Contact Name Company .1 Title E-mall Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 • Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2.710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 I • II $0•701 Eni E&P Division I Well Name:SI29-S2 EN!Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq •2^n Date:3/8/2012 - Report#: 33 aI APlluwb sas29 23464-oaoo II 'I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information - Contractor Rig Name Rig Type -- DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 29.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(SC) Weather Wind 4,867.35 1,184.60 465.12 12.98 35.8 96.0 -34.5 Clear,WC-39° 225°SSW @ 5.5 mph Daily summary operation 24h Summary Drill ahead rotary steerable as to formation(/14443'-1/15969'.\Continued monitor of fluid loss-last 24 hrs.=165 bbls.\Total fluid loss to well bore 255 bbls.\Also ballooning effects still occurring while drilling. Operation at 07.00 Drilling ahead 8 3/4"hole section as per well plan. 24h Forecast Drilling 8 3/4"hole section(/15969'to proposed TD @ 19505'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deur. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill rotary steerable f/14443'-t/14911'(3873'TVD).\Pump rate 532 gpm @ 3000 psi.\60-135 rpm @ 17-21 K torque on bottom/11-15K off bottom.\WOB 8-16K.\Mud wt.=9.2 ppg\ECD 11.09 ppg.\Up wt.=212K-Dn wt.=N/A-Rot wt.=142\ ART=3.14 hrs.-ADT=41.63 hrs.\Jars=97.53 hrs.\Wellbore still has a ballooning effects,monitor for loses and ECD. 06:00 12:00 ' 6.00 12.00 DRILL E 3 P Drill rotary steerable(/14911'-1/15258'(3876'TVD).\Pump rate 532 gpm @ 3010 psi.\60-135 rpm @ 17-20K torque on bottom/13-16K off bottom.\WOB 10-16K.\Mud wt.=9.2 ppg\ECD 11.17 ppg.\Up w4.=222K-Dn wt.=N/A-Rot wt.= 143K.\ART=2.89 hrs.-ADT=44.52 hrs.\Jars=100.42 hrs.\Loss for 12 hrs.85 bbls.to wellbore. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary steerable 1/15258'-815658'(3889'ND).\Pump rate 530 gpm @ 3050 psi.\80-135 rpm @ 19-20K torque on bottom/14-16K off bottom.\WOB 8-20K.\Mud wt.=9.2 ppg\ECD 11.21 ppg.\Up wt.=215K-Dn wt.=N/A-Rot wt= 146K.\ART=3.27 hrs.-ADT=47.79 hrs.\Jars=103.69 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable f/15658'-t/15969'(3891'TVD).\Pump rate 522 gpm @ 2990 psi.\80-135 rpm @ 18-19K torque on bottom/16K off boffom.\WOB 10-12K.\Mud wt.=9.2 ppg\ECD 11.15 ppg.\Up wt.=215K-Dn wt.=N/A-Rot wt.=145\ ART=3.68 hrs.-ADT=51.47 hrs.\Jars=107.37 hrs.\Loss for 12 hrs.80 bbls.to wellbore-Total lose for the day 165 bbls.\Slight ballooning effects still occurring while drilling. Total ADT=51.47 hrs. Total Jar=107.37 hrs. Daily Contacts Position _ Contact Name Company Title Email Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher ngis@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.poffer@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 I EEni E&P Division 'Well Name:SI29-S2 j�J ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • API/UWI:50-629-23464-00-00 en a Date:3/9/2012 - Report#: 34 i) II Wellbore name: SI29-S2 • page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 30.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,369.05 1,174.97 501.70 11.73 42.8 94.0 -38.0 Clear,WC-58.4 239°SSW @ 8.1 mph Daily summary operation 24h Summary Drill ahead rotary steerable lateral section(/15969'-5/17432'(survey indicated 8.7°dog leg-contact town and back ream).\Back ream f/17432'-1/17245'and ream/wash(/17245'-5/17432'reduce dog leg to 7.46°-(ECD dropped 611.42 ppg-5/11.35 ppg)\Drill rotary steerable f/17432'-1/17615'.1 Continued monitor of fluid loss-last 24 hrs.=156 bbls.\Total fluid loss to well bore 411 bbls./Ballooning effects still occurring in wellbore. Operation at 07.00 Drilling ahead 8 3/4"lateral hole section. 24h Forecast Drilling 8 3/4"lateral section f/17615'to proposed TD @ 19505'. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 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 3 P Drill rotary steerable f/15969'-V16423'(3889'TVD).\Pump rate 530 gpm @ 3080 psi./135 rpm @ 20-23K torque on bottom/13-17K off bottom.\WOB 8-12K.\Mud wt=9.2 ppg\ECD 11.10 ppg.\Up wt.=226K-Dn wt.=N/A-Rot wt.=142\ ART=2.51 hrs.-ADT=53.98 hrs.\Jars=109.88 hrs. 06:00 12:00 ' 6.00 12.00 DRILL E 3 P Drill rotary steerable f/16423'-V16805'(3878'TVD).\Pump rate 532 gpm @ 3150 psi.\60-135 rpm @ 20-25K torque on bottom/15-16K off bottom.\WOB 10-16K.\Mud wt.=9.2 ppg\ECD 11.12 ppg.\Up wt.=222K-Rot wt.=141K-Dn wt.= N/A.\ART=4.22 hrs.-ADT=58.20 hrs.\Jars=114.10 hrs.\Loss for 12 hrs.90 bbls.to wellbore. 12:00 18:00 ' 6.00 18.00 DRILL E 3 P Drill rotary steerable f/16805'-1/17245'(3862'TVD).\Pump rate 530 gpm @ 3200 psi.\135 rpm @ 20-22K torque on bottom/14-15K off bottom.\WOB 10-12K.\Mud wt=9.2 ppg\ECD 11.21 ppg.\Up wt.=235K-Rot wt=142K-Dn wt.= N/A.\ART=2.86 hrs:ADT=61.06 hrs.\Jars=116.96 hrs. 18:00 20:00 2.00 20.00 DRILL E 3 P Drill rotary steerable f/17245'-V17432'(3860'ND).\Pump rate 530 gym @ 3200 psi.\135 rpm @ 20K torque on bottom/ 18K off bottom.\WOB 10-15K.\Mud wt.=9.2 ppg\ECD 11.42 ppg.\Up wt.=240K-Rot wt=140K-Dn wt.=N/A./ART= 1.03 hrs.-ADT=62.09 hrs.\Jars=117.99 hrs.\Survey indicated a 8.7°dog leg @ 17432'and was reconfirmed by second survey. 20:00 22:00 2.00 22.00 DRILL E 6 P Back ream 5/17432'-5/17245'to wipe out dog leg-pumping 530 gpm @ 3200 psi./135 rpm @ 20K torque.\RIH washing down f/17245'-1/17432'-reduce pump rate to 375 gpm @ 1800 psi.\135 rpm @ 20K torque./ECD dropped(/11.42 ppg to 11.35 ppg.\Resurvey reduced dog leg to 7.46`,note will ream out section on trip out. 22:00 00:00 ' 2.00 24.00-DRILL E 3 P Drill rotary steerable f/17432'-V17615'(3852'TVD).\Pump rate 530 gpm @ 3250 psi.\135 rpm @ 20K torque on bottom/ 16K off bottom./WOE 10-15K.\Mud wt.=9.2 ppg\ECD 11.48 ppg.\Up wt.=245K-Rot wt.=145K-Dn wt.=N/A.\ART= 1.11 hrs.-ADT=63.20 hrs.\Jars=119.10 hrs.\Loss for 12 hrs.66 bbls.to wellbore-Total loss for the day 156 bbls.\Slight ballooning effects. Total ADT=63.20 hrs. Total Jar=119.10 hrs. Daily Contacts Position Contact Name Company 1Title °I E-mail Office Mobile Eni representative -Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher ng75@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 liffass.iiis Eni E&P Division I Well Name:S129-S2 EN/Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • 2^n Date:3110/2012 - Report#: 35 APIIUWI:50-629-23464-00-00 " "'I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0129-52 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 31.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 5,758.59 1,168.73 389.53 12.65 30.8 94.0 -27.6 Cloudy,Blowing 229°SSW@ 23 Snow,WC-67.7 mph Daily summary operation 24h Summary Drill rotary steerable lateral section 517615'-U18893'.\Ballooning effects still occurring in well bore and monitoring of fluid loss-last 24 hrs.=341 bbls.\Total fluid loss to well bore 752 bbls. Operation at 07.00 Drilling 8 3/4"lateral hole section per geological formation. 24h Forecast Drilling 8 3/4"lateral section 518,898'to proposed TD @ 19460'.1 Circulate bottoms-up 10X and clean per K&M parameters-(rack back one stand for 4X CBU&two stands for 6x CBU)-SLM out.\POOH back ream per K&M time parameters,continue SLM. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill rotary steerable f/17615'-518086'(3857'TVD).\Pump rate 531 gpm @ 3290 psi.\135 rpm @ 20-22K torque on bottom/18-20K off bottom.\WOB 6-12K.\Mud wt=9.2 ppg\ECD 11.41 ppg.\Up wt.=222K-Rot wt.=143K-Dn wt.= N/A.\ART=2.28 hrs.-ADT=65.48 hrs.\Jars=121.38 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable f/18086'-518273'(3849'TVD).\Pump rate 530 gpm @ 3310 psi.\80-135 rpm @ 20-22K torque on bottom/15-16K off bottom.\WOB 10-16K.\Mud wt.=9.2 ppg\ECD 11.30 ppg.\Up wt.=216K-Rot wt.=144K-Dn wt.= N/A.\ART=3.41 hrs.-ADT=68.89 hrs.\Jars=124.79 hrs.\Loss for 12 hrs.220 bbls.to well bore. 12:00 18:00 6.00 18.00 DRILL E 3 'P Drill rotary steerable f/18273'-518614'(3828'TVD).\Pump rate 530 gpm @ 3250 psi.\70-135 rpm @ 21-25K torque on bottom/19-20K off bottom.\WOB 10-20K.\Mud wt.=9.2 ppg\ECD 11.42 ppg.\Up wt.=220K-Rot wt=145K-Dn wt.= N/A.\ART=3.79 hrs.-ADT=72.68 hrs.\Jars=128.58 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable(/18614'-1/18893'(3837'TVD).\Pump rate 530 gpm @ 3300 psi.\70-135 rpm @ 20-27K torque on bottom/16-17K off bottom.\WOO 10-20K.\Mud wt.=9.2 ppg\ECD 11.31 ppg.\Up wt.=240K-Rot wt=142K-Dn wt.= N/A.\ART=3.17 hrs.-ADT=75.85 hrs.\Jars=131.75 hrs.\Schlumberger computers crashed on surface-circulated and reboot @ 1830 hrs.\Loss for 12 hrs.121 bbls.to well bore-Total lose for the day 341 bbls. Total ADT=75.85 hrs. Total Jar=131.75 hrs. Daily Contacts Position Contact Name Company Tide E-mail 1Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com -907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Dolling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilting.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2.710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) •P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 Vol Eni E&P Division (Well Name:S129-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUIM:50-629-23464-00-00 e^o Date:3/11/2012 - Report#: 36 I' II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI29-02 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 32.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 174.04 5.30 32.8 93.0 -21.6 Partly Cloudy.WC-1 326°NNW @ 3 mph Daily summary operation 24h Summary Drill rotary steerable f/18893'-V19464'TD lateral section.\Circulate bottoms-up per K&M guidelines f/19464'-1/18461'(rack one stand for 4 CBU and two stands for 4 CBU-Total 8X bottoms-up.\SLM pipe.)Last 24 hrs.=259 bbls.\Total fluid lost to wellbore 1011 bbls. Operation at 07.00 POOH back ream to K&M parameters-hole condition dictate speed. 24h Forecast Circulate bottoms-up 2X more or until clean per K&M parameters f/18461'-(rack back two stand each CBU).\POOH back ream per K&M parameters V4500',continue SLM.\POOH on elevators and L/D BHA#6. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 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 3 P Drill rotary steerable f/18893'-V19205'(3835'TVD).\Pump rate 530 gpm @ 3280 psi.\60-135 rpm @ 24-27K torque on bottom/15-18K of bottom.\WOB 6-19K.\Mud wt.=9.2 ppg\ECD 11.41 ppg.\Up wt.=250K-Rot wt.=148K-Dn wt.= N/A.\ART=3.09 hrs.-ADT=78.94 hrs.\Jars=134.84 hrs. 06:00 '11:00 5.00 11.00 DRILL E 3 P Drill rotary steerable f/19205'-1/19464'(3834'TVD).\Pump rate 530 gpm @ 3300 psi.\135 rpm @ 20-22K torque on bottom/16-18K off bottom.\WOB 6-10K.\Mud wt.=9.2 ppg\ECD 11.43 ppg.\Up wt=250K-Rot wt.=143K-Dn wt.= N/A.\ART=2.21 hrs.-ADT=81.15 hrs.\Jars=137.05 hrs. Total ADT=81.15 hrs. Total Jar=137.05 hrs. 11:00 12:30 1.50 12.50 DRILL 'E 7 P Circulate bosoms-up as per K&M guide lines 1/19464-V19395'(Obtain&record drag data and Schlumberger final survey of bottom).\Pumping 530 gpm @ 3300 psi.\135 rpm @ 20-21 K torque.\ROT wt.=142K. 12:30 .13:00 0.50 13.00 DRILL E 6 P Ream back to bottom f/19395'-1/19464'with pump rate 320 gpm @ 1820 psi.\135 rpm @ 20-21K torque.\reshoot survey and obtain SPR for all mud pumps. 13:00 00:00 11.00 24.00 DRILL E 7 P Circulate bottoms-up per K&M guide lines f/19464'=1/18461'-pump rate 530 gpm @ 3150 psi.\135 rpm @ 21K torque.\Rot wt.=142K.\First four CBU rack back one stand and remaining rack back two stands back on CBU-Total 8X.\Loss for 11 hrs.134 bbls.to wellbore.Total lose for the day 259 bbls.\SLM pipe. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv 'SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Matls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 vot Eni E&P Division I Well Name:SI29-S2 EN!Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • Date:3/12/2012 - Report#: 37 APIIUWI:50-629-23464-00-00 2" " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 33.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 91.0 -31.5 Partly Cloudy,WC- 26°NNE @ 16.1 66.7 mph Daily summary operation 24h Summary Circulate bottoms-up per K&M guide lines 1/18461'-1118275'(rack two stands for each CBU-Total 10X CBU from TD @ 19464'.\POOH back reaming 1/18275'-1111271'per K&M parameters with 18'-20' per mins.\SLM pipe.\Last 24 hrs.losses=170 bbls.\Total fluid lost to well bore 1181 bbls. Operation at 07.00 POOH back ream to K&M parameters. 24h Forecast POOH back ream per K&M parameters to'1/-4500'\Continue POOH on elevators.\L/D BHA#6 as per Schlumberger./Vetco pull wear bushing.\Test BOPE to AOGCC requirements(Notified @ 1730 hrs. -left recorded message).\Vetco set wear bushing.\P/U BHA#7. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) _ __ _ _ 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 7 P Circulate bottoms-up per K&M guide lines 1/18461'-1118275'-pump rate 530 gpm @ 3050 psi./135 rpm @ 19K torque.\Rot wt.=140K.\Rack back two stands each CBU-Total 10X.\MW=9.2 ppg./ECD 11.36 ppg.\SLM pipe. 03:30 12:00 8.50 12.00 DRILL E 4 P 'POOH back reaming(/18275'-1116217'per K&M parameters start @ 8-10'per min.Hole condition dictated pulling speed- increasing to 15-18'per min.\Pump rate 530 gpm @ 3000 psi./135 rpm @ 18K torque./Rot wt.=139K.\MW=9.2 ppg.\ ECD 11.23 ppg.\SLM pipe./Loss for 12 hrs.88 bbls.to well bore. 12:00 18:00 6.00 18.00 DRILL E 4 P POOH back reaming 1/16217'-1114200 to K&M parameters-hole condition dictated pulling speed-increasing to 18'per min.\Circulate 530 gpm @ 2950 psi.\135 rpm @ 20K torque.\Rot wt.=140K.\MW=9.2 ppg.\ECD 10.89 ppg.\SLM pipe. 18:00 00:00 6.00 24.00 DRILL E 4 P POOH back reaming(/14200'-1111271'to K&M hole cleaning parameters and hole condition @ 18-20'per mins.\Circulate 530 gpm @ 2650 psi.\135 rpm @ 14K torque./Rot wt.=136K.\MW=9.2 ppg.\ECD 10.51 ppg.\SLM pipe./Loss for 12 hrs. 82 bbls.to well bore. Daily Contacts Position Contact Name Company Tido Email Office Mobile Eni representative Jack Keener ENI -Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Matte Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 9.46' 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 Viiiiil Eni E&P Division 'Well Name:S129-S2 I ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq � APIIUWI:50-629-23464-00-00 enil Date:3/13/2012 - Report#: 38 I' II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) •Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 34.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 93.0 -35.0 Clear,WC-70° 6°N @ 13.8 mph Daily summary operation 24h Summary POOH back reaming f/11271'-119495'.\Change saver sub,monitor well-static.\Continue POOH back reaming 1/9495'-114500'1 Slip&cut drilling line.\Service rig.\Pump dry slug.\POOH on elevators (/4500'-1/1373'monitor for swabbing./Last 24 hrs.losses=102 bbls.\Total fluid lost to wellbore 1283 bbls. Operation at 07.00 R/U for BOPE test. 24h Forecast Continue POOH on elevators f/1373-5/265'.\PJSM w/Schlumberger-L/D BHA#6\Vetco pull wear bushing.\Test BOPE to AOGCC requirements(Lou Grimaldi with AOGCC-contacted @ 0900 hrs.& 1500 hrs.-need 2 hrs notice before test)./Vetco set wear bushing.\P/U BHA#7(dumb iron).\RIH to 19464'TD to displace./Mix and displace lateral section with FazeWay breaker./POOH to K&M parameters. Lithology Shows MAASP(kgflcma) Mud Weight(gIL) 1102.4 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 4 P POOH back reaming 1/11271'-119495'10 K&M parameters and hole condition @ 18-20'per mins./Circulate 530 gpm @ 2460 psi./135 rpm @ 11-12K torque./Rot wt.=132K./MW=9.2 ppg.\ECD 10.33 ppg.\SLM pipe. 06:00 08:30 2.50 8.50 DRILL E 5 P PJSM-blow down TD and change elevators\Change out saver sub on Top Drive f/TT525 U 4 1/2"NC 46(XO).\Monitor well on trip tank-static. 08:30 12:00 3.50' 12.00 DRILL E 4 P 'POOH back reaming(/9495'-5/8661'per K&M parameters.\Pump rate 530 gpm @ 2370 psi.\135 rpm @ 10K torque.\Rot wt.=132K.\MW=9.2 ppg.\ECD 10.20 ppg.\SLM pipe.\Loss for 12 hrs.80 bbls.to wellbore. 12:00 '18:30 6.50 18.50 DRILL E 4 •P POOH back reaming f/8661'-1/4500'@ K&M parameters./Circulate 530 gpm @ 1890 psi./135 rpm @ 10K torque./Rot wt.=128K.\MW=9.2 ppg.\ECD 10.17 ppg./SLM pipe. 18:30 20:00 1.50' 20.00 DRILL E 25 'P Blow down TD.\PJSM.\Slip&cut drilling line./Inspect brake linkage. 20:00 21:00 1.00' 21.00 DRILL E 25 'P Service rig components. 21:00 21:30 0.50 21.50 DRILL E 7 P Pump slug and blow down TDA P/U Schlumberger source box to floor. 21:30 00:00 2.50 24.00 DRILL E 4 -P 'POOH 1/4500'.5/1373'@ K&M parameters 3 1/2 min/std.while monitoring for swabbing-increased rate @ 3679'/Up wt.= 100K.\MW=9.2 ppg.\SLM pipe./Loss for 12 hrs.22 bbls.to wellbore. Daily Contacts Position Contact Name Company Title E-mail Office Mobile ° Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Matls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcma) Eq.Mud Weight(gIL) P LeakOff(kgflcma) 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 lifigis Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • Date:311412012 - Report#: 39 API/UWI:50-629-23464-00-00 e" " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 35.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(n5hr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 100.0 -34.5 Clear,WC-55.1° 10°N @ 9.2 mph Daily summary operation 24h Summary Continue POOH on elevators f/1373-5265'./PJSM wl Schlumberger-L/D BHA#61 Vetco pull wear bushing.\Test BOPE to AOGCC requirements(Lou Grimaldi with AOGCC-contacted @ 0900 hrs.) Waived witness.\Vetco set wear bushing.\P/U BHA#7(dumb iron). Operation at 07.00 RIH with Hole Opener 24h Forecast RIH with dumb iron to displace well to Faze Breaker. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deem 00:00 01:00 1.00 1.00 DRILL E 4 P POOH f/1373'-265'on elevators. 01:00 01:30 0.50 1.50 DRILL E 19 P Observe well.Change elevators to 5". 01:30 02:30 1.00 2.50 DRILL E 20 P Blow down Top-Drive,stand back jar stand and hold PJSM for unloading Nuclear source. 02:30 03:30 1.00 3.50 DRILL E 20 P Unload nuclear source from BHA as per SLB MWD. 03:30 05:30 2.00 5.50 DRILL E 4 P UD BHA and take photos. 05:30 07:00 1.50 7.00 DRILL E 20 P Clear and clean floor area.Pump stack out. 07:00 08:00 1.00 8.00 DRILL E 20 P P/U and M/U test jt.Pull wear bushing and install test plug. 08:00 09:30 1.50 9.50 DRILL E 20 P R/U to test BOPE.Clear OBM from surface equipment and fill stack and choke with water. 09:30 19:30 10.00 19.50 DRILL E 12 P Test BOPE with 4.5"and 5"test joints to 250/2500 psi on Annular,250/3500 psi for all other components.Koomey draw down-41 sec on 200 psi buildup,191 sec on full system pressure.5-bofles avg.2300 psi.Check chokes,manifold and Poor boy.Chokes tested to 1500 psi. 19:30 20:30 1.00 20.50 DRILL E 20 P Blow down&R/D testing equipment. 20:30 22:00 1.50 22.00 DRILL E 20 P Change saver sub from NC46 to TT525. 22:00 23:00 1.00 23.00 DRILL E 20 'P Service Rig. 23:00 23:30 0.50 23.50 DRILL E 20 P Pull test plug and install wear bushing. 23:30 00:00 0.50 24.00 DRILL A 20 P PJSM on P/U 8 M/U BHA#7. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2.710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 2.710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 Volt Eni E&P Division 'Well Name:S129-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 2 �)^n Date:3/15/2012 - Report#: 40 II �' page 1 of 1 Wellbore name: S129-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0129-S2 DRILLING 2/6/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 36.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 98.0 -36.4 Clear,WC-70.4° 31°NNE @ 12.7 mph Daily summary operation 24h Summary RIH with hole opener to 19,460'.Circ.and weight up from 9.2 to 9.4 ppg @ 200 gpm. Operation at 07.00 Spotting Fazeaway breaker fluid. 24h Forecast Spot 9.5 pg Fazeaway breaker and POOH to 8700'.9 5/8"Csg Shoe @ 8892'. Displace with 9.1 ppg KCL brine.POOH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act Plan Oper.Defier. 00:00 02:00 2.00 2.00 DRILL E 4 P M/U hole opener BHA and fill.Obtain K&M parameters,81k rotw,25 prm,2k tq,200 gpm,90 psi.B/D T/D. 02:00 16:30 14.50 16.50 DRILL E 4 P RIH with hole opener on 4.5"and 5"DP to 16,803'. 16:30 20:30 4.00 20.50 DRILL E 4 P RIH from/16,803'-19,459'rotating @ 20-25 rpm.16-17k tq,143k rotw,220k puw, 122k sow.Total fluid losses for the day =14 bbls. 20:30 00:00 3.50 24.00 DRILL E 7 P Circ.and weight up mud system from 9.2 to 9.4 ppg.@ 200 gpm,680 psi. Daily Contacts Position I Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv -SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Tool Push Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Em representative Francis Bowe ENI Mails Coordinator 907-685-0718 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 l� Eni E&P Division I Well Name:SI29-S2 EN!Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq • Date:3/16/2012 - Report#: 41 APIIUWI:50-629-23464-00-00 2 rr rr ii page 1 of 1 Wellbore name: SI29-S2 Well Header • Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 37.33 Daily Information End Depth(mKB) •End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 96.0 -43.9 Clear,WC-75.2° 233°SSE @ 7 mph Daily summary operation 24h Summary Spot 9.5 pg Fazeaway breaker and POOH to 14,512'. Operation at 07.00 POOH 24h Forecast POOH and UD BHA. Lithology Shows MAASP(kgflcrn) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dascr. 00:00 05:30 ' 5.50 5.50 DRILL E 7 P Circ.and bring MW up to 9.4 ppg. 05:30 09:30 4.00 9.50 DRILL E 7 P PJSM Displace 9.4 ppg OBM with 800 bbls of 9.5 ppg FazeAway breaker+109 bbls FazePro+15 bbls 10.7 ppg slug @ 200 gpm,640 psi,220k puw,138k rotw,25 rpm,15k tq. 09:30 12:00 2.50 12.00 DRILL E 4 P POOH f/19,460'-19,045'.Tour fluid losses @ 21 bbls. 12:00 18:00 - 6.00 18.00 DRILL E '4 P POOH(/19,045'-17,005'at 12 min/std as per K&M. 18:00 00:00 6.00 24.00 DRILL E 4 P POOH f/17,005'-14,512'@ 9 min/std.Tour fluid losses @ 127 bbls. Daily Contacts Position Contact Name Company Title E-mail Office I, Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 °715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907.685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigCterksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Torn Klein ENI Mails Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 9.46 2,710.43 2/27/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 Eni E&P Division I Well Name:SI29-S2 f; ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikadchuq � APIIUWI:50-629-23464-00-00 2 II^• Date:3/17/2012 - Report#: 42 '� II n page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 38.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 96.0 -41.1 Clear,WC-63° 218°SSW @ 6 mph Daily summary operation 24h Summary POOH and UD BHA.R/U to run 4.5"liner. Operation at 07.00 M/U and run 4.5"liner. 24h Forecast M/U and run 10,800'of 4.5"liner to 19,424'on 5"DP and set Baker hanger. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start ' End Cum Time Time Due(hr)_Dur(hr) Phase Opr. Act Plan . Oper.Dance. 00:00 .10:30 10.50 10.50 DRILL E 4 P POOH f/14,512'-8635'@ 6 min/std.Total losses for tour=85 bbls. 10:30 15:00 4.50 15.00 DRILL E 7 P PJSM,Displace well as per MI,circ.OBM mud @ 5 bpm,flush mud pumps w/LVT and citric acid.Displace with 9.2 ppg brine @ 7 bpm,420 psi,rotate and reciprocate 80 rpm,10k tq. 15:00 -15:30 0.50 15.50 DRILL 'E 19 P Monitor well.Blow down Top-Drive. 15:30 20:00 4.50 20.00 DRILL E 4 P POOH f/8635'-BHA 20:00 21:30 1.50 21.50 DRILL E 4 P L/D BHA 21:30 22:00 0.50 22.00 DRILL E 20 P Clear and clean rig floor. 22:00 23:30 1.50' 23.50 DRILL 'E 20 P R/U to run 4.5"liner. 23:30 00:00 0.50 24.00 DRILL E 20 P PJSM for running 4.5"liner.M/U silver bullet to jt#1.Total losses for tour=34 bbls. Daily Contacts Position Contact Name Company I Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Alec Dunlop Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Tool Push Alec Dunlop Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L80 2,617.35 5,920.44 3/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm) 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 litos Eni E&P Division I Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Report Well Code:26210 Field Name:Nikaitchuq � e(l 11 n Date:311812012 - Report#: 43 APIIUWI:50-629-23464-00-00 (� iii page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 39.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 96.0 -36.1 Clear,WC-49° 180°S @ 5mph Daily summary operation 24h Summary Run 4.5"11.69 L-80 Hydril 521 liner to 14,533'. Operation at 07.00 POOH LDDP. 24h Forecast Run and set 4.5"liner @ 19,424'.POOH LDDP. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan _ Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 4 P PJSM,P/U&M/U 4.5"11.69 L-80 Hydril 521 liner to 5496'.Fluid loss for tour=48 bbls. 12:00 21:30 9.50 21.50 DRILL E 4 P -P/U&M/U 4.5"liner f/5496'-10,754',take K&M readings 112k rotw,6k tq,104k sow.P/U&M/U Baker liner hanger/packer SLZXP.Mix and pour pal mix in tieback sleeve.Wad 30 min.for setup. 21:30 00:00 2.50 24.00 DRILL E 4 -P M/U XO to hanger assy.and P/U std of 5"DP,fill and perform 118k rotw,@ 30 rpm,7.5k tq.RIH wi 5"DP f/10,754'- 14,533'. Daily Contacts Position Contact Name Company Title E-mail Office 1 Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 '715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Chad Johnson Doyon Drilling Tour Pusher mike.seward@enipetroleum.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Alec Dunlop Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Data LINER 41/2 3.960 L80 2,617.35 5,920.44 3/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 foil Eni E&P Division I Well Name:SI29-S2 J ENI Petroleum Co.Inc. Daily ReportWell Code:26210 Field Name:Nikaitchuq • APIIUWI:50-629-23464-00-00 2^n Date:3/19/2012 - Report#: 44 II II�I page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S129-S2 DRILLING 2/8/2012 5,945.12 1,176.69 5,914.34 172.37 34.3 40.33 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,932.63 1,168.54 0.00 96.0 -37.8 Clear,WC-57° 183°S@ 7 mph Daily summary operation 24h Summary Run 4.5"liner and set as per program.POOH LDDP. Operation at 07.00 R/U to run 4.5"completion string. - _ 24h Forecast Finish LDDP.R/U and run 4.5"completion tubing. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 Time Log Start End • Cum • . Time Time Dur(hr) Dur(hr) Phase Opr. Aet. _ Plan Oper.Deser. 00:00 02:00 2.00' 2.00 DRILL E 4 P RIH with 4.5"liner on 5"DP f/14,533'-16,868'.72-80k sow. 02:00 06:00 4.00' 6.00 DRILL E 4 P Est.parameters @ 30 rpm,140k rotw,14k tq.Rotate liner in hole f/16,868'-19,390'.Break circ.@ 2.5 bpm,270 psi,and wash down to 19,464'TD. 06:00 06:30 0.50 6.50 DRILL E 19 'P 240kpuw to spot TO Liner @8638'. 06:30 08:30 2.00 8.50 DRILL E 19 P Pressure test lines to 4200 psi,Drop Baker 1.625"composite ball and pump @ 2.5 bpm,180 psi.Seat ball and pressure up to 3000 psi and shear packer.Hold pressure for 5 min and pressure up to 4000 psi for 5 min.Packer set. 08:30 09:00 0.50. 9.00 DRILL E 12 P R/U and test packer to 1500 psi via pumping down annulus.Charted. 09:00 09:30 0.50 9.50 DRILL 'E 19' P Check packer release as per Baker.P/U 180k 6-8'and 8/0 130k set down 50k.Repeat 2X and rotate @ 20 rpm,12k tq. Good release.Pull up above liner top to 8600'. 09:30 10:00 0.50 10.00 DRILL E 20 P Blow Down testing equipment. 10:00 18:30 8.50 18.50 DRILL E 4 P Monitor well-static.PJSM R/U and POOH LDDP f/8600'-surface.UD Baker running tool. 18:30 19:30 1.00 19.50 DRILL E 20 'P R/D 5"equipment,clean floor and R/U 4.5"equipment and install mousehole. 19:30 00:00 ' 4.50 24.00 DRILL E 4 'I, UD 219 jts.4.5"DP in mouse hole.Tour fluid losses of 42 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Chad Johnson Doyon Drilling Tour Pusher mike.seward@enipetroleum.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Tool Push Alec Dunlop Doyon Dolling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Eni representative Francis Bowe ENI Malls Coordinator 907-685-0718 • Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L80 2,617.35 5,920.44'3/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/em') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 • • I'll tr...0.41 Eni E&P Division I Well Name: SI29-S2 ENI Petroleum Co.Inc. Daily Report l Well Code:26210 Field Name: Nikaitchuq • 2^ Date:3/20/2012 - Report#: 1 API/UWI:50 629-23464-00-00 II II page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 COMPLETION 5,945.12 1,176.69 41.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 -37.2 Clear,WC-52 180`S @ 5 mph Daily summary operation 24h Summary LDDP and R/U and run completion 4.5"tubing. Operation at 07.00 Set Packer 24h Forecast Run 4.5"completion tubing.land.set packer.N/D stack E.N/U tree and test.Freeze protect well and change out valve in GLM.Release rig. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 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 E 4 P L/D 4.5"DP-69 jts. 02:00 03.00 1.00 3.00 COMP E 20 P L/D mouse hole and clean floor. 03:00 0330 0.50 3.50 COMP E 20 P PJSM pull wear bushing. 03.30 04.30 1.00 4.50 COMP K 20 P Lubricate and inspect rig. 04:30 06:00 1.50 r 6.00 COMP K 20 IP Mobilize completion tools and equipment to rig floor. 06:00 08.00 2.00 8.00 COMP K 20 P R/U casing equipment. 08:00 09.30 1.50 9.50 COMP K 20 P R/U SLB TEC vire spooler and equipment. 09.30 11 00 1.50 11.00 COMP K 4 P P/U 8 M/U 4.5"completion jewelry as per detail to 235'. 11.00 -12.00 1.00 12.00 COMP K 4 -P R/U Tec wire to Gauge Carrier Sub and test per SLB. 12.00 00.00 12.00 24.00 COMP K 4 P Run 4.5"completion as per detail 1/235'-7696'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 4 1:2 3.960 L80 2,617.35 5.920.44 3/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 Vol Eni E&P Division (Well Name:SI29-S2 ENI Petroleum Co.Inc. Daily Repo).,}L Well Code:26210 Field Name:Nikaitchuq • API/HIM:50-629-23464-00-00 en n Date:3/21/2012 - Report#: 2 �' II 1) page 1 of 1 Wellbore name: S)29-S2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 COMPLETION 5,945.12 1,176.69 42.33 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 -17.8 Clear,WC_60 10°N @ 5 mph Daily summary operation 24h Summary Run 4.5"completion tubing,land and set packer.Shear GLM set BPV.N/D stack and N/U and test.R/U Lil Red and freeze protect well with 164 bbls of diesel. Operation at 07.00 R/D from well SI29-S2 and prep to move. 24h Forecast Rig Down and move rig from SI29-S2 To S120-N4. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start I End Cum Time Time Our(hr) Dur(hr) Phase• Opr. Act. Plan Oper.Descr. 00:00 '01:30 1.50 1.50 COMP 'K 4 P Run 4.5"completion tubing f/7696'-8619'.145k puw,100k sow. 01:30 '02:30 1.00 2.50 COMP K 4 P Space out for landing tubing,tag @ 8665'and set down 25k.Did not observe shear.UD space out jts. 02:30 '04:00 1.50 4.00 COMP K 20 P M/U hanger assy.with XO pup and perform TEC line feed through hanger as per Vetco/SLB. 04:00 '05:30 1.50 5.50 COMP K 4 P Land tubing string and run in lock down screws.Test upper and lower hanger seals to 5000 psi for 10 min. a^ 05:30 06:00 0.50 6.00 COMP 'K 20 P PJSM,R/U testing equipment. PtY • 06:00 09:00 3.00 9.00 COMP 'K 12 P Pressure test lines to 4200 psi.Pressure up to 1200-3500 psi and set Howco packer.Hold and chart pressure for 30 min. Note;Observe shears @ 1400&2100 psi.Bleed tubing to 2000 psi&pressure Annulus to 2500 psi and chart for 30 min. Bleed Ann.to 0 psi and increase tubing pressure to 4450 psi to open Mirage plug.Bleed tubing to 0 psi. 09:00 09:30 0.50 9.50 COMP K 12 P Pressure up Annulus and shear out GLM valve @ 2550 psi.Pump 10 bbls to verify shear out,2 bpm,140 psi. 09:30 11:00 1.50 11.00 COMP K 20 P PJSM,Blow down and R/D all testing equipment. - 11:00 11:30 0.50 11.50 COMP K 20 P L/D landing jt.and set BPV. 11:30 15:00 3.50 15.00 COMP K 20 P PJSM,clean dip pan,clear floor,remove flow line and choke line.Prep for N/D stack. 15:00 17:30 2.50 17.50 COMP K 20 P 'N/D stack and set back on stump.N/D riser. 17:30 18:00 0.50 18.00 COMP K 20 P Install TEC wire on well head as per Vetco/SLB.SLB down hole readings,1593 psi,74.43 degrees F. 18:00 22:00 4.00 22.00 COMP K 20 P N/U tree and test void to 5000 psi for 10 min.R/U and test tree to 500 psi f/5 min,5000 psi f/15 min.R/D test equipment. 22:00 22:30 0.50 22.50 COMP K 20 P Pull TWC and R/U to freeze protect. 22:30 00:00 1.50 24.00 COMP 'K 7 P PJSM,Pressure test Lil Red and lines to 2500 psi.Pumped 40 bbls before retums @ 1.5 bpm,ICP=800 psi.Released rig @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L80 2,617.35 5.920.44 3/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,710.28 1,124.20 FazePro 1102.4 52.7 1571.4 176.6 ;r"" } Eni E&P Division Well Name:SI29-S2 I EN/Petroleum Co.Inc.- Daily Report Well Code:26210 Field Name: Nikaitchuq • Date:3/22/2012 - Report#: 3 APIIUWI:50-629-23464-00-00 2" " page 1 of 1 Wellbore name: SI29-S2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212006 ENI PETROLEUM 100.00 HORIZONTAL INJECTION Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.47 12.47 3.99 11.22 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI29-S2 COMPLETION 5,945.12 1 176.69 43.83 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 Daily summary operation 24h Summary Freeze protect SI29-S2 w/164 bbls..diesel.RU wireline and changeout shear valvein GLM and test Operation at 07.00 Operation at 1200 hrs.finish rig down from S12-52. 24h Forecast Freeze protect well SI29-S2,finish wireline work and prepare to move rig. Lithology Shows MAASP(kgf/cm2) Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 COMP K 19 P Freeze protect well SI29-S2 with 164 bbls.diesel@3bpm,400 psi 01:30 03:00 1.50 3.00 COMP K 19 P U-tube Ann/Tubing.Blow down and rig down lines. 03:00 04:00 ' 1.00 4.00 COMP 'K 19 P R/U Howco wirelineW/BOPS/lubricator and test to 1000psi. 04:00 06:00 2.00 6.00 COMP K 19 P RIH with Howco slip stop catcher.set and POOH 06:00 09:00 3.00 9.00 COMP K 19 P RIH and retrieve shear valve.Took 2 attempts 09.00 10:00 ' 1.00 10.00 COMP K 19 P RIH and set annulus to tubing 2000 psi shear valve. 10:00 10:30 0.50 10.50 COMP K 19 P LRS pressure test new shear valve to 500 psi for 10 min. 10:30 11:30 ' 1.00 11.50 COMP K 19 P RIH and retrieve slip stop catcher. 11 30 12:00 0.50 12.00 COMP K '19 P R/D HOWCO wire line equipment. 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( I cn 7.= MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg c� / DATE:Tuesday,May 01,2012 P.I.Supervisor I \ef�j 1/I z- SUBJECT:Mechanical Integrity Tests ( ENI US OPERATING CO INC SI29-S02 FROM: Jeff Jones NIKAITCHUQ SI29-S02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI29-S02API Well Number 50-629-23464-00-00 Inspector Name: Jeff Jones Permit Number: 212-006-0 Inspection Date: 4/13/2012 Insp Num: mitJJ 120414151035 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' 5129-SO2 `Type Inj W -TVD 3639 - IA 776 1687 1686 1687 PTD 2120060 , Type Test SPT Test psi 1500 OA 260 250 240 230 Interval INITAL P/F P Tubing 28 31 31 32 Notes: Post-injection MIT. Tuesday,May 01,2012 Page 1 of 1 HALLI BURTON Sperry Drilling To: Alaska Oil and Gas Conversation Commission 333 W 7t" 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 — SI29-S2 AFE # 5506 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports R 1 Final Data Listing on CD-ROM r' v� ( `t 7 et 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: Print Name dd1/4/—e) Sign 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 u 7_4(( DATE:Thursday,April 19,2012 P.I.Supervisor ` SUBJECT:Mechanical Integrity Tests ENI US OPERATING CO INC SI29-S02 FROM: Jeff Jones NIKAITCHUQ 5129-S02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ S129-S02 API Well Number 50-629-23464-00-00 Inspector Name: Jeff Jones Permit Number: 212-006-0 Inspection Date: 4/13/2012 Insp Num: mitJJ120414151035 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5129-S02 - Type Inj W'TVD 3639 IA 776 1687 - 1686 1687 - PTD 2120060 - Type Testi SPT,Test psi 1500 OA 260 250 240 230 . Interval INITAL � P/F P - Tubing 28 31 . 31 32 - Notes: Pre-injection MIT. - Thursday,April 19,2012 Page 1 of 1 21Z--oo6 2-122 $cblumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SI29-S2 Date Dispatched: 22-Mar-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SI29-S2 Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5inTVD 1 Received By: Y�'�� i „J/> Please sign and return one copy� to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanana.enipetroleum.com LWD Log Delivery V2.1,03-06-06 ��,p),�/ f SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Nelson Carbello Drilling and Completion Superintendent Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI29-S2 Eni US Operating Co. Inc. Permit No: 212-006 Surface Location: 4439' FSL, 1437' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 1504' FSL, 2635' FEL, SEC. 29, T14N, R9E, UM Dear Mr. Carbello: 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. Sincere JO ,/: i u . • -- ssioner DATED this 2 2f day of January, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ::,,,r,-„,r,Elvto STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION `* "' 7 ?012 PERMIT TO DRILL 20 MC 25.005 - .- * ' :.41',i Co 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil El Service- Winj ❑� . Single Zone ❑ lc.Specify if well;is proppsec0for: �� Drill Q - Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas El 2.Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 . SI29-S2 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 19505- TVD: 3860 Nikaitchuq/Schrader Bluff 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4439 FSL,1437 FEL,S19 T14N R9E UM ADL 0391283,0390616' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2110 FSL,987 FEL,S24 T14N R8E UM ADL 417493 2/3/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1504 FSL,2635 FEL,S29 T14N R9E UM 1280 11140'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 54.1 15.Distance to Nearest Well Open Surface:x- 511474. y- 6053619, Zone- 4 GL Elevation above MSL: • 13.1 to Same Pool: 1029'to SP27-N1 16.Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.23 degrees Downhole: 1660 psig ' Surface: 1257 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 160 36 36 160 ' 160 Pre-Installed 1723 TOTAL sx • 16" 13-3/8" 68 L-80 BTC 4541 35 35 4576' 2484 LEAD:1453 sx 10.7 ppg ASL TAIL:270 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 8959 33 33 8992 ' 3708 617 TOTAL 617 sx 12.5 ppg DeepCrete 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 10713 8792 3690 19505. 3860 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑✓ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 MC 25.050 requirements❑✓ 21. Verbal Approval: Commission Representative: Date 1/16/2012 22. I hereby certify that the foregoing is true and correct. Contact Joseph Longo 907-865-3323 i Printed Name Nelson Carbal Title Drilling and Completion Superintendent / .7-':7-., . / 2 Signature �./fir "; {y �? / Phone (907)865-3325 Date 1/16/2012 Commission Use Only Permit to Drill G API Number: ( C, ermit Ap See cover letter for other Number: 50-6 7 7 c/64-6� -late: (11 112 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: I Other: �f'3 p 3L LSO P I 1• -- Samples req'd: Yes ElNo[t]/ Mud log req'd: Yes ❑ No -/FS[�D "LZL J4rhrcwr//JJ4,� ►Gs'# L H2S measures: Yes❑ No[ ' Directional svy req'd: Yes R"No 111-- (A.(+ �i. . cif-Q.Alla r.� w. ,),9 wl, (o .34 - C 6 L i m tr- .07,..„..s ;if q 4 APPROVED BY THE COMMISSION DATE: I 3/ -1 (..- e ,COMMISSIONER Form 10 401(Revised 7/2009) This permit is valid for 24 mon t e i° a r va (20 AAC 25.005(g)) Submit in Duplicate 4 j'L� A !Z7•l L uR J TALL ai ! f 4 ED Viits En troeu tJAN 7 2ni? ern Alaska Oil&Gag Cons.ECEV' �ammission Afichcru��,g 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com January 16,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer SI29-S2 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the offshore Injector well SI29-S2.This well will be drilled and completed using Doyon 15. The planned spud date could be as early as 2/3/2012. 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 907-865-3323. Sincerely, �/-2 / Nelson-Ear Io Drilling and Completion Superintendent 2no 10#1 Etnili Ptir©IIuiirini Application for Permit to Drill SI29-S2 Proposed Drilling Program Requirements of 20 AAC25,005(c)(13) An application for a Permit to Drill must be dcuumpanied by each of the following items, except for an item already on file with the commission and identified in the application: 1) Move in / rig up Doyon 15. 2) Spud and directionally drill 16"hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4) Install and test wellhead to 5000 PSI. 5) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6) Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 13.D p 8) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, '1, P recording results. M,.;1," 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. 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. or- ,fcJrJ �l `r j 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. -�� S, t Co L . 18) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. -. Lo1 ; /Z pray 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 4-1/2"slotted liner with swell packers and ICD's 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 4-1/2"completion assembly with Injection Packer as required and RIH to depth. 120127 SI29-S3 Drilling Proceudre.doc Page 1 of 2 Printed: 27-Jan-12 C ■ PtiroIIeumC1n� � Application for Permit to Drill • Verify that PHL packer placement is set below base of Ugnu formation and at least 300' below the top of intermediate cement prior to running in the hole. 23) Land tubing hanger and test upper and lower seals to 5,000 psi and hold for 10 min. 24) Line up to set packer. Test surface lines to 5,000 psi and bleed back to zero. 25) Set PHL Packer. • Pressure down tubing string to 3500 psi to set packer and hold for 30 min, record on chart. • Reduce tubing pressure to 2000 psi and pressure inner annulus to 2500 psi and hold for 30 min, record on chart. 26) Bleed all pressure off tubing. Pressure inner annulus to 2500 psi and shear SOV 27) Pull landing joint and set BPV 28) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). • 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. 29) Pull BPV and set TWCV. 30) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 31) Pull TWCV. 32) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 33) Set BPV and secure tree and wellhead. 34) RDMO 120127 SI29-S3 Drilling Proceudre.doc Page 2 of 2 Printed: 27-Jan-12 If* • en11 MS (0) 1C WELL SI29-S2 Spy Island Nikaitchuq Field S129-S2 North Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO I: Cement to Surface 1 I 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' 4:: Driven Welded N/A 0 GR/Res 5urfaee Csg Dir/PWD ' 0 13-3/8" 68# MW(PPMWellbore Stability y Mud Motor R,'Permafrost 2100 1728 rr- L-80,BTC 8.8-9.5 Lost Circulation u Hole Cleaning a Casing Sections KOP:200' Casing Wear DLS: Surface T/Tail Cement 3953 2361 0-4.°/100' Hole Anglefrie/ 78.59 Deg 13-3/8"Csg 4,576' 2,484' /xa 16" 50°F WBM GR/RES rl Neutron/Density/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 •'' Torque&Drag Casing Sections Tangent Angle: \ Casing Wear #DIV/0!Deg e BHA Expense Intermediate TOC 7,014' 3,174' Pick-up Top of Sand N 14 G 3 NOTE:Include SONIC LWD in Production Hole BHA N Top 8,014' 3,531' iii0 p PHL Injection Packer 8,692' 3,678' . Hole Angle TOL 8,792' 3,690' 85.00 Deg 9-5/8"Casing 8,992' 3,708' 12.25" 85"F MOBM GR/RES/SONIC V ICD ADN/PeriSCOPE/PWDi Wellbore Stability fp E 0p�1 Lost Circulation x, slotted Liner Hole Cleaning E ICD 4-1/2" Torque&Drag ep 11.6# MW(ppg) Casing Sections Xceed 675 1_ 0 21 L-80,Hydril 521 8.7 9.4 Casing Wear BHA Expense ST ICD CE El ICD . Hole Angle 91.05 Deg 4-1/2"Liner 19,505' 3,860' - 8-3/4" 85'F MOBM Ste( pis t"J. £4( DL••:..`r SI29-S2 Drilling Wellplan Page 2 of 39 01/16/12 em us operating WELL SI29-S2 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 10 Surface Cementing 13 Pick Up Intermediate Drilling Assembly 15 INTERMEDIATE SECTION 16 Intermediate Drilling 18 Intermediate Casing 19 Intermediate Cementing 22 Pick Up Production Drilling Assembly 24 PRODUCTION SECTION 25 Production Drilling 27 Production Liner 28 ATTACHMENTS 31 Area of Review 32 Recommended Drilling Practices 33 Health, Safety & Environment 34 Safety Meeting Topics 35 Well Shut In Procedure While Running Production Tubing 37 Conductor Broach—Contingency Cementing Plan 38 TAM PORT COLLAR Utilization Decision Tree 39 S129-S2 Drilling Wellplan Page 3 of 39 01/16/12 en Enil1,710I Petirolleum Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 Application for Permit to Drill Document Producer Well SI29-S2 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(0 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 P/ease see Attachment 7;Surface Platt 3 Requirements of 20 MC 25.050(b) 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 6 (LSND) 6 Lateral Mud Program 6 (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 AOGCC PERMIT Document.doc Page 1 of 8 Printed:16-Jan-12 VOlt = • tiroIIeuim • ine e enn Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 Requirements of 20 MC 25.005(c)(10) 7 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 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 7 Requirements of 20 MC 25.005(c)(14) 7 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 BOP and Diverter Configuration 8 Attachment 4 Cement Loads and CemCADE Summary 8 Attachment 5 Well Schematic Error!Bookmark not defined. Attachment 6 Formation Integrity And Leak Off Test Procedure 8 Attachment 7 Surface Platt 8 AOGCC PERMIT Document.doc Page 2 of 8 Printed:16-Jan-12 %St • PetiroHeumCCMI eno Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SI29-S2 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready 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 4439 FSL, 1437 FEL, S19 T14N R9E UM /' ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1'AMSL Northing: 6,053,619' Easting:511,474' Pad Elevation 13.1'AMSL Location at Top of Productive Interval 2110 FSL, 987 FEL, S24 T14N R8E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9046' Northing: 6,051,285' Easting: 506,845' Total Vertical Depth, RKB: 3712' Total Vertical Depth, SS:: 3658' Location at Total Depth 1504 FSL, 2635 FEL, S29 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 19,505' Northing: 6,045,413' Easting: 515,598' Total Vertical Depth, RKB: 3,860' Total Vertical Depth, SS: 3,806' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan AOGCC PERMIT Document.doc Page 3 of 8 Printed:16-Jan-12 Igh • EEi '=_tIroleum ern Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 (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 mall;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 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 MC 25.035,20 AAC 25.036, or 20 AAC 25.037,as applicable,' Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; 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 = (3,659'TVDss)(0.45 - 0.11 psi/ft) = 1257 psi • (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.030(1) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 8 Printed:16-Jan-12 ��•f Enli �• ena Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 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 Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (R) (R) (R) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 160'/ 160' Pre-Installed 1723 TOTAL sx 13-3/8 16 68 L-80 BTC 4541' 35/ 35 4576'/ 2484' LEAD: 1453 sx 10.7 ppg ASL TAIL: 270 sx 12.5 ppg DeepCrete • 617 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 8959' 33 / 33 8992'/ 3708' 617 sx 12.5 ppg.peepCrete TOC: 7,014'MD/3,174'TVD 8-3/4"OA - 4-1/2 Sand 11.6 L-80 Hydril 521 10713' 8792'/ 3690' 19505'/ 3860' Liner in Open Hole-no cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP Configuration. E -sues s that AOGCC waive dive er requ - - .. .- . - . . C.t,Q V i JLr to v7 G.L.D AOGCC PERMIT Document.doc Page 5 of 8 • Printed:16-Jan-12 l"- Ein � PtiroIkuim ii em Application for Permit to Drill SI29-S2 Saved. 16-Jan-12 8. Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Perm,, 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 (MOBM) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value - Density(ppg) , 8.7-9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy Funnel Viscosity (CP) 15 25 (seconds) 45 60 Yield Point Plastic Viscostiy (lb/100 sf) 15 20 (CP) 12 18 HTHP Fluid loss Yield Point (ml/30 min <5.0 (lsf) 18-24b/100 200psi&100°F API Filtrate4 - 6 Oil/Water 60 / 40 (cc/30 min)) Ratio Chlorides(mg/1) <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. 9. Abnormally Pressured Formation Information Requirements of 20 AAC25.005(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(0; Not applicable: Application is not for an exploratory or stratigraphic test well. AOGCC PERMIT Document_doc Page 6 of 8 Printed.16-Jan-12 EnN Petirolleum enn Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 10. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b),• Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 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: Please refer also to Attachment 5— Drilling Procedure E4-14j • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). (1). ---we.-Wi-.' • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the 4L p 144-1--• tree u 1— tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. qr� t 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Dnll 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 25080 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 the Spy Island 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 7 of 8 Printed: 16-Jan-12 2n� *tot • Einii PtiroIIuim Application for Permit to Drill SI29-S2 Saved: 16-Jan-12 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Drilling Procedure Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt AOGCC PERMIT Document.doc Page 8 of 8 Printed: 16-Jan-12 • • • ernR S129-S2(P4b)Proposal Report Schlumberger (Del Plan) Report Dab: January 12,2012-10:27 AM Survey l DLS Computation: Minimum Curvature/Luhnski Client Eni Petroleum �7 Verges)Section Azimuth: 153.404°(True North) Field: Nikeitchuq �FI�(�� Bcel Section Origin: 00005,0.000 ft Structure l Slot: Spy Island/SP29 f O a" _-,IVD Reference Datum: Rotary Table Well: S129S2 /�g1(r+L 0 U TVD Reference Elevation: 54.100 ft above MSL Borehole: 0129-02 r5 Seabed 1 Ground Elevation: 13.100 ft above MOL UWI IAp01: Unknown/50 Magnetic Declination: 20.662° • Survey Name: S129-02(P4b) Total Field Strength: 57649.609 nT Survey Date: October 162011 Magnetic Dip Angle: 81.071° Tort 1 AHD I DDI I ERD Rego: 307.301°/18022.0535/7.442/4.612 Declination Date: February29,2012 Coordinate Reference System: NAD27 Alaska State Plane,Zone 04.US Feet Magnetic Declination Model: BGGM 2011 Location Latl Long: N 70°33'27.74205,W 149°54'21.21788- North Reference: True North Location Grid NIE TM: N 6053619.4505US,E 511073.700 ftUS Grid Convergence Used: 0000° CRS Grid Convergence Angle: 0.08873998° Total Corr Meg Nortl1>True 20.882° North: Grid Style Feeler: 0.99090015 Local Coord Referenced To: Well Heed MD Incl btm True 7V088 TVD VSEC NS EW 7F OILS Directional Exclusion Zone Exoloelon Zone Northing Essen° Commentsle (ft) C) C) (8) (ft) (ft) (ft) (ft) C) (11005)Difficulty Index Alert X1,1 (MIS) (MIS) RTE 0.00 0.00 280.00 -54.10 0.00 0.00 0.00 0.00 200M N/A 0.00 8.93 805381945 511473.70 10000 0.00 290.00 4590 10000 000 0.00 0.00 290M 000 0.00 893 6053619.45 511473.70 KOP Cry 1.5/100 20000 0.00 290.00 14590 20000 0.00 0.00 000 290M 0.00 0.00 8.93 6053610 45 511473.70 Cry 4/100 30000 1.50 200.00 245.89 299.99 -005 0.45 -1.23 290M 1.50 0.29 9.07 6053619.90 511472.47 400.00 5.50 290.00 345.88 399.78 -5.39 2.54 6.97 HS 4.00 1.61 1053 605362197 511486.73 500.00 9.50 29000 444.81 498.91 -14.87 700 -19.23 HS 4.00 2.29 13.08 6053528.42 511454.46 600.00 13.50 290.00 542.78 596.88 -20.35 13.82 -37.96 HS 4.00 2.74 16.23 6053633.21 511435.72 700.00 17.50 290.00 839.12 893.22 -48.76 22.95 -03.07 HS 4.00 3.07 19.67 8053642.30 511410.80 SV-4 77743 20.00 290.00 712.30 700.40 -67.12 31.60 -0081 HS 4.00 3.29 22.47 6053650.91 51138685 800.00 21.50 200.00 733.37 78747 -73.01 34.37 -94.43 HS 4.00 3.34 23.29 6053853.67 511379.23 900.00 25.50 290.00 825.05 879.15 -101.97 48.00 -131.89 1/0 4.00 3.58 27.02 8053687.24 511341.75 1000.00 29.50 290.00 913.74 967.84 -135.51 83.79 -17527 HS 4.00 3.75 3080 8053882.97 511298.35 1100.00 33.50 290,00 998.98 1053.08 -173.46 81.88 -224.36 HS 4.00 3.02 34.63 6053700.75 511240.24 SV-3 1187.84 3701 200.00 1070.70 1124.80 -210.90 09.00 -27200 US 4.00 4.05 38.03 0053718.02 511201.58 1200.00 37.50 290.00 1080.38 1134.48 -215.65 01.52 -278.02 HS 4.00 007 38.50 6053720.53 511194.65 130000 41.50 29000 1157.53 1211.83 -261.85 23.27 33858 HS 4.00 4.21 4238 605374218 511134.87 1400.00 45.50 290.00 1230.05 1284.15 31185 48.81 -403.35 HS 4.00 4.33 4828 6053765.62 511070.17 1500.00 49.50 290.00 1297.59 1361.60 36540 72.02 -472.82 HS 4.00 4.44 50.19 6053790.72 511000.87 Cry 0.5/100 1503.71 49,65 290.00 1300.00 1354.10 367.16 72.08 -47527 HS 4.00 4.45 50.34 6053791.88 510998.21 SV-2 1598.52 49.81 200.00 1322.50 1370.60 388.75 82.07 -50.23 HS 0.50 4.47 50.51 6053800.73 510073.24 1600.00 50.13 290.00 136204 1416.14 -420.96 98.17 -544.47 HS 0.50 4.52 5081 8053816.76 510928.98 1700.00 60.63 290.0 1425.81 1479.91 -478.92 24.52 -61685 HS 0.50 4.58 5130 8053842.09 510858.58 1800.00 51.13 290.00 1488.90 1543.0 -533.20 51.05 -08076 HS 0.50 064 5179 605386041 51078363 100.0 51.63 29000 1551.32 1605.42 -690.05 77.77 -763.18 HS 0.50 4.70 5228 6053896.01 510710.17 2000.00 52.13 20.0 1613.05 1667,15 647.21 0488 -837.10 HS 0.50 4.75 52.77 6053922.80 510636.21 2100.00 5263 2000 1874.09 1728.19 -704.75 3177 -911.53 HS 0.50 479 53.26 8053949.77 51056175 2200.00 53.13 20.0 1734.44 1788.54 -762.68 5904 -98816 HS 0.50 4.84 53.75 8053976.93 510486.78 2300.00 5363 200.00 1794.09 1848.19 621.0 88.49 -106186 HS 0.50 4.88 5424 605400426 510411.33 Cry 4/100 2309.98 53.88 290.00 1800.00 1854.10 -82683 8924 -106013 50811 0.50 4.88 54.29 605400698 51040378 240000 5600 286.63 185185 10595 378.76 1234 -113920 4887L 4.00 4.94 5709 605402098 510333.89 50-1 2410.87 56.29 288.24 1857.90 19120 -88492 14.80 -1147.95 4005L 4.0 4.95 57.43 054032.52 510325.23 2500.00 5868 283.11 1905.81 1959,91 -934.46 33.90 -122065 4697L 400 5.01 60.26 605405141 510252.51 2600.00 61.46 279.78 195571 200981 -987.82 51.05 -130557 4531 400 5.07 8349 6054068.44 510167.57 2700.00 64.31 276.63 2001.30 2055.40 -1038.58 483.72 -1393.64 43.871 4.00 5.13 68.77 05400.96 51079.48 200.00 67,22 273.62 2042.35 2098.45 4086.48 71.83 -148444 42.63L 400 5.18 700 605408894 509988.68 290000 70.10 270.74 2078.87 2132.77 -1131.31 7536 -157/.53 41.591 400 524 73.44 6054092 31 508895.60 300.00 73.20 267.97 2110.08 2164.18 -1172.83 74.27 -167244 40 711 4.00 530 7681 6054091 08 509800.70 3100.00 76.25 285.29 2136.42 2190.52 -1210.84 488.58 -1788.72 40.011 4.00 5.35 8020 605408524 509704.44 Ugnu Top(U04) 9117.05 76.77 284.83 2140.40 2104.0 -1216.90 40715 -1785.24 39.01 4.00 510 8078 6054053.70 500087.92 End Cry 3176.10 78.59 263.29 2153.00 2207.10 -1237.31 461.18 -1842.81 HS 4.00 539 8279 6054077.73 509630.58 3200.00 78.59 263.29 2157.73 2211.83 -124528 458.44 -1865.88 HS 0.00 5.40 82.79 8054074.96 509607.30 3300.0 78.59 263.29 2177.51 2231.61 -1278.62 44899 -196323 HS 0.00 543 82.79 605406335 50950998 3400.00 78.58 263.29 2197.29 2251.39 -1311.96 436.54 -206058 HS 0.00 5.46 82.79 6054051.75 50941265 300.00 78.59 283.29 2217.08 2271.18 -1345.30 424.08 -2157.04 HS 0.00 5.48 8279 6054040.15 509315.33 3600.00 78.59 263.29 223686 220.96 -1378.84 412.63 -225529 HS 0.00 5.51 82.79 05402854 509218.01 3700.00 78.59 263.29 225664 2310.74 -1411.09 401.17 -2352.84 HS 0.00 554 82.79 6054018.94 509120.88 300.00 78.59 263.29 2278.43 2330.53 -1445.33 38972 -244999 HS 0.00 5.56 8279 6054005.33 50023.38 300.00 78.59 283.29 2296.21 2350.31 -1478.67 37826 -254734 HS 0.00 5.59 82.79 6053993.73 508926.03 400.00 78.59 263.29 2315.99 2370.09 -1512.01 366.81 -264470 HS 0.00 5.81 82.79 6053982.13 08828.71 4100.00 78.59 263.29 233578 2389.88 -1545.35 35535 -274205 HS 0.00 5.83 82.79 6053970.52 508731.38 4200.00 78.59 263,29 2355.56 2409.68 -1578.0 343.90 -2839.10 HS 000 5.85 82.79 6053958.92 508634.06 4300.0 78.59 263.29 2375.34 242944 -1612.04 33245 -2936.75 HS 0.00 5.67 8279 6053947.31 508536.74 4400.00 78.59 283.29 2395.13 244923 -1645.38 320.99 -3034.10 HS 0.00 5.60 82.79 6053935.71 50843941 400.00 78.59 263.29 2414.91 240.01 -1678.72 309.54 -313116 HS 0.00 571 82.79 6053924.11 08342.09 13-9.8-Csg 4576.28 7850 20.20 2430.00 2484.10 -1704.15 30080 -3205.72 HS 0.00 5.73 8270 605391525 0810785 4800.00 7859 263.29 243459 2488.79 -17120 298.08 -3228.81 HS 0.00 5.73 8279 605391250 50824476 4700.00 78.59 263.29 2454.48 208.58 -1745.40 286.0 -3326.16 HS 0.00 5.75 82.79 0539090 508147.44 4800.00 78.59 263.29 2474.26 2528.36 -1778.74 275.17 -3423.51 HS 0.00 5.77 82.79 605388929 50805011 4900.00 78.59 263.29 2494.04 2518.14 -1812.09 26372 352086 HS 00 5.79 82.79 6053877.89 07952.79 500000 78.59 263.29 2513.83 2567.93 -184543 252.27 361622 HS 000 5.80 82.79 05380.09 07855.47 5100.00 78.0 283.29 2533.61 258771 -1878.77 240.81 3715.57 HS 0.00 5.82 82.79 6053854.48 507758.14 5200.00 78.59 263.29 2553.39 260749 -1912.11 229.30 -381292 HS 000 5.84 82.79 605384288 0768082 5300.0 78.59 26329 2573.18 2627.28 -194515 217.0 -391027 HS 0.00 5.85 82.79 605383127 507583.49 5400.00 780 26329 2592.96 284706 -1978.78 206.45 -4007.82 HS 0.00 5.87 82.79 8053819.87 07468.17 Cry 4/100 5442.03 78.59 263.29 2601.27 2655.37 -1992.81 201.0 -4048.54 110.431 0.00 5.87 8279 05381479 0742528 550000 77.79 28107 2613.14 2667.24 -2011.07 19391 4104.75 109971_ 400 5.89 82.30 605380899 0736907 5600.00 7645 257.20 263544 2669.54 -2037.50 175.56 4200.47 109.111 1.00 5.93 81.47 6053788.47 07273.39 UG-2 Coal Bed 5610.77 70.23 25055 2630.40 2009.0 -2041.20 171.85 4216.34 108.961 400 593 81.94 6053784.75 07257.53 Marker 570000 7517 20.29 2659.96 2714.06 -2057.40 15017 429420 108.151 400 5.96 6089 6053763 85 07179.71 5800.0 73.98 249.33 2686.58 2740.68 -2070.66 12000 4385.49 107.11 4.00 5.99 79.95 605373265 07088.47 5900.00 72.82 245.33 2715.17 270.27 -2077.24 83.09 4473.90 105951 400 6.02 7926 6053695.61 0700.13 6000.00 71.76 241.28 274560 2799.70 -2077.09 4032 4558.99 104.721 400 605 78.62 6053852.71 50015.11 610000 70.79 237.19 2777.71 2831.81 -2070.22 -8.10 -4640.38 103.411 400 6.07 7804 605304.16 0033.83 Fault 1 018760 70.02 233.56 207.10 2561.20 -2058.70 -5498 4708.26 102.191 4.00 6.09 7758 6053557.18 0676001 620000 6991 233.04 281135 2885.45 -2056.65 61.94 4717.60 102011 400 610 7751 605355021 50670.0 6300.00 69.13 228.86 2846.35 200.45 -2036.47 -12094 479033 10551 4.00 6.12 7705 6053491.11 06884.05 6400.00 68.45 224.83 2882.54 2936.64 -200.75 -16480 485821 9802L 4.00 6.14 7865 053427.15 0018.28 6500.00 67.88 220.38 291976 2973.60 -1976.64 -253.21 4920.90 97.431 4.00 6.17 76.31 605335864 06553.70 8600.00 67.42 216.07 29570 301190 -1937.29 32585 4978.10 95791 400 6.19 7604 605328502 506496.62 670000 67.07 211.74 2998.0 305060 -1891.0 40238 -02953 94.121 4.00 621 7584 6053209.34 06445.31 6600.00 66.84 207.40 3035.68 3089.76 -1840.69 48237 -074.03 92421 400 623 75.72 605312927 50640.04 600.00 0.73 203.05 3075.10 3129.20 -1783.91 -56548 311410 90711_ 4 00 6.25 7566 6053048.11 506351 01 700.00 66.74 198.70 311061 3168.71 -172183 65129 -514883 88991 400 8.27 7567 605296028 506328.41 7100.00 66.87 194.35 3154.0 320810 -1654.78 -730.39 -517296 87271 400 8.29 7576 6052872.13 06302.42 Lower Ugnu 7121.91 66.02 10340 3102.60 3218.70 -1630.43 -758.05 -517770 860/. 400 020 75.78 6052852.56 00207.02 7200.0 6712 190.01 3193.10 324720 -1583.02 629.33 -5192.37 85581_ 400 6.31 7591 6052782.16 506283.15 730000 67.49 185.70 3231.69 3285.79 -108.96 -920.70 -5204.97 83.911 400 8.33 76.14 605269078 508270.0 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:30 AM Page 1 of 4 MD Ind Aar8 True 11/02151 ND VBEC NS EW 7F DLS DlebW e . Enelo.lon Zone EBeMr.bn Zara Nor8Yn0 Er8n9 canm«d. 16) (1 C) I6) 00M) IM () (1 pion)68190116 Index u.n PI 4 9t (nus) (TWO 7400.00 87.97 181.40 3269.50 3323.70 -1426.96 -101304 -5210.70 82281_ 400 6.35 7643 6052598.45 50626511 7500.00 88.58 177.15 3306.65 3380.75 -1343.40 -1105.69 -5209.51 80.711 4.00 8.38 7679 805250580 506266.44 7800.00 69.28 172.92 3342.84 3390.74 -1256.89 -1196.82 -5201.43 79.191 4.00 6.38 7722 6052412 70 508271.88 7700.00 70.08 168.74 3377.41 3431.51 4167.25 -1291.36 -518619 77.73L 4.00 8.40 7771 8052320.19 506289,74 Schrader Bluff Top 7740.15 70.40 100.71 3394.00 344010 -1122.42 -1336.56 -5170.65 77.051 4.00 0.41 77.07 0052275.01 50020005 7800.00 70.96 184.61 3410.79 3464.89 -1075.52 -1383.08 -5184.76 78.351- 4.00 6.42 78.25 6052228.53 50831161 N Sequence Top 7882.95 71.77 101.21 3437.30 3401.40 -008.01 -1458.18 5141.00 75.271_ 4.00 0.43 78.75 6052153.40 508334.82 7000.00 71.95 16052 3442.61 3496.71 -981.95 -1473.49 513635 75.051 4.00 8.43 78.86 605213818 508340.16 8000.00 7302 156.48 3472.72 3526.82 -88698 -1562.19 -5101.40 73.841 4.00 8.45 7952 6052049.52 508375.24 N Top 0015.43 73.10 155.80 3477.20 3591.30 572.23 -1575.09 5005.44 73.09- 4.00 0.40 79.02 6052030.03 500981.29 8100.00 74.17 152.49 3500.97 3555.07 -791.09 -1648.73 -5060.08 72.711 4.00 6.47 8023 6051963.05 508416.69 Fault 2 8131.28 74.55 151.25 3509.40 3563.50 -700.08 -1075.30 -5045.88 72.371 4.00 6.47 00.40 0051036.51 500430.04 ' N Bottom 0102.80 7531 148.82 3525.40 3570.50 -701.00 -1726.75 -5016.21 71.741 4.00 6.48 80.93 0051885.10 506400.08 8200.00 75.40 148.54 3527.22 356132 -894.75 -1732.70 -5012.59 71.071 4.00 6.49 80.98 5051879.16 508484.31 8300.00 75.69 141.64 3551.35 3605.45 -508.41 -181369 4959.15 70.731 4.00 0.50 81.78 805179827 506517.87 840000 78.03 140.78 3573.24 3827.34 -502.55 -1891.29 4900.04 89.881 4.00 6.52 8262 6051720.76 508577.09 8500.00 79.44 136.96 3592.78 3648.88 407.84 -1965.14 4835.54 69.141 4.00 6.54 83.49 6051847.02 505641,70 N Sequence Base 8572.94 80.40 194.19 3005.50 9050.00 -330.27 -2010.43 4785.27 68.601 4.00 0.55 84.14 0051505.82 500602.05 6000.00 80.88 133.17 3509.88 3863.96 -31414 -2034.87 -4765.96 68.491. 4.00 8.58 84.39 6051577.41 508711.38 8700.00 82.37 12942 352445 3678.55 -222.50 -2100.14 4691.64 67.94E 4.00 8.57 8531 6051512.26 50678580 8800.00 83.88 125.69 3836.43 3890.53 -133.18 -2160.64 -4812.95 67.51 4.00 8.59 8826 6051451.89 506884.57 EO4 Cry 8872.53 8500 123.00 3643.05 3697.55 -70.08 -2201.38 -4553.35 HS 4.00 6.60 8616 6051411.27 506924.23 8900.00 85.00 12300 364585 3699.95 -48.48 -2218.26 4530.40 HS 0.00 6.01 86.96 8051398/0 508947.20 0-58-C.9 8092.39 85.00 123.00 3653.00 3706.00 322.00 -2280.30 -4453.21 HS 0.00 0.01 8000 6051340.30 507024.46 900000 85.00 123.00 3654.56 3708.66 39.44 -2270.52 -4446.85 HS 0.00 6.61 8616 605134228 507030.82 OA Top 004076 85.00 123.00 3058.90 3713.00 82.10 -2207.52 4405.28 NS 0.00 0.02 8000 0051315.94 507072.44 9100.00 85.00 123.00 3881.28 3717.38 125.38 -2324.78 438330 HS 0.00 6.62 8826 6051288.15 507114.45 0.4-2 Top 012003 85.00 123.00 306580 3710.90 150.22 -2340.47 4399.13 HS 0.00 0.69 86.06 6051272.50 507138.64 SI-52 MN 9172.53 8500 123.00 3669.60 3723.70 187.68 -2384.13 430270 HS 0.00 663 86.96 605124890 507175.10 Cry 2.75/100 9192.53 85.00 123.00 367134 3725.44 204.86 -2374.98 4286.00 52.621. 0.00 6.63 85.96 8051238.08 507191.82 9200.00 85.09 122.88 3671.99 372609 211.27 -237903 4279.75 52.61L 2.00 6.63 87.03 5051234.04 507198.08 04-3 Top 020721 8518 122.77 3072.00 3720.70 217.40 -2382.02 4273.71 52.9. 2.00 0.03 87.10 0051290.15 00720412 6300.00 8631 121.29 3679.49 3733.59 296.46 -2431.99 -419527 52191 2.00 865 87.99 605118121 507282.63 End Cry 9388.05 8738 119.92 368424 3738.34 368.67 -2475.73 4121.32 HS 2.00 6.68 88.82 8051137.59 507356.64 9400.00 87.36 11992 3684.89 373810 38030 -2482.68 410924 HS 000 6.66 88.82 6051130.66 507368.73 9500.00 87.36 119.92 3689.50 3743.60 483.62 -253251 4022.68 HS 0.00 887 88.82 6051080.97 507455.37 Cry2/100 9571.37 87.38 119.92 3892.79 3748.89 523.08 -2588.07 396088 17336 0.00 8.88 88.82 6051045.51 507517.21 ' 960000 8679 11999 3694.28 3748.38 546.84 -2582.35 -3938.10 173.29R 2.00 5.88 88.27 6051031.27 507542.01 • SI-S2 T911 9889.95 8500 12020 3700.70 3754.80 621.92 -2627.35 3858.47 189.066 2.00 8.69 86.54 6050986.40 507619.70 ' 9700.00 84.80 12024 3701.59 3755.69 630.29 -263238 384083 189.068 2.00 6.89 86.35 6050981.38 507628.35 9800.00 8284 120.62 3712.35 3780.45 713.69 -2882.73 3764.11 169.01R 2.00 8.70 84.47 8050931 17 507714.13 End Cry 9825.23 8232 120.72 3715.74 378984 735.57 -2696.00 -3741.74 HS 200 8.71 8397 6050917.94 507738.53 9900.00 8232 120.72 3725.59 370989 79710 -2733.34 -3878.89 HS 0.00 8.71 83.97 6050880.69 50779912 Cry 2/100 9975.73 82.32 120.72 3735.71 3789.81 880.27 -2771.68 3814.37 HS 000 0.72 8397 605084245 507883.09 Feu6A 0070.41 8234 120.72 373580 3780.00 860.84 -2772.03 3019.70 HS 2.00 0.72 83.00 6050842.11 507864.56 10000.00 8281 120.72 373885 3792.05 880.53 -2783.8 359388 845 2.00 8.72 84.45 6050830.19 507884.70 10100.00 8481 120.72 3749.83 3803.73 964.20 -2834.77 3508.22 HS 2.00 6.73 86.43 6050779.54 507970.23 10200.00 86.81 120.72 3756.94 381104 1048.14 -2885.71 -3422.49 HS 2.00 8.75 88.40 6050728.73 508056.04 01S2T912 10209.50 8700 120.72 375715 3611.55 1058.12 -2890.56 -3414.33 1.54/ 2.00 6.75 88.59 605072390 508064.20 Pauli B 10240.3e 87.62 120.70 3758.00 3813.00 1082.08 -2000.31 5387.81 1.541 2.00 6.75 89.20 0050708.10 508000.74 10300.00 88.81 120.67 3760.78 381488 113222 -2938.72 3336.57 1.541 2.00 876 89.63 6050677.86 508142.03 • End Cm 10370.14 90.21 120.63 3761.36 3815.48 119120 -2972.48 327823 HS 2.00 877 88.25 605064220 508202.41 10400.00 90.21 120.83 376125 381535 121831 -2987.70 3250.54 HS 0.00 6.77 88.25 6050627.03 508228.12 10500.00 9021 120.63 3760.88 3811.98 1300.39 3038.65 318449 HS 0.00 6.78 88.25 605057621 508314.24 10600.00 90.21 120.63 3780.51 381461 138448 308960 3078.45 HS 0.00 879 88.25 605052540 508400.35 10700.00 9021 120.83 378014 381124 1468.58 3140.58 -288241 HS 0.00 680 88.25 605047458 50848517 042/100 10720.35 90.21 120.63 3780.07 3811.17 1485.88 3150.93 -297489 176.758 0.00 660 88.25 605048424 50850319 SI-S2 T913 1072894 90.10 120.84 376015 3814.15 149037 3153.78 -2970.09 171.218 2.00 6.80 8836 605046140 508508.80 End Cry 10733.30 89.95 120.66 3760.05 381115 1496.58 -3157.53 -2983.78 HS 2.00 6.60 8850 805045706 508515.14 10800.00 89.95 120.66 3700.10 381420 155287 3191.54 -2906.38 HS 0.00 6.81 8850 6050423.73 50857256 10900.00 89.95 120.86 3760.18 381428 1836.78 3242.54 -282038 115 0.00 6.81 88.50 8050372.87 508858.65 11000.00 8995 120.66 376026 381436 172089 3293.54 -2734.34 HS 0.00 8.82 88.50 6050322.01 508744.74 11100.00 89.95 120.66 3760.34 381414 160500 3344.54 -2848.33 110 0.00 883 88.50 8050271.15 508830.83 11200.00 89.05 120.66 3760.42 3811.52 188911 3305.54 -256231 HS 0.00 884 88.50 13050220.29 508918.92 Cry 2/100 11239.90 44.95 120.68 378015 3814.55 192288 3415.89 -2527.98 15.381 0.00 6.84 8880 6050200.00 50895127 SI-S2 T904 1124228 90.00 120.65 3780.45 3814.55 1924.88 341709 -2525.95 0.888 2.00 8.84 88.45 8050198.80 508953.30 End Cry 11254.48 90.24 120.65 3780.42 3814.52 1934.94 3423.32 -2515.44 HS 2.00 885 88.21 8050192.59 508963.82 1130000 90.24 12065 3700.23 3814.33 1873.22 3446.53 -2478.28 HS 0.00 6.85 88.21 8050169.44 509003.01 11400.00 90.24 120.65 375980 3813,90 2057.32 3497.51 -2390.25 115 0.00 6.88 88.21 6060118.60 609089.11 11500.00 90.24 120.85 3759.38 3813.48 2141.42 3548.40 -2304.23 HS 0.00 6.87 88.21 6050087.78 500175.20 11800.00 00.24 12085 3758.05 3813.05 2225.53 3599.47 -2218.20 HS 0.00 8.87 8821 6050016.01 509281.30 11700.00 90.24 12085 3758.52 381282 2309.83 3860.46 -2132.16 110 0.00 0.88 88.21 6049966.07 50934740 Cry 2/100 11748.32 00.24 120.85 3758.33 3812.43 234859 3874.08 -2092.33 179.341 0.00 6.89 8821 604994251 509387.28 5152 1915 11758.54 90.00 120.65 3758.30 3812.40 2358.88 3680.31 -2081.81 178.091 2.00 8.69 88.45 604993830 509397.80 End Cry 11763.21 89.01 120.65 375830 381210 2382.79 3682.68 -2077.80 HS 2.00 6.89 88.55 6049933.93 509401.82 11800.00 69.91 120.65 3758.38 3812.46 239373 3701.44 -204015 HS 0.00 8.89 88.55 604901523 509433.49 11900.00 89.91 120.65 3758.53 3812.63 2477.82 3752.41 -196012 110 0.00 8.90 88.55 6049854.39 509519.80 12000.00 89.91 120.65 375869 381279 256192 -3803.39 -1874.08 HS 0.00 8.01 8855 0040013.55 509805.70 12100.00 89.91 120.65 3758.85 3812.95 2646.02 3854.38 -1788.05 HS 0.00 6.91 8855 6049762.72 509891.80 12200.00 89.01 120.65 375901 3813.11 2730.11 3905.34 -170202 HS 0.00 6.92 88.55 004971188 509777.90 Cry 2/100 12204.58 0991 120.65 3759.02 3813.12 2733.96 3907.67 -1898.08 179.876 0.00 5.92 8855 6049709.55 50978185 01S2 1986 12274.92 88.50 120.65 376000 3814.10 2793.11 3943.52 -1637.58 179.846 2.00 8.93 8994 004967380 509842./0 12300.00 88.00 120.65 3760.77 3814.87 281420 3956.30 -161801 179.836 2.00 6.93 89.57 604966105 509883.99 End Cry 12325.51 87.49 120.65 3761.77 381587 2835.64 3969.30 -1594.07 145 2.00 6.93 89.06 0049848.09 509885.94 12400.00 8710 120.65 376504 381914 289822 4007.24 -1530.06 HS 0.00 6.94 89.06 604961025 50985001 12500.00 87.19 120.65 3769.42 382352 296224 4058.17 -1444.11 HS 0.00 695 89.06 804955948 51003802 12600.00 87.40 120.65 3773.80 3827.90 308827 4109.11 -1358.17 HS 0.00 895 89.06 6049508.88 510122.04 12700.00 8718 120.85 3778.18 383228 315029 4160.04 -1272.22 HS 0.00 6.06 89.06 604845787 51020805 Cm 2/100 12788.57 67.09 120.65 3762.07 3838.17 322471 4205.16 -1188.10 2.89E 0.00 617 89.08 8018/1287 510284.23 • 01521917 12791.67 87.55 12065 378220 3838.30 3227.31 4206.74 -1193.44 1.791 2.00 827 89.12 6049411.30 510286.90 End Cry 12790.37 8764 120.85 378240 383850 323126 4209.13 -1189.39 HS 200 8.97 89.22 804940891 510290.95 ' 12800.00 8764 120.65 3782.55 3838.65 323431 4210.98 -1188.28 HS 000 697 89.22 6049407.07 510294.07 12900.00 8764 120.85 378688 3840.76 331834 -4281.91 -110032 HS 0.00 697 8922 6049356.28 510380.10 13000.00 8764 12065 371677 3844.87 340236 431284 -1014.36 HS 0.00 898 89.22 6049305.48 510486.12 13100.00 87.84 120.65 3794.88 3848.98 348639 436177 62840 HS 0.00 899 89.22 6049254.69 510552.15 1320100 87.64 120.85 3798.90 3853.09 3570.41 4414.70 54244 HS 0.00 899 89.22 6049203.90 510038.18 • Cry 2/100 13291.27 87.84 120.85 3802,74 3856.84 3847.10 4481.19 -763.98 179.510 0.00 7.00 8922 8049157.54 510716.70 13300.00 87.47 120.65 3803.11 385721 3654.44 4465.64 -75848 179.516 2.00 7.00 80.04 6049153.10 510724.21 01.62 1918 13308.47 8730 120.65 3803.50 3857,80 308156 4469.95 -74920 179296 2.00 7.00 88.88 6049148.80 510731.50 End Cry 13320.58 87.06 12085 3804.10 385820 3871.73 4476.12 -73880 HS 2.00 7.00 8864 6049142 65 510741.91 1340000 87.06 120.85 3808.17 388227 3738.43 4518.55 570.56 HS 0.00 7.01 8664 604910232 510810.20 13500.00 87.06 120.65 381331 388741 3822.43 4567.47 584.65 HS 0.00 7.01 88.64 8049051.54 510898.18 i 1360000 87.06 120.55 381844 3872.54 3906.42 4618.39 408.74 HS 0.00 7.02 8864 8049000.77 510982.17 1 13700.00 87.08 12065 3823.57 387767 390041 4889.30 412.82 410 0.00 7.03 88.64 604894999 511068.15 Cry 2/100 13753.28 87.06 120.65 3825.31 388011 4035.18 4898.43 387.05 0.12L 0.00 7.03 8864 604892293 511113.90 • 13800.00 87.99 12065 382832 3882.42 407402 -4720.23 326.89 0.121 2.00 7.03 89.56 6048899.20 511154.15 51521919 1382539 88.50 120.65 3829.10 388320 4895.76 4733.17 305.06 0.111 200 7.04 89.94 6048888.30 511176.00 13900.00 89.99 12065 3830.08 388418 415850 -4771.20 -240.88 0.111 2.00 704 88.46 6048848.37 51124023 End Cry 13906.26 00.12 120.65 383008 388418 4103.76 4774.38 -235.50 HS 2.00 7.05 88.34 6048845.19 511245.62 14000.00 90.12 120.65 3829.88 388318 4242.60 4822.17 -154.85 HS 0.00 7.05 88.34 6048797.54 511326.34 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:30 AM Page 2 of 4 I EaduelefZone Commando MD Ind Adm True TVDSS TVI) VBEC NB EW TF OLD D y14.49Eaelwbn Zone Northing Eastfig(888) (61 O (°) (0) (8) (6) (M (8) CI (17900)D6ncully hale% Alert Angle (NUS)(0U8) (m)61 14100.00 90.12 120.65 3829.88 3883.78 432889 -4873.14 .88.82 HS 0.00 7.06 88.34 6048746.70 517412.44 14200.00 90.12 120.85 382917 3883.57 441079 -4014.12 17.22 HS 0.00 7.00 68.34 604889587 511408.54 14300.00 90.12 120.65 382927 3883.37 4494.89 -4975.09 103.25 HS 0.00 707 88.39 6048645.03 511684.84 Cry2/100 1431089 9012 12085 382925 3883.35 450405 -4980.85 17282 170.7R 0.00 7.07 68.34 604883949 511504.02 0142 Tot 10 14341.76 89.50 12065 382935 3883.45 4530.01 -4998.38 139.18 179.86 2.00 7.07 8805 8048622380 511620.80 End Cry 14382.72 89.08 12065 3828.61 388371 4547.83 -5007.06 157.21 HS 2.00 7.08 89.36 6048613.15 511838.61 14400.00 89.08 120.65 3830.21 388431 4578.98 .502807 189.27 HS 0.00 708 89.36 6048594.19 511670.74 14500.00 8008 120.85 383181 388591 486307 507705 275.29 HS 0.00 7.09 89.38 604854335 511756.82 14600.00 89.08 120.65 383312 3887.52 4147.16 .512802 381.31 HS 0.00 709 8936 6048492.51 511842.91 14700.00 899.08 120.65 383502 388912 4831.26 -517900 447.32 HS 0.00 7.10 88.36 6048441.88 571929.00 14800.00 89.08 12065 383682 3890.72 491535 5229.98 533.34 HS 0.00 7.10 89.38 004839084 512015.08 Crv2/100 14852.11 89.08 120.65 3837.46 3891.58 495917 5258.54 578.18 6.181. 0.00 7.11 89.36 804836435 572059.94 S142 19111 14858.10 89.20 120.64 3837.55 389185 4964.21 -525980 583.31 183 2.00 7.11 89.25 8048361.30 512005.10 End Cry 14888.45 89.41 120.85 3837.68 3891.78 497291 -5264.87 592.22 HS 2.00 7.11 89.04 6048358.04 512074.01 1490000 89.41 120.65 383800 3892.10 499944 -5280.95 619.38 HS 0.00 7.11 89.04 6048340.00 512101.17 15000.00 89.41 120.85 363904 3893.14 5083.53 -533192 705.30 HS 0.00 7.12 89.04 8048289.17 512187.27 1510000 89.41 120.85 3840.07 3804.77 5167.82 -5382.89 791.42 HS 0.00 7.12 89.04 8048238.34 512273.37 15200.00 89.41 120.65 3841.11 389521 5251.71 -5433.88 877.45 HS 0.00 7.13 89.04 80413167.51 512359.47 15300.00 89.41 120.85 3842.14 3896.24 5335.81 -5484.83 903.48 HS 0.00 7.13 89.04 804813688 512445.57 Cry 2/100 15353.90 89.41 120.85 3842.70 380680 5381.13 -5512.30 1009.84 120.3R 0.00 7.14 8004 6046100.28 512491.97 SI-S2 TOt 12 15374.41 89.20 121.00 384295 389705 5398.41 -5522.81 '1027.45 118.07R 2.00 7.14 89.19 0046098.80 512500.60 15400.00 88.96 121.45 3843.36 3897.48 5420.07 -5536.08 1049.34 118.066 2.00 7.14 8936 6048085.57 512531.60 End Cry 15425.07 88.72 121.89 384387 389707 544139 -5540.24 1070.61 1-10 2.00 7.14 89.53 8048072.44 512552.85 15500.00 8872 121.89 3845.54 3899.64 550525 -5588.82 1134.27 415 0.00 7.15 89.53 6046032.97 512818.51 15600.00 8872 121.89 3847.77 390137 5590.49 564181 1219.15 HS 0.00 7.15 89.53 8047980.28 512701.48 15700.00 88.72 121.89 3849.89 3904.09 5875.72 5694.46 1304.03 445 0.00 7.16 89.53 847927.59 512788.42 15800.00 88.72 121.89 3852.22 390632 576095 .6747.28 1388.91 415 0.00 7.18 89.53 6047874.91 512871.37 Cry 2/100 15815.16 8872 121.80 385256 300666 5773.87 -575529 1401.78 32266 0.00 7.17 89.53 6047886.92 512881.25 51-92 T9113 15890.64 90.00 12270 385340 3807.50 583848 -5795.82 1465.58 38376 2.00 7.17 88.14 6047828.70 512948.10 15900.00 90.15 122.82 385339 380710 5848.55 580088 147315 38.376 2.00 7.17 8708 8047821.55 512955.98 16000.00 9171 • 124.06 385176 3805.88 5933.16 -5855.77 1555.88 38.396 2.00 7.18 8624 60477138.60 51303949 End Cry 18026.73 92.13 124.39 3850.87 3804.07 505848 .5870.60 1578.97 HS 2.00 7.18 85.78 6047751.70 513081.00 16100.00 92.13 124.39 3848.14 390224 802052 5912.18 1639.39 110 0.00 7.19 85.78 6047710.44 513122.08 16200.00 92.13 124.39 3844.41 389851 810791 -5988.60 1721.88 85 0.00 7.19 8518 6047854.13 513201.62 Crv2/100 18231.66 92.13 124.39 384324 3897.34 8135.57 .5986.47 1747.06 117.688 0.00 720 8578 8047838.31 513230.75 18300.00 91.50 125.80 384107 3895.17 8185.85 5025.64 1803.92 117.7216 2.00 720 8822 8047507.22 513288.77 1640000 90.57 127.37 383027 389337 6284.80 508509 1884.30 117.756 2.00 721 8688 6047537.00 513367.23 314279114 18407.28 90.50 12750 383920 389330 6281.32 5089.50 1600.08 111.176 2.00 721 8893 8047533.50 513373.00 16500.90 89.82 129.23 383894 389304 637535 -614706 1062.78 111.478 2.00 722 8734 804747600 513445.80 1660000 88.09 131.00 3839.89 389389 646722 5211.54 2039.20 111.488 2.00 723 87.79 8047411.70 51352231 End Cry 16877.11 88.53 132.52 3841.50 3895.60 653890 -6252.94 2008.67 HS 2.00 724 88.14 0047350.41 513579.85 18700.00 8853 13252 3842.09 3896.19 6560.28 -627840 1113.53 HS 000 724 88.14 8047344.97 513596.74 16800.00 88.53 132.52 384466 3898.76 685388 4345.97 218721 HS 0.00 724 88.14 6047277.53 513670.51 Cry 2/100 16873.33 88.53 132.52 3848.55 3900.85 672217 4395.51 2241.23 10276 0.00 725 88.14 6047228.07 51372481 16900.00 89.05 13262 3847.11 390121 6747.09 4413.55 1260.87 10276 2.00 725 87.61 8047210.06 513744.27 SIS219115 1692286 8.50 132.70 3847.40 3901.50 6768.47 4429.04 2277.88 15.336 2.00 725 87.15 8047194.80 513761.10 17000.00 9099 133.11 384707 3901.17 6840.72 -6481.55 2334.18 15.336 2.00 726 85.62 6047142.18 513817.68 End Cry 17084.36 92.23 133.45 384526 3899.36 6901.12 -652585 2381.02 HS 2.00 7.26 84.34 6047008.15 513864.58 Cry 2/100 17094.87 92.23 13345 384408 3898.18 6929.78 -654682 2403.15 101.85R 0.00 720 84.34 8047077.23 513886.74 17100.00 92.21 133.55 3843.88 389798 803480 -6550.15 2406.87 101858 2.00 727 8435 6047073.70 513890.47 17200.00 91.80 135.51 384039 380449 7020.15 4520.23 2478.11 10193R 2.00 727 84.48 6047003.74 513961.81 17300.00 91.38 137.48 3837.61 3891.71 7124.79 4892.72 2548.91 101.068 2.00 728 84.62 6046931.37 51403074 17400.00 90.97 13942 383556 388986 722137 4767.53 2813.26 102.02R 2.00 7.29 84.76 6046858.67 514097.17 $132 19116 17439.81 9080 140.20 3834.95 3889 05 7280.07 419794 2838.94 93.03R 2.00 729 84 82 604682830 514122.90 1750000 90.72 141.70 3834.15 388825 7318.83 -884467 2576.88 93.058 2.50 730 8468 6046779.83 51418088 17600.00 90.59 144.20 3833.01 3887.11 7417.18 4924.48 2737.10 03.078 2.80 7.31 8449 5045899.93 514221.24 17700.00 9045 146.70 3832.10 388620 7516.18 -7086.83 2793.81 93.10 2.80 7.32 8431 8048817.67 514278.07 End Cry 17750.49 90.38 147.96 383174 388584 7668.38 -704932 2821.06 HS 2.50 7.32 84.22 804657522 514305.39 17800.00 80.38 147.90 383140 3885.50 751557 -709129 2847.33 HS 0.00 7.32 8422 804853330 51433172 Cm2.5/100 17831.94 90.38 147.96 3831.19 3885.29 7647.47 -7118.37 286428 80.41- 0.00 7.33 84.22 8048506.25 514348.71 17900.00 8087 146.28 383056 388466 771511 -7175.51 2601.23 80421. 250 7.33 84.15 6046449.17 514385.74 5152 196 17 17955.91 90.90 14490 382980 3883.90 7770.50 -7221.64 293282 85.941. 2.50 734 84.09 8046403.10 514417.40 18000.00 9099 143.58 382907 3883.17 781402 -725741 2058.58 65.90. 300 7.34 84.17 0046367.37 514443.21 18100.00 9120 140.59 3827.15 388125 791204 -7338.28 3020.01 86.02- 3.00 7.35 8436 6046288.61 514504.76 18200.00 91.41 137.59 3824.87 3878.97 800890 -7111.82 308547 86.09-5 300 736 8457 6015213.17 514570.33 16300.00 91.61 134.60 3822,24 3876.34 810433 -7483.84 3154.79 86.17E 3.00 7.37 8479 6045141.27 614630.75 End Cry 18322.02 91.68 133.04 3821.81 387571 8125.12 -7499.20 3170.54 HS 300 737 8484 6048125.93 514055.53 CIV 3/100 18334.52 9188 133.94 382125 3875.35 813690 -7507.87 3179.54 102.61. 0.00 737 84.84 8018117.28 511654.54 18400.00 91.23 132.02 3819.60 3873.70 8198.25 -7552.80 3227.43 102641- 3.00 738 8554 604607273 51471219 515210118 1847250 9075 129.90 3818.35 3872.45 828524 -7600.02 328217 98.16. 3.00 739 86.32 8048025.30 514707.30 18500.00 90.87 129.36 3818.01 387211 8290.40 -7617.55 330335 98.2-5 200 739 8818 6046007.80 514788.50 18800.00 90.39 127.38 3817.09 3871.19 8381.00 -7679.62 3381.75 98.221 2.00 739 8706 6045945.88 514866.99 End Cry 18819.08 90.16 125.81 3816.71 3870.81 845158 -7726.78 344524 HS 2.00 7.40 8752 8045898.82 514930.55 1870000 90.18 12581 _ 3818.85 387075 8470.12 -7730.00 346220 HS 0.00 7.40 87.51 8045886.61 511047.53 18800.00 90.16 125.81 381637 3870.47 8558.74 -7797.51 3543.30 HS 0.00 7.11 87.52 8045828.23 515028.71 18900.00 90.18 125.81 381609 3870.19 864737 -7858.02 3624.39 HS 0.00 7.11 8752 6045768.85 515109.88 Cry2/100 1898089 90.16 125.81 381592 387002 8703.81 -7893.29 367604 28.538 0.00 7.41 87.52 804573287 515161.59 51295279119 18988.75 80.60 126.05 3815.75 3869.85 8726.05 -7907.99 380633 30.998 2.00 7.42 8705 8045718.00 515181.90 19000.00 90.79 128.17 3815.61 388971 8736.04 -791482 3705.42 30.998 2.00 7.42 8684 6045711.39 515191.00 End Cry 19014.93 91.05 128.32 381537 388947 874932 -7923.44 3717.48 HS 2.00 7.42 86.56 8045702.58 515203.05 19100.00 91.05 126.32 3813.82 386792 882505 -7973.82 3785.99 HS 0.00 7.42 86.56 804565211 515271.65 19200.00 91.05 126.32 3811.99 388609 9914.07 -803304 3856.55 HS 0.00 7.43 86.55 604559323 515352.29 19300.00 9105 128.32 3810.15 3864.26 900300 409226 3947.11 HS 0.00 7.43 88.58 6045531.14 515432.04 19400.00 91.05 126.32 380833 388243 9002.11 4151.48 4027.67 HS 0.00 7.44 88.56 8045175.05 515513.58 1950000 91.05 128.32 380649 3860.59 9181.13 4210.70 4108.23 HS 000 7.44 86.55 8045415.80 51560422 TO -. 19505.18 91.05 ` 12632 3806.40 3880.50 918574 4213.77 411240 0.00 744 88.56 6045412.90 515598.40 Survey Type: Del Plan Sunny Error Model: ISCWSA Rev 0.-3-D 95.000%Confidence 2.7955 eipne Survey Program: MD From MD To MU Free DescriptionMI Mtl IPo Survey Tool TTM Borehole/Survey 0.000 41.000 1/100.000 SLB_NSG455HOT-09061 Only 512952/512052(P4b) 41.000 500.000 1/100000 SLB_NSG4SSHOT 5129-52/512952(P4b) 500.000 2000.000 1/100.000 SLB_MMWDSTD 512981/5129.52(P4b) 2000.000 4676000 1/100.000 SLB_W04GMAG 512942/S129-02(P491) 4676.000 8200.000 1/100.000 SLB_MWDSTD 012952/$12952(P48) 4875.000 9992000 1/100000 SLB MW009MAG S129$2/5129-92(P444) 8992000 11500.000 1/100.000 SLB MWD-STD 312052/5129-$2(P45) 8992.000 19505.183 1/100.000 SL9_91W000MA0 512942/S11942(P41) Legal Deacripbon: Normin0(y) EasQng(XI Surface:4437.8 051 14382 FEL 519 1149 09E UM 6053619450 511473.700 ' 9-52 heel:2073 FSL 656 FEL 24 T149 98EUM 6051248900 507175.100 N-521911:1810 FOL 212 FEL 24 T149 R8EUM 6050988.400 507619700 e1-521972:1547 FSL 4861 FEL 10 71414 69E0M 8050723.900 508064200 • 4-021913:1284 FSL 4418 FEL 19 T1411 R9EUM 6050461100 508508 800 9-521961 1020 FSL 3975 FEL 19 T1411 R9EUM 6050108.800 508953.300 e1-51 tot 5:757 FSL 3532 FEL 19 T149 R9EUM 6049936300 509397800 9.42 t976:494 051 3089 FEL 19 T149 R9EUM 6049673.800 509842 400 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:30 AM Page 3 of 4 MD Incl M011,0* TYDSS TVD VSEC NS EW TF DLS Directional Exclusion Zonan Zone Northing Fasting CommmM (6) (") (°) 00 ON (8) (8) (8) (°) (51008)DMlkulry Index Alert Argl°' (SUS) (NUS) 9.821917:231 FSL 2645 FEL 19 714N R9EUM 6040411300 510286.900 9-82 t9t 8:5248 FSL 2202 FEL 30 714N R9EUM 6049148/00 510731.500 9-82 7919:4985 FSL 1759 FEL 30114N R9EUM 6048888.300 511176.000 si-8219110:4721 FSL 1316 FEL 30714N R9EUM 6048823 800 511620.800 9-8210111:4458 FSL 873 FEL 30 714N R9EUM 6048361.300 512065.100 9-8210112:4195 FSL 429 FEL 30 714N 89E089 8048098.800 512509800 4-82tut 13:3922 FOL 5272 FEL 29714N R9EUM 6047826.700 512948.100 9-s210t 14:3628 FOL 4849 FEL 29714N R9EUM 6047533.500 513373.000 4-8289116 3289 F614463 FEL 29T14N R9EUM 8047194.600 513761.100 4-8289116:2910 FSL 4103 FEL 29T14N R9EUM 8046828.300 514122.900 0-s2 10t 17:2496 FSL 3811 FEL 29714N R9EUM 6040403.100 514417.400 9-8210118:2117 FSL 3463 FEL 29714N R9EUM 6046025300 514767,300 929-82[9119:1809 FSL 3050 FEL 29714N R9EUM 8045718 000 515181.900 t6/BHL:1503 FSL 2635 FEL 29714N R9EUM 8045412.900 515598.400 • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:30 AM Page 4 of 4 Schlumberger 2rnn � WELL el LD STRUCTURE S129-S2 (P4b) Nikaitchuq Spy Island Magnetic Parameters Surface L°oNm NAD21 Nelda State Plane,20e 04,US Feet Miscellaneous Motlef. BGGM 2011 Dp: 81.07, Date: February 29,2012 Lel: N 70 33 21.742 Northing: $053019.458US Grid Com:008813898° Slot SP20 TVD Ref Rotary TebBy54,18 above AWL) Meg Dec: 20.782° ES: 51840.SnT Lon: W 1485421218 Whitey: 511413.10 MMS Sule Fact'.099990015 Plan: 6120-S2(PCB Sny Date:October 18,2011 -2250 -1500 -750 0 0 0 RTE KOP Cry 1.5/100 Cry 4/100 750s o 750 `3 ; da Cry 0.51100 V2 1500 1500 Cry 4/100 V-1 LO End Cry LO 2250 •nu TOP(uc4� 2250 N 13-3/8"Ca) f6 • U co Q cm 4/100 4 `- G-2 Coal Bed Marker Fault 1 3000 3000 Lower Ugnu • Cry 2.76,100 81-82 heel 211!e4eclvR7ba...... • klEegLaDAB-t • • •••• N SeLrerlce ase .41 3750 614 'rnottx-s-rdd ,_. um 3750 End Cry End Cry 9-5/8•'Gag Cry 2/100 5129-52(P4b) 4500 4500 -2250 -1500 -750 0 Vertical Section(ft)Azim=153.4°Scale=1:600(ft) Origin=0 N/-S,0 E/-V No o 0 ) e. 0 ( l.. � a) § ! / 0 = i i - ® 3 & U ` � = g ; §� s ° .1) k ° COD & /; 3 § . . ..f . \ 2 _1 . CO X33 ' ii 2 `| k » C ! � � . `i ` § &3 /! VI .« e i7, G! © ' Z . CO ) v. --- - ii ! ■ •- \ '2 V' " k � / | § » ii a:. } 3 0 ƒ -23/ 0 - 3 § 0 ! ! ■ ; ! .- | ; - . • _:; 3 . ) !!; - 1i/ - \ 0 A = 11 § ` ' R \ _ !� 0 [ . ..a § C.) ; - e , 2 • 3 § e k ed E a ¥ !§| 2 ; • 6 ! ; :! - — 33 8k ro | C ... }I VI ! { 5 j H � ° > ! ! ,E 12 LL,;E" a 0 §..� CV & ; E. / � a1 \ ,& ) k 2aN—COs, § 2 _ . §/ \ +} \w § § 14. 2 . § 2 •_ § H IL ) :s C ] S : / a , . / | | Ili Q 0 �.. | 'If_ 0 ( );000=33SCIA! Schlumberger ani WELL FIELD STRUCTURE SI29-S2(P4b) Nikaitchuq Spy Island Magnetic Patemetery 5urtace Locatim NAD27 Ala,Fe State Plane,Zone 04 US MU (. BGGM 2011 Dp'. 81071° Date. F. O Guary 20.2012 LN 703327.742 Northing m bilg. 005361045 BUS Grid Co008lot 873006° Selb Mo. SP20 TVD Ret Rotary T0bI(54.18 above MSL/ Meg Dec'. 20.682° FS'. 578406,7 Lan'. W1405421.218 EaOOy. 511473.706US Scab Fed'.000000015 P. 5129-S2(174h) SIW D.October 18.2011 -4500 -3000 -1500 0 1500 3000 1500 RTE 1500 N KOP Cry 1°5/100 End CivCry 41100 Cry 4/100 QM 4/100 0 • 0 134/8-Cog Cry 0.5/100 -1500 -1500 9.518'Cog SI-S2 heel NO Cry 2/100 SI-S2 Tgt 1 Cry 2/100 End Cry End Cry SI-S2 Tgt 3 A Cry 2.751100 End Cry •A End Civ - End Cry Z -3000 - -3000 Cry 2/100 SI-S2 Tgt 6 SI-S2 Tgt 2 = End Cry Cry 21100 : End v O tr in SI-S2 Tgt 8 _� Cry 2/100 Cry 2/100 4— 51-52 Tgt 4 - 11 End Cry • Cry 2/100 - • ' CFw21100 SI-S2 Tgt 10 /n -4500 11< • Cry 2/100 -4500 81-62•/ b: E9d.Cry SI-S2 Tgt 7 Cry 2/100 End Cry • -S2 Tgt 12 End CryV End Civ End Cr,/ V V Cry 2/100 Cry 2/100 51-S2 Tgt 9 SI-S2 Tgt 13 End Cry End Cry • Cry 2/100 Cry 2/106 SI-S2 Tgt 14 SI-S2 Tgt 11 End C 211oe• -6000 -6000 End'Cry SI-S2 Tgt 15 Cry 2/100 SI S2 Tgt 16 • End Cry 5129-52 Tgt 19 Cry 2.5/100 Cry 2/100 End Cry -7500 S&SZIgt.tz -7500 End Cry TD Cry 3/100 SI-S2 Tgt 18 - End Civ SI29-S2(P4b) -9000 -9000 -4500 -3000 -1500 0 1500 3000 «< W Scale=1:1500(ft) E >>> hlmr -41101** Sc u be ger ( nn "ALL S129-S2 (P4b) Flap Nikaitchuq I 07RUCTURE Spy Island 04081 Pelannt 20 Surface Location NAM)Ales.Stele Pore.Zan 04.US F. SIP. nese MoBel: SGGM Att pip: 20.882 Dere: 570420 28.Aft Let N 70332].102 Northing 0053019 45 AUS G.Com'.008873098° Std'. SPR TVD Ref: Raary TeM 251.18 above MSLI Meg Dec'. 2.882° FS'. 57.0(MT Lm. W 149 54 21218 Easing 511473 70 MUS Scale FM:008890015 P. 5129$2(POW S.Dela:October 18.2011 SI13-FN4(P2) SP18-N5PB1 Field SP18-N5 MWD-STD S102-SE6(P2) S120-N4 (P4) SP18-N5 field survey S108-FN6(P2) SP01-SE7(P2) SP16-FN3(P3) SP10-FN5(P2) SP18-N5PB1 field survey SP11-N7(P2) S119-FN2 (P2) 4 Ia -3000 500 0 1501 •'0 / 300 • •P05-FN7 )} (-r nt1/4 3000 – A4\, \ 3000 • —23-N3 y� 0, dohs i ••� d'_ '' 4° 3p0 0 Tip Q °o S125-N2 (F2),�e�,�4°• �°• e .SrVD�:'� �� • �'c'° • \ y : ' t• ".�34- San.\ P:46 .� ..YC,.' 1500 – ��so• �N �5q . ., SSE5 (P2)0c• l• ` It o tir . et • #58 \k .k`` , C • J c° ti` a o . -' ?';..' 5107-SE4 (P2) 0, .*. .1-b ",9" ,,'s---;il 41" '1',1%. '' •B1 (P1) • VP A "�` ,oq'°o(,00 e'C. /. 1!�•�;1q'N3 su s Pq .3 �i••:R OOD ND Z -1500 –•A. �- �• �•� -19-S1 ' �.�•zJcdrt- -1 0 W1 ) h^Q o .P152-SE3(P2) •90 olh�� igun 1 h4^~4^~ ,1 �O � �1�Tv� .fes dp Tuva.. ST • l �4h . h o -30'0 – Kiin 1 PB1 :4 •••,„ " • I'I3}°�E2 (P2) .iiv ^h • ' T, SP33-W3h P2) /. S 4500 -•••11101•9' ''Q h}}p^ 46 �°,a �°• / SP �-SE1 (P2) • • 4h �.;hqh qh 0115-S4(P9b) °� '4 h • SI35 ' 4(- h^ e E `§iTL 001 h^ �o �~ O • .• �, SP36-W51AP2 `� §' �o• -6000 ^� 4' ,�q>` �C'�q•• • - -6000 2 • ' 1-09 ti qh. <4°• • •�° o• �G��;'°• •�Q° 4`•,f' .f'° OP09-S1 huh a E • ..,f .f • h N 'L 4� C ^�hyo- .. 027OS • -7500 – – -7500 b -03 �° • ThOVic• 4 O /�' h hbyye P4b O• ,may O• .-; "' '� 0113-03 ' ' OP10-09 r0115-S4'(P9b) OP'14-S3 -450 -3000 -1500 0 1500 3000 <<< W Scale = 1:1500(ft) E >>> SI29-S2 (P4b) Viiiikt Scblumberger 2n fl WELL SI29-S2 (P4b) gINikaitchuq `II<I""n" Spy Island NAD27 AleeFn Slale Plane.Zone PM,US Feat Mixelklwon MatleI��PBGGM 2011 1.ii Lel^ L Nl']0332].]42 NMbitg: 0053810.4511US Gntl Corn: oogo3000° Slot: SP. TVD Rel: Rotary Tabbl5111 above MSL1 Ion W1.5421.218 Eaeling: 5114]3.]01115 Scale Fact oO B0g00015 Plan 312&S2(P4b) S.Dere:October 18,20111 SP12-SE3 (P2) SP1O-FN5 (P2) SP18-N5 MWD-STD S113-FN4 (P2) S108-FN6 (P2) S120-N4 (P4) S107-SE4 (P2) SP16-FN3(P3) SP05-FN7 (P2) SP04-SE5 (P2) SP12-SE3 (P2) S102-SE6 (P2) -1600 -1200 ,, -800 -40o a 400 SP18-N5PB1 field survey 9 aF 1200 `a°• • 1200 9-FN2 (P2)e<41 • SP01-SE7 (P2) • 1' ''CJ -FN1 (02 ° llf, S' e ' P2) • ° ��O• 0,,,,,,• .P12-SE3(P2) - 800 '` 800 1� A N., .18-N'P MWD-STD A A ° Z SI29-S2 (P4. ~�c ° SP18-N5P:1 field survey 400 > • 400 0 34-N Sand (P2) 0 71: .1,0 i • 1 II Aee '�• 0 "4 '7,,74.1.,.,* 0 •,III .,;4, �,:`11;-• ..1 . , ;°° SP18-N5•131 field survey v 12 ••,14,'..,`.::. \\) SP18- 5 MWD-STD v \ -400 \• •21,nli,;41 -400 ( ) .-2." . '/ • x,.117-SE2(P2) o 0,,,,,. / • 10010 TVD ti• -800 SP24-SE1 (P2) , °• -800 ,.S, a J / a 1525- • "gur -ys 1 1 1 1 1 1 -1600 -1200 -800 -4.0 0 400 «< W .cale = .400 t) > -> S120-N4PB1 (P1) SP24-SE1 (P2) S125-N2 (P2) SP36-W5 (P2) SP33-W3 (P2) S132-W2 (P2) S135-W4 (P2) SP23-N3(P6b) SP30-W1 (P2) SP27-N1 1,-,* Scblumberger 2n n SI29-S2 (P4b) F'F`D Nikaitchuq """"`"" Spy Island SUAece Location N53810 5RO Stele Plere.Zane M,US Feat .i Mopel Boom2011 [Op 81071° ES: Fed001,10 2012 Ld N ]0332].]x2 90lOS S0.M 70:0088]3980° dory T18.2011R above M8L1 Map Deo. 20802° F5. 5]Bx98nT Lm. W1x95121118 Ee&ig'. 511x]3.108U8 Scab Fx1.009980015 i. "i1 i,� bSrvy Dale:October 10.2011 SP1O-FN5(P2) S108-FN6 (P2) S107-SE4 (P2) SP05-FN7 (P2) SP12-SE3 (P2) S113-FN4 (P2) SP04-SE5 (P2) S120-N4 (P4) S102-SE6 (P2) SP16-FN3(P3) -300 -21: -100 0 100 200 I I I 400 -- 400 300 -F "2) 300 10011 Tyr) A ( • 1 A \010.1200 \� '' -c•19• 200 Z 00 • q\°D • \` I \100 \ 100 U / N , \ V 0 __` \ o 0 0 y 18-N5':1 field surve SP22-FN1 (P2) 11111\ \ o •\a`0 O SP24 SE1 (P2) •o \D.`` 100 . oar : `c }PQ P -N7(P2) SI29-S2 (P4b) • 100() 13 )L . , '‘' %1111 .I17-SE2 (P2) -300 -200 -100 0 1f0 200 S114-N6 (P2) « r S - e = :100(f E > SP36-W5 (P2) S135-W4 (P2) S120 N4 (P4) SP18-N5 MWD-STD Sx34-N Sand (P2) SP27-N1 S120-N4PB1 (P1) SP33-W3 (P2) SP23-N3(P6b) S132-W2 (P2) SP30-W1 (P2) S125-N2 (P2) SP23-N3 surveys S120 N4 (P4) Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907)273-1766 Fax (907) 561-8367 Friday Jan 12, 2012 Joe Longo, Luca Borri, Spy Island SI29-S2 (P4b) ENI Petroleum Doyon 15 Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the Schlumberger close approach anti-collision standards (S002 v5.1). Method of analysis: 1. A list of wells to be analyzed is created in SLB DOX drilling software. The list is created using in house procedures by evaluating the surface location of the subject well and scanning the AOGCC database list of all wells in the area. Wells are then loaded into the database using in house and AOGCC records. 2. Wells are analyzed using the SLB DOX Anti-collision module with major risk safety factors applied. Wells failing the surface anti-collision allowable deviation rule and/or wells having an oriented separation factor (OSF) less than 1.5 are noted as failing either minor or major risk criteria. Further analysis of those wells is subject to Schlumberger's exemption process. 3. All depths are relative to the planned well profile. Survey Program: MD From MD To EOU Freq (ft) (ft) (ft) Survey Tool Type 0 000 41 000 1?100 000 SLB_NSG+SSHOT-Depth Only 41 000 600 000 1/100 000 SLB rJSG+SSHOT 600 000 2000 000 1/100 000 SLB -STD 2000 000 4676 000 1/100 000 SLB_P.1L^JD+GPv1AG 4676 000 6200 000 1/100 000 SLI MWD-STD 4676 000 5992 000 1/100 000 SLB_MWD+GMAG 8992 000 11600 000 1/100 000 SLMWD-STD 8992 000 19505 183 1100 000 SLB MWD+GMA.G Survey Interval Surface hole— 1 per stand —93 ft Intermediate hole—93 ft Final hole— 1 per stand — 93 ft Close Approach Analysis results: Under method (2), note: All wells pass major risk rules. One well plan fails the minor risk rule. The well is greater than 100 feet away and will can be replanned to reduce the risk. There may be magnetic interference below the rig and around the conductor, so a single shot is planned to be run for 500', or as necessary. A Traveling Cylinder with tolerance lines, referencing the planned wells, will be drawn up. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A traveling cylinder will be provided. Crispin Chatar 1/12/2012 • voitso Schlumberger S129-S2 (P4b) Anti-Collision Summary Report en ft Analysis Date-24hr Time: January 12,2012-10:26 Analysis Method: 3D Least Distance Client: Eni Petroleum Reference Trajectory: SI29-S2(P4b)(Def Plan) Field: Nikaitchuq Depth Interval: Every 100.00 Measured Depth(ft) Structure: Spy Island Rule Set: DMA AntiCollision Standard S002 v5.1/5.2 Slot: SP29 Min Pts: All local minima indicated. Well: SI29-S2 Borehole: SI29-S2 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 Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major SP30-W1(P2)(Def Plan) Fail Minor 7.97 6.75 1.35 N/A 0.00 000 CtCt<=15m<15.00 Enter Alert 1 7.031 4.611 0.411 N/A 300.00 299.99 MinPts 26.02 22.18 19.39 WA 500.00 498.91 CtCt<=15m>15.00 Exit Alert 89.15 84.02 82N 22 5 700.00 893.22 MinPt-O-SF 824.00 619.9 I} 77.83 1503.71 1354.10 MinPt-O-SF 2413.64 2363.301 2338 66 48 96 350000 2271.18 MinPt-O-ADP 2794.80 2712.44 267176 34.331 4900.00 2548.14 MinPt-O-SF 384.93 298.57 255.88 4.50 7800.00 3464.89 OSF<5.00 Enter Alert 117.38 30.34 -12.67 1.35 8400.00 3627.34 OSF<1.50 Enter Minor 1 109.071 26.541 -14.231 1.331 8500.00 3646.88 MinPts 113.37 36.90 -0.84 1.49 8600.00 3663.98 OSF.1.50 Exit Minor 281.94 219.38 188.5r :1111 9689.96 3754.80 MinPt-O-SF 406.93 324.58 283.91 4.99 10000.00 3792.95 OSF.5.00 Exit Alert 8379.97 8262.32 8203.98 71.82 19505.18 3860.50 TD SP27-N1(Def Survey) Warning Alen 16.02 14.80 2.98 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1 15.54 13.631 2.491 N/A 200.00 200.00 MinPts 40.67 36.90 27.63 N/A 500.00 498.91 CtCt<=15m>15.00 Exit Alert 748.91 739.69 735.6:1 imm E 160000 1416.14 MinPt-O-SF 2089.17 2016.59 1980.7. 30 16 4800.00 2528.36 MinP1-O-SF 1948.54 1877.59 184261 NM= 500000 2567.93 MinPt-O-SF 593. 535.41 506.83 10.37 7100.00 3208.10 MinPt-CtCt 596 6 534.701 504.21 9.77 7200.00 3247.20 MinPts 651.34 576.30 539.28 8,781 7500.00 3360.75 MinPt-O-SF 720.57 636.43 594.85 865 7729.03 3441.35 MinPt-O-SF 888. 793.95 747.00 9.45 9300.00 3733.59 MinPt-CtCt 889.1 791.3 742.85 9.17 9400.00 3738.99 MINPT-O-EOU 893.54 792.74 742.83 8.94 950000 3743.60 MinPt-O-ADP 939.72 83096 777.08 8.71 9826.23 3789.84 MinPt-O-SF 3667.43 3602.12 29. 14300.00 3883.37 MinPt-O-SF 1 8380.10 8259.61 8199.86 70.12 19505.18 3860.50 TD 5132-W2(P2)(Def Plan) Warning Alert 31.92 30.69 6.14 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1 27 641 24.5311 861 N/A 400.00 399.78 MinPts 33.45 29.38 7.67 N/A 500.00 498.91 CtCt<=15m>15.00 Exit Alert 3556.80 3480.8: 3443 46 47 50 4600.00 2488.79 MinPt-O-ADP 1319.00 1218.83 _ 1169 8400.00 3627.34 MinPt-O-SF=N5J4613.39 8600.00 3663.98 MinPts 824.13 731.42 685.60:-.:/ 10370.14 3815.46 MinPt-O-SF 700.20 6326 11111EMS 10.50 10800.00 381420 MinPt-O-ADP M111Ct 600.24 11.23 10900.00 3814.28 MinPts 884.04 80322 763.3$MEE 11800.00 3813.05 MinPt-O-SF 7507.22 7396.79 734207 68.58 19505.18 3860.50 TD S125-N2(P2)(Def Plan) Warning Alen 32.04 30.81 6.16 N/A 0.00 000 CtCt<=15m<15.00 Enter Alert 1 32.041 30.031 6.161 WA 200.00 200.00 MinPts 41.12 37.94 15.24 N/A 400.00 399.78 CtCt<=15m>15.00 Exit Alert 1529.03 1463.27 1430.8.IIMER 4700.00 250858 MinPt-O-SF 1 1028.31' 966.92 936.72 17.01 6100.00 2831.81 MinPt-CtCt 1032.0.`,11 965.04 932015 6200.00 2865.45 MinPts 1168.10 1076.19 1030.721 12.841 6700.00 3050.80 MinPt-O-SF 1 1789.091 1679.38 1625.01 16.44 9700.00 3755.69 MinPt-CtCt 1789.3 1677.18 1621.59 16.09 980000 376645 MINPT-O-EOU 1790.08 167726 1621. 18.00 9826.23 3769.84 MinP1-0-ADP 2149.43 1992.21 1914.0 13.751 1150000 3813.48 MinPt-O-SF 7789.05 7668.07 7608.07 64.90 19505.18 3860.50 ID SP33-W3(P2)(Del Plan) Warning Alert • 40.01 38.78 7.76 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1 35.871 32 851 3.621 N/A 400.00 399.78 MinPts 37.50 33.34 5 25 WA 500.00 498.91 CtCt<=15m,15.00 Exit Alert 3795.93 3682.28 3625 95 3372 6500.00 2973.86 MinPt-O-SF 1066.79 977.36 933.14 MjElal 10300.00 3814.86 MinPt-O-SF 864.2• 805.6$MEMO 14.97 11000.00 3814.36 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 1 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) TVD(ft) Alert I Minor I Major 1063.87 984.33 945.0511 13.5 11700.00 3812.62 MinPt-O-SF 7880.04 7768.91 7713.83 71.53 19505.18 3860.50 TO SD37-DSP1(Def Survey) Warning Alen 80.68 79.45 47.87 N/A 0.00 0.00 Surface 46.17 41.82 13.36 N/A 600.00 596.88 CtCt<=15m<15.00 Enter Alert I 36.061 31.211 3251 N/A 700.00 693.22 MinPts 47.95 42.58 1514 NA 800.00 787.47 CtCt<=15m>15.00 Exit Alert 4628.40 4605.58 4594 7011 212 671 6200.00 2865.45 MinPt-O-SF 4167.811 4015 691 3940.12 27.57 11600.00 3813.05 MinPts 4185.84 4032.06 3955.66 27.39 12000.00 3812.79 MinPt-OSF 9206.12 9074.69 9009.47 70.57 19505.18 3880.50 TD Sx34-N Send(P2)(Def Plan) Warning Alert 48.00 46.78 15.19 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1 36.231 33.171 3.431 N/A 500.00 498.91 MinPts 40.56 36.87 7.75 N/A 600.00 596.88 CtCt<=15m>15.00 Exit Alert 111 1559.221 1531. 1518.29 58.64 3600.00 2290.96 MinPts 1561.47 1531.66 1517.29 54.29 3700.00 2310.74 MinPt-O-ADP 2256.06 2172.91 2131 83i 27.4511 5700.00 2714.06 MinPt-O-SF 11 3258.00 3112.51 3040.26 22 54 11400.00 3813.90 MinPt-CtCt 3259.8"96 3109.95u 3035.50 21.89 11500.00 3813.48 MinPts 3264.04 311189 3036.31 21.591 11600.00 3813.05 MinPt-O-SF 8633.86 8511.98 8451.53 71.41 19505.18 3860.50 TD SP23-N3 surveys(Non-Def Survey) Warning Alert 63.09 61.18 MEM N/A 0.00 0.00 MinPts 64.98 47.77 32.17 N/A 300.00 299.99 OSF<5.00 Enter Alert 7237 EIMEa 3620 3.09 400.00 399.78 MINPT-O-EOU 88.89 56.42 41.15 imica 500.00 498.91 MinPt-O-SF 295.62 228.40 195.751�4.50 1000.00 967.84 OSF>5.00 Exit Alert 4950.86:®ansip min 6100.00 2831.81 MlnPta 3848.78 3582.86 3450.70 18 11600.00 3813.05 MinPt-O-SF 3781.49 3528.6' t. rS 15.04 12200.00 3813.11 MinPt-O-ADP 3781. •.r.580E 3402.97 15.05 12204.58 3813.12 MINPT-0-EOU lllllllllE! 3528.87 3404.09 15.14 12274.92 3814.10 MInPt-CtCt 837927 8154.14 8042.39 37.48 19505.18 3880.50 TD Kigun 1(Def Survey) Warning Alert 4956.71 4954.80 4923.91 N/A 000 0.00 Surface 39458 298.62 252.19 4.22 8600.00 3663.98 OSF<5.00 Enter Alert 268.75 175.18 130.39 2.961 8800.00 3690.53 MinPt-0SF 1 253.891 168.511 127.93 3.08 8872.53 3697.55 MinPts 278.55 214.28 184.16 4.56 9000.00 3708.66 OSF>5.00 Exit Alert 10419.35 10346.62 10311.06 146.49 19505.18 3860.50 TD OP14-S3(Def Survey) Warning ANA 6581.79 6388.02 6292.54 34.45 0.00 0.00 Surface 1271.90 1017.71 894.5 5 131 9571.37 3746.89 MinPt-O-SF 1237.89 986.63 864.8 5.05( 9975.73 3789.81 MinPt-OSF 1215.06 96506 843.60 498 10300.00 3814.86 OSF<5.00 Enter Alert IIIIIIIME=Mal 825.30 4.86 10900.00 3814.28 MinPts 1202.03 948.2 AEREEIE, 11000.00 3814.36 MinPts 1205.1>MEM) 825.67 4 83 11239.90 3814.55 MINPT-O-EOU 1206.12 949.9 0 4.81 11300.00 3814.33 MinPt-O-ADP 1214.19 954.85 828. ' 11500.00 3813.48 MinPt-O-SF 1220.95 969.98 848.21 4.98 12000.00 3812.79 OSF>5.00 Exit Alert 1215.10 965.92 844.96 4.99 12200.00 3813.11 OSF<5.00 Enter Alert 1MMO 965 8• 844.9 111 12204.58 3813.12 OSF>6.00 Exit Alert 1149.74 914 19800.1. 5.01 13291.27 3856.84 MinPt-O-SF 1148.72 9130>1r 799.8 502 13320.58 3858.20 MinPt-O-ADP 1120.77889 95 778.34 4.99 13700.00 3877.67 OSF<5.00 Enter Alert onEE2 886 4:�'• 4.96 13825.39 3883.20 MinPts 1117.78 886.67 774.6 54/ 13900.00 3884.18 MinPt-O-SF 1124.09 893.69 781.92 5.00 14100.00 3883.78 OSF>5.00 Exit Alert 1464.05 1246.01 1139.76 IMEE2 16873.33 390065 MinPt-O-5F rr 1067.59 848.44 741.98 4.98 18300.00 3876.34 OSF<5.00 Enter Alert 1 1052.73 832.321 725.27 4.89 18600.00 3871.19 MinPts 1054.29 833.57 726.34 4 8 18679.08 3870.81 MinPt-O-SF 1 1026.091 800.661 690.49 4.63 19505.18 3860.50 MinPts S135-W4(P2)(Def Plan) Paaa 56.00 54.77 23.19 N/A 000 0.00 Surface MEE 50.32 20 49 N/A 400.00 399.78 MinPts 54.00 49.69 21.20 N/A 500.00 498.91 MINPT-O-EOU 3137.42 3072.7' 3040.92 49.30 4400.00 2449.23 MinPt-O-ADP 1397.59 1301.26 1253.59 MUM 9826.23 3769.84 MinPt-OSF 1079..4 mum 990.0 18 37 10800.00 3814.20 MinPts MIME 1019.76 991.17 18.83 1090000 3814.28 MinPt-C1Ct 1313.61 1236.32 1198 161 17.2011 11700.00 3812.62 MinPt-O-SF 8099.76 7991.23 7937.45 75 30 19505.18 3860.50 TD SP24-SE1(P2)(Def Plan) Pace 55.15 53.92 22 34 N1A 000 0.00 Surface l 55.15 53.131 n N/A 200.00 200.00 MinPts 54 76 47.92 21.96 N/A 600.00 596.88 MinPts 54 90 47.61 22.09 WA 700.00 693.22 MINPT-O-EOU Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\S129-S2\S129-S2(P4b) 1/12/2012 10:27 AM Page 2 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 142.22 118.18 106.78 618 170000 1479.91 MinP1-0-SF 390.79 334.10 306.38 P 7 021 3000.00 2164.18 MinPt-O-SF 1r y 2655.26. 2415.72 2296.44 1113 16300.00 3895.17 MinPt-CtCt 2656.73 2415.291 2295.07 11.04 16400.00 389337 MinPts 2763.86 2504.72 2375.65 10.7 17300.00 3891.71 MinPt-OSF 3087.191 2782.44 2630.61 10.1 19505.18 3860.50 MinPts SP36-W5(P2)(Def Plan) Pau 64.05 6283 31.24 N/A 000 000 Surface 61.73 58.77 28.92 N/A 400.00 399.78 MinPts 61.99 57.67 29.19 N/A 500.00 498.91 MINPT-O-EOU 1566.11 1473.31 1427.39 17.051 9900.00 3779.69 MinPt-O-SF I 1210.111 1151.84 11231 2111 11000.00 3814.36 MinPts 1473.18 1395.23 1356.7 19.13 11900.00 3812.63 MinPt-O-SF 8215.89 8109.29 8056.48 77.78 19505.18 386050 TD SP23-N3(P6b)(Def Plan) Pau 63.09 61.87 30.29 N/A 0.00 0.00 Surface 63.09 61.08 30.291 N/A 200.00 200.00 MinPts . 1332.54) 1294.38 1275.79 35.81 5100.00 2587.71 MinPts ' 1335.94 1295.28=En 33.65 5200.00 2607.49 MinPt-O-ADP 1625.16 1553.05 1517.48 22.8 6200.00 2865.45 MinPt-O-SF 2641.06 2559.94 2519.87 32. 8900.00 3699.95 MinPt-OSF • I1 q 2178.62 2034.05 1962.26 15.17 11300.00 3814.33 MinPt-CtCt 2180.49 2031.43 1957.40 14.72 11400.00 3813.90 .MINPT-0-EOU •• 2185.06 2031.58 1955.3 14.32 11500.00 3813.48 MinPt-O-ADP • 2192.35 2036.57 1959.18 14.161 11600.00 3813.05 MinPt-OSF • 7896.71 7779.15 772087 67.73 19505.18 3860.50 TD • SP22-FN1(P2)(Def Plan) Pass 71.18 69.96 38.38 N/A 0.00 0.00 Surface 7118 69.17 36. N/A 200.00 200.00 MinPts 72.12 68.77 39.31 N/A 400.00 399.78 MINPT-O-EOU 407.27 356.44 331.55 2900.00 2132.77 MinPt-O-SF 4710.90 4562.91 4489.41 1:13M 11600.00 3813.05 MinPt-OSF 9737.02 9607.06 9542.57 75.48 19505.18 3860.50 TD S120-N4(P4)(Def Plan) Paas _87.12 85.89 54.31 N/A 0.00 0.00 Surface I 87.121 85.10 5431 N/A 200.00 200.00 MinPts 2024.151 1998.14 1985.69 80.97 3100.00 2190.52 MinPts • 2513.47 2455.41 242687 440 4700.00 2508.58 MinPt-OSF 311468 3037.70 2999.71 40.9 5800.00 2740.68 MinPt-O-SF 4472.46 4363.18 4309.04 41. 10400.00 3815.35 MinP1-0SF 4153.01 4004.01 3929.99 28.05 12100.00 3812.95 MinPt-CtCt 4153. 4003.841 3929.5 27.94 12200.00 3813.11 MinPts 4171.40 4020.36 3945.34 27.74 12500.00 3823.52 MinPt-OSF 8745.00 8611.25 8544.87 65.86 19505.18 3860.50 TD S120-N4PB1(P1)(Def Plan) Pass 87.12 85.89 54.31 N/A 0.00 0.00 Surface • 1 87.12 85.101 54.31 N/A 200.00 200.00 MinPts 5033.88 5007.78 4995.22 200.361 6200.00 286545 MinPt-O-SF I 3997.021 3843.971 3767.95 26.28 12200.00 3813.11 MinPts 4020.89 3865.80 3788.75 26.091 12600.00 3827.90 MinPt-0-SF 8651.54 8517.63 8451.17 65.08 19505.18 3860.50 TD 5119-FN2(P2)(Def Plan) Pass 95.15 93.93 62.34 N/A 0.00 0.00 Surface 95.15 93.14 62.34 N/A 200.00 200.00 MinPts 95.32 92.86 62.51 N/A 300.00 299.09 MINPT-O-EOU 464.93 419.42 397.19 min2700.00 205540 MinPt-O-SF 479358 4646.47 4573.41 MIMI 11600.00 3813.05 MinPt-O-SF 9734.14 9603.77 9539.08 75.23 19505.18 3860.50 TD SP18-N5PB1 field survey(Def Survey) Pass 111.15 109.92 78.34 N/A 0.00 0.00 MinPts 111.44 109.49 78.63 N/A 200.00 200.00 MINPT-O-EOU • 3107.85 3032.5 2995. 41.82 4000.00 2370.09 MinPt-O-ADP 3410.72 3326.23 3284 48 40.831 4600.00 2488.79 MinPt-O-SF 4187. 4032.53 3955.66 27.23 12500.00 3823.52 MinPt-CICt 4188. 4032.220 3954.671 27.00 12600.00 3827.90 MinPts 4243.12 4082.14 400214 26.511 13200.00 3853.09 MinPt-OSF 8406.00 8255.05 8180.07 56.05 19505.18 3860.50 TD SP18-N5PB1 Field(Def Survey) Pass 111.15 109.90 78.341 N A 0.00 0.00 MinPts • 111.44 109.47 78.63 N A 200.00 200.00 MINPT-O-EOU 3107.84 2917.8 MEW 16.46 4000.00 2370.09 MinPts 5755.50 554119 5434.5r 26.99 8100.00 3555.07 MinPbOSF 4187.26 3933.89 3807.70 16.59 12500.00 3823.52 MinPt-CtCt 4191.6 3926.114 3793.791 15.84 12700.00 3832.28 MinPts 4387.48 4090.41 3942.36 14.811 13825.39 3883.20 MinPf-0SF 8406.00 8105.57 7955.84 28.07 19505.18 3860.50 TD SP18-N5 field survey(Non-Def Survey) Pass ® 109 92 MEENA 0.00 0.00 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 3 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 11144 109.49 78.63 N/A 200.00 200.00 MINPT-O-EOU 3107 85 3032 581 2995.441F 41.82 4000.00 2370.09 MinPt-O-ADP 3519.61 3431.04 3387 241 40.1711 4800.00 2528.36 MinPt-O-SF 4187.261 4032.53 3955.66 27,23 12500.00 3823.52 MinPt-CtCt 4188.301 4032.221 3954.67 27.00 12600.00 3827.90 MinPte 4243.12 4082.14 4002.14 26.51 13200.00 3853.09 MinPt-O-SF 8406.00 8255.05 8180.07 56.05 19505.18 3860.50 TD SP18-N5 MWD-STD(Non-Def Survey) Pass ® 108.921111111111,E1 N/A 0.00 0.00 MinPts 111.44 109.49 78.63 N/A 200.00 200.00 MINPT-O-EOU 3111.51 2979 3E1IMEIEB 23.72 4000.00 2370.09 MinPte 3522,74 3360.28 3279.54 MILO 4800.00 2528.36 MinPt-OSF 3806.74 3630.29 3542.55=NE 5300.00 2627.28 MinPt-O-SF I 4189.671 4039.26 3964.54 28.03 12500.00 3823.52 MinPte 4190.72 4039. 3964.45 27.90 12600.00 3827.90 MinPt-O-ADP 4230.68 4076.40 3999 7511 27 591 13100.00 3848.98 MinPt-0SF 8407.76 8266.64 8196.58 59.99 19505.18 3860.50 TD SI17-SE2(P2)(Def Plan) - Pees 119.19 117.96 86.38 N/A 0.00 0.00 Surface 119.19 117.17 86.38 N/A 200.00 200.00 MinPte 12111 115.51 88.30 N/A 500.00 498.91 MINPT-O-EOU 407.11 363.21 341.87 2400.00 1905.95 MinPt-O-SF 11 3872 2811 3639.68 3523.87 16.71 16300.00 3895.17 MinPt-CtCt 3873 4111 3638.931 3522.18 16.58 16400.00 3893.37 MINPT-O-EOU 3673.61 3638.991 3522 17 16 58 16407.26 3893.30 MinPt-O-ADP 4054 07 3796.19 3667.741 15 781 17600.00 3887.11 MinPt-O-SF 14289 4 1 4003.91 3861 64 15 07 18963.69 3870.02 MinPt-CtCt 4293 721 3995.98r 30476011 14.4711 19505.18 3860.50 MinPte SP16-FN3(P3)(Def Plan) Pass 127.11 125.89 94.30 N/A 0.00 0.00 Surface 127.11 125.12 94.30 N/A 200.00 200.00 MinPts 127 37 124 92 94 56 N/A 300.00 299.99 MINPT-0-E0U 589.11 546 58 525 93 14.231 2600.00 2009.81 MinPt-O-SF 4828.31 4735.271 4689.2511 52.44 9000.00 3708.86 MinPt-O-ADP 1 4796 331 4698.83 4650.58 49.69 9975.73 3789.81 MinPt-CtCt 4802.5411 4688.2311 4631.56 42.37 10600.00 3814.61 MINPT-O-EOU 4807 42 4689 3211 4630 7611 41.04 10720.35 3814.17 MinPt-O-ADP 4903.90 4757 90 4685 391 33.8111 11600.00 3813.05 MinPt-O-SF 9730.61 9599 74 9534 80 74.91 19505.18 3860.50 TD 0114-N6(P2)(Def Plan) Pass 143.09 141.86 110.28 N/A 0.00 0.00 Surface ( 143.091 141.081 11028 N/A 200.00 200.00 MinPts 5237.27 5212.64 5200861 222.231 6300.00 2900.45 MinPt-O-SF 4264.92 4117.49 4044.27 29.12 12400.00 3819.14 MinPte 4309.51 4158.50 4083.49 28.721 13000.00 3844.87 MinPt-O-SF 8528.46 8388.04 8318.32 61.16 19505.18 3860.50 TD 5113-FN4(P2)(Def Plan) Pass 151.09 149.86 118.28 N/A 0.00 0.00 Surface 151.09 149.08 118.28 N/A 200.00 200.00 MinPte 15142 148.93 118.61 N/A 300.00 299.99 MINPT-O-EOU 657.78 618.53 599.521 17.271 2500.00 1959.91 MinPt-O-SF x4902.81 4790.73 4735.19 44.12 10600.00 3814.61 MinPt-CtCt 4908.06) 4785.7811 4725.13 40.46 10900.00 3814.28 MINPT-0-EOU 4912.92 4787.1•`,11 4724 71 39.35 11000.00 3814.36 MinPt-O-ADP 4974.02 4828.61 4756.40 34.4311 11600.00 3813.05 MinPt-O-SF 9727.10 9595.79 9530.62 74.63 19505.18 3860.50 TD SP12SE3(P2)(Def Plan) Pass 174.23 173.01 141.43 N/A 0.00 0.00 Surface 174.23 172.22 141.43 N/A 200.00 200.00 MinPts 174.64 172.14 141.84 N/A 300.00 299.99 MINPT-O-EOU 699.53 659.64 640.30 main 2400.00 1805.95 MinPt-OSF I 4990.40 4892.18 4843.56 51.31 10000.00 3792.95 MinPt-CtCt 4995.8 4885.90 4831.43 45.85 10370.14 3815.46 M1NPT-O-EOU 5001.65 4887.4 4830.79 44.16 10500.00 3814.98 MinPt-O-ADP 5065.84 4932.15 4865.80 38.171 11100.00 3814.44 MinPt-O-SF 5108.86 4967.47 4897.26 36.3 11600.00 3813.05 MinPt-O-SF 11 5071 8511 4844.00 4730.57 22.35 16300.00 3895.17 MinPt-CtCt 5073 0511 4643 3511 4728 9911 22.18 16400.00 3893.37 MinPte 1 5490 7011 5210.27 5070.54 19.64 18963.69 3870.02 MinPt-CtCt 5495 421 5202 82118.841 19505.18 3860.50 MinPte • SP11-N7(P2)(Def Plan) Pass 182.26 181.04 149.46 N/A 0.00 0.00 Surface I 182.26 180.251 149.461 N/A 200.00 200.00 MInPts 4420.61 4273.55 4200.51 30.26 30.26 12600.00 3827.90 MinPt-CtCt 4421.25 4273.411 4199.91 30.10 12700.00 3832.28 MinPte 4468.95 4317.18 424178 29.631 13300.00 3857.21 MinPt-OSF 8363.31 8216.58 8143.70 57.38 19505.18 3860.50 TD SP10-FN5(P2)(Def Plan) Fjp1! 190.34 189.11 157.53 N/A 0.00 0.00 Surface 1 190.341 188.331 157.531 N/A 200.00 200.00 MinPte Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S129-52\5129-S2\5129-S2(P4b) 1/12/2012 10:27 AM Page 4 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 871.70 834.28 816.18 24.05 2500.00 1959.91 MinPt-O-SF 1 5075 651 4955.78 4896.33 42.68 10900.00 3814.28 MinPt-CtCt 508165 4950.63 488561 39.07 11200.00 3814.52 MINPT-O-EOU 5084.28 4951 331 4885.351 38 52 11254.48 3814.52 MinPt-O-ADP 5109.10 4966.18 4895.211 35.99] 11600.00 3813.05 MinPt-OSF 9721.61 9589.61 9524.10 74.19 19505.18 3860.50 TD 3108-FN6(P2)(Def Plan) Pass 206.27 205.05 173.46 N A 0.00 0.00 Surface 1 206.271 204.261 173.46 N'A 200.00 200.00 MinPts 996.14 963.44 94769 31.601 2500.00 1959.91 MinPt-O-SF 5087.51 4961.22 4898.57 40.59 11100.00 3814.44 MinPt-CtCt 5093.51 4955.55 4887.06 37.18 11400.00 3813.90 MINPT-O-EOU 5098.66 4957.09 4886.79 36.26 11500.00 3813.48 MInPt-O-ADP 5105.23 4961.99 4890 8611 35.881 11600.00 3813.05 MinP1-0SF 9687.68 9555.15 9489.38 7364 19505.18 3860.50 TD 1 S107-SE4(P2)(Def Plan) Pass 214.23 213.01 18142 N/A 0.00 0.00 Surface 1 214.231 212.221 181.42 5,4 200.00 200.00 MinPts 1021.01 986.22 969.43 30.381 2400.00 1905.95 MinPt-O-SF 1148.28 1108.33 1088.97 29.621 2600.00 2009.81 MinPt-O-SF 5450.88 5370.47 5330.76 68.611 9600.00 3748.36 MinPt-O-SF ' 1-5241.261 5106.43 5039.51 39.15 11500.00 3813.48 MinPt-CtCt 5242.7 5105.951 5038.0 38.59 11600.00 3813.05 MinPts 5248.08 5111.04 5043.0 38.5j 11746.32 3812.43 MinPt-O-SF A 6271.04 6043.33 5929.96 27.65 16300.00 3895.17 MinPt-CtCt 6272.34 6042.76 5928.46 27.43 16400.00 3893.37 MinPts ' 6697.49 6404.88 6259.07 22.961 19505.18 3860.50 MinPts SP05-FN7(P2)(Def Plan) Pass 238.34 237.12 205.53 N/A 0.00 0.00 Surface L 238.341 236.331 205.53 N/A 200.00 200.00 MinPts 1109.88 1079.06 1064.27 37.4-61 2400.00 1905.95 MinPt-O-SF 5243.95' 5108.38 5041.09 38.96 11500.00 3813.48 MinPt-CtCt 5244.571 5107.101 5038.85 38.42 11600.00 3813.05 MinPts 5251.09 5113.28 504487111 38.371 11800.00 3812.46 MinPt-O-SF 9712.13 9579.20 9513.23 73.60 19505.18 3860.50 TD SP04-SE5(P2)(Def Plan) Pass 246.23 245.01 213.42 N'A 0.00 0.00 Surface ®®® N/A 200.00 200.00 MinPts • 1240.81 1215.17 1202.96® 2400.00 1905.95 MinPt-O-SF =ME ME= 38 52 11600.00 3813.05 MinPts 5261.66 5123.49 5054.90® 12100.00 3812.95 MinPt-O-SF 7561.06 Ie 7206.49 32.07 17000.00 3901.17 MinPts 1 7909.50 7632.89 7495.07 28.69 19000.00 3869.71 MinPt-CtCt 7911.12 19505.18 3860.50 MinPis 1 SI02SE6(P2)(Del Plan) Pass • 262.21 260.99 229.41 N/A 0.00 0.00 Surface 1 262.211 260.201 22941 N/A 200.00 200.00 MinPts 1571.97 1549.60 1539.031 74.201] 2500.00 1959.91 MinPt-O-SF 1 5345.971 5210.95 5143 93 39 88 11746.32 3812.43 MinPt-CtCt 5345.941 5210.9111 5143 87 39 86 11763.21 3812.40 MinPts 5372.63 5235.95 516811 39.5911 12274.92 3814.10 MinPt-OSF I 9097.9 8819.18 8680.27 32.74 18988.75 3889.85 MinPl-CtCt 9101.51 8811.0611 8666 3211 31 441 19505.18 3860.50 MinPts SP01SE7(P2)(Del Plan) Pass 270.32 269.10 237.52 N/A 0.00 0.00 Surface 1 270.321 268.311 237.52 5'4 200.00 200.00 MinPts 5454.35 5432.11 5421.53 25762 6400.00 2936.64 MinPt-OSF ®I 5179 8111 5112 581 39.52 11800.00 3812.46 MinPts 5339.60 5202.37 5134.24 39.181 12300.00 3814.87 MinPt-O-SF 1 9655.18 9520.44 9453.56 72.18 19505.18 3860.50 TD ' Tuvaaq ST 1(Def Survey) Paas • 4956.71 4954.80 4923.91 NA 0.00 0.00 Surface ' 759.71 68407 648.17 10.531 7800.00 3464.89 MinPt-O-SF 699.83 634.95 604.38 11.38 8000.00 3526.82 MinPt-O-ADP 1 692.531 633.50 605.79 12.43 8100.00 3555.07 MinPts 10419.35 10346.62 10311.06 146.49 19505.18 3860.50 TD Kigun 1 PB1(Del Survey) Pass 4956.71 4954.80 4923.91 N/A 0.00 0.00 Surface ' 1281.37 1208.93 1173.60 18.111 7900.00 3496.71 MinPt-O-SF 1006.20 963.301 942.74 24.42 8700.00 3678.55 MinPts 1 1005.72 964.73 945.13 25.61 8800.00 3690.53 MinPt-CtCt 1177.71 1133.31 1111.931 27.5111 9386.05 3738.34 MinPt-O-SF • 10419.35 10346.62 10311.06 146.49 19505.18 3860.50 TD OPO4-07(Def Survey) Pass 9383.00 9320.26 9291.12 160.92 0.00 0.00 Surface 1 9161.611 9098.531 9069.361 156.92 800.00 787.47 MinPts 11180.76 11096.88 11056.67 138.96 4700.00 2508.58 MinPt-O-SF 12085.57 11988.22 11940.76 127.2 6300.00 2900.45 MinPt-O-SF 2656.44 2521.26 2455 20 20.0 17500.00 3888.25 MinPt-O-SF 2410.70 2281.38 2218.63 19.18 17900.00 388466 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 5 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct•Ct(ft)_ EOU Mt.Dev.{ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1178.01 1024.64 949.42 781 1950513 356050 M IrPts 0PO4-07PB1(Def Survey) Pass 10543.37 10492.03 10468.51 224 06 0.00 0.00 Surface I 10357.341 10306.011 10282.61 221.16 800.00 787.47 MinPts 12220.31 12144.39 12108.11 168.36 4700.00 2508.58 MinPt-O-SF 13004.41 12912.24 12867.41 145 00 6300.00 2900.45 MinPt-O-SF I 1211.21 1068.591 999.22 8.70 19505.18 3860.50 MinPts OP09-S1(Def Survey) Paas 4885.60 4725.23 4646.31 30 93 0.00 0.00 Surface 2254.05 2045.25 1943.78 1101 4300.00 2429.44 MinPt-O-SF 2015.73 1849 2 1769.81 12.63 5100.00 2587.71 MinP1-0-ADP 2006.48 1846.72 1770 64 13.14 5200.00 2607.49 MINPT-O-EOU 20021 1849.11 1776.43 13.72 5300.00 2627.28 MinPt•CtCt 1263.68 1011.87 886.46 irE 9172.53 3723.70 MinPt-OSF 1256.90 1008.5• 884.8 5.08 9300.00 3733.59 MinPts 1281.94 1042.96 923.9 MIME 10100.00 3803.73 MinPt-OSF 1255.31 1009.98 887.8., 11600.00 3813.05 MinPt-O-SF 1246.26 .io =1:10T 5.16 11800.00 3812.46 MinPts IM-MIfi. 1004.29 884 69 520 11900.00 3812.63 MinPt-CtCt 1225.84 996.83 882.81 5.3 12900.00 3840.76 MinPt-O-SF 1215.07 988.861 876.25 5.39 13100.00 3848.98 MinPts I 1214.06 989.44 877.61 5.42 13200.00 3853.09 MinPt-CtC1 1243.10 1025.5711KM 5.74 14100.00 3883.78 MinPt-O-ADP 1242.0 .88 I 917.59 5.76 14200.00 3883.57 MINPT-O-EOU 1235.35 1020.20 913.1 jL0 14500.00 3885.91 MinPt-O-SF 1227.9•I r�j'.1 909.371 5.80 14800.00 3890.72 MinPts FMEIEE 101570 910.12 5.81 14852.11 3891.56 MinPt-CtCt 1 r8r5W ' 910 10 I 61 15900.00 3907.49 MinPts 1611.33 1288 31Y1®® 18963.69 3870.02 MinPts I� 1194 30 19300.00 3864.26 MinPt-O-SF seem minEgmatrim® 19505.18 3860.50 MinPts OP08-04(Def Survey) pass 10389.08 10340.29 10318.12 234.17 0.00 0.00 Surface 10353.82 1030515 10283.05 234.1 100.00 100.00 MinPt-O-SF I 10183.54 10136.74 10115.64 24148 900.00 879.15 MinPts 11273.04 11205.99 11174.69 179.98 4700.00 2508.58 MinPt-O-SF 11703.45 1161602 11574.28 14015 6300.00 2900.45 MinPt-O-SF I 2027.74 1800.431 1689.94 915 19505.18 3860.50 MinPts 0107-04(Def Survey) Pass • 10585.32 10528 73 10502.33 200 40 0.00 0 00 Surface p 10403.04 10346.02 1031948 195.95 800.00 787.47 MinPts 12526.25 12451.25 12415.08 173.1 4700.00 2508.58 MinPt-O-SF 13437.99 13349.74 13306.47 155.2 6300.00 2900.45 MinPt-0-SF I 2362.63 2222.791 2154.24 17.21 19505.18 3860.50 MinPts 0115-S4(P9b)(Def Plan) Pass 7581.48 7395.31 7303 68 41.36 0.00 0.00 Surface 2481.38 2233.96 2113 56 MIME 9100.00 3717.38 MinP1-0SF 2468.85 2224.2.M'; 10.35 9386.05 3738.34 MinPt-O-ADP 246773 2223.86� 10.37 9500.00 3743.60 MinPt-O-ADP 2459.39 2217.65 2100.1r®"� 9975.73 3789.81 MinPt-O-SF 2422.46 2166.17 2041.3• 11600.00 3813.05 MInPt-O-SF IMMO I® 2030.6. 9.88 13200.00 3853.09 MinPts 2409.68 2159.26 2037.0 9.84 13500.00 3867.41 MinP1-0-SF 2537.60 2284.91 2161. • 1. ii 15500.00 3899.64 MinPt-O-SF 2485.55 2223.67 2095.2'I�'"4-y 17700.00 3886.20 MinPt-O-SF MOM=MEMEMO 9.62 18322.02 3875.71 MinPts 2364.83 2115.08 1992.40 18334.52 3875.35 M1nPt-OSF 2653.84 2407.66 2285.53 10.86 19505.18 3860.50 TD 0608-04651(Def Survey) Pass. 12114.81 12086.03 12073.50 483.4 0.00 0.00 MinPt-O-SF f 11963.44 11935.341 11923.24 494.37 800.00 787.47 MinPts 13423.79 13358.67 13327.71 216.7 4700.00 2508.58 MinPt-OSF 13963.99 13877.36 13835.36 166.2 6300.00. 2900.45 MinPt-O-SF I 2516.671 2326.131 2235.63 13. 19505.18 3860.50 MinPts 0111-01(Def Survey) Pass 10756.29 10698.68 10671.99 201.47 0.00 0.00 Surface 10582.96 10525.12 10498.41 •.0 600.00 596.88 MinPt•O-SF 054 8 In=I 199.64 1000.00 967.84 MinPts 11242.71 11168.22 11133.3•moo 4700.00 2508.58 MinPt-O-SF 11483.95 11390.78 11346.,-•=j1ini 6300.00 2900.45 MinPt-O-SF Ijjj gram=gm 15.81 18600.00 3871.19 MinPts 3394.61 3174.31 3066.50 18963.69 3870.02 MinPt-0SF MEM="'M=1:1® 19505.18 3860.50 MinPts OP10-09(Def Survey) Pass 8546.79 8343.59 8243.34 42.61 0.00 0.00 Surface 4630.61 4341.14 4199.351 16.31) 7500.00 3360.75 MInPt-O-SF 3875.84 3598.62 3463.15 8800.00 3690.53 MinPt-O-SF 3814.37 3540.48 3406.61® 9192.53 3725.44 MinPt-OSF 3791.63 3522.30r 3390.76 14.39 9400.00 3738.99 MinPts 3727.53 3466 21 3338 76 14 60 9900.00 3779.69 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 6 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Nert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major , 3646.74 3388.94 3263 301 14 49 10500.00 3814.98 MinPt-O-SF 3533.64 3264.55 3133 051 13 41 11500.00 3813.48 MinPt-O-SF i 3503.68 3237.76 3107 771_13 4 12000.00 3812.79 MinPt-O-SF 3499.53 3234 501 3104.88 1348 12204.58 3813.12 MinPts • 1 3498.2 3234 83 Map 13.55 12400.00 3819.14 MinPts 3501.88 3238 47 3109 49113.55 12800.00 3827.90 MinPt-O-SF 3587.13 3336 74 3214 13 14 611 13900.00 3884.18 MinPt-O-SF 3832.91 3598.95 3483.44 MIIM 18100.00 3881.25 MinP1-0-SF ' 3830.21 3596,61 3481.25 16.59 18200.00 3878.97 MinPts 4117.85 3884.86 376951 17.84 19505.18 3860.50 TD OP03-P05(Def Survey) Peas 11764.97117.03.91 11674.94 203 01 0.00 0.00 Surface � 11609.3 Itut6 9 11511518.0&'. 197.83 700.00 693.22 MinPts 11827.73 11764.24 11734.1:1=113E2 1503.71 1354.10 MinPt-OSF 13842.54 13765.00 13727.1,MIMI 4700.00 2508.58 MinP1-0SF 14776.28 14686.48 14642.061 6300.00 2900.45 MinPt-O-SF IM •IN=111=13 MEED 19505.18 3860.50 MinPts OP03-P05PB2(Del Survey) Paas • 13446.73 13398.15 13375.24 293.45 0.00 0.00 Surface I["13320.04 13270.901 13247.78 288.08 700.00 693.22 MinPts 15359.32 15290 71 15257.23 229.3 4700.00 2508.58 MinPt-O-SF 16150.05 16065.71 16024.0 193.7 6300.00 2900.45 MinPt-O-SF I 4149.081 4055.851 4012.62 47.91 19505.18 3860.50 MinPts 0111-01PB1(Def Survey) Pass 13399.36 13376.08 13366.55 N/A 0.00 0.00 Surface ' 13263.961 13242911 13231.15 N/A 800.00 787.47 MinPts 1448351 14420.23 14390 09 240.19 4700.00 2508.58 MinPt-O-SF 14878.17 14791.68 147497 177,35 6300.00 2900.45 MinPt-O-SF ' 1 4187.971 3981.611 3882 48 21.08 19505.18 3860.50 MinPts OP12-01(Def Survey) Pass 9711.21 9571.85 9504.00 71.53 0.00 0.00 Surface 9440.35 9299.77 471 69.0 900.00 879.15 MinPt-O-SF 9378.99 9240.801.'11, 69.99 1500.00 1351.69 MinPt-O-ADP 9378.96 9240.80 9173.84 70.01 1503.71 1354.10 MinPts 9313.63, 9 92 SINEINEE 80.14 4400.00 2449.23 MinPts EllgESE 9192.36 9134.46 80.37 4500.00 2469.01 M1nPt-CtCt 9244.97 9125.93 9069.2*1 6300.00 2900.45 MinPt-O-SF 1 4291.72 4055.14 3939.55 18.54 14600.00 3887.52 MinPt-CtCt 4291.98 4054.501 3938.38 18.46 14700.00 3889.12 MinPts 4316.19 4076.17 3958.40 18.30 15100.00 3894.17 MinPt-OSF 4701.04 4467.41 43519 20. 17831.94 3885.29 MinPt-O-SF I 4619.591 4386.701 4272.09 20.14 18400.00 3873.70 MinPts 4620.95 4387.94 4273.20 20.121 18500.00 3872.11 MinPt-O-SF 4747.64 4512.08 4395.91 20.42 19505.18 3860.50 TD • OP23-W W02(Def Survey) Paas , 14346.15 14309.92 14293.24 429.97 0.00 0.00 Surface 14006.9 13969.9.NEM 416.56 1100.00 1053.08 MinPts 15168.12 15103.87 15073.3*MEM 4700.00 250858 MinPt-0SF 15665.95 15583.19 15543.0; 195. •• 6300.00 2900.45 MinPt-O-SF 1 4585.531 4457.131 4396.20 37.58 19505.18 386050 MinPts 0106-05PB1(Def Survey) Rats i... 12286.92 12226.74 12197 84 212.58 0 00 0.00 Surface • NEMO 12081.81®1.1E1M. 700.00 693.22 MinPts 12386.86 12326 14 12297.02. 1503.71 1354.10 MinPt-OSF 14587.33 14517.15 14482.561 4700.00 2508.58 MinP1-0-SF 15623.62 15541.34 15500.6,1 6300.00 290045 MinP1-0SF 6189.96 6065.04 6003.3 1 17800.00 3885.50 MinP1-0SF NEM MBE ®' 19505.18 3860.50 MinPts 0106-05(Def Survey) Pass 12010.33 11945.74 11914.60 192.79 0.00 0.00 Surface r 11858.421 11793.66 11762.53 190.29 700.00 693.22 MinPts 11863.13 11798.36 11787.19* 190.29 800.00 787.47 MinPt-O-SF 14342.85 14268.67 14232.06 195.92 4700.00 2508.58 MinPt-O-SF • 15411.49 15326.09 15283.88 182.58 6300.00 2900.45 MinP1-0SF 6173.09 6035.29 5966 88 45.11 17900.00 3884.66 MinPl-OSF 5993.99 5858.03 5790.54 44.40 18200.00 3878.97 MinPt-OSF I 4925.441 4790581 4724.10 37.03 19505.18 3860.50 MinPts 0113-03(Def Survey) Pass 9914.90 9714.24 9615.05 49.97 0.00 0.00 Surface 5762.36 5458.97 5309.36 11.11M1 7900.00 3496.71 MinPt-O-SF 1 5595.05 5306.69 5164.991 8200.00 3581.32 MinPt-O-SF 5462.44 5182.95 5045.8511.. 8500.00 3646.88 MinPt-O-SF 5356.91''11 4946.721 9000.00 3708.66 MinPts I 5272.79 5016.45 48911516, 9571.37 3748.89 MinPt-O-SF 5230.01 4975.63 4851 31®I 9900.00 3779.69 MinPt-O-SF ' 5167.51 4910.85 4785.291 10400.00 3815.35 MinPt-0SF 5043.71 4777.19 4646.5.1.1 11600.00 3813.05 MinPt-O-SF 5036.96 l� 19.34 11763.21 3812.40 MinPts MIME may, 19.55 12300.00 3814.87 MinPts 5019.70 4758.26 4629.,-MEM 12400.00 3819.14 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 7 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Statue Ct-Ct(ft) EOU OIL Dev.(ft Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 5018.27 4770 201 4648.6 20.63 13320.58 3858.20 MlnPts 4989.21 4746.27 4627.25 20.94 14000.00 3883.98 MinPts 4992.62 4748.95 4629.4 20.8711 14200.00 3883.57 MinPt-O-SF 5265.63 5033.76 4918.71 22.88 17955.91 3883.90 MinPt-O-SF 5258.4 5026.371 491151 22.88 18100.00 3881.25 MinPts 5257. 5026.38 4911.65 22.90 18200.00 3878.97 MinPt-CtCt 5459.73 5227.20 5111.97 23.68 19505.18 3860.50 TD OP26-DSPO2(Def Survey) Pass 14891.09 14869 05 14858.28 N/A 0.00 0.00 Surface U 14681.5811-71-6 08 14648.77 N/A 900.00 879.15 MinPts 15738 53 15675 03 15644.70` 259.371 4700.00 2508.58 MinPt-0SF 16089.86 16003.93 15962.22 192.82 6300.00 2900.45 MinPt-O-SF 1 5234.041 5045.711 4955.72 29 04 19505.18 3860.50 MinPts Oliktok Point 1-2(Def Survey) Pus 10752.30 10581.98 10498.20 64.15 0.00 0.00 Surface 10449.26 10277.15 10192.67 MO 1200.00 113448 MinPt-O-SF 10406.06 10236.0:' 10152.86 62.50 2000.00 1667.15 MinPts 9807.95 9653.02 9578.14 65.46 6300.00 2900.45 MinPt-0-SF 5604.041® 22 87 14200.00 3883.57 MinPts 5621.84 5371.25 5247.90® 14600.00 3887.52 MinPt-0-SF 6024.80 5785.92 5667. 18100.00 3881.25 MinPt-0SF 6023.66 14 5666.6' 25 42 18200.00 3878.97 MinPts 6179.18 5940.83 5822.4 26 q 18963.69 3870.02 MinPt-0SF 6301.66 6063.11 5944.46 26.55 19505.18 3860.50 TD OP22-W W03(P1)(Def Plan) Paas 14839 24 14792 50 14769.75 326.19 0.00 0.00 Surface 1 14284 5611 14235 221 14211.8 304.89 1400.00 1284.15 MinPts I` 5647 921 5493 54 5418 94 37.82 19505.18 3860.50 MinPts Oliktok Point I-2PB2(Def Survey) Pas 12534.49 12413.62 12354.61 106.18 0.00 0.00 Surface 12357.73 12236.10 12176.79 104.161 800.00 787.47 MinPt-0SF 12337.73 12216.44 12157 35 104.36 1100.00 1053.08 MinPt-O-ADP 12337.41 12216.36 12157.36 104.53 1200.00 113448 MinPts 12510.601 12392.17 12334.80 109.01 4000.00 2370.09 MinPts 12529.53 12409.52 12351.4 107.8 4700.00 2508.58 M1nPt-OSF 12471.98 12345.73 12284.61 101.981 6300.00 2900.45 M1nPt-OSF 1 6087.761 5849.101 5731.03 25 77 18334.52 3875.35 MinPts 6087.87 5849.19 5731.06 25.761 18400.00 3873.70 MinPt-0SF 6297.37 6058.99 5940.42 26.55 1950518 3860.50 TD OP05-06(Def Survey) Pas 12628.12 12569.94 12541.47 221.75 0.00 0.00 Surface 12498 63 12440.71 12412.41 11 500.00 498.91 MinPt-O.SF 112489.9:'1 601,6615 221.08 700.00 693.22 MinPts 15141.03 15076.04 15044.0 4700.00 2508.58 M1nPt-OSF 16294.29 16218.94 16181.7 - 6300.00 2900.45 M1nP1-0SF 8099.48 7977.24 7916.61 66 79 16900.00 3901.21 M1nPt-0SF 7979.09 7857.88 7797.7 66 36 17064.36 3899.36 M1nPt-OSF 6222.86 6088.58 6021.921 19505.18 3860.50 MinPts OP05-06PB2(Def Survey) Pass 13462.89 13408.64 1338228 255 36 0.00 0.00 Surface 13356.57 13302.54 13276.3. 254 691 400.00 399.78 MinPt-O-SF 1 MEM 111=13 254.95 600.00 596.88 MinPts 15872.32 15811.79 15782.0. 266.56 4700.00 2508.58 MinPt-OSF 16937.23 16865.07 16829.4 11 6300.00 2900.45 M1nPt-OSF 6900.68 6770.59 6706.0 V/6! 18700.00 3870.75 M1nPt-0SF WEE MIME 6042.97 5009 19505.18 3860.50 MinPts OP17-02(Def Survey) Pass 11352.88 11142.61 11038.24 54.38 0.00 0.00 Surface 6790.27 6513.66 6377.51® 9700.00 3755.69 MinPt-0SF 6776.9•1' 6366.0..- 10100.00 3803.73 MinPts 6764.85 6507.62 6381. •- 10209.50 3811.55 MinPt-0SF 6659.34 6394.91 6265.0 1. 11000.00 3814.36 M1nPt-OSF 6548.24 6281.82 6150.8 1 12100.00 3812.95 MinPt-O-SF 6540.61 6275.061 25.01 12400.00 3819.14 MinPts `iz 6275.27 6144.90 25.07 12500.00 3823.52 MinPt-C1Ct MUM Min 6946.1. 30.92 18000.00 3883.17 MinPts 7304.63 7067.55 6949. .1 18200.00 3878.97 MinPt-0SF 7437.89 7200.62 7082.6,MEE 18900.00 3870.19 MinPt-0SF 7559.72 7322.07 7203.73 31.94 19505.18 3860.50 TD OP17-02PB1(Def Survey) Pass 11405.63 1119346 11088.13 54.13 000 0.00 Surface 7555.94 725553 7107.3'MEM 7700.00 3431.51 MinPt-OSF 7275.62 6986.95 6844.9.1 8100.00 3555.07 M1nPt-O-SF 706427 6784.62 6647.2.mg" 8500.00 3646.88 MinPt-OSF 6968.81 6692.05 6556.0r.1 8800.00 3690.53 MinPt-O-SF 6806.9 1 6534.96i 6401.1.1"' 10100.00 3803.73 MinPts 6797.59 6535.73 6407.21", 10209.50 3811.55 M1nPt-OSF 6636.03 6363.19 6229.0111 1160000 3813.05 MinPt-O-SF 6631.2 6358.9.1 24.74 11700.00 3812.62 MinPts 6595.15 6332.05 62026. 12400.00 3819.14 M1nPt-0SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 8 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft1 Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6589.37 6327.26 6198.28 25.53 12700.00 3832.28 MinPts 6589.16 6327.60 6198.87 25.58 12788.57 3836.17 MinPt-CtCt 6589.99 6328.55 6199. 25 581 12900.00 3840.76 MinPt-O-SF 7338.12 7100.23 6981.7 30 9/ 17955.91 3883.90 MinPt-O-SF 7329 981 7092.551 6974.3 31.00 18100.00 3881.25 MinPts 7573.85 7335.63 7217.26 31.9 19300.00 3864.26 MinPt-O-SF 7607 93 7369 40 7250 76 32.06 19505.18 3860.50 TD • Oliktok Point 1-2PB1(Oaf Survey) Pass 14769.01 14686 62 14646 62 184.60 0.00 0.00 Surface 14637.81 14555.04 14514 91® 700.00 69322 MinPt-O-SF 14630 6 MITZEgi 4507.85 18250 900.00 879.15 MinPts 15234.22 15139.19 15093.01® 4700.00 2508.58 MinPt-O-SF • 15314.48 15205.25 15151.9:® 6300.00 2900.45 MinPt-O-SF MEM 6549.66 6434.00® 19505.18 3860.50 MinPts OP03-P05PB1(Def Survey) Pass 16757.89 16719.23 16700 73 452.87 0.00 0.00 Surface I 16663.13 16624.211 1660562 44808 600.00 596.88 MinPts 18414.05 18348.79 18316 66 286 601 4700.00 2508.58 MinPt-O-SF 19000.53 18915.28 18873.171 225.571 6300.00 2900.45 MinPt-O-SF 7150.721 7015.891 695220 56.081 19505.18 3860.50 MinPts OP21-W W01(P3)(Def Plan) Pass 17134.71 17071.41 1704025 274.96 0.00 0.00 • Surface 16892 73 16829 08 16797.82 270.14 1000.00 967.84 MinPts 18210.24 18125 03 18082 92 216.21 4700.00 2508.58 MinPt-O-SF 7174 50 7029.72' 6960.58 51.84 19505.18 3860.50 MinPts • Oliktok Point l-1A-106(P5)(Def Plan) Pass • 13581.93 13411.08 13326.61 80.37 0.00 0.00 'Surface I 13451.821 13279.331 13194.04 78.85 600.00 59688 MinPts 13477.18 13303.90 13218.22 78.64 900.00 879.15 MinPt-O-SF 7516.22 7335.561 7246.04 41.97 19505.18 3860.50 MinPts OP18-08(Def Survey) Pass 13685.17 13475.94 13371.86 65.74 0.00 000 Surface 8763,07 8442.83 8283.8811111111111111 8500.00 3646.88 MinPt-O-SF Man MIIMICE. 82644 27.61 8700.00 367855 MinPts 9029.55 8752.81 8616.21. 1M 11758.54 3812.40 MinPt-O-SF 8736.56 8493.7.MEOW 3648 14800.00 3890.72 MinPt-O-ADP 8690.83 8454.21 8337.71MEM 15300.00 3896.24 MinPt-O-SF ®� 8662.77 8427.29 8311. 'j 15600.00 3901.87 MinPt-O-SF 8627.56 8395.45 82812 ® 15900.00 3907.49 MInPt-OSF 8596.84 8367.21 8254.2: Elig Eli16100.00 390224 MinPt-O-SF 8559.53 8331.50 8219.41 MEM 16300.00 3895.17 MinPt-O-SF 839324 8166.62 8055.2•MUM 16922.86 3901.50 MInPt-O-SF • 8069.42 7842.18 7730.••mom 17750.49 3885.84 MinPt-O-SF 8026.79 7801.53 7690.:: ifie 1783194 3885.29 MInPt-OSF �E7748.057525.20 7415.8:�"' 18500.00 3872.11 MinPt-O-SF i' mom 7206.97,®I 19505.18 3860.50 MinPts OP18-08PB2(Def Survey) Pass 13685.17 13475.99 13371.93 65.75 0.00 000 Surface • 8920.44 8618.76 8469.47=En 8900.00 3699.95 MinPt-O-SF 1 8906.11 tO 66.mrzfE 29.91 9300.00 3733.59 MinPts 9098.38 8798.70 8649.7.mozE 11100.00 3814.44 MinPt-0SF 9029.55 8752.85 8616.2 ME= 11758.54 3812.40 MinPt-O-SF • 8736,56 8493.7'milim 36.49 14800.00 3890.72 MinPt-O-ADP 8690.83 8454.23 8337.7 NIMIII 15300.00 3896.24 MinPt-O-SF 8662.77 8427.31 8311.3 MEE. 15600.00 3901.87 MinPt-O-SF i 8627.56 8395.47 8281.2 MR& 15900.00 3907.49 MinPt-OSF 8596.84 8367.23 8254.3. .' 16100.00 3902.24 MinPt-O-SF 8559.53 8331.52 8219.••MOM 16300.00 3895.17 MinPt-0SF 8393.24 8168.64 8055.2 ® 16922.86 3901.50 MinPf.O-SF • 8069.42 7842.19 7730.4 Mr' 17750.49 3885.84 MinPt-13-SF 8026.79 7801.55 7690.9. ZIER 17831.94 3885.29 MinPt-OSF 7748.05 7525.21 7415.9.MEM 18500.00 3872.11 MinPt-O-SF 7548.00 NEEDEE 7206 97 11111EMEE 19505.18 3860.50 MinPts 0124-08(P10b)(Def Plan) Pass 12466.31 12245.52 12135.66 56.73 0.00 000 Surface 7726.57 7417.13 7264.02® 8800.00 3690.53 MinPt-O-SF NEFEJE 7416.99 MEM 25.23 8872.53 3697.55 MinPts 7876.13 7596.51 7458.6. 28 54 10500.00 3814.98 MinPt-0-ADP 7864.06 MEIMAIZEM.11EM 10700.00 3814.24 MinPts 7737.17 7462.24 7326.7:,MIKIE 11900.00 3812.63 MinPt-O-SF 7719.47 7446.2.M:1,: 28 62 12400.00 3819.14 MinPt-O-ADP �'1 7311.50 28 65 12500.00 3823.52 MinPts 8378.09 8135.57 8014.8 34.6811 17900.00 3884.66 MinPt-O-SF I 8353.391 8112.111 7991.961- 34.76 16200.00 3878.97 MinPts 8561.46 8320.07 8199.86 35.61 19505.18 3860.50 TO Nikaitchuq 3PB1(Def Survey) Pass 8011.18 8009.26 7978.37 N/A 0.00 0.00 Surface 8011.16 8009.02 7978.35 N/A 100.00 100.00 MinPts 8011.31 800862 797851 N/A 200.00 200.00 MINPT-0-EDU Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 9 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct fft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 12778 92 12756 04 12745 481 605 041 6300.00 2900.45 MinPt-O-SF 9479 891 9304 60 9217 76 54 57 16475.55 3893.00 MinPt-0001 9475 9011 9304 2811 9217 281 54.47 16500.00 3893.04 MinPts 10181 25 9971 46 9867 37 48.901 19505.18 3860.50 MinPt-0-SF Nikaitchuq 3PB2(Def Survey) Pass 8011.18 8009.26 797837 N/A 0.00 0.00 Surface 8011.16 8009.02 7978.35 N/A 100.00 100.00 MinPts 801131 8008.62 797851 N/A 200.00 200.00 MINPT-0-EOU 12778.92 12756.04 12745.481 60504 6300.00 2900.45 MinPt-O-SF 9479.8 9304.60 9217.76 54.57 16475.55 389300 MinPt-CtCt 9479.9 9304.281 9217.2 54.47 16500.00 389304 MinPts 10181.25 9971.46 9867.37 48.901 19505.18 3860.50 MinPt-O-SF Nikaitchuq 3PB3(Def Survey) Pass 8011.18 8009.26 7978.37 N/A 0.00 0.00 Surface 8011.16 8009.02 7978.35 N/A 100.00 100.00 MinPts 8011.31 8008.62 7978.51 NA 200.00 200.00 MINPT-O-EOU 12778.92 12756.04 12745.4:. 605.01 6300.00 2900.45 MinPt-O-SF 9479.8 9304.60 9217.76 54.57 16475.55 3893.00 MinPt-CtCt • 9479.9 9304.281 9217 2 54.47 16500.00 3893.04 MinPts 10181.25 997146 9867.37 48.901 19505.18 3860.50 MinPt-O-SF Nikaitchuq 3(Def Survey) Paas 8011.18 8009 26 7978.37 N/A 0.00 0.00 Surface 801116 8009.02 7978.35 N/A 100.00 100.00 MinPts 801131 8008.62 7978.51 NA 200.00 200.00 MINPT-O-EOU 12778.92 12756 04 12745.48; 605 041 6300.00 2900.45 MinPt-O-SF 9479 89 9304 60 9217.76 54 57 16475.55 3893.00 MinPt-CtCt 9479.90 9304 281 9217.2811 54 47 16500.00 3893.04 MinPts 10181.25 9971 46 9867 37 48 901 19505.18 3860.50 MinPt-O-SF Nikaitchuq 4(Def Survey) Pass 8257.21 M3E23 N/A 0.00 0.00 MinPts 8259.1•wow 8226.38 N/A 100.00 100.00 MINPT-O-EOU 8096.87 8048.31 8024.99 173.55 1100.00 1053.08 MinPts 8519.56 8454.23 8422.52 INICEM. 2600.00 2009.81 MinPt-OSF 12547.35 12466.59 12427.09x' 8200.00 3581.32 MinPt-0SF 12521.27 12443.44 12405 41 MEI= 8400.00 3627.34 M1nPt-0SF 12210.28 12131.06 12092.26, N 9200.00 3726.09 MinPt-OSF 11722.17 11628.79 11582.9.=HE 10209.50 3811.55 MinPt-0SF 9699.76 9526.86 9441. 21111EZEF, 16200.00 3898.51 MinPt-O-SF 1-9681.6. 9506.1: 9419.26 55.69 16500.00 3893.04 MinPts 10309.12 10098 81 9994.47 ENKE 19505.18 3860.50 MinP0-O-SF Nikaitchuq 1(Def Survey) Peas 8143.76 8141.84 8110.95 N/A 0.00 000 Surface Mil=INECE0 MI= N/A 200.00 200.00 MinPts 10167.43 10143.26 10132.1'MILEME 3400.00 2251.39 MinPt-O-SF 10953.65 10927.58 10915.5.=Rag 4200.00 2409.66 MinPt-O-SF 11444.98 1141802 11405.4 1=2Ell 4700.00 2508.58 MinPt-OSF 12035.11 12006.87 11993.6 ® 5300.00 2627.28 MinPt-O-SF 12884.02 12854.66 12840.8 466.87 6200.00 2885.45 MinPt-0SF 13194.52 13164.46 13150.311 _ 466.22 6600.00 3011.90 MinPt-O-SF 13834.01 13597.98 1358085L 397.89 7700.00 3431.51 MinPt-O-SF 10034.11 9863.35 9778.78 59.31 16475.55 3893.00 MinPt-CtCt 10034.13 9863 07 9778341 59.21 16500.00 3893.04 MinPts 10691.59 10486.35 10384.53 52.50 19505.18 3860.50 M1nPt-OSF Nikaitchuq 4PB1(Del Survey) Pass 8259.13 8257.21 8226.32 N/A 0.00 0.00 MinPts 8259.19 8257.14 8226.38 N/A 100.00 100.00 MINPT-O-EOU 13097.84 13075.26 13064.85 629.0 6300.00 2900.45 MinPt-O-SF 9676.21 9500.43 9413.35 55.55 16600.00 3883.99 MinPts 10285.17 10074.71 9970.28 49.24 19505.18 3860.50 MinPt-O-SF 0120-07(P14)(Def Plan) Pass 15577.19 15405.52 15320.22 91.30 0.00 000 Surface 10774.71 10359.53 10152.55 26.031 8500.00 3646.88 MinPt-O-SF I10757.09 10343.28 10136.93 26.06 870000 3678.55 MinPts 8399.061 8181.241 8074 75, 39 41 19505.18 3860.50 MinPts OP16-03(Def Survey) Pass 14297.68 14096.65 13996.62 i 1 46 0.00 0.00 Surface 9648.11 9341.91 9189.92 MIMI 8600.00 3663.98 MinPt-0-SF 9631.6• 9326,61al= 3179 880000 3690.53 MirrPte 9868.67 9603.1• 9472 09.111M1M 10900.00 3814.28 MinPts 9558.13 9302.56 9176. 12900.00 3840.76 MinPt-0SF 9528.7. , 38.08 13700.00 3877.67 MinPts immac 9276.44 9151.76 38.20 13825.39 388320 MinPt-CtCt 9250.26 9041.33 8939.19 45.26 18000.00 3883.17 MinPt-0SF 8636.51 8420.78 8315.33 40 93 19400.00 3862.43 MinPt-0-SF 1 8594.771 8382.511 8278 93 41.46 19505.18 3860.50 MinPts Oliktok Point I-1(Def Survey) Pass 17841.59 17840.48 17808.79 N/A 0.00 0.00 Surface 1 17841201 17838.921; 17808.391 N/A 200.00 200.00 200.00 MinPts 19439.37 19380.46 19351.51 335.6 4700.00 2508.58 MinPf-0SF 19822.63 19739.17 19697.93 240.3 6300.00 2900.45 MinPt-0SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 10:27 AM Page 10 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1422427 14109.96 14054.55 128.321 13320.58 3858.20MinP1-0-SF I 8891.901 8733.931 8658.08 58.58 19505.18 3860.50 MinPts OP18-08PB1(Def Survey) Pass 17622.62 17610.51 1758981 N/A 0.00 0.00 Surface 1 17602.561 17590.321 17569.75 N/A 400.00 399.78 MinPts 19066.74 19006.14 18976.43 320.86 4700.00 2508.58 MinPt-O-SF 19414.07 19329.09 19287.18 231.6 6300.00 2900.45 MinPt-O-SF 1 9087.20 8910.461 8824.91 53.08 19505.18 3860.50 MinPts OP05-O6PB1(Def Survey) Pass 1 17847.88 17846.66®1 N/A 0.00 0.00 MinPts 17848.08 17846.08 17815.27 N/A 200.00 200.00 MINPT-O-EOU 19455.36 19396.18 19367.12 334.74' 4700.00 2508.58 M1nPt-O-SF 19834.37 19750.62 19709.28 239.86 6300.00 2900.45 MinPt-O-SF 9199.681 9032.511 8951.99 57.081 19505.18 3860.50 MinPts Nikeitchuq 2(Def Survey) Pass .111315111. 16045.79 16014.901 N/A 0.00 0.00 MinPts 16047,7,I 16045.20 16014.93 N/A 200.00 200.00 MINPT-0-EOU 20827.65 20799.93 20786.95 802.23 6300.00 2900.45 MinPt-O-SF 2106425 21036.31 21023.21 804.36 6700.00 3050.60 MinPt-0-SF 13977.111 13793.511 13702821 76.801 19505.18 3860.50 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\S129-S2(P4b) 1/12/2012 10:27 AM Page 11 of 11 Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: 929-S2 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rul- _ Date: October 18,2011 used:Minor Risk-Separation - Factor I 0- 600' North 350 0 10 340 20 330 30 320 40 60 if 310 50 / ' �_ 300 � 60 N. i orAiwo4...:11,111- 290 alp 70 . I� �� . 20 if (IF • ,,gill411 280 l'---141111401.,,,---11111111..,‘...., ♦i '% ..\ ( •, r,A . ►�``7�� ;• .P22 FN1 (P2) A ,,,,,....„ fifA ,iiiibrit/A. ',,4 z7o ` 80 009--- v ` 4 ,43, 4 ' e. itti =- i:A .,� � �� _-;f: �\ ' � ,\ 1 i:riciiIli :��..� ��p �� , tit,'!<•4421#48• ,1 ie 011,--s• i �' �0 * 1 ` ��:;_�� 0 \��' SP23N3surveys 260 i!" ,,•I'�� '' I ii `NAIT V iWa,�W 100 2501k4 _•,-17,/ 110 1 ip"'w4rig. / `%� piii ` Nill pVillikkV`.� 5125 N2(P2) 24\ \/* j// ,_ a `'it' 111,120 `=`t: . .yip: �'�1.r 1 SP3 V!. ir 230�,�� 11�'• � 130 \ - 1 N l4Ya1jjj21 SOMM um- Pa 1 210 �� 1111L 150 200 160 190 180 170 Well Ticks Type: _ MD on SI29-S2(P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=25.00 ft Schlumberger TRAVELING C YLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: S129-S2 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rul: A Date: October 18,2011 used:Minor Risk-Separation c Factor 4 600' - 13 3/8" North SP24-SE1(P2) 350 0 10 340 ®��,; 20 330 11140M111,1:* W�se��4�\ 30 320 ��1 �� ► 40 AIWSI17-SE2(P2) 310 10141111 1411,10040101424a 1(11ftminir• ' Ai* 11‘*44116, 5� $ 4ria*A11171 k .416 300III gallik ��•�� @ � 60 SP22-FN1 (P2) 4 \ larrAdOrt W �� ,if �1 ,iari�'1�- SI19-FN2(P2) 290 �:;,,. ��1i�� .�1`70' i ,, ,`,`"�1 SPt6 FN3(P3) ♦ lk 280 `1 �A y , ll ire . , . 80 270 111111111 ;..'- � - ' 90 11111 0 !� wlittellorlier . 260III / A • ^ \0. . . , _` .i4r4,4,�F �tif., �100 '1..___�,, i Ana .,- 250 ,' '�,' SP23-N3(P6b) �\ . bits i i„A. 4 , % vsli��-.�►�S��_ �\`�,`��j�_w�'=. SP23 N3 surveys 240 lt,\*Iteliv `riatarov- �►�f► \�1,,�, v'�`l'��.120SI25-N2(P2) li ,. do ,230 ►��• � , 1130 SD37-DSP1 Tam 220 1741111,•6!'�`�,�• :*„.' \ 0S o. ��'�� SI32-W2(P2) 210 +■ ji1l► 150 20041 �� •I 160 Sx34-N Sand(P2) 190 1:1 SI35-W4(P2) SP33-W3(P2) SP36-W5(P2) V Well Ticks Type: MD on SI29-S2(P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: S129-S2 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rul: Date: October 18,2011 used:Minor Risk-Separation Factor 13 3/8" - 9 5/8" North 350 0 10 340 20 330 30 100M 140 ar 320 40 120: 310 All1101111 Ipp, 50 300Sit \ 60 "0780 itip, 290 60 till 70 01 ' " 40 00 OA 4 4111 ilk 280komp*"..11&_P----.4-0...---N la _ 80 441.--, -44w, 270 4 , 02 90 `� o01111Ik � 1111111111111 260 0s �� 100 44... - ��\ 14 250 a- 1 -2)m o �� \ (N 110 oro 4, a 240,` '11 a _ N 20 oN ro�d , 4, 230-14. 130 22Viet 0 140 lk _ i`\ } ' m / 210 ` 150 00 \\ 160 SP30-W1 (P2) 190 180 170 Well Ticks Type: MD on SI29-S2(P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based on: Client: Eni Petroleum Oriented EOU Dimension N Well: SI29-S2 Field: Nikaitchuq NoGo Region Anti-Collision rule Structure: Spy Island used:Minor Risk-Separation Am, Date: October 18,2011 Factor 9 5/8" - TD North 350 0 10 340 20 330280 30 260 320 ..„-- _ 240 40 lissim ,” 220 31040111 00 200 50 4180 300 • � 4 160 71111111,411.404411, 60 4100. 140 itl 290iiititiipilk120 70 100 4 le *It 80 . #4. \ \ \ ii, 280 ' � � 60 j 80 r7 IRiiIIIILs270 _ __ t ::� 49, "II �� 1 0 �� .� . � �at r � � 0 0,c,,,,, t #4, 260 ,, o a� , �� \-''\ o' ,, --44417�� SR-W1 (P2) ,, ...... ,,, ,„ , 0, 250 \ qx * p 110 oy r 411prollip o t ib 240 \ Ilir 414411r ° eli �,120 lir 111.411111 230 /' 130 S ._ / iwa.,,,, _ 220 140 \______ 210 NW150 200 160 190 180 170 Well Ticks Type: MD on S129-S2(P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft 1,1 e n n Schlumberger "ALL S129-S2(P4b) FIELD Nikaitchuq STRUCTURE Spy Island MaOnete PSurixe Lacetian RAD"Ala..St&e Plane.Zane NI US Feet BOOM Miecalleneoua Model: BOOM 2011 Op 81071° Date: Febcoary 3012 Lel: 5 732142 Northing: 8053610.058U5 OW Cony 0.008]3000° Slot. SPZO 0 1V041: Rotary Te51e154.111ebove MSL) Mag Dec: 2085 57640 2• FS'. 576406nT Lon: W 1400 21 54 218 Feeling: 511473.70M15 Scale Fact'.0.00000015 Plan'. S120-52)740) Stvy Date:October 18.2011 SP27-N1 Tuvaaq ST 1 SP18-N5PB1 field survey SP18-N5 field survey -6000 -4000 -2000 a• 2000 4000 6000 1 I I ;: .° • o • �:I T D y • O ��^"�'�,r. • N3 surveys •, a� ^�" , -�9-S1 -2000., -2000 �� 902, i'heel • A 8019 '. .' O ENO A Kigun 1 :1-f,` „ 40 9 tra °T_• / ::E. ''1 ZD" -a000 — 6 -4000 N OP14=S3 b OPO4-07PB1 ii OP10-09 • OPO4-07 W nv C Q • 4.' / U c.,O ° ,•',' •, �q`� -6000 "` �} , _ AN -6000 0113-03 •, • V AKS .• D u K ° • •„ 4 • ? 4.°. S129•S2 Toe • -8000 t, - • °• ,� -8000 4411° - `, h • VD • \•• I, All •• A� • OP12-01 ��~ 5129-52 (PO • ��° • 4' , • • '•�P12--0 3874 D °� —• • Iliktok PdiTit 1-?',5,,c,°• �° " ' -!;-,-A''.:".,4,,,,,,-.. \°,°• • �' . J• 5.$49 ,10^�• ••*.I8-0,A 3§6 t -10000 — ]t h„ti a ,°• • �oy.Q ,.•, • S yrj°,.��• -10000 ��• �a. .• �•°•1-01 $ • I ^• �,,,,,' i N5� 1 - <,,,°• -6000 4,,0) ,5°4 -2000 0113-03 0 000 ,^ 40k' 6000 OP17-02 OP17-02PB1 < W Scale = 1:2000(f E >>> 0P08-04 OP17-02PB1 Oliktok Point 1-2 OP10-09 0111-01 OP17-02 OP14-S3 OPO4-07PB1 OPO4-07 OP09-S1 2n Il SI29-S2 (P4b)Anti-Collision Report Schlumberger Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: January 12,2012-18:38 North Reference: True Analysis Machine: DEC-AKA-980 Client Enl Petroleurn Database I Project: localhost\drilling-nikaitchuq_2.5 Version/Patch: 2 5.1100.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. All local minima Indicated. Anti-Collision Rules Used Rule Set Name D&M AntiCollision Standard S002 05.1/5.2 Exemption Risk Level: Minor Rule Name Risk Level Rule Tvoe Rut.Lab.I N000 Rule SLB Alert Zone Threshold OSF=5.0 S002 v5.1/5.2 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5$002 v5.1/5.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule S002 v5.1/5.2 Major CT_CT MAS=32.81(ft) SLB Alert Zone Threshold CtCt<=15m$002 05.1/5.2 Alert CT_CT MAS=49.21(0) • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\S129S2(P4b) 1/12/2012 4:44 PM Page 1 of 55 Reference Trajectory Summary Field: Nikaitchuq Well: Sl29-S2 Structure: Spy Island Borehole: 5129-S2 Slot: SP29 Trajectory: S129-52(P4b) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08873996` Grid Scale Factor: 0.99990015 Magnetic Declination: 20.662' Magnetic Declination Date: February 29,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(lsd) Slot Unc.(1sd( 6053619.450(ftUS) 511473.700(EUS) 54.100(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.000 1/100.000 SLB_NSG+SSHOT-Depth Only-No Globe 16.000 SI29-S2/SI29-S2(P4b) 41.000 500.000 1/100.000 SLB_NSG+SSHOT-No Globe 16.000 SI29-S2/SI29-S2(P4b) 500.000 4676.000 1/100.000 SLB_MWD+GMAG-No Globa 16.000 SI29-S2/SI29-S2(P4b) 4676.000 6200.000 1/100.000 SLB_MWD-STD-No Globa 12.250 SI29-S2/SI29-S2(P4b) 6200.000 8992.000 1/100.000 SLB_MWD+GMAG-No Globe 12.250 SI29-S2/SI29-S2(P4b) 8992.000 11500.000 1/100.000 SLBMWD-STD-No Globe 8.750 SI29-S2/SI29-S2(P4b) 11500.000 19505.183 1/100.000 SLB_M_WD+GMAG-No Globe 8.750 SI29-S2/SI29-S2(P4b) • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 2 of 55 Offset Trajectory Summary Offset Selection Criteria: Wellhead distance scan:Global within 80515.88 ft Offset Selection Criteria:Definitive Surveys -All Non-Def Surveys when no Def-Survey is set in a borehole Offset Selection Summary Wells Selected:28 Boreholes Selected:48 Definitive Surveys Selected:47 Non-Def Surveys Selected:3 Definitive Plans Selected:0 Non-Def Plans Selected:0 Total Trajectories:50 None OSF fitter in detailed report Trajectory Borehole Well Type SP27-N1 SP27-N1 SP27-N1 Def Survey 5D37-DSP1 SD37-DSP1 SD37-DSP1 Def Survey 5P23-N3 surveys SP23-N3 SP23-N3 Non-Def Survey Kigun 1 Kigun 1 Tuvaaq ST 1 Def Survey OP14-S3 OP14-S3 OP14-S3 Def Survey SP18-N5PB1 field survey SP18-N5PB1 SP18-N5 Def Survey SP18-N5 MWD-STD SP18-N5 SP18-N5 Non-Det Survey SP18-N5 field survey SP18-N5 SP18-N5 Non-Def Survey SP18-N5PB1 Fold SP18-N5PB1 SP18-N5 Def Survey Tuvaaq ST 1 Tuvaaq ST 1 Tuvaaq ST 1 Def Survey Kigun 1 PB1 Kigun 1 PB1 Tuvaaq ST 1 Def Survey OPO4-07 OPO4-07 OPO4-07 Def Survey OPO4-07PB1 0PO4-07PB1 OPO4-07 Def Survey OPO9-S1 OP09-S1 OP09-S1 Def Survey OP08-04 OP08-04 OP08-04 Def Survey 0107-04 0107-04 0107-04 Def Survey OP08-04PB1 OP08-04PB1 OP08-04 Def Survey 0111-01 0111-01 0111-01 Def Survey OP10-09 OP10-09 OP10-O9 Def Survey OP03-P05 OP03-P05 OP03-P05 Def Survey OP03-P05PB2 OP03-P05PB2 OP03-P05 Def Survey 0111-01 P81 OP11-01 PB1 0111-01 Def Survey OP12-01 OP12-01 OP12-01 Def Survey OP23-W W02 OP23-WVV02 OP23-W 802 Def Survey 0108-05P81 0108-05PB1 0108-05 Def Survey 0108-05 0108-05 0108.05 Def Survey 0113-03 0113-03 0113-03 Def Survey • 0P28-DSPO22 OP28-DSPO2 OP28-DSPO2 Def Survey Oliktok Point 1-2 Oliktok Point 1-2 Oliktok Point 1-2 Det Survey Oliktok Point I-2PB2 Oliktok Point I-2PB2 Oliktok Point 1-2 Def Survey OP05-08 OP05-08 OP05-08 Oct Survey OP05-08PB2 OP05-08PB2 OP05-08 Det Survey OP17-02 OP17-02 OP17-02 Det Survey OP17-02PB1 OP17-02PB1 OP17-02 De/Survey Oliktok Point I-2P81 Oliktok Point I-2PB1 Oliktok Point 1-2 Def Survey OP03-P05PB1 0P03-P05PB1 OP03-P05 Def Survey OP18-08 OP18-08 OP18-08 Def Survey OP18-08PB2 0P18.08PB2 OP18-08 Def Survey Nikaitchuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Def Survey Nikaitchuq 3PB1 Nikaitchuq 3PB1 Nikaitchuq 3 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Def Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Def Survey Nikaitchuq 4 Nikaitchuq 4 Nikaitchuq 4 Def Survey Nikatchuq 1 Nikaitchuq 1 Nikaitchuq 1 Def Survey Nikaitchuq 4PB1 Nikaitchuq 4PB1 Nikaitchuq 4 Def Survey OP10-03 OP18-03 OP18-03 Def Survey Oliktok Point 1-1 Oliktok Point I-1 Oliktok Point 1.1 Def Survey OP18-08PB1 OP18-08PB1 OP18-08 Def Survey OP05-08PB 1 OP05-08PB 1 OP05-08 Oct Survey Nikaitchuq 2 Nikatchuq 2 Nikatchuq 2 Oct Survey Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 3 of 55 Field: Nikaitchuq Well: SP27-N1 Structure: Spy Island Borehole: SP27-N7 Slot: SP27 Trajectory: SP27-N1 Client: Eni Petroleum Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08886174° Grid Scale Factor: 0.99990015 Magnetic Declination: 20.802° Magnetic Declination Date: December 01,2011 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(tsd( Slot Unc.(lsd) 6053622.430(8US) 511489.440(IIUS) 53.870(ft)MSL 0.000(ft) 0.000(ft) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.770 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 SP27-N1/SP27-N1 40.770 40.770 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global • 16.000 SP27-N1/SP27-N1 40.770 736.000 Act-Stns SLB_NSG+SSHOT-No Global 16.000 SP27-N1/SP27-N1 736.000 2607.040 Act-Stns SLB_MWD+GMAG-No Global 16.000 SP27-N1/SP27-N1 2607.040 8215.960 Act-Stns SLB_MWD+GMAG-No Global 12.250 SP27-N1/SP27-Nt 8215.960 14094.410 Act-Stns SLB_MWD+GMAG-No Global 8.750 SP27-N1/SP27-N1 14094.410 14155.000 Act-Stns SLB BLIND 2-No Global 8750 SP27-N1/SP27-N1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (") (ft) (ft) (°) All local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.00 ft Results filtered:Ct-Ct separation<=1500.00 ft Results Highlighted:Ct-Ct<=1320 ft 9100.00 3717.38 -2324.78 -4363.30 7186.49 367307 -1607.12 -3830.62 36.15 894.84 804.38 9,99 170.23 1 9200.00 3726.09 -237903 -4279.75 7116.80 3688.31 -1648.10 -3774.46 38.74 890,46 79827 9.75 171.07 1 930000 3733.59 -2431.99 -4195.27 7058.26 3684.57 -1680.42 -3725.79 35.7: :, 793.95 9.45 172.70 1 9400.00 3738.99 -2482.68 -4109.24 700276 3660.38 -1708.87 -3678.32 34.95 889.1: /-- r 9.17 172.05 I 950000 3743.60 -2532.51 -4022.66 6945.57 3654.08 -1735.74 -3628.25 35.51 893.54 792.74 8.94 169.44 1 960000 3748.36 -2582.35 -3936.10 8880.21 3843.56 -176426 -3570.41 36.36 902.21 799.01 8.82 185.07 1 9700.00 3755.69 -2632.38 -3849.83 6816.11 3630.04 -1790.28 -3513.40 37.42 915.50 809.91 8,74 160.60 1 980000 3766.45 -2682.73 -3764.11 6756.41 3815.92 -1812.68 -3459.89 38.61 933.93 825.86 8.71 157.31 1 9826.23 3769.84 -2696.00 -3741.74 6742.24 3812.61 -1817.64 -3447.05 38.87 939.72 830.9. 158.84 1 9900.00 3779.69 -2733.34 -3678.89 6702.44 3603.81 -183083 -3410.55 39.68 957.85 84723 8.73 156.85 1 1000000 3792.95 -2783.98 -3593.68 6638.14 3591.08 -1849.95 -3350.50 40.92 988.05 873.43 8.82 157.48 1 1010000 3803.73 -283477 -3508.22 6570.08 3579.54 -1888.48 -3286.03 42.44 1016.53 902.02 8.95 158.74 1 10200.00 3811.04 -2885.71 -3422.49 6512.88 3570.39 -1882,16 -3231.24 43.67 1049.58 932.84 9.06 158.42 1 10300.00 3814.86 -2936.72 -333657 8444.01 3559.61 -1896.47 -3164.77 44.80 1084.80 966.10 921 158.46 1 1040000 3815.35 -2987.70 -325054 6379.33 3549.91 -1908.52 -3101.96 4552 1121.23 1000.44 9.35 157.79 1 1050000 3814.98 -3038.65 -3164.49 6323.28 3542.03 -1917.08 -3047.13 45.64 1160.25 1037.26 950 156.08 1 10600.00 3814.61 -3089.60 -3078.45 6271.64 3535.02 -1923.24 -2996.35 45.71 1202.21 1077.11 9.68 154.20 1 10700.00 3814.24 -3140.56 -2992.41 6222.23 3528.09 -1927.50 -2947.61 45.76 1247.15 1120.06 9.88 152.34 1 10800.00 381420 -319154 -2906.38 6176.33 3521.26 -1930.01 -2902.29 45.72 1295.10 1166.17 10.11 150.34 1 10900.00 3814.28 -3242.54 -2820.38 8132.17 3514.13 -1931.09 -2858.73 45.79 1345.91 1215.27 10.37 148.51 1 11000.00 3814.36 -3293.54 -2734.34 6091.47 3507.24 -1930.83 -2818.63 45.85 1390.43 1267.25 10.88 148.70 1 11100.00 3814.44 -3344.54 -2848.33 17052.82 3500.64 -1929.34 -2780.37 45.89 1455.57 1321.99 10.97 144.95 1 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 4 of 55 Field: Nikaitchuq Well: SD37-DSP7 Structure: Spy Island Borehole: SD37-DSP7 Slot: SP37 Trajectory: SD37-DSP7 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08812728' Grid Scale Factor: 0.999900147 Magnetic Declination: 20.902' Magnetic Declination Date: September 26,2011 Magnetic Model: BGGM 2011 Reference Point: Northing Easlina Elevation Structure Unc.(lsdt Slot Unc.(7sd) 6053604.090(ftUS) 511394.510(ftUS) 53.650(ft)MSL 0.000(ft) 0.000(9) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 40.550 Act-Stns SLB_CNSG+CASING-Depth Only-No Global 16.000 SD37-DSP1/SD37-DSPI 40.550 40.550 Act-Stns SLB_CNSG+CASING-Depth Only-No Global 16.000 SD37-DSP7/SD37-DSP1 40.550 6550.000 Act-Stns SLB_CNSG+CASING-No Global 16.000 SD37-DSP1/SD37-DSP1 6550.000 6958.000 Act-Stns SLB MWD+GMAG-No Global 12.250 SD37-DSP1/5D37-DSP1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Alen Ct-Ct Distance Clearance OSF Angle Trace 7t (ft) (ft) (6) (0) (ft) (6) (6) (6) (') (ft) (ft) (°) At local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.00 ft Results filtered:Ct-Ct separation<=1500.00 ft End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 5 of 55 Field: Nikaitchuq Well: Tuvaaq ST 1 Structure: Nikaitchuq Exploration Borehole: Kigun 1 Slot: Tuvaaq ST 1 Trajectory: Kigun 1 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.05667531' Grid Scale Factor: 0.999900061 Magnetic Declination: 24.117' Magnetic Declination Date: March 15,2005 Magnetic Model: BGGM 2009 Reference Point: Northing Easting Elevation Structure Uncilsd) Slot Unc.11sdl • 6050899.000(ftUS) 507330.900(ftUS) 35.030(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Frog: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(In) Borehole I Survey 0.000 32.690 Ad-Stns SLB_MWD+GMAG-Depth Only-No Globe 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 32.690 Ad-Stns SLB_MWD+GMAG-Depth Only-No Globe 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 1837.510 Act-Stns SLB_MWD+GMAG-No Globe 30.000 Tuvaaq ST 1/Tuvaaq ST 1 1837.510 2429.990 Act-Stns SLB_MWD+GMAG.'2-No Globa 30.000 Kigun 1 PB1/Kigun 1 PBI 2429.990 4509.980 Act-Stns SLB_MWD+GMAG""2-No Globa 30.000 Kigun 1/Kigun 1 4509.980 9098.000 Act-Stns SLB_MWD+GMAG"3-No Globa 30.000 Kigun 1/Kigun 1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (8) (ft) (`) (ft) (ft) (') All local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.00 ft Results filtered:Cl-Ct separation<=1500.00 ft 9100.00 3717.38 -2324.78 -4363.30 3792.87 3715.28 -2420.74 -4681.49 216.75 332.35 279.28 6.66 84.93 1 9200.00 3726.09 -2379.03 -4279.75 380151 3723.93 -2420.82 -4681.53 218.47 403.95 354.25 8.64 85.05 1 9300.00 3733.59 -2431.99 -4195.27 3808.88 3731.29 -2420.88 -4681.56 217.12 486.43 438.19 10.25 86.30 1 9400.00 3738.99 -2482.68 -4109.24 3814.10 3736.51 -2420.92 -4681.59 21530 575.68 523.87 11.70 87.38 1 9500.00 3743.60 -2532.51 -4022.66 3818.50 3740.91 -2420.96 -4681.61 216.37 668.33 614.92 13.11 87.39 1 9000.00 3748.38 -2582.35 -3936.10 3822.99 3745.41 -2420.99 -4681.64 219.20 762.81 707.96 14.52 86.84 1 9700.00 3755.69 -2832.38 -3849.83 3829.90 3752.31 -2421.05 -4681.68 227.04 858.28 802.22 15.93 84.87 1 9800.00 3766.45 -2682.73 -3764.11 3839.98 3762.39 -2421.13 -4681.74 235.24 954.20 897.09 17.34 82.94 1 9900.00 377509 -2733.34 -3678.89 3852.49 3774.90 -2421.23 -4681.83 239.08 1050.40 992.38 18.74 82.45 1 10000.00 3702.95 -2783.98 -3593.68 3865.18 3787.59 -2421.33 -4881.93 239.65 1147.09 1088.30 20.16 82.95 1 10100.00 3803.73 -2834.77 -3508.22 3875.42 3797.83 -2421.42 -4682.01 233.88 1244.46 1185.00 21.58 84.96 1 10200.00 3811.04 -2885.71 -3422.49 388226 3804.07 -2421.47 -4682.06 228.08 1342.42 1282.39 23.02 88.98 1 10300.00 3814.88 -2938.72 -3338.57 388571 3808.12 -2421.50 -4682.09 218.02 1440.81 1380.28 24.48 88.97 1 End of results • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 7 of 55 l Field: Nikaitchuq Well: OPt4-S3 Structure: Oliktok Point Borehole: OP14-S3 Slot: OP14 Trajectory: OP14-S3 Client: ENI Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12842137 Grid Scale Factor: 0.999900315 Magnetic Declination: 21.155° Magnetic Declination Date: April 18,2011 Magnetic Model: BGGM 2010 Reference Point: Northing Easting Elevation Structure Uncdlsd) Slot Unc.(tsdl 6036520.670(ftUS) 516647.470(ftUS) 53.230(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Fred Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.030 Act-Stns SLB_GYRO-MWD-Depth Only-No Globe 16.000 OP14-S3I 0P14-S3 41.030 41.030 Act-Stns SLB_GYRO-MWD-Depth Only-No Globe 16.000 OP14-S3/OP14-S3 • 41.030 922.480 Act-Stns SLB GYRO-MWD-No Globe 16.000 OP14-S3/OP14-S3 ' 922.460 2259.120 Act-Stns SLB__MWD+GMAG-No Globe 16.000 OP14-S3/OP14-S3 2259.120 10384.510 Act-Stns SLB_MWD+GMAG-No Globe 12.250 OP14-S3 I OP14-S3 10384.510 21340.000 Act-Stns SLB_MWD+GMAG-No Globe 8.750 OP14-S3/OP14-S3 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (9) (8) (9) (°) (0) (ft) (°) All local minima indicated. • Results filtered:Depth 9172.00 ft c MD<=19505.00 ft • Results filtered:Ct-Ct separation<-1500.00 ft 9100.00 3717.38 -2324.78 -4363.30 21336.11 3872.59 -3539.49 -4898.64 210.24 1328.20 1068.33 5.24 188.82 1 9200.00 3726.09 -2379.03 -4279.75 21231.22 3670.27 -3581.60 -4802.60 209.61 1312.50 1054.78 5.22 168.75 1 8300.00 3733.59 -2431.99 -4195.27 21141.00 3668.98 -3617.55 -4719.87 207.94 1298.06 1041.50 5.19 171.69 1 9400.00 3738.99 -2482.68 -4109.24 21052.38 3870.25 -3653.91 -4639.06 206.59 1287.33 1031.64 5.16 174.45 1 9500.00 3743.60 -2532.51 -4022.66 20959.73 3674.54 -369245 -4554.93 206.57 1278.10 1023.30 5.14 174.88 1 9571.37 3746.89 -2588.07 -396088 20892.71 3678.23 -3720.69 -4494.26 206.58 1271.90 1017.711 5.131 175.06 1 9600.00 3748.38 -2582.35 -3936.10 20860.72 3679.83 -3734.15 -4485.28 208.59 1289.40 1015.70 5.13 174.80 1 9700.00 3755.89 -2632.38 -384983 20758.51 3683.52 -3776.70 -4372.43 206.44 1280.08 1007.69 5.12 173.50 1 9800.00 3766.45 -2682.73 -3784.11 20672.66 3686.34 -3812.78 -4294.57 206.28 1250.93 998.99 5.09 172.56 1 9900.00 3779.89 -2733.34 -3678.89 20592.73 3689.16 -3847.52 -4222.65 205.94 1243.09 991.27 5.06 172.23 1 9975.73 3789.81 -2771.68 -3614.37 20523.82 3688.96 -3877.87 -4160.79 205.49 1237.89 986.631 5.051 189.54 1 10000.00 3792.95 -2783.98 -3593.88 2049487 3687.77 -3890.57 -4134.80 205.28 1238.29 985.58 5.06 168.82 1 • 10100.00 3803.73 -2834.77 -3508.22 20380.38 3678.68 -3938.60 -4031.29 204.39 1227.88 979.13 5.06 168.10 1 10200.00 3811.04 -2885.71 -3422.49 20306.52 3872.80 -3970.19 -3984.81 203.97 1220.40 971.29 5.02 171.36 1 10300.00 381486 -2936.72 -3336.57 20239.93 3669.12 -4000.39 -3905.57 203.73 1215.06 965.06 4.98 175.88 1 10400.00 3815.35 -2987.70 -3250.54 20148.56 3688.44 -4044.00 -382529 203.67 1211.48 961.43 '4.96 177.70 1 1050000 3814.98 -3038.65 -3164.49 20047.14 367106 -4092.65 -3736.34 203.79 1207.74 957.82 4.95 177.81 1 10600.00 3814.61 -3089.60 -3078.45 19958.61 3672.16 -4135.23 -3658.73 203.84 1204.30 953.93 4.93 178.28 1 10700.00 3814.24 -3140.56 -2992.41 19871.26 3673.06 -4178.16 -3582.67 203.89 1202.07 951.10 4.90 178.64 1 10800.00 3814.20 -3191.54 -2908.38 19782.60 3874.65 -4222.50 -3505.90 203.99 1200.73 949.14 4.88 178.87 1 10900.00 3814.28 -3242.54 -2820.36 19699.10 3676.49 -4265.06 -3434.09 204.071 1200.491 947.91 4.88 178.00 1 11000.00 3814.36 -3293.54 -2734.34 19621.26 3680.89 -4306.15 -3368.13 204.29 1202.03 948.2 4.841 175.30 1 11100.00 3814.44 -3344.54 -2648.33 19507.52 3689.32 -4368.54 -3272.12 204.70 1203.86 949.86 4.84 17582 1 11200.00 3814.52 -3395.54 -2562.31 19402.60 3896.15 -4421.34 -3182.91 205.02 1204.75 949.85 4.83 176.44 1 11239.90 3814.55 -3415.89 -2527.98 19367.08 3698.30 -4439.93 -3152.72 205.13 1205.1 4.83 176.46 1 11300.00 3814.33 -3446.53 -2476.28 19316.28 3701.28 -4466.71 -3108.66 20527 1206.12 949.9 4.81 176.18 1 11400.00 3813.90 3497.51 -2390.26 19240.95 3705.28 -4507.35 -3046.36 205.48 1209.15 951.38 4.79 175.98 1 11500.00 3813.48 -3548.49 -2304.23 19164.37 3709.49 -4549.94 -2982.86 205.72 1214.19 954.: 174.59 1 1160000 3813.05 -3599.47 -2218.20 19055.12 3715.99 -4611.66 -2892.95 206.07 1220.34 961.15 4.81 175.75 1 11700.00 3812.62 -3650.46 -2132.18 18924.47 3721.30 -4683.07 -2783.68 208.37 1224.37 96707 4.86 176.90 1 1180000 3812.48 -3701.44 -2046.15 18793.65 3724.14 -4751.35 -2672.14 206.51 1225.55 970.39 4.91 179.79 1 • 1190000 3812.63 -375241 -1960.12 18641.71 3721.37 -4826.87 -2540.35 208.37 1224.53 97246 4.98 177.31 1 1200000 3812.79 -3803.39 -1874.08 18551.01 3719.70 -4870.15 -2460.86 206.27 1220.95 969.98 4.98 177.83 1 12100.00 3812.95 -3854.36 -1788.05 18443.56 3718.54 -4921.54 -2386.31 206.19 1217.44 968.09 500 177.76 1 12200.00 3813.11 -3905.34 -1702.02 18379.20 3719.20 -4953.07 -2310.20 206.21 1 15.10 965.92 4.99 178.61 1 • 12204.58 3813.12 -3907.67 -1698.08 18376.25 371928 -4954.56 -2307.66 206.221 115.061 965.891 4.94 178.56 1 12300.00 3814.87 -3958.30 -161601 18300.61 3722.00 -4993.54 -2242.89 206.29 1215.51 967.02 501 179.33 1 12400.00 3819.14 -4007.24 -1530.06 18198.01 3725.56 -5046.91 -2155.34 206.26 1216.82 969.699 5.04 179.18 1 12500.00 3823.52 -4058.17 -1444.11 18079.86 3729.24 -5107.29 -2053.86 206.19 1217.10 971.69 5.08 179.14 1 12600.00 3827.90 -4109.11 -1358:17 17944.98 3733.98 -5173.75 -1936.59 208.13 1215.26 972.08 5.12 178.05 1 12700.00 3832.28 -4160.04 -1272.22 17819.04 3739.86 -5233.03 -1825.63 206.12 1210.83 969.68 5.15 176.84 1 12800.00 3836.65 -4210.98 -1188.28 17677.27 3746.10 -5296.43 -1698.99 206.10 1203.86 865.47 5.19 174.82 1 12900.00 3840.76 -4261.91 -1100.32 17508.36 3750.73 -5363.31 -1543.99 205.91 1190.81 956.84 5.24 171.48 1 1300000 3844.87 -4312.84 -1014.36 17418.16 3758.30 -5397.38 -1460.67 205.95 1176.12 942.75 5.19 171.83 1 13100.00 3848.98 -4363.77 -928.40 17350.54 3761.73 -5423.96 -1398.74 20604 1163.11 929.23 5.12 173.24 1 13200.00 3853.09 -4414.70 -842.44 17304.29 3765.18 -5443.86 -1357.13 206.10 1154.04 918.95 5.04 175.92 1 13291.27 3856.84 -4461.19 -763.98 17253.13 3768.27 -5467.97 -1312.12 206.14 1149.74 914.11 1111140i1 178.08 1 13300.00 3857.21 -4465.64 -756.48 17242.88 3768.75 -5472.89 -1303.14 208.14 1149.45 914.04 5.01 178.04 1 13320.58 3858.20 -4476.12 -738.80 1721873 3769.64 -548443 -1281.94 206.11 1148.72 913.65 5.02 177.46 1 13400.00 3862.27 -4516.55 -670.56 17051.54 377040 -5557.87 -1131.85 205.67 1142.62 911.05 5.10 172.80 1 ' 13500.00 3887.41 -4567.47 -584.65 16994.89 377143 -5581.86 -1080.55 205.55 1133.19 901.76 5.03 175.38 1 • 13800.00 3872.54 -4618.39 -498.74 16906.92 3775.85 -5621.68 -1002.24 205.52 1126.70 885.79 5.01 176.17 1 • 13700.00 3877.87 -4689.30 -41282 16829.46 378248 -5657.11 -933.69 205.64 1120.77 889.95 4.99 176.76 1 13800.00 3882.42 -4720.23 -328.89 16765.21 3788.19 -5688.30 -877.80 205.78 1117.83 886.79 4.96 176.91 1 • 13825.39 3883.20 -4733.17 -305.06 16748.58 3789.64 -5696.66 -863.50 205.831 1117.551 886.4 4.96 176.55 1 13900.00 3884.18 -4771.20 -240.88 16699.74 3783.73 -5721.84 -821.85 20601 1117.78 886.677 4.981 175.21 1 • 1400000 3883.98 -4822.17 -154.85 16619.45 3799.96 -5764.79 -754.31 206.34 1120.24 889.44 4.97 175.11 1 14100.00 3883.78 -4873.14 -68.82 16538.37 3805.55 -5809.01 -686.57 206.65 1124.09 893.69 5.00 175.48 1 14200.00 3883.57 -4924.12 17.22 16463.42 3808.79 -5851.11 -624.65 206.83 1130.00 900.04 5.03 175.34 1 14300.00 3883.37 -4975.09 103.25 16390.59 3811.05 -5893.38 -565.39 206.98 1138.23 908.79 5.08 174.22 1 • 14400.00 3884.31 -502607 189.27 16304.32 3812.77 -5944.69 -496.07 207.16 1148.34 919.61 5.14 173.88 1 14500.00 3885.91 -5077.05 275.29 16190.31 3813.48 -6012.54 -404.44 207.14 1158.63 930.71 5.20 174.80 1 • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 8 of 55 Trajectory.SI29-S2(P4b)Vs.OP14-S3 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim C1-C1 Distance Clearance OSF Angle Trace# (6) (ft) (6) (6) (6) (6) (#) (ft) (°) (6) (ft) (°) 14600.00 3887.52 -5128.02 :t.1 31 16059.89 381355 -6087.32 -297.60 20/ 13 939.22 5.26 176.05 14700.00 3889.12 -5179.00 447.32 15970.05 3813.86 -6138.63 -223.86 207.03 1173.47 947.20 5.31 175.61 14800.00 3890.72 -5229.98 533.34 15864.14 3813.26 -6198.96 -136.81 206.95 1180.69 955.21 5.37 175.60 14900.00 389210 -5280.95 619.36 15776.70 3810.46 -6248.70 -6497 206.74 1188.07 963.24 5.41 174.84 15000.00 3893.14 -5331.92 705.39 15712.52 3807.81 -6286.35 -13.05 206.60 1197.66 873.37 5.47 173.18 15100.00 3894.17 -5382.89 791.42 15638.72 3805.20 -6331.28 45.43 20647 1209.90 98628 553 172.28 15200.00 3895.21 -5433.86 877.45 15567.11 3803.94 -6375.99 101.36 206.41 1224.03 1001.13 5.61 171.12 15300.00 3896.24 -548483 963.48 15504.09 380321 -6418.71 14944 206.38 1240.85 1018.80 5.71 169.49 15400.00 3897.46 -5538.08 1049.34 15433.91 3802.61 -8463.46 201.77 207.26 1259.92 1038.77 582 168.96 15500.00 3899.64 -558882 113427 15358.97 3802.26 -651456 25659 207.70 1279.38 1059.13 5 93 188.35 15600.00 3901.87 -5641.64 1219.15 15278.16 3802.55 -6570.61 314.81 207.69 1300.27 1080.79 6 04 167 60 15700.00 3904.09 -5894.46 1304.03 15191.21 3803.53 -6631.55 378.82 207.71 1322.11 1103.27 6.16 187.13 15800.00 3908.32 -5747.28 1388.91 15109.56 3804.79 -6689.38 434.45 207.75 1344.94 1126.84 629 186.45 15900.00 3907.49 -5800.68 1473.45 15031.34 3805.69 -6745.47 488.95 208.40 1388.29 1151.00 8.42 186.60 16000.00 3905.86 -5855.77 1558.88 14936.79 3805.75 -6813.91 554.19 209.47 1390.48 1173.60 8.53 187.67 16100.00 3902.24 -5912.16 1639.39 14851.38 3805.39 -6875.78 613.08 209.90 1411.11 1194.79 8.84 167.46 18200.00 3898.51 -5968.60 1721.86 14776.21 3805.28 -8930.94 864.13 210.06 1433.02 1217.47 6.77 186.43 16300.00 3895.17 -6025.84 1803.92 14700.93 3806.67 -6987.11 714.23 211.68 1455.91 1241.13 8.90 186.57 16400.00 3893.37 -8085.09 1884.30 14480.95 3814.74 -7147.30 884.64 214.23 1474.51 1256.97 6.92 172.25 16500.00 3893.04 -6147.06 1962.78 14257.40 3826.55 -7295.31 1031.66 216.65 1479.83 1280.74 8.91 177.31 16600.00 3893.99 -6211.54 2039.20 14157.83 3831.83 -7357.57 1109.20 218.63 1477.21 1258.30 8.91 177.29 16700.00 3896.19 -6278.40 2113.53 14050.75 3836.64 -7425.40 1191.90 220.11 1472.60 1253.79 8.89 178.22 16800.00 3898.76 • -6345.97 2187.21 13977.54 3839.95 -7471.45 1248.72 220.15 1468.80 1248.12 8.87 177.02 16873.33 3900.65 -8395.51 2241.23 13937.12 3842.23 -7497.71 1279.36 220.20 1464.05 1248.01 .x. 177.62 18900.00 3901.21 -6413.55 2280.87 13922.41 3843.15 -7507.43 1290.38 220.33 1463.50 1245.65 6.88 177.13 17000.00 3901.17 -6481.55 2334.18 13723.99 3853.18 -7836.05 1441.04 221.31 1460.44 1241.45 6.83 174.09 17100.00 3897.98 -6550.15 2406.87 13608.81 3850.99 -7706.19 1532.33 221.93 1450.33 1231.23 6.78 173.43 17200.00 3894.49 -8820.23 2478.11 13300.20 3834.08 -7872.83 1791.08 223.52 1429.92 1211.68 6.75 163.02 17300.00 3891.71 -8692.72 2548.94 13220.85 3830.53 -7911.32 1860.60 225.28 1399.93 1181.52 6.60 181.84 17400.00 3889.66 -8767.53 2813.26 13137.83 3827.80 -7952.15 1932.61 227.01 1367.64 1149.11 8.44 180.36 17500.00 3888.25 -6844.87 2676.86 13058.04 3825.76 -7992.16 2001.81 229.10 1332.89 1114.22 6.27 158.73 17600.00 3887.11 -6924.48 2737.10 12983.90 3824.99 -8030.13 2065.28 231.48 1295.25 1076.42 6.08 157.07 17700.00 3886.20 -7008.83 2793.81 12914.48 3824.98 -8066.65 2124.32 233.83 1255.06 1036.08 5.89 155.58 17800.00 3885.50 -7091.29 2847.33 12849.22 3825.21 -8102.08 2179.11 235.00 1213.19 994.10 5.68 155.52 17900.00 3884.68 -7175.51 2901.23 12769.37 3825.63 -8146.52 2245.46 233.43 1173.18 954.01 5.49 157.75 18000.00 3883.17 -7257.41 2958.58 12674.85 3826.12 -8199.51 2323.72 230.88 1137.48 918.24 5.32 180.37 18100.00 3881.25 -7336.28 3020.01 12596.55 3826.32 -8243.52 2388.49 227.97 1106.77 887.47 5.17 184.20 18200.00 3878.97 -7411.82 3085.47 12527.37 3826.58 -8283.75 2444.75 225.05 1083.30 864.02 5.06 188.61 18300.00 3878.34 -7483.84 3154.79 12459.10 3826.98 -8324.97 2499.18 222.12 1067.59 848.44 4.98 173.04 18400.00 3873.70 -7552.50 3227.43 12374.79 3828.32 -8377.41 2565.18 219.83 1058.83 839.57 4.94 175.80 18500.00 3872.11 -7617.55 3303.35 12243.22 3831.38 -8458.71 2668.56 217.17 1054.59 834.45 4.90 177.34 18800.00 3871.19 -7679.62 3381.75 12153.43 3833.21 -8513.19 2739.91 215.311 1052.731 832.31 4.89 177.91 18679.08 3870.81 -7726.76 3445.24 12078.82 3836.00 -8558.89 2798.81 213.91 1054.29 833.5 4.8911 178.51 1870000 3870.75 -7739.00 3462.20 12058.93 3836.96 -8571.11 2814.48 213.97 1055.04 834.22 4.89 176.26 18800.00 3870.47 -7797.51 3543.30 11884.17 3844.81 -8672.61 2958.46 214.42 1053.96 831.68 4.86 177.27 18900.00 3870.19 -7856.02 3824.39 11765.85 3848.04 -8737.65 305526 214.61 1049.61 826.63 4.83 178.55 19000.00 3869.71 -7914.62 3705.42 11675.84 3851.11 -8786.77 3130.62 215.18 1044.69 821.11 4.79 175.89 19100.00 3867.92 -7973.82 3785.99 11582.87 3855.07 -8838.25 3207.94 215.88 1039.97 815.76 4.75 175.67 19200.00 3866.09 -8033.04 3866.55 11497.53 3858.39 -8888.09 3278.52 215.93 1036.11 811.32 4.72 176.88 19300.00 3864.26 -8092.26 3947.11 11409.67 3860.79 -8936.45 3350.47 218.15 1033.76 808.35 4.70 177.14 19400.00 3862.43 -8151.48 4027.67 11308.07 3884.03 -8995.20 3433.30 216.43 1032.06 805.85 4.87 176.58 19500.00 3860.59 -8210.70 4108.23 11160.19 3868.74 -9078.08 3555.67 218.84 1028.45 801.08 4.64 175.74 19505.18 3860.50 -8213.77 4112.40 11151.76 3888.86 -908258 3582.79 216.804 1028.091 800.681 4.631 175.55 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 9 of 55 Field: Nikaitchuq Well: Tuvaaq ST 1 Structure: Nikaitchuq Exploration Borehole: Tuvaaq ST 1 Slot: Tuvaaq ST 1 Trajectory: Tuvaaq ST 1 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.0566753T Grid Scale Factor: 0.999900061 Magnetic Declination: 24.151° Magnetic Declination Date: February 15,2005 Magnetic Model: BGGM 2009 Reference Point: Northinn Eastinp Elevation Structure Unc.(led) Slot Unc.11sdl 6050899.000(ftUS) 507330.900(WS) 35.030(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(In) Borehole I Survey 0.000 32.680 Act-Stns SLB M WD+GMAG-Depth Only-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 32.690 Act-Stns SLB M WD+GMAG-Depth Only-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 2049.020 Act-Stns SLB_MWD+GMAG-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 2949.020 8882.810 Act-Stns SLB_MWD+GMAG"2-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 8862.810 17630.000 Act-Stns SLB_MWD+GMAG"3-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace S (ft) (fl) (6) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.0011 Results filtered:Ct-Ct separation<=1500.00 ft 3717.38 -2324.78 -4363.30 3172.67 2875.12 -2200.40 -5175,28 146.59 1176 51 1 127 81 25.11 132.25 1 3726.09 -2379.03 -4279.75 3121.70 2840.36 -2217.08 -5142.39 145.18 1246 84 1 197.46 26.19 131.47 1 3733 59 -2431 99 -4195.27 3075.63 2808.44 -2233.42 -5112,98 140.80 1318 16 1268 01 27.21 131.81 1 9400.00 3738.99 -248268 -4109.24 3008.39 2759.81 -2258.09 -5089.22 138.74 1389.85 1339.33 28.43 132.94 1 9500.00 3743.60 -2532.51 -4022.66 2933.90 2709.42 -2279.77 -5022.80 135.76 1460.72 1409.89 29.86 133.08 1 End of results • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 14 of 55 r Field: Nikaitchuq Well: Tuvaaq ST 1 Structure: Nikaitchug Exploration Borehole: Kigun 1 PBI Slot: Tuvaaq ST 1 Trajectory: Kigun 1 PB1 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.05667531° Grid Scale Factor: 0.999900061 Magnetic Declination: 24.117" Magnetic Declination Date: March 15,2005 Magnetic Model: BGGM 2009 Reference Point: Northing Easting Elevation Structure Unc.(tsd) Slot Unc.ltsdl 6050899.000(ftUS) 507330.900(ftUS) 35.030(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAS 3-D 95900%Confidence 2.7955 sigma Surveying Proq: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 32.690 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 32.690 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 1837.510 Act-Stns SLB_M WD+GMAG-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 1837.510 2794.000 Act-Stns SLB_MWD+GMAG^^2-No Global 30.000 Kigun 1 PB1/Kigun 1 PBI Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (8) (ft) (ft) (ft) (°) (ft) On (`) All local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.00 ft • Results filtered:Ct-Ct separation<=1500.00 ft 9100.00 3717.38 -2324.78 -4363.30 2794.00 2714.49 -2388.23 -4696.71 138.50 1058.76 1018.51 27.41 94.03 I 9200.00 3726.09 -2379.03 -4279.75 2794.00 2714.49 -2388.23 -4696.71 138.34 1094.20 1052.86 27.55 94.12 1 9300.00 3733.59 -2431.99 -4195.27 2794.00 2714.49 -2388.23 -4696.71 134.01 1136.63 1093.74 27.53 95.27 1 9388.05 3738.34 -2475.73 -4121.32 2794.00 2714.49 -2388.23 -4696.71 131.87 1177.71 1133.31® 96.26 1 9400.00 3738.99 -2482.68 -4109.24 2794.00 2714.49 -2388.23 -4696.71 131.87 1184.75 1140.10 27.51 96.26 1 9500.00 3743.60 -2532.51 -4022.66 2794.00 2714.49 -2388.23 -4696.71 131.87 1238.64 1192.15 27.58 96.26 1 9600.00. 3748.36 -2582.35 -3936.10 2794.00 2714.49 -2388.23 -4696.71 132.08 1298.11 1249.84 27.79 95.70 1 9700.00 3755.69 -2632.38 -3849.83 2794.00 2714.49 -2388.23 -4698.71 132.90 1364.15 1314.20 28.19 93.73 1 9800.00 3766.45 -268273 -3764.11 2794.00 2714.49 -2388.23 -4696.71 134.09 1436.35 1384.87 28.77 91.78 1 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2)SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 15 of 55 1 Field: Nikeitchuq Well: OPO4-07 Structure: Oliktok Point Borehole: OPO4-07 Slot: OPO4 Trajectory: OPO4-07 Client: EN/ Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12913048° Grid Scale Factor: 0.999900318 Magnetic Declination: 21.610° Magnetic Declination Date: June 06,2010 Magnetic Model: BGGM 2010 Reference Point: NorthingEastina Elevation Structure Unc.(lsd) Slot Unc.(lsd) 6036569.440(ftUS) 516739.270(flUS) 53.360(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole I Survey 0.000 41.160 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 OPO4-07PB1/OPO4-07PB1 41.160 41.160 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 OPO4-07PB1/OPO4-07P81 41.160 549.000 Act-Stns SLB_NSG+SSHOT-No Global 16.000 OPO4-07PB1/OPO4-07PB1 549.000 2382.520 Act-Stns SLB_MWD+GMAG-No Global 16.000 OPO4-07PB1/OPO4-07PB1 2382.520 8686.400 Act-Stns SLB_MWD+GMAG-No Global 12.250 OPO4-07PB1/OPO4-07PB1 8686.400 9880.190 Act-Stns SLB_MWD+GMAG-No Global 8.500 OPO4-07PB1/OPO4-07PB1 9880.190 12144.000 Act-Stns SLB MWD+GMAG-No Global 8.500 OPO4-07/OPO4-07 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 9172.00 ft 0=MD<-19505.00 ft Results filtered:Ct-Ct separation<=1500.00 fl 19100.00 3867.92 -7973.82 3785.99 10866.28 3908.76 -7915.32 5275.01 32.49 1490.73 1343.88 10.35 128.65 1 19200.00 3866.09 -8033.04 3866.55 10816.66 3906.25 -7964.82 5277.35 32.45 1413.01 1264.51 9.70 129.17 1 19300.00 3864.26 -8092.26 3947.11 10753.53 3903.52 -8027.82 5280.47 32.36 1335.49 1186.23 9.12 129.16 1 19400.00 3862.43 -8151.48 4027.67 10704.67 3901.97 -8076.58 5283.09 32.25 125827 110116 8.48 129.78 1 19500.00 3860.59 -8210.70 4108.23 10657.45 3901.36 -8123.69 5286.25 32.06 1181.94 1028 68 7.84 130.55 1 1950518 3860.50 -8213.77 4112.40 10654.96 3901.35 -8126.17 5286.44 32.051 1178.011 1024 641 7.811 130.59 1 End of results • • • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 16 of 55 Field: Nikaitchuq Well: OPO4-07 Structure: Oliktok Point Borehole: OPO4-07PB1 Slot: OPO4 Trajectory: OPO4-07P81 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12913048° Grid Scale Factor: 0.999900318 Magnetic Declination: 21.706° Magnetic Declination Date: May 18,2010 Magnetic Model: BGGM 2009 Reference Point: Northing Easting Elevation Structure Unc4lsd) Slot Unc.(led) 6036569.440(WS) 516739.270(ftUS) 53.360(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pro..: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.160 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 OPO4-07PB1/OPO4-07PB1 41.160 41.160 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 OPO4-07PB1/OPO4-07PB1 41.160 549.000 Act-Stns SLB_NSG+SSHOT-No Global 18.000 OPO4-07PB1/OPO4-07PB1 549.000 2382.520 Act-Stns SLB_MWD+GMAG-No Global 16.000 OPO4-07PB1/OPO4-07PB1 2382.520 8686.400 Act-Stns SLB_MWD*GMAG-No Global 12.250 OPO4-07PB1/OPO4-07PB1 8686.400 10540.000 Act-Stns SLB_MWD+GMAG-No Global 8500 OPO4-07PB1/OPO4-07PB1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS•Reference EW Offset MD Offset ND Offset NS Offset EW Adm Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (`) (ft) (ft) (') All local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.00 ft Results filtered:Ct-Ct separation<=1500.00 ft 19200.00 3866.09 -8033.04 3866.55 10540.00 3868.84 -8238.48 5323.34 34.31 1471.20 1342.88 11.88 127.12 1 19300.00 3864.26 -8092.26 3947.11 10540.00 3886.84 -8238.48 5323.34 34.31 1383.98 1251.66 10.80 127.12 1 19400.00 3862.43 -8151.48 4027.67 10540.00 3866.84 -8238.46 5323.34 34.31 1298.60 1161.65 9.76 127.12 1 19500.00 3860.59 -8210.70 4108.23 10540.00 3866.84 -823846 5323.34 34.31 1215.45 1073.13 8.75 127.12 1 19505.18 3860.50 -8213.77 4112.40 10540.00 3866.84 -8238.46 5323.34 34.311 1211.211 1068.591 8.701 127.12 1 End of results , Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 17 of 55 Field: Nikaitchuq Well: OP09-S1 Structure: Oliktok Point Borehole: OP09-S7 Slot: OP09 Trajectory: OP09-S7 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12880319" Grid Scale Factor: 0.999900317 Magnetic Declination: 21.062° Magnetic Declination Date: June 15,2011 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(lsd) Slot Unc.11sdl 8036546.910(ftUS) 516696.900(SUS) 53.400(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.200 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 OP09-S1/OP09-S1 41.200 41.200 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 OP09-S1/OP09-S1 41.200 1202.200 Act-Stns SLB_GYRO-MWD-No Global 18.000 0P09-S1/OPO9-S1 1202.200 2258.530 Act-Stns SLB_MWD+GMAG-No Global 16.000 OPO9-S1/OP09-S1 2256.530 13182.760 Ad-Stns SLB_MWD+GMAG-No Global 12.250 OP09-S1/OP09-S1 13182.760 22370000 Act-Stns SLB MWD0GMAG-No Global 8.750 OP09-S1/OP09-S1 • Reference Cylinder North EOU-EOU Intersection • MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) • (°) All local minima indicated. Results filtered:Depth 9172.00 ft<=MD<=19505.00 ft Results filtered:Ct-Ct separation<=1500.00 ft 0100 00 3717.38 -2324.78 -4363.30 22370.00 3784.71 -1369.82 -3525.21 30.87 1272.35 1019.51 5.05 174.29 1 • 8172.53 3723.70 -2364.13 -4302.70 22370.00 3784.71 -1369.82 -3525.21 30.67 1283.68 1011.871 5.031 174.29 1 9200.00 3726.09 -237903 -4279.75 22370.00 3784.71 -1369.82 -352521 30.55 1$81.46 1010.21 5.04 174.29 1 9300.00 3733.59 -2431.99 -4195.27 22370.00 3784.71 -1369.82 -3525.21 29.021 1256.0641- 1008.5.4 5.08 173.99 1 8400.00 3738.99 -2482.68 -4109.24 22342.83 3789.13 -1382.93 -3501.83 27.59 1257.34 1012.31 5.15 173.25 1 950000 374360 -253251 -4022.66 22250.14 3803.92 -1427.58 -3421.94 27.11 1259,14 101577 5.10 173.83 1 • 8800.00 3748.36 -2582.35 -3936.10 22161.53 3817.32 -1469.62 -3345.12 28.75 1261.82 1020.14 524 174.29 1 970000 3755.69 -2632.38 -3849.83 22055.52 3833.43 -1519.67 -3253.06 26.54 1285.02 1024.36 5.27 176.14 1 • 9800,00 3766.45 -2682.73 -3784.11 21977.74 3844.66 -1556.13 -3185.29 26.68 1269.01 1030.00 5.33 177.02 1 9800.00 3779.69 -2733.34 -3678.89 21875.20 385725 -1603.05 -3094.98 28.81 1274.56 1036.18 5.36 176.74 1 1000000 3792.95 -278398 -3593.68 21765.59 3867.21 -1654.14 -2998.53 27,05 1279.16 1040.99 539 175.65 1 1010000 3803.73 -2834.77 -3508.22 2162746 3871.99 -1720.73 -2877.64 27.57 1281.94 1042.'z AKE 175.18 1 1020000 3811.04 -2885.71 -3422.49 21532.55 3872.04 -1787.43 -2785.02 27.92 1283.74 1045.15 540 176.24 1 10300.00 381486 -2936.72 -3338.57 21449.53 3871.61 -1807.57 -2722.35 28.10 1288.85 1048.77 5.43 177.42 1 1040000 3815.35 -2987.70 -3250.54 21388.63 3871.83 -1845.71 -2651.01 28.13 1291.03 1053.95 5.48 176.99 1 1050000 3814.98 -3038.65 -3184.49 21229.82 3873.37 -1911.98 -2529.05 28.05 1294.83 1056.72 5.46 178.43 1 10600.00 3814.61 -3089.60 -3078.45 21106.48 3876.18 -1973.74 -2422.33 27.91 1295.84 105728 5.45 17820 1 1070000 3814.24 -314056 -2992.41 20991.20 3879.52 -2032.88 -2323.43 27.74 1295.66 1056.61 5.44 178.07 1 10800.00 3814.20 -3191.54 -290638 20886.01 388224 -2087.62 -2233.64 27.65 1294.55 105520 543 178.56 1 10900.00 3814.28 -3242.54 -2820.36 20797.72 3883.63 -2133.37 -2158.15 27.58 1293.69 105425 542 17924 1 1100000 3814.36 -3293.54 -2734.34 20691.37 3884.84 -2187.91 -2066.86 27.54 1293.42 1053.39 5.41 179.41 1 1110000 3814.44 -3344.54 -2646.33 2052331 °3884.46 -2277.66 -1924.80 27.55 1290.98 1049.20 536 176.51 1 11200.00 3814.52 -3395.54 -2582.31 20371.03 3882,80 -2368.48 -1801.12 27.80 1281.80 1038.79 529 174.12 1 11300,00 381433 -3446.53 -2476.28 20303,99 3880.95 -2405.55 -1746.69 27.83 1272.93 102931 524 175.38 1 1140000 3813.90 -3497.51 -2390.26 20227.54 3878.40 -2448.59 -168356 27.71 1266.41 1022.06 520 176.86 1 11500.00 3813.48 -3548.49 -2304.23 20131.04 3878.37 -2502.15 -1603.28 27.69 1261.10 1015.72 5.16 176.84 1 • 11600.00 3813.05 -3589.47 -2218.20 20030.81 3875.52 -2556.14 -1519.97 27.78 1255.31 1009176.71 1 11700.00 3812.82 -3850.48 -2132.18 19942.99 3875.00 -2806.57 -1446.98 27.78 1250.25 1006.4911: 14 177.23 1 11800.00 3812.46 -3701.44 -2046.15 19861.91 3878.88 -2850.75 -1379.00 27.69 12462 1004.111 5.16 177.38 1 11900.00 3812.63 -3752.41 -1960,12 19794.15 3879.52 -2886.42 -1321.45 27.57 1244. 1004.29 5.20 177,53 1 12000.00 3812.79 -3803.39 -1874.08 19728.28 3882.71 -2719.61 -1284.65 27.43 1245.34 1007.31 5.25 176.88 1 1210000 3812.95 -385436 -1788.05 18661.54 3886.37 -2751.65 -1206.22 27.27 1248.95 1013.17 5.32 176.05 1 12200.00 3813.11 -3805.34 -1702.02 19592.68 3889.57 -2783.16 -1145.08 27.14 1255.11 1021.60 5.39 175.34 1 12300.00 3814.87 -395630 -1618,01 19518.10 • 3892.59 -2816.70 -1076.29 28.93 1263.34 1031.88 5.48 174.83 1 12400 00 3819.14 -4007.24 -1530.06 19342.35 3903.73 -2895.06 -921.70 26.75 1270.51 1038.17 5.49 177.00 1 1250000 3823.52 -4058.17 -1444.11 19156.77 3917.19 -2890.44 -763.15 26.51 1269.86 1037.19 5.48 177.94 1 1260000 3827.90 -4109.11 -1358.17 18934.92 3923.84 -3119.51 -58301 26.58 1260.71 1028.33 5.44 17241 1 12700.00 383228 -4160.04 -1272.22 18841.09 3925.85 -3177.49 -509.28 26.63 1247.51 1016.22 5.41 172.80 1 12800.00 3836.65 -4210.98 -1186.28 18765.02 3926.81 -3223.77 -448.92 26.69 1235.49 1005.29 173.54 1 12900.00 3840.76 -4281.91 -1100.32 18697.17 3926.85 -3263.69 -394.04 28.80 1225.84 996.841:1174.65 1 1300000 3844.87 -4312.84 -1014.36 18633.83 392645 -3299.59 -341.62 26.93 1218.98 991.30 .3 178.02 1 13100.00 3848.98 -4363.77 -928.40 18569.24 3926.04 -3334.38 -28745 27.06 1215.0 988.86' 5.39 177.03 1 1320000 3853,09 -4414.70 -842.44 18504.37 3925,88 -3367.85 -231.88 27.211 1214. 989.44 5.42 177.30 1 13300.00 3857.21 -4485.84 -758.48 18441.03 3925.22 -3398.91 -176.68 27.35 1216.01 993.14 5.48 178.27 1 13400.00 3862.27 -4516.55 -870.56 18368.04 3924.24 -3432.85 -112.08 - 27.57 1220.72 999.44 5.54 174.62 1 13500.00 3867.41 -4587,47 -584.65 1828308 3921.76 -3471.09 -36.25 27.90 1227.09 1007.02 5.60 173.60 1 1360000 3872.54 -4818.39 -498.74 18188.02 3918,57 -3513.27 48.88 28.29 1234.21 1015.04 5.65 173.63 1 13700.00 3877.67 -4869.30 -412.82 18058.72 3916.26 -3571.21 164.44 28.72 1241.18 1021.95 5.68 175,65 1 13800.00 3882.42 -4720.23 -326.89 17929.91 3917.09 -3633.06 277.41 29.00 1244.31 1025.22 5.70 178.06 • 1 13900.00 3884.18 -477120 -240.88 17799.04 3918.61 -3897.98 391.04 29.06 1245.92 1027.08 5,71 179.55 1 1400000 3883.98 -4822.17 -15485 1767425 3919.61 -3762.68 497.73 29.00 1244.85 1026.47 5.72 178.83 1 14100.00 3883.78 -4873.14 -68.82 17577.09 3920.28 -3813.69 580.43 28.96 1243.10 1...5.57 5.74 179.14 1 1420000 3883.57 -4924.12 17.22 17487.31 3919.54 -3860.26 657.18 2099 1242.0•NimeNlai 5.76 179.31 1 1430000 3883.37 -4975.09 103.25 17387.52 3918.19 -3811.42 742.84 29.04 1241.65 1025.76 577 179.19 1 1440000 3884.31 -5026.07 189.27 1724548 3916.18 -3986.25 883.55 29.22 1239.71 1023.97 577 177.25 1 14500.00 3885.91 -5077.05 27529 17144.39 3916.67 -4041.51 948.19 29.26 1235.35 1020.2. ikE 177.55 1 14600.00 3887.52 -5128.02 361.31 17065.98 3919.71 -4083.77 1014.16 29.18 1231.06 1017.72 5.77 177.48 1 14700.00 3889.12 -5179.00 447.32 16965.77 3926.03 -4136.56 1099.10 28.95 1228.99 1016.41 5.78 176.67 1 14800.00 3890.72 -5229.98 533.34 16884.75 3931.10 -4179.39 1167.69 28.78 1 27.•,111111iEWF. 5.80 178.17 1 14852.11 3891.56 -5256.54 578.16 16849.86 3932.42 -4197.23 1197.64 28.7• r 1015.70 5.81 179.18 1 14900.00 3892.10 -5280.95 819.36 16804.56 3933.36 -4219.98 1236.80 28.72 122824 101641 5.82 179.53 1 15000.00 3893.14 -5331.82 705.39 16696.51 3933.62 -4274,80 1329.90 2076 1228.48 1016.99 5.83 179.43 1 • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\SI29-S2(P4b) 1/12/2012 4:44 PM Page 18 of 55 Trajectory.SI29-S2(P4b)Vs.OP09-S1 Reference Cylinder North EOU-EOU Intersection MO Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSE Angle Trace*/ (8) (8) (6) (ft) (ft) (ft) (ft) (8) (°) (ft) (ft) (°) 1510000 3894.17 -5382.89 791.42 '604.32 3934.00 -4321.58 1409.36 2_ _ 1228.77 1017.84 5.85 179.37 1 15200.00 389521 -5433.86 877.45 16518.11 3933.79 -4384.47 1484.13 28.84 1230.10 1019.80 5.87 178.70 1 15300.00 3896.24 -5484.83 963.48 16430.78 3934.31 -4407.30 1560.23 28.86 1232.33 1022.62 5.90 178.35 i 15400.00 3897.46 -5538.08 1049.34 18385.34 3934.70 -4438.21 1617.90 29.65 1238.92 1028.28 5.95 175.81 1 15500.00 3899.64 -5588.82 113427 16276.69 3834.15 -4478.33 1696.96 30.19 1245.39 1037.33 6.01 174.56 1 15600.00 3901.87 -5841.84 1219.15 16028.91 3929.27 -4602.69 1911.00 30.68 1248.54 ,799 61 5 97 176.57 1 15700.00 3904.09 -569446 1304.03 15835.19 3923.94 -4716.70 2067.47 31.11 1240 4 173.25 1 15800.00 3906.32 -574728 1388.91 15747.39 3922.58 -4770.59 2136.76 31.26 r. 9 174.27 1 15900.00 3907.49 -5800.68 1473.45 15709.78 3922.41 -4792.69 2187.20 32.11 iFRMER.MIIMIIIME IIN6 178.27 1 16000.00 3905.88 -5855.77 1556.88 15872.02 3922.15 -4813.29 2198.83 33.37 1224.39 9 177.26 1 16100.00 3902.24 -5912.16 1639.39 15608.36 3921.23 -4845.39 2253.79 33.67 1231.19 .,74 175.47 1 16200.00 3898.51 -5968.60 1721.86 15504.25 3917.40 -4897.13 2344.05 33.67 1239.18 1031.1£: 5.98 175.72 1 1630000 3895.17 -6025.64 1803.92 15385.95 3913.38 -4957.30 2445.82 34.88 1246.49 1038.34 6.01 175.38 1 1640000 3893.37 -6085.09 1884.30 15275.88 3911.74 -5014.40 2539.93 36.59 1255.82 1047.50 6.06 174.09 1 16500.00 3893.04 -6147.06 1982.78 15165.12 3912.10 -5072.65 2634.11 38.33 1267.05 1058.94 6.11 172.77 1 1660000 3893.99 -6211.54 2039.20 15079.73 3912.53 -5117.54 2706.75 40.09 1281.72 1073.76 6.19 170.27 1 16700.00 3896.19 -6278.40 2113.53 14988.99 3912.82 -518454 2784.36 41.48 1300.38 1092.46 628 168.49 1 18800.00 3898.78 -6345.97 2187.21 14908.37 3913.39 -5205.77 2853.64 41.55 1320.75 1112.88 6.38 187.73 1 16900.00 3901.21 -8413.55 2260.87 14839.00 3913.70 -5240.27 2913.83 41.84 1342.80 1135.10 6.49 166.46 1 17000.00 3001.17 -8481.55 2334.18 14778.37 3913.87 -5269.04 2987.19 42.83 1367.86 1160.52 8.62 184.42 1 17100.00 3897.98 -6550.15 2406.87 14694.42 3914.00 -5307.45 3041.83 43.52 1395.61 1188.31 6.76 163.37 1 1720000 3894.49 -6620.23 2478.11 14423.15 3919.14 -5441.88 3277.17 44.86 1424.10 1215.35 6.85 167.67 1 17300.00 3891.71 -6892.72 2546.94 14287.91 3928.30 -5531.58 3403.37 46.25 1443.28 1234.66 8.95 188.44 1 17400.00 3889.66 -6767.53 2613.26 14060.95 3931.07 -5659.47 3565.98 47.93 1481.92 1254.25 7.07 171.21 1 17500.00 3888.25 -6844.87 2676.86 13925.89 3930.79 -5748.98 3867.11 50.15 1477.48 1270.28 7.16 170.38 1 1760000 3887.11 -6924.48 2737.10 13820.48 3930.68 -5819.95 3745.05 52.62 1495.94 1288.71 725 188.18 1 19300.00 3864.26 -8092.26 3947.11 11507.48 3742.77 -7489.29 5290.30 41.15 1477.33 1288.31 MilriM 149.52 1 19400.00 3862.43 -8151.48 4027.87 11315.84 3720.44 -7885.54 5362.43 42.48 1427.54 1245.13 7 86 145.26 1 19500.00 3860.59 -8210.70 4108.23 11180.82 3704.17 -7792.87 5404.31 43.64 1 70.72 1191.85 7.70 143.00 1 19505.18 3860.50 -8213.77 4112.40 11173.68 3703.31 -7799.45 5406.32 43.7 1367.6 -11/ 41.0.'--- -7-.84 142.88 1 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI29-S2\SI29-S2\S129S2(P4b) 1/12/2012 4:44 PM Page 19 of 55 Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced / drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels - mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip • sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates,reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 8-1/2" Open Hole / 5-1 '2'" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal,Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools,hole opener runs,decreased mud weight Lost Circulation Low Reduced pump rates,mud rheology, LCM Hole Swabbing on Trips Moderate . Trip speeds,proper hole filling(use of trip sheets),pumping out,backreaming sg W N i'l C O E . cn o Z 'Q N IR 000 l r NO Y J N W 0O o Ei w • J= Q Yo Y U a \ 7 W J j �] Y U m m H Q lL Q (V M in t0 N li PI fi O Q <n m CD 50 O w Dp0 0 Lt c z Q pp Cl, J z J N Q a W o MN = z�z � ^ �/ _�{}� c.c.c.,W ingyp— O Q t& ,,/''."' 9 • \p z a YLC)Z _ a —� / \ a =N b ;,/ I gra Qm mJ �w� 411--- wo P r =tea O CO u_ it_ z a l8 cl, w $ $ $ $ o - 1d g qE a m m m m iii ! G 'g wS MS E Se 17-. 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' i, Y 03 = i I— yO > A C Q. a > °1 It) am � O U �: a JRc 8 4 w0 T- ..1 Qc � > c > a Ed as - o d V L c a > c z � o t4) � vc � a as OU Q I L -7, o c. _ C cv f- 0N0 = 6R - iv z m W y 0 mi O tW � � > aZ ct Z iu to Ct 46 a., Q ch 03 11 d Schlumberger CemCADE*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : SI29-S2 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Joseph Longo Location : Doyon 15 Proposal No. : Draft v1 (P4) Service Point : Prudhoe Bay,Alaska Date Prepared : 01/12/2012 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 cikS�G� c 0L -740AT 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 mtormation.All proposals,recommendations.or predictions are opinions only. NO WARRANTY IS GIVEN 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 : SI29-S2 Noisier 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 : 4576.0 ft BHST : 44 degF Bit Size : 16 in ft (x 1000) psi < J C ' 0- - Fran 1 2 - —Pore —Siltstone— 1.'Sandstone'.1 —Siltstone— ■ Shale •;;Sandstone•. • ■ a– Lc, Coal Well Lithology Formation Press. Page 2 S129-S2 v1 1-12-12.ctw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SI29-S2 ScI rger 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 :4496.0 ft Casing/liner Shoe MD : 4576.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 4576.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 103.1 % Mean OH Equivalent Diameter: 18.317 in Total OH Volume : 1439.2 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 2100.0 16.000 190.0 20.063 4576.0 16.000 35.0 16.822 Page 3 SI29-S2 v1 1-12-12.cfw:01-13-2012; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schl verger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 79 deg Max. DLS : 4.046 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 290.0 0.000 100.0 100.0 0.0 290.0 0.000 200.0 200.0 0.0 290.0 0.000 300.0 300.0 1.5 290.0 1.500 400.0 399.8 5.5 290.0 4.000 500.0 498.9 9.5 290.0 4.000 600.0 596.9 13.5 290.0 4.000 700.0 693.2 17.5 290.0 4.000 776.7 765.7 20.6 290.0 4.003 800.0 787.5 21.5 290.0 3.991 900.0 879.2 25.5 290.0 4.000 1000.0 967.8 29.5 290.0 4.000 1100.0 1053.1 33.5 290.0 4.000 1186.9 1124.1 37.0 290.0 3.993 1200.0 1134.5 37.5 290.0 4.046 1300.0 1211.6 41.5 290.0 4.000 1400.0 1284.2 45.5 290.0 4.000 1500.0 1351.7 49.5 290.0 4.000 1503.7 1354.1 49.7 290.0 4.043 1537.4 1375.9 49.8 290.0 0.475 1600.0 1416.1 50.1 290.0 0.511 1700.0 1479.9 50.6 290.0 0.500 1800.0 1543.0 51.1 290.0 0.500 1900.0 1605.4 51.6 290.0 0.500 2000.0 1667.2 52.1 290.0 0.500 2100.0 1728.2 52.6 290.0 0.500 2200.0 1788.5 53.1 290.0 0.500 2300.0 1848.2 53.6 290.0 0.500 2310.0 1854.1 53.7 290.0 0.501 2400.0 1905.9 56.0 286.6 4.001 2409.6 1911.3 56.3 286.3 3.928 2500.0 1959.9 58.7 283.1 4.002 2600.0 2009.8 61.5 279.8 4.007 2700.0 2055.4 64.3 276.6 3.998 2800.0 2096.4 67.2 273.6 4.000 2900.0 2132.7 70.2 270.7 4.002 3000.0 2164.1 73.2 268.0 3.997 3100.0 2190.5 76.3 265.3 3.998 3114.5 2193.9 76.7 264.9 3.962 3176.1 2207.1 78.6 263.3 4.014 3200.0 2211.8 78.6 263.3 0.000 3300.0 2231.6 78.6 263.3 0.000 3400.0 2251.3 78.6 263.3 0.000 3500.0 2271.1 78.6 263.3 0.000 3600.0 2290.9 78.6 263.3 0.000 3700.0 2310.7 78.6 263.3 0.000 3800.0 2330.5 78.6 263.3 0.000 3900.0 2350.3 78.6 263.3 0.000 4000.0 2370.0 78.6 263.3 0.000 4100.0 2389.8 78.6 263.3 0.000 4200.0 2409.6 78.6 263.3 0.000 4300.0 2429.4 78.6 263.3 0.000 4400.0 2449.2 78.6 263.3 0.000 Page 4 S129-S2 v1 1-12-12.cfw,01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4500.0 2469.0 78.6 263.3 0.000 4576.0 2484.0 78.6 263.3 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 777.0 11.50 8.43 SV-4 Siltstone 1187.0 11.50 8.43 SV-3 Sandstone 1537.0 11.50 8.43 SV-2 Siltstone 2100.0 12.00 8.43 Permafrost Base Shale 2410.0 11.80 8.43 SV-1 Sandstone 3115.0 12.50 8.43 Ugnu Top UG4 Coal 4576.0 12.50 8.43 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 40 0.0 2000.0 1667.2 32 -0.5 i 4576.3 2484.0 44 0.2 ft degF deg 31 q. 40 45 0 ?fl 40 60 80 Geoth.Profile IJ L Deviation I I I Tubular Fluids Annulus- . I 1--,, f i-- -� -� { � I j ! ( 1 _ 1 ill II + li I ld , I 0 I 1 1 O 0 0 0 Temp. Profile At 281 min Deviation Page 5 SI29-S2 v1 1-12-12.cfw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : Sl29-S2 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 lbf/100ft2 Displacement Volume 673.2 bbl Total Volume 1481.2 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 Ibf/100ft2 ASL 633.0 3952.8 10.70 k:9.99E-2 lbf.s^n/ft2 n:0.276 Ty:16.35 lbf/100ft2 LiteCRETE 75.0 623.2 3952.8 12.50 k:3.97E-3 lbf.s^n/ft2 n:0.949 Ty:21.23 lbf/100ft2 Mud 673.2 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2019 psi at 4496.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 61 ton Check Valve Diff Press 164 psi Page 6 SI29-S2 v1 1-12-12.cfw,01-13-2012, LoadCase Surface Casing,Version wcs-cem4f2_12 Client : Eni Petroleum Well : SI29-S2 Scllberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well :S129-S2 String : 13.375"Surface Casing District :Prudhoe Bay,Alaska Country :USA ft lb/gal 0 8 9 10 1I1 1I2 13 - Hydrostatic -Mn.Hydrostatic in -Max.Dynamic -Mn.Dynamic - Frac - Pore • 0 3 0 r, N U N U a N 1 o - , O O' o N • Fluid Sequence Dynamic Well Security bN F..'• ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 lbf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 ASL Load 2 633.0 bbl 10.70 lb/gal Herschel:k=9.99E-2 lbf.s^n/ft2 n=0.276 Ty=16.35 Ibf/100ft2 ■LiteCRETE Load 4 75.0 bbl 12.50 lb/gal Herschel:k=3.97E-3 lbf.s^n/ft2 n=0.949 Ty=21.23 Ibf/100f12 ■Mud 673.2 bbl 9.50 lb/gal Herschel:k=8.28E-2 lbf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 4576.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Selidelliell Page 7 S129-S2 v1 1-12-12.cfw,01-13-2012; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 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 Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug ASL 5.0 633.0 126.6 633.0 80 Start Mixing Lead Slurry LiteCRETE 3.0 75.0 25.0 75.0 80 Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 7.5 10.0 1.3 10.0 80 Kick-Out Plug Pause 0.0 0.0 5.0 0.0 80 Swap to Rig Pumps Mud 7.5 663.2 88.4 673.2 80 Displace to Float Collar Shut-In 0.0 0.0 5.0 0.0 80 Bleed off/Check Floats Total 04:36 hr:mn 1481.2 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 1 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2016 psi at 4496.0 ft Burst 4664 psi at 0.0 ft Temperature Results BHCT 80 degF Simulated Max HCT 72 degF Simulated BHCT 72 degF Max HCT Depth 4576.0 ft CT at TOC 68 degF Max HCT Time 04:36:21 hr:mn:sc Static temperatures : At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 68 degF 40 degF Bottom Hole (degF) 72 degF 44 degF Page 8 SI29-S2 v1 1-12-12.cfw,01-13-2012: LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : Sl29-S2 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD at Casing Shoe: O Depth= 4576 ft Fluids at 180 ft V- (.,11 d N O N- Hydrostatic Dynamic Frac Pore O 5-5Otn �v 4:1- of- O Of- O cd- cd O 30 60 90 120 150 180 210 240 270 300 Time(min) ECD at Conductor Casing Shoe: o Depth= 180 ft ri Hydrostatic N- Dynamic -Frac -Pore O N- � I o 0 o- of o of1 ad- cd O 30 60 90 120 150 180 210 240 270 300 Time (min) Page 9 5129-52 v1 1-12-12.cfw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 ScMibergcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing BHCT Cement Slurry: —to O First Sack Terrp. Last Sack Temp. OO N o -M In _� -co O 0 30 60 90 120 150 180 210 240 270 300 Time(min) Surface Pressure Model: Calc.Pump Press. a 0 T T 0 30 60 90 120 150 180 210 240 270 300 Time (min) Page 10 SI29-S2 v11-12-12.cfw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 ScM brgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 4576 ft co -O Out -O In — N-- O- I ^cam •�� M- N- O — — 0 30 60 90 120 150 180 210 240 270 300 Time (min) Annular Velocity: $ Depth= 4576 ft —Annular Velocity 8- r - O_ 0 0 30 60 90 120 150 180 210 240 270 300 Time(min) Page 11 S129-S2 v1 1-12-12.cfw.01-13-2012; LoadCase Surlace Casing.Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 S hlohrgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: fluid descriptions 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 :673.2 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% Rheometric Measurements Rheometer type :35 (rpm) At 65 degF Geometry : R1 B1 (deg) Spring No : 1.0 300 42.0 200 38.0 100 31.0 60 28.0 30 24.0 6 16.0 3 13.0 I Viscosity:(cP) 10 sec Gel Strength 8.54 lbf/100ft2 10 min Gel Strength 6.40 lbf/100ft2 • Page 12 S129-S2 v1 1-12-12.cfw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : Sl29-S2 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) SPACER Spacer Type : MUDPUSH II Porosity :92.5% Solid Fraction :7.5% Mud Type :WBM Water/Spacer(vol.): 92.0% Job volume : 100.0 bbl BASE FLUID Type : Fresh water Density :8.32 lb/gal Weighting Agent(s) Code Conc. Density D031 95.37 lb/bbl of spacer 270.31 lb/ft3 O (Ib/ft3) Additives Code Conc. Function D182 6.0000 lb/bbl of base fluid Turb.Spacer D047 0.2000 gal/bbl of spacer Antifoam Rheometric Measurements Rheometer type :35 (rpm) At 65 degF Geometry : R1B1 (deg) Spring No : 1.0 300 47.0 200 41.0 100 34.0 60 31.0 30 27.0 6 19.5 3 17.0 I Viscosity:(cP) 10 sec Gel Strength (lbf/100ft2) 10 min Gel Strength (lbf/100ft2) tl Page 13 S129-S2 v1 1-12-12.cfw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ASL Load 2 DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 9.99E-2 Ibf.s^n/ft2 At temp. : 70 degF n :0.276 Ty : 1 6.35 lbf/100ft2 Gel Strength :9.98 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 11.513 gal/sk Job volume :633.0 bbl Dry Density : 110.25 lb/ft3 Yield :2.45 ft3/sk Quantity : 1452.96 sk Sack Weight : 100 lb Solid Fraction : 37.1 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 11.513 gal/sk Rheometric Measurements Rheometer type : 35 (rpm) At 70 degF Geometry : R1 B5 Spring No : 1.0 300 58.0 200 ' 53.0 100 47.0 60 43.5 30 37.0 6 18.1 3 12.1 Viscosity :(cP) 10 sec Gel Strength 10.69 Ibf/100ft2 10 min Gel Strength 9.98 Ibf/100ft2 Page 14 S129-S2 v1 1-12-12.cfw,01-13-2012, LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing LiteCRETE Load 4 DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 3.97E-3 Ibf.s^n/ft2 At temp. : 70 degF n : 0.949 Ty : 21.23 lbf/100ft2 Gel Strength :40.56 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.472 gal/sk Job volume : 75.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity : 269.11 sk Sack Weight : 100 lb Solid Fraction : 53.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.472 gal/sk Additives Code Conc. Function D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D167 0.2500%BWOB Fluid loss D153 0.1000%BWOB Antisettling Rheometric Measurements Rheometer type : 35 (rpm) At 70 degF Geometry : R1B5 (deg) Spring No : 1.0 300 85.0 200 65.0 100 42.5 60 34.5 30 28.5 6 21.9 3 18.8 Viscosity: (cP) 10 sec Gel Strength 26.13 Ibf/100ft2 10 min Gel Strength 45.13 lbf/100ft2 Page 15 5129-S2v11-12-12.cfw,01-13-2012; LoadCase Surface Casing,Version wcs-cem462,,12 Client : Eni Petroleum Well : S129-S2 Schlumlfirger 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 :4566.0 ft Casing Shoe :4576.0 ft NB of Cent. Used :69 NB of Floating Cent. :69 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2016.0 25 1/2 N11-0T-313 TR 0.0 676.0 4536.0 42 2/3 N11-0T-313 TR 19.1 2031.0 4576.0 2 2/1 N11-0T-313 TR 74.7 4536.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (Ibf) N11-0T-313 TR 13 3/8 16.581 14.685 No Weatherford''' 16.000 230.00 2543.00 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications okft 0 20 40 60 80 100 0- ff > { L Between Cent. ._ — + +At Cent. 1- ++ O 1 +$$ o $- 1 I t 0 o- ' co O O _1 O O O 0 Well Pipe Standoff • Page 16 5129-52 v1 1-12-12.cfw.01-13-2012, LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : Sl29-S2 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ft ton 0 25 50 75 100 125 150 175 o- - -.- Hookload Up Hookload Dow n Weight - Drag Force O \ O_ 0 0 O_ 0 N 0 0 O- M O O_ O O O O U)- Running Forces Running Force Calculations: Travelling Block Weight :35.0 ton Friction Factor Centralizer/Formation :0.5 Total Drag Force :58.5 ton Hook load Down Stroke :49.1 ton Hook load Up Stroke :166.0 ton Page 17 SI29-S2 v1 1-12-12.cfw;01-13-2012; LoadCase Surface Casing;Version wcs-cem462_12 wr Client : Eni Petroleum Well : Sl29-S2 Sc h1,1: 13.375 District : Prudhoe Bay,Alaska Y '� Mier Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II ft 0 0 50 100 0 25 50 75 100 1 Std Betw.Cent. Mud Contantination r.� - Cement Coverage '--- ncontaminated Slurry g _ O- IS -- .e.._,_f 1- ) `1 f I _ ....,___________. __ Fluid Sequence Cement Coverage Uncontaminated Slurry 3 z 3 3 z 0I0 0 0 500lIF 500 500 t 500 1000- ,. 1000 1000 1000 1500 1500 1500 . 1500 Via" 2000- 7000 2000- - 2000 rJ I_.. n 2500 - 2500 a a 2500 i IIS 2500 n ar C Q m 3000 3000 3000 �', 3000 3500 3500 3500 3500 4000 4000 4000 4000 4500 4500 4500 4500 I a) 3 a, a, 3 ar -o o -o o v 3 a 3 3 0 3 z z ---- '.- eM 1.'JIt'm' ♦ • t 4 i , r s • 1..4/0.1+t Page 18 S129 S2 v1 1-12-12.cfw;01-13-2012; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger 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 1452971b 1453 sack 100lb D972 269081b 270 sack 100 lb D182 552 lb 23 sack 251b D047 20.0 gal 5 can 5.0 gal D031 95371b 87 sack 1101b D046 54 lb 11 sack 50 lb D065 67 lb 2 sack 50 lb D167 671b 3 sack 251b D153 271b 2 sack 251b Mix Water Requirements : Fresh water 525 BBI 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 6.0000 lb/bbl of base fluid D047 20.000 gal 0.2000 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer ASL Load 2 Volume :633.0 bbl Density : 10.70 lb/gal Yield : 2.45 ft3/sk Dry Phase Liquid Phase Blend: 145296 lb Design Mix Water 398.3 bbl 10.0 bbl LAS Design B809(100 lb 145296.219 Fresh water 398.275 bbl 10.001 bbl lb LiteCRETE Load 4 Volume : 75.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix 35.1 bbl 10.0 bbl LAS Design _ Water D972 26907.930 lb Fresh 35.059 10.001 bbl water bbl D046 53.816 lb 0.2000%BWOB D065 67.270 lb 0.2500%BWOB D167 67.270 lb 0.2500%BWOB D153 26.908 lb 0.1000%BWOB Page 19 SI29-S2 v1 1-12-12.cfw,01-13-2012: LoadCase Surface Casing:Version wcs-cem462_12 Schlumberger CemCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : SI29-S2 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Joseph Longo Location : Doyon 15 Proposal No. : Draft v1 (P4) Service Point : Prudhoe Bay,Alaska Date Prepared : 01/12/2012 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 na n e; �G q��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 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 : SI29-S2 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 : 8992.0 ft BHST : 95 degF Bit Size : 12 1/4 in ft (x 1000) psi < 0 2.5 - Frac —Siltstone— Pore ;'""Shale Coal ■ *14: 41s1 O ,Coal • • •Sandstone• • • .• .••Sandstone ME Shale III Well Lithology Formation Press. Page 2 SI29-S2v11-12-12.cfw;01-13-2012; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 SGMINrger 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) 4576.0 13 3/8 68.0 12.415 Landing Collar MD : 8912.0 ft Casing/liner Shoe MD : 8992.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 8992.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 HYD 563 Mean OH Diameter : 12.250 in 0 Mean Annular Excess : 50.0 /o Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 766.9 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 4.046 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 290.0 0.000 100.0 100.0 0.0 290.0 0.000 200.0 200.0 0.0 290.0 0.000 300.0 300.0 1.5 290.0 1.500 400.0 399.8 5.5 290.0 4.000 500.0 498.9 9.5 290.0 4.000 600.0 596.9 13.5 290.0 4.000 700.0 693.2 17.5 290.0 4.000 776.7 765.7 20.6 290.0 4.003 800.0 787.5 21.5 290.0 3.991 900.0 879.2 25.5 290.0 4.000 1000.0 967.8 29.5 290.0 4.000 1100.0 1053.1 33.5 290.0 4.000 1186.9 1124.1 37.0 290.0 3.993 1200.0 1134.5 37.5 290.0 4.046 1300.0 1211.6 41.5 290.0 4.000 1400.0 1284.2 45.5 290.0 4.000 1500.0 1351.7 49.5 290.0 4.000 1503.7 1354.1 49.7 290.0 4.043 1537.4 1375.9 49.8 290.0 0.475 1600.0 1416.1 50.1 290.0 0.511 1700.0 1479.9 50.6 290.0 0.500 1800.0 1543.0 51.1 290.0 0.500 1900.0 1605.4 51.6 290.0 0.500 1 2000.0 1667.2 52.1 290.0 0.500 2100.0 1728.2 52.6 290.0 0.500 2200.0 1788.5 53.1 290.0 0.500 2300.0 1848.2 53.6 290.0 0.500 2310.0 1854.1 53.7 290.0 0.501 2400.0 1905.9 56.0 286.6 4.001 2409.6 1911.3 56.3 286.3 3.928 2500.0 1959.9 58.7 283.1 4.002 2600.0 2009.8 61.5 279.8 4.007 2700.0 2055.4 64.3 276.6 3.998 Page 3 SI29-S2 vt 1-12-12.cfw,01-13-2012; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 ScNNrger 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) 4576.0 13 3/8 68.0 12.415 • Landing Collar MD : 8912.0 ft Casing/liner Shoe MD : 8992.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 8992.0 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: 13.371 in Total OH Volume : 766.9 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 4.046 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 290.0 0.000 100.0 100.0 0.0 290.0 0.000 200.0 200.0 0.0 290.0 0.000 300.0 300.0 1.5 290.0 1.500 400.0 399.8 5.5 290.0 4.000 500.0 498.9 9.5 290.0 4.000 600.0 596.9 13.5 290.0 4.000 700.0 693.2 17.5 290.0 4.000 776.7 765.7 20.6 290.0 4.003 800.0 787.5 21.5 290.0 3.991 900.0 879.2 25.5 290.0 4.000 1000.0 967.8 29.5 290.0 4.000 1100.0 1053.1 33.5 290.0 4.000 1186.9 1124.1 37.0 290.0 3.993 1200.0 1134.5 37.5 290.0 4.046 1300.0 1211.6 41.5 290.0 4.000 1400.0 1284.2 45.5 290.0 4.000 1500.0 1351.7 49.5 290.0 4.000 1503.7 1354.1 49.7 290.0 4.043 1537.4 1375.9 49.8 290.0 0.475 1600.0 1416.1 50.1 290.0 0.511 1700.0 1479.9 50.6 290.0 0.500 1800.0 1543.0 51.1 290.0 0.500 1900.0 1605.4 51.6 290.0 0.500 2000.0 1667.2 52.1 290.0 0.500 2100.0 1728.2 52.6 290.0 0.500 2200.0 1788.5 53.1 290.0 0.500 2300.0 1848.2 53.6 290.0 0.500 2310.0 1854.1 53.7 290.0 0.501 2400.0 1905.9 56.0 286.6 4.001 2409.6 1911.3 56.3 286.3 3.928 2500.0 1959.9 58.7 283.1 4.002 2600.0 2009.8 61.5 279.8 4.007 2700.0 2055.4 64.3 276.6 3.998 Page 3 SI29-S2 v1 1-12-12.cfw,01-13-2012, LoadCase 9-5/8 Intermediate Casing(a).Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Sckiokrger 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) 2800.0 2096.4 67.2 273.6 4.000 2900.0 2132.7 70.2 270.7 4.002 3000.0 2164.1 73.2 268.0 3.997 3100.0 2190.5 76.3 265.3 3.998 3114.5 2193.9 76.7 264.9 3.962 3176.1 2207.1 78.6 263.3 4.014 3200.0 2211.8 78.6 263.3 0.000 3300.0 2231.6 78.6 263.3 0.000 3400.0 2251.3 78.6 263.3 0.000 3500.0 2271.1 78.6 263.3 0.000 3600.0 2290.9 78.6 263.3 0.000 3700.0 2310.7 78.6 263.3 0.000 3800.0 2330.5 78.6 263.3 0.000 3900.0 2350.3 78.6 263.3 0.000 4000.0 2370.0 78.6 263.3 0.000 4100.0 2389.8 78.6 263.3 0.000 4200.0 2409.6 78.6 263.3 0.000 4300.0 2429.4 78.6 263.3 0.000 4400.0 2449.2 78.6 263.3 0.000 4500.0 2469.0 78.6 263.3 0.000 4576.3 2484.0 78.6 263.3 0.000 4600.0 2488.7 78.6 263.3 0.000 4700.0 2508.5 78.6 263.3 0.000 4800.0 2528.3 78.6 263.3 0.000 4900.0 2548.1 78.6 263.3 0.000 5000.0 2567.9 78.6 263.3 0.000 5100.0 2587.7 78.6 263.3 0.000 5200.0 2607.4 78.6 263.3 0.000 5300.0 2627.2 78.6 263.3 0.000 5400.0 2647.0 78.6 263.3 0.000 5442.0 2655.3 78.6 263.3 0.000 5500.0 2667.2 77.8 261.1 -3.994 5600.0 2689.5 76.4 257.2 -4.003 5613.8 2692.7 76.3 256.7 -4.020 5700.0 2714.0 75.2 253.3 -3.998 5800.0 2740.6 74.0 249.3 -4.004 5900.0 2769.2 72.8 245.3 -3.999 6000.0 2799.6 71.8 241.3 -4.001 6100.0 2831.7 70.8 237.2 -3.993 6186.0 2860.5 70.0 233.6 -4.009 6200.0 2865.3 69.9 233.0 -3.985 6300.0 2900.3 69.1 228.9 -3.993 6400.0 2936.5 68.4 224.6 -4.002 6500.0 2973.7 67.9 220.4 -4.004 6600.0 3011.7 67.4 216.1 -3.994 6700.0 3050.4 67.1 211.7 -4.008 6800.0 3089.5 66.8 207.4 -4.000 6900.0 3129.0 66.7 203.1 -3.999 7000.0 3168.5 66.7 198.7 3.996 7100.0 3207.8 66.9 194.4 4.000 7120.9 3216.0 66.9 193.4 4.009 7200.0 3246.9 67.1 190.0 4.001 7300.0 3285.5 67.5 185.7 3.993 7400.0 3323.4 68.0 181.4 4.008 7500.0 3360.4 68.6 177.1 3.992 7600.0 3396.4 69.3 172.9 4.008 7700.0 3431.2 70.1 168.7 4.000 Page 4 SI29-S2 v1 1-12-12.cfw;01-13-2012; LoadCase 9-5/8 Intermediate Casing(al;Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 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) 7747.9 3447.4 70.5 166.8 3.989 7800.0 3464.6 71.0 164.6 4.003 7881.9 3490.7 71.8 161.3 3.997 7900.0 3496.4 71.9 160.5 4.024 8000.0 3526.5 73.0 156.5 3.998 8014.3 3530.6 73.2 155.9 4.039 8100.0 3554.7 74.2 152.5 3.989 8130.1 3562.8 74.5 151.3 4.021 8191.6 3578.8 75.3 148.9 3.995 8200.0 3581.0 75.4 148.5 4.020 8300.0 3605.1 76.7 144.6 3.999 8400.0 3627.0 78.0 140.8 3.998 8500.0 3646.5 79.4 137.0 4.003 8571.6 3659.0 80.5 134.2 4.008 8600.0 3663.6 80.9 133.2 3.988 8700.0 3678.2 82.4 129.4 3.998 8800.0 3690.1 83.9 125.7 3.999 8872.5 3697.2 85.0 123.0 4.001 8900.0 3699.5 85.0 123.0 0.000 8992.0 3707.6 85.0 123.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 777.0 11.50 8.43 SV-4 Siltstone 1187.0 11.50 8.43 SV-3 Sandstone 1537.0 11.50 8.43 SV-2 Siltstone 2100.0 12.00 8.43 Permafrost Base Shale 2410.0 11.80 8.43 SV-1 Sandstone 3115.0 12.50 8.43 Ugnu Top UG4 Coal 4576.0 12.50 8.43 Surf. Csg. Shoe Shale 5614.0 12.30 8.43 UG-2 Coal Bed Marker Coal 6186.0 12.50 8.43 Fault 1 Sandstone 7121.0 12.50 8.43 Lower Ugnu Sandstone 7748.0 12.50 8.43 Schrader Bluff Shale 7882.0 12.50 8.43 N Seq Top Sandstone 8014.0 12.50 8.43 N Sand Top Sandstone 8192.0 12.50 8.43 N Sand Bottom Sandstone 8572.0 12.50 8.43 N Seq Base Sandstone 8992.0 12.50 8.43 TD Csg. Pt. Shale 9046.0 12.50 8.43 OA Sand Top Sandstone Page 5 SI29-S2 v1 1-12-12.cfw.01-13-2012, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger 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 40 0.0 2100.0 1728.2 32 -0.5 8992.0 3707.6 95 1.5 9046.0 3712.3 95 1.5 ft degF deg 75 100 0 ''' 60 90 Geoth.Profile I I -- Deviation Tubular Fluids Annulus _ 0 Ln • Temp. Profile At 150 min Deviation Page 6 SI29-S2 v1 1-12-12.cfw;01-13-2012; LoadCase9-5/8Intermediate Casing(a),Version wcs-cenr462_12 • Client : Eni Petroleum Well : S129-S2 Schloberger 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 @ 7,014'(1,000'above the"N"Top) Original fluid Mud 9.40 lb/gal k:5.97E-3 Ibf.s^n/ft2 n :0.616 Ty: 8.86 lbf/100ft2 Displacement Volume 675.8 bbl Total Volume 917.8 bbl TOC 7008.8 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 6172.2 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 LiteCRETE 172.0 1983.2 7008.8 12.50 Pv:168.266 cP Ty:26.14 Ibf/100ft2 Mud 675.8 0.0 9.40 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks Frac 400 psi at 4576.0 ft Pore 125 psi at 4576.0 ft Collapse 2528 psi at 8912.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 60 ton Check Valve Diff Press 103 psi Page 7 SI29-S2 v1 1-12-12.cfw.01-13-2012, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 SCM 1141 8011 String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * Ce"CADE Client : Eni Petroleum Well :S129-S2 String :9-5/8"Intermediate Casing District :Prudhoe Bay,Alaska Country : USA lb/gal ft o- 8 9 10 1i1 1I2 1I3 —Hydrostatic —Mn.Hydrostatic —Max.Dynamic —Mn.Dynamic — Frac 1 o I —Fore o N NI - Q• Op - w O— c _. - I O i 0_ (13 E I I • O 1 I O_ I co U J N O 1 2C — L Fluid Sequence Dynamic Well Security N ■MUDPUSH II 70.0 bbl 10.50 lb/gal Herschel:k =5.23E-2 Ibf.s^n/ft2 n =0.324 Ty=12.92 lbf/100ft2 m ■LiteCRETE Load 4 172.0 bbl 12.50 lb/gal Bingham:FV=168.266 cP Ty=26.14 lbf/100ft2 ■Mud 675.8 bbl 9.40 lb/gal Herschel:k =5.97E-3 Ibf.s^n/ft2 n =0.616 Ty=8.86 Ibf/100f12 II Total Depth = 8992.0 ft Top of Cement= 7008.8 ft *Mark of Schlumberger Sept Page 8 SI29-S2 v1 1-12-12.cfw,01-13-2012; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 SGhlumingur 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 lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Begin Mixing Slurry LiteCRETE 5.0 172.0 34.4 172.0 80 Mix&Pump Cement Slurry(3 to 7 BPM) 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 Pause 0.0 0.0 5.0 0.0 80 Swap to Rig Pumps Mud 8.5 665.8 78.3 675.8 80 Displace to Float Collar Pause 0.0 0.0 5.0 0.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 02:28 hr:mn 917.8 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 195 psi at 8992.0 ft Pore 125 psi at 4576.0 ft Collapse 2494 psi at 98.2 ft Burst 4468 psi at 0.0 ft Temperature Results BHCT 88 degF Simulated Max HCT 73 degF Simulated BHCT 69 degF Max HCT Depth 0.0 ft CT at TOC 69 degF Max HCT Time 02:23:54 hr:mn:sc Static temperatures : At Time 00:00 hr:mn 00:01 hr:mn Geo.Temp. Top of Cement 69 degF 69 degF 78 degF 1 Bottom Hole 69 degF 69 degF 95 degF Page 9 SI29-S2 v1 1-12-12.cfw;01-13-2012; LoadCase 9-5/8 Intermediate Casing(al;Version wcs-cem462_12 Client : Eni Petroleum Well : SI29-S2 ScMl�n�rg�r String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD at Casing Shoe: O Depth= 8992 ft ri O Hydrostatic O Dynamic Frac Fore u) O ai oziO O) U - 00 0 20 40 60 80 100 120 140 160 Time(min) ECD at Surface Casing Shoe: Depth= 4576 ft Fluids at 8992 ft cd U N o N- I - Hydrostatic O III Dynamic Frac Pore Od O� U 0 20 40 60 80 100 120 140 160 Time(min) Page 10 8129-S2 vl 1-12-12.cfw 01-13-2012, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : Sl29-S2 SChi i String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) BHCT Cement Slurry: -10 o First Sack Temp. Last Sack Temp. o_] —N Lo. -M o -QT" �✓ I T 0 20 40 60 80 100 120 140 160 Time(min) Surface Pressure Model: calx.R,mp R-ess. N O X •�o to d � d N d — I 0 0 20 40 60 80 100 120 140 160 Time(min) Page 11 S129-02 v1 1-12-12.cfw.01-13-2012; LoadCase 9-5/8 Intermediate Casing(aI,Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Sckikerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Returns Rate: Fluids at 8992 ft 0 Out I Q In r- co ^c 7 v- N- 0 20 40 60 80 100 120 140 160 Time (min) Annular Velocity: Depth= 8992 ft Annular Velocity N- E Imo- ��l 0 20 40 60 80 100 120 140 160 Time(min) Page 12 S129-S2v11-12-12.cfw,01-13-2012; LoadCase 9-5/8 Intermediate Casing Ca) Versionwcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: fluid descriptions Mud DESIGN Fluid No: 1 Density : 9.40 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 :675.8 bbl Water Type : Fresh VOLUME FRACTION Solids :6.0% Oil : 1.0% Water :93.0% Rheometric Measurements Rheometer type : 35 (rpm) At 80 degF Geometry : R1 B1 (deg) Spring No : 1.0 600 50.0 300 35.0 200 30.0 100 23.0 6 11.0 3 9.0 I Viscosity:(cP) 10 sec Gel Strength 17.08 Ibf/100ft2 10 min Gel Strength 32.02 lbf/100ft2 Page 13 SI29-S2 v1 1-12-12.cfw;01-13-2012, LoadCase 9-5/8 Intermediate Casing lal;Verson wcs-cem462_12 Client : Eni Petroleum Well : Sl29-S2 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) MUDPUSH II DESIGN Fluid No:2 Density : 10.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 Ibf.s"n/ft2 At temp. :65 degF n :0.324 Ty : 12.92 Ibf/100ft2 Gel Strength :40.56 lbf/100ft2 SPACER Spacer Type :MUDPUSH II Porosity : 91.1 % Solid Fraction :8.9% Mud Type :WBM Water/Spacer(vol.): 91.1 % Job volume :70.0 bbl BASE FLUID Type : Fresh water Density :8.32 lb/gal Weighting Agent(s) Code Conc. Density D031 117.13 Ib/bbl of spacer 270.31 Ib/ft3 () (Ib/ft3) Additives Code Conc. Function D182 6.0000 lb/bbl of base fluid Turb. Spacer D046 0.2000 lb/bbl of base fluid Antifoam Rheometric Measurements Rheometer type :35 (rpm) At 65 degF Geometry : R1 B1 (deg) Spring No : 1.0 300 51.5 200 46.5 100 39.0 60 36.5 30 32.5 6 24.5 3 21.5 I Viscosity: (cP) 10 sec Gel Strength 20.28 lbf/100ft2 10 min Gel Strength 40.56 lbf/100ft2 Page 14 0129-S2 v1 1-12-12.cfw;01-13-2012, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) LiteCRETE Load 4 DESIGN Fluid No: 7 Density : 12.50 lb/gal Rheo. Model : BINGHAM Pv : 168.266 cP At temp. : 50 degF Ty :26.14 Ibf/100ft2 Gel Strength : 57.01 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.471 gal/sk Job volume : 172.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity : 617.13 sk Sack Weight : 100 lb Solid Fraction : 53.3 BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.471 gal/sk Additives Code Conc. Function D167 0.2500%BWOB Fluid loss D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D153 0.1000%BWOB Antisettling Rheometric Measurements Rheometer type : 35 (rpm) At 50 degF Geometry : R1 B5 (deg) Spring No : 1.0 300 101.0 200 75.5 100 50.0 60 40.0 30 33.0 6 27.2 3 24.6 Pv : 168.266 cP Ty:26.14 Ibf/100ft2 10 sec Gel Strength 33.25 Ibf/100ft2 10 min Gel Strength 57.01 Ibf/100ft2 Page 15 SI29-02 v1 1-12-12.cfw.01-13-2012, LoadCase 9-5/8 Intermediate Casing lal:Version wcs-cem462_12 Client : Eni Petroleum Well : SI29-S2 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: centralizer placement Top of centralization :3000.0 ft Bottom Cent. MD :8982.0 ft Casing Shoe :8992.0 ft NB of Cent. Used :21 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 7912.0 0 0/0 0.0 7930.5 8232.0 8 1/1 NW-ST-9 5/8-6-ST A3A WO9R 0.0 8215.3 8512.0 0 0/0 0.0 8232.0 8952.0 11 1/1 NW-ST-9 5/8-6-ST A3A WO9R 0.0 8528.8 8992.0 2 2/1 NW-ST-9 5/8-6-ST A3A WO9R 83.9 8962.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-ST-9 5/8-6-ST WO9R 9 5/8 14.583 10.882 No Hannover 12.625 768.85 1656.84 A3A (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft 0 20 40 60 80 100 o < 8 Betw een Cent. r ' '+ +At Cent. I I Well Pipe Standoff Page 16 SI29-S2 v1 1-12-12.crw;01-13-2012, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem462_12 Client : Eni Petroleum Well : S129-S2 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 61713 lb 617 sack 100lb D182 382 lb 16 sack 251b D046 136 lb 3 sack 501b D031 8199 lb 75 sack 110 lb D167 154 lb 7 sack 251b D065 154 lb 4 sack 501b D153 621b 3 sack 251b Mix Water Requirements : Fresh water 145 BBI 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 6.0000 lb/bbl of base fluid D046 12.749 lb 0.2000 lb/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer LiteCRETE Load 4 Volume : 172.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 62206 lb Design Mix 80.4 bbl 10.0 bbl LAS Design . Water D972 61712.605 lb Fresh 80.395 bbl 10.001 bbl water D167 154.282 lb 0.2500%BWOB D046 123.425 lb 0.2000%BWOB D065 154.282 lb 0.2500%BWOB D153 61.713 lb 0.1000%BWOB Page 17 SI29-S2 v1 1-12-12.cfw,01-13-2012; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem462_12 vsk eni us operating WELL SI29-S2 Drilling Procedure SI29-S2 Spy Island Conductor slot #29 Reservoir location #S2 Injector (Schrader Bluff) Nikaitchuq Project S129-S2 Drilling Wellplan Page 1 of 39 01/16/12 141/4 en� us operating WELL SI29-S2 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Injector Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 4-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. S129-S2 Drilling Wellplan Page 4 of 39 01/16/12 enn us operating WELL SI29-S2 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2. Land Intermediate casing point within 100' radius of the planned directional target. 3. Land the Intermediate hole section with the targeted inclination of 85° -87° above the OA sand. Maximum dogleg severity in the landing shall be no greater than 3.5°/100' DLS. 4. Target Greater than 90%within the OA sand Reservoir. 5. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD—Require GR/Res/Dir to achieve TD. SI29-S2 Drilling Wellplan Page 5 of 39 01/16/12 irAis enn us ope athriig WELL SI29-S2 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPO Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators,and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. ➢ Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SI29-S2 Drilling Wellplan Page 6 of 39 01/16/12 troll — 2 r11° Ms op rrafins WELL SI29-S2 SURFACE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (4b) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-3 1187 1124 SV-2 1537 1376 B/Permafrost 2100 1728 SV-1 2410 1911 Ugnu Top (UG4) 3115 2194 13-3/8" Csg 4576 2484 SCP UG-2 Coal Bed Marker 5614 2693 Fault 1 6186 2861 Lower Ugnu 7121 3216 Schrader Bluff Top 7748 3448 N Sequence Top 7882 3491 N Top 8014 3531 ReCalc Intermediate Cement w/Actual Fault 2 8130 3563 N Bottom 8192 3579 N Sequence Base 8572 3659 9-5/8" Casing 8992 3708 ICP-Set ABOVE OA Sand Top OA Sand Top 9046 3713 OA-2 Top 9125 3720 OA-3 Top 9204 3726 Fault A 9974 3790 Fault B 11873 3813 Fault C 17990 3883 4-1/2" Liner 19505 3860 Total Depth SI29-S2 Drilling Wellplan Page 7 of 39 01/16/12 • enll us opc rr h nag WELL SI29-S2 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diaaram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth Loss PH (ppg) Reading (ml/30min) (mg/1) 110'- 1800' 8.8-9.2 20-24 <8 <2000 9.0-9.5 Surface: 1800'-C.P. 9.2-9.5 20-24 <6 <2000 9.0-9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppJ) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections Surface Hole Procedure: SI29-S2 Drilling Wellplan Page 8 of 39 01/16/12 2nO Ms cooperr hno WELL SI29-S2 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. V • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. ➢ Consider adding 0.5%Drilzone for screen blinding in shallow intervals right below the conductor. 5. Surface casing point: ➢ Landed in good shale found in this area between 2000' SSTVD and 2150'SSTVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). ➢ Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: ➢ Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher ➢ Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. SI29-S2 Drilling Wellplan Page 9 of 39 01/16/12 ifoi* 2 rr11 D us ©p`rr ung WELL S129-S2 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from:While backreaming out of the hole in the transition from horizontal to vertical, have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PPO) Type (in) (Psi) (Psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque(ft.lbs) OD WT Opt. (in) (PPOGrade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. SI29-S2 Drilling Wellplan Page 10 of 39 01/16/12 2n us operating WELL SI29-S2 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: ➢ obtain SO Weights every 10 joints ➢ obtain PU Weights every 10 joints 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel hanger 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotarytable. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 18 13-3/8"Tandem Rise Weatherford SI29-S2 Drilling Wellplan Page 11 of 39 01/16/12 2nD us co perr ins WELL S129-S2 Surface Centralizer Placement 10' float 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of l' joint. • 1 at 10'above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry),1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. kb. SI29-S2 Drilling Wellplan Page 12 of 39 01/16/12 2nD co* us operating WELL SI29-S2 Surface Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 633 bbls Yield 2.45 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 75 bbls yield 1.56 ft3/sk Top of Tail @ 3,953'MD Surface Cementing Casing Cementing Notes ,1 a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. > To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool ➢ If necessary,rack TAM running tool in derrick and ready to run > Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. ➢ Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than`/z the shoe joint volume). SI29-S2 Drilling Wellplan Page 13 of 39 01/16/12 • 2no us ©perrahns WELL SI29-S2 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low > Do not test BOPE against casing. > Notify AOGCC 24 hours prior to performing BOP test. ■ PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC �� S129-S2 Drilling Wellplan Page 14 of 39 01/16/12 iffy* 2nD us oper has WELL SI29-S2 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit ■ Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM > 120— 140 RPM > See BHA attachment for running order and specifications 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. > Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note:All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50'of new hole using spud mud. 5. Displace hole to new LSND mud system. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. > PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. SI29-S2 Drilling Wellplan Page 15 of 39 01/16/12 voiht en us operating WELL SI29-S2 INTERMEDIATE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (4b) Measured True Formation Tops Depth,ft Vertical Comments Depth,ft SV-3 1187 1124 SV-2 1537 1376 B/Permafrost 2100 1728 SV-1 2410 1911 Ugnu Top(UG4) 3115 2194 13-3/8" Csg 4576 2484 SCP UG-2 Coal Bed Marker 5614 2693 Fault 1 6186 2861 Lower Ugnu 7121 3216 Schrader Bluff Top 7748 3448 N Sequence Top 7882 3491 N Top 8014 3531 ReCalc Intermediate Cement w/Actual Fault 2 8130 3563 N Bottom 8192 3579 N Sequence Base 8572 3659 9-5/8" Casing 8992 3708 ICP-Set ABOVE OA Sand Top OA Sand Top 9046 3713 OA-2 Top 9125 3720 OA-3 Top 9204 3726 Fault A 9974 3790 Fault B 11873 3813 Fault C 17990 3883 4-1/2" Liner 19505 3860 Total Depth - SI29-S2 Drilling Wellplan Page 16 of 39 01/16/12 10* en us operating WELL SI29-S2 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density PV 6 RPM API FL pH Drill Solids MBT (ppg) Reading (ml/30min) (/o) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 Intermediate Lo22in2/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Joint Body DP Tool Make Up Tensile WT Conn. Joint Body Torsion Torsional capacity Pipe (ppb Grade Type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity ID(in) (ft .lbs) (kips) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300'TVD from the top of the uppermost OA sand and at least 200'MD in length. b. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). c. Shallow test MWD tools. d. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off'slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. SI29-S2 Drilling Wellplan Page 17 of 39 01/16/12 2n us orr � �Cnng WELL S129-S2 Intermediate Drilling 1. Directionally Drill 12-1/4"hole - Use the following Parameters: • Flow rate of 900 GPM • 120— 140 RPM 2. Casing Point:Land Intermediate casing 50'into the 0A2 sand reservoir 3. LOW ROP:Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: ➢ Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-S1:While backreaming out of the hole in the transition from horizontal to ✓' vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. ➢ Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. S129-S2 Drilling Wellplan Page 18 of 39 01/16/12 2n us operating WELL SI29-S2 • Intermediate Casing Program: (all depths feet RKB) OD 1J'T Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppf Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque(ft.lbs) Min. Target Max. ODWT Make ( Grade Conn. Type Torque,Uft- Make Up Make Up Yield Torque lbs Torque Torque 9-5/8 40 L-80 H563il 10,800 13,000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: I. Have a spare float shoe and collar made up with centralizers and on location ready to go D Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. D Draw a longitudinal line across the pin and box and reapply the published target torque. D If the drawn line does not move more than'/"after the second torque application,continue running the rest of the string normally using the published target torque. ➢ If the drawn line moves more than'h"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than''A",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than'h",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than'/2". SI29-S2 Drilling Wellplan Page 19 of 39 01/16/12 • en II us operr one WELL SI29-S2 • It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order 1 Float shoe—Davis-Lynch Model 501-DV-PVTS Baker-Lock down jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydrofonns(Floating) Volant 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. ➢ Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000'MD and check flow through floats. Circulate bottoms up each time. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights every 10 joints 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. SI29-S2 Drilling Wellplan Page 20 of 39 01/16/12 lot . • 2nd us op aCn rrrnng WELL SI29-S2 Intermediate Centralizer Placement 111 1 I 10' Float 9-5/8"x 11-3/4" Hydroform Centralizers Collar Run 1 H'droform: • On Stop collar 5'above Float shoe. • On centStop on next joint • On Stop collar 10'above Float Collar. • From 4th joint to+/-1000'above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500'above N sand oil bearing zone , 5' ,____: ___ _if_ SI29-S2 Drilling Wellplan Page 21 of 39 01/16/12 us op rr long WELL SI29-S2 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9-5/8" Mudpush II 70 bbls Density 10.5 ppg DeepCrete 172 bbls Density 12.5 ppg Top of Cement @ 7,014'MD (617 sacks) Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement no more than 1/2 the shoe ioint vs ii- c. or injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. J' 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! ➢ Cement volume is based on 50%excess and at least 1000'of annular fill above top of the N sand(highest known hydrocarbon bearing zone). Refer to attached cement detail sheet for volumes. ✓ 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps and LSND water-based drilling mud. > Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. > Pump cement at 5 bpm and displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger / ➢ Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. ➢ Do not exceed 80%of intermediate casing collapse ➢ Record test on IADC report and in WellView S129-S2 Drilling Wellplan Page 22 of 39 01/16/12 2nd �S op rrahhns WELL SI29-S2 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. D Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. D Pressure limitations are as follows:80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) D Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) D Test rams and choke manifold components to 3500 psi high/250 psi low D Test annular preventer to 2500 psi high/250 psi low D Do not test BOPE against casing. D Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite SI29-S2 Drilling Wellplan Page 23 of 39 01/16/12 fiAls eni els operating WELL SI29-S2 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. D. 8-3/4"PDC D Rotary Steerable > Flow rate: 550 GPM ➢ 120- 140 RPM 2. RIH to the float equipment. D. Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). D Plot Casing Pressure Test on the Pressure LOT form in N drive Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid D Do not contaminate new OBM in rig pits D Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. D See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50'of new hole using the Oil Based Reservoir Drill-1n fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. D PU into casing and perform LOT. D If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines L.-Or/Fir r/Fit (attached). D If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. �---- ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. D Plot on LOT form in N drive SI29-S2 Drilling Wellplan Page 24 of 39 01/16/12 10* 2ri us op 1aHns WELL SI29-S2 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan -1,1)1 Measured True Formation Tops Depth,ft Vertical Comments Depth,ft SV-3 1187 1124 SV-2 1537 1376 B/Permafrost 2100 1728 SV-1 2410 1911 Ugnu Top(UG4) 3115 2194 13-3/8" Csg 4576 2484 SCP UG-2 Coal Bed Marker 5614 2693 Fault 1 6186 2861 Lower Ugnu 7121 3216 Schrader Bluff Top 7748 3448 N Sequence Top 7882 3491 N Top 8014 3531 ReCalc Intermediate Cement w/Actual Fault 2 8130 3563 N Bottom 8192 3579 N Sequence Base 8572 3659 9-5/8" Casing 8992 3708 ICP- Set ABOVE OA Sand Top OA Sand Top 9046 3713 OA-2 Top 9125 3720 OA-3 Top 9204 3726 Fault A 9974 3790 Fault B 11873 3813 Fault C 17990 3883 4-1/2" Liner 19505 3860 Total Depth SI29-S2 Drilling Wellplan Page 25 of 39 01/16/12 en II WELL S129-S2 Production Mud Program: FazePro Density HTHP FL Electrical Interval (ppg) VP (ml/30min) Oil:water Stability mlVolts Production 9.2 V 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) • LWD GR/Res/Sonic Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile Pipe WT Grade Conn. Joint Joint Body Torsion Torsional capacity Torque Capacity (ppj) type OD ID(in) al Yield Yield w/conn. (in) ID in t.lbs) (ft lbs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. SI29-S2 Drilling Wellplan Page 26 of 39 01/16/12 roill en Ms operating WELL SI29-S2 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. • Geosteering will be required to remain in the target boundary 100%of the time D Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. D Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: D At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM D Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE:2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreaming until depth at which itis possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. D Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA D When out of hole,down load the recorded tool data and send to the Geologist in town S129-S2 Drilling Wellplan Page 27 of 39 01/16/12 looteni us operating WELL SI29-S2 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (ppJ) Type (in) (psi) (psi) (kips) • 4-1/2 11.6 L-80 H52dnl 4.695 3.960 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Min. Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield (in) (ppJ) Torque, ft Torque Torque* Torque lbs 4-1/2 11.6 L-80 Hydril 521 3600 6300 N/A 16,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 4-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • The liner will be run in FazePro RDF. Consult with completions engineer for liner detail. Liner string will be adjusted according to actual depths after drilling. Consult with completion engineer and ops geologist to determine exact placement and number of swell packers prior to installation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: SI29-S2 Drilling Wellplan Page 28 of 39 01/16/12 2nA us operr hng WELL S129-S2 String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 4-1/2"11.6#Hydril 521 16,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 4650 mch rel,2 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix"and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIB with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO, and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt.immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIB with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. SI29-S2 Drilling Wellplan Page 29 of 39 01/16/12 1101 2n� us operating WELL S129-S2 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test,rotating dog sub can be used to set packer. If running tool cannot be hydraulically released,4,650 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 pog KC1 brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. SI29-S2 Drilling Wellplan Page 30 of 39 01/16/12 2no Ms operrfing WELL SI29-S2 ATTACHMENTS 1. Area of Review 2. Recommended Drilling Practices 3. Health,Safety,and Environment 4. Safety Meeting Topics 5. Well Shut In Procedure While Running Tubing 6. Conductor Broaching Contingency Plan 7. Port Collar Decision Tree SI29-S2 Drilling Wellplan Page 31 of 39 01/16/12 • ii • en� us operfing WELL 5129-S2 Area of Review To the knowledge of Eni US Operating Co.Inc.there are no other wells completed in the Schrader Bluff formation other then those stated in the attached 1/4 mile scan report. The Nikaitchuq Unit also includes the following wells drilled by Kerr McGee Oil&Gas Corporation: Nikaitchuq#1: Plugged and Abandoned 04/01/04 Nikaitchuq#2: Plugged and Abandoned 04/01/04(East of Nikaitchuq Unit) Nikaitchuq#3: Plugged and Abandoned 04/26/05 Nikaitchuq#4: Plugged and Abandoned 04/21/05 Kigun#1: Plugged and Abandoned 03/30/05 Tuvaaq State#1: Plugged and Abandoned 03/09/05 To Eni US Operating Co.Inc.'s knowledge all wells have been cemented across the Schrader Bluff formation as per AOGCC regulations and plugged and abandoned. All wells that fall into the'/mile radius said herein have been drilled and completed in the Schrader Bluff formation in accordance with 20 AAC 25 AOGCC regulations. SI29-S2 Drilling Wellplan Page 32 of 39 01/16/12 rnnA us operating WELL SI29-S2 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable.RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/Connection Speeds High POOH and RIFT speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to fmd the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. SI29-S2 Drilling Wellplan Page 33 of 39 01/16/12 ig • en!, us operating WELL SI29-S2 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. ✓ 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. / Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SI29-S2 Drilling Wellplan Page 34 of 39 01/16/12 • en us op rritonc WELL SI29-S2 Safety Meeting Topics Move In, Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. D. A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. SI29-S2 Drilling Wellplan Page 35 of 39 01/16/12 rnn us operating- WELL p rrtingWELL SI29-S2 D Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion D Operation of the control line spooler. D Pinch points associated with tongs and slips. D Proper tripping practices and hole fill calculations with tubing and control line. D Well control practices while running production tubing with control line. D Pressure testing and minimizing personnel exposure to pressurized lines. SI29-S2 Drilling Wellplan Page 36 of 39 01/16/12 en us operating WELL SI29-S2 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install 11W and close annular around pipe and control line. 2. _Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. • SI29-S2 Drilling Wellplan Page 37 of 39 01/16/12 i en us op rrahng WELL SI29-S2 Conductor Broach — Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID:(36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20'below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200'below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50'below the conductor. POOH to 20' inside the conductor. 6. Mix and displace+/-80 bbls of Artic Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40'below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. S129-S2 Drilling Wellplan Page 38 of 39 01/16/12 enil LIS Operat0n9 WELL SI29-S2 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin PrimaryOne e 9 Stage Cement Job No Cement Ce to Surface S Drilling Foreman and Nipple Up and Engineer determine the x Test BOP's Top of Cement Top of Top l#!Q Continue with Cement Cement above Port below Port Completion Collar Collar (1000'TVD) -, (1000'TVD) ♦ K Indicators of Cement Top ur- Perform Top Job as per ► Open Port Collar 1. Observation of Tracers in Spacer ahead of lead cement requirements of If Top Job is ineffective or using drillpipe p AOGCC unacceptable to AOGCC 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Circulate Cement Test BOP's to Surface and close Port Collar Continue with Nipple Up and Completion Test BOP's Continue with Completion SI29-S2 Drilling Wellplan Page 39 of 39 01/16/12 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. E&P DivisionL 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= P +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). VASENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Esti 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. SPEO IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. m 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 Erni E&P Division REVISION STAP-P-1-M-6140 0 1 VA LEAK—OFF TEST REPORT Report N° Date: WELL NAME: WELL CO DE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rig type: J.UPs Hole Diameter(in): 121/4 Weight(KgA): 1.3 R.K.B.elevat on(m): 26 Last Csg.Shoe(m): 797 Marsh Mscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter On): 13''3r8 P.V.(cps): 19 Pumps: 12-P-160 Grade: .155 Y.P.Qb/100 e): 5 Liners(in): 6.5" Weight Obit): 61 GelsQb/1001): 218 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc.00 min): 10.5 Litholog y Shale Expected EMW 1.68 ' Kg/cm2J10 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bid) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 400 16 2 435 2 0.50 100 9 5 2 480 3 0.75 200 10 2 470 4 1DD 300 10.5 2 483 5 125 400 11 2 465 6 150 500 11.5 2 460 7 1.75 570 12 2 446 8 2.00 600 13 2 440 8 2.00 550 14 2 437 8.5 2D0 505 15 2 435 Ncte: Pumped with a constant low rate of(661): Volume pumped(bbl): Vblume retum ed(bbl): (pm) 1000 900 , 800 stop pump F 700 e 600 / -'� S r shut in curve 500 S U 400 • i F 18 minutes e 300 200 100 0 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bin I I r, Time mins RESULTS:(press., +Press.Lo.)x101Depth=[(1.3 x 797/10)+(430 x 0.07)1 x10 1797=1.68(Kg/cm2/10 m) Note: I Company Representatiue ' Figure 15-1 - Leak-Off Test Report P i V DATE BY CK APP - DCSCRIPTION REV DATE BY CK APP DESCRIPTION 10/01/10 DHS CC CC irit,c1 Drowir g VICINITY MAP SCALE: , . I IF fa i', 14 i .7 le: 17 16 ,-... I 14 i i N 1 4.,.. _ l _ _ __ r..7........_ _.....-.:. . _ ... ,... ...... 21 12 21 ,4 21 i.34 t 23 14 19 20 THIS ....... 7 51 2, 28 SURVEY •/..., 30 2D ?E 2 26 5 • I L`g w 8 A.S P NADa3, :(4 .V.,`" 3f 51 32 1 . T14N • T14N • ! 1 T13N T13N D.KrEm Pow paolt14.1100K 5 , 2 1 : • ‘"4 . is,,, A' -,---o .-7-- s, , I ii, , is . 1 ., .• 'r 9 IL, ,, ,c. r. ,-, 7 ,,, ‘ ... v AS- 1 ,/ , ''' I 1 CI , 1 0 a: \--i• NOCir'"Iirart u e ,• 15 N.\ 14 - DS-30 _ • 111.- ,, toPID) 1. ----- It AA _ ) ., . --virn '' D 3@ ' ,,,,...• , ' ,• \4:- I n mi' tk) , I 21 22 23 t) le f \c„1-) *4 s ii. is 28 27 45 C. I . .. .) - -CIOst —--' ...44.6i 3 'k 1\-‘ 'AL• 'h _A, (liN'''')',at li... ," 1 /''' ' 1,4Y .11 (:;' .4.D D DRAWING NOTES; 1. GRID COORDINATES SHOWN ARE ALMA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM CPS 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 REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS. 7. REFERENCE LOUNSBURY DOCUMENT E-087 OR COORDINATE VALUES IN NAD27, lowkimiiiiit OF 4a-c v....................... s fc-)N,..- SURVEYOR'S CERTIFICATE 1 4S 49th I‘ \* $ I 0 f HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 T"-- 4 ' a LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF t :' /A....Comp:p..4 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY .1.ig . r c-, : FRANCIS ..1. CORNING/' i DONE BY ME OR UNDER MY DIRECT SUPERVISION AND •0 THAT ALL. DIMENSIONS AND OTHER DETAILS ARE CORRECT 1‘,,,.% L S-w .. LS-1O95 ••• • • AS OF OCTOBER 01. 2010 ..• oei, -...io I I letn.fe 4. ta SSION ..4•• "Illitlissii*.- oilitt tt 4s- toe SPY ISLAND DRILL SITE 4,, — 4.• ' 0,11,•.: WELL CONDUCTORS AS—BUILT LOCATIONS orn ri " . ti CAD FILE:ENI354309 . uperaiii1/4,„.„s o ng OAIE' DRAWING NO. PART:OF i REV: ID/Da/2010 Eni-3543—d9 1 3 I 0 REV DAlt BY GK APP Df,SCR1PT10N REV' DATE BY CK APP OESCRIP 1ON 0 10 0'/300"S CC CC Iri ic: Drcw - g N 44 G � _ _ lec 1$ -\ Sec- 17 ti� Sec ' + ' Ser.. 2p+ V . W��1 N �\ 0 A.SF. kW. Z�. _ W 1 °C1 l N ttA N ! N OlF'd tri J CS'LA ftt W- N A �tA C3 OD CPA C DETAIL A. SCALE: 1"=80' SANDBAG 10E va i c r` r wY� DETAIL A ` 1 SPY ISLAND DRILL SITE - - ; (SID) 1 G4Z \\\\\*.N.'"----....._ A+r i G6AG LEGENC SN°*LDE SCALE 200C -00 200 0 - 1M_L_ CONDUCTOR AS-BUILT THIS SURVEY 1" - 200' F1441 I. as I SPY ISLAND DRILL SITE 1 WELL CONDUCTORS ��" AS—BUILT LOCATIONS 2fn1 ,{ . COAFILE.ENI3543D9 "I' us Op a1flng 0AltC/01/2D1G DRAWING No. Eni-3543—d9 IPA2 OF 3 1REo 13EV DATE r BY CK , APP DESCRIPTION REV DATE P'r __ CK APP , p 9CRIPIION 0 10/0',I0 C D.--S CC v4 rit,c Drco.'ng Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic 1 Section Line Offset Pad Well No. 'Y' 'X' _atitude(N) Longitude (W) F.N.L F.E.L Elev. (USft.) (US ft.) 1 6053423.20 1651769.82 70°33'27.209" 149'54'24.765" 797 1171 12.4 2 6053421.65 1651761.87 70°33'27.194" 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 70°33'27.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149'54'2.5.925" 804 1210 12.4 7 6053412.44 1651714.77 70°33'27.104" 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"5427.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149°54'27.318" 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 70°33'26.986" 149'54'28.221" 819 1288 12.4 1 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" 149°54'28.685" 822 1304 12.4 16 6053395,82 1651629.26 70°33'26.942" 149°54'28.917" 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" 149'54'29.380" 827 1327 12.4 19 6053389.63 i 1651597.90 70°33'26.881" 149'54'29.843" 830 1343 12.4 20 6053388.17 1651590.00 70°33'26.867" 149°54'30.076' 831 1351 12.4 21 6053386.60 1651582.24 70°33'26.852" _ 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70°33'26.838" 149'54'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70°33'26.823" 149°54'30.773" 836 1374 12,4 24 6053382.12 1651558.61 70°33'26.808" 149.54'31.003" 837 1382 12,4 25 6053377.65 1651535.94 70°33'26.764" 149'5431.673" 842 1405 12.4 26 6053376.14 1651528.13 70°33'26.750" 149'54'31.904" 843 141.3 12.4 27 6053374.53 1651520.23 70°33'26.734' 149°54'32.137" 845 1421 12.4 28 6053373.11 1651512.46 70°33'26.720" 149°54'32.366" 846 1428 12,4 , 29 6053371.56 1651504.49 70°33'26.705" 149'54'32.602' 848 1436 12.4 30 6053370.06 1651496.66 7033'26.690" 149°54'32.833" 849 1444 12.4 31 6053367.05 1651480.97 70'33'26.661" 149°54'33.296" 852 1460 12.4 32 6053365.47 1651473.16 71'733'26.646" 149°54'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70°33126.631" 149'54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70'33'26.616" 149°54133.993" 857 1483 12.4 35 6053360.91 1651449.52 7(733'26.601" 149°54'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149°54'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70°33'26.555" 149°54'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70°33'26.541" 149°54'35.177" 864 1524 12.4 Vois 401&4, SPY ISLAND DRILL SITE lt WELL CONDUCTORS • , AS-BUILT LOCATIONS PI-1111 's,;h . 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TRANSMITTAL ETTER CHECKLIST WELL NAME C/L l cc---/, ""�rS 5� Z PTD# Development Service Exploratory Stratigraphic Test Non-Coventional Well / / FIELD: 7/.�.! t"1 �L. , 1 , 7,21 POOL: Gc�b'z�c l ti' (rC 14" Check Box for 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 produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 9/09/2011 CB > m G) D 3 CO $ a o n - CO 3 n o ° v ° 3 C° y . ,r- 3 G) .< 0 j 30D = o ; T 0 "m o C) N N .moi N .co d.. 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T 'Z O p d O 'D N Ca .� 'a0 SAD �3 7 �A CA �S W co� I- , -, 13 L2 ° 3 QV Q <a 3 'c �'o 3 'o . . . o 73 Q' .3 S)_ ° ^' tD n =. . fl y . dV . .� c a) U1 y ❑❑ L Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: March 21, 2012 Surface Data Logging End of Well Report SI29-S2 TABLE OF CONTENTS 1. General Well 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: Formation Evaluation Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI File LAS Files GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SI29-S2 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23464-00-00 Sperry Job Number: AK-AM-0009113840 Job Start Date: 05 Feb 2012 Spud Date: 08 Feb 2012 Total Depth Date: 11 Mar 2012 Total Depth: 19,464’ MD, 3833.8’ TVD North Reference: True Declination: 20.707˚ Dip Angle: 81.068˚ Total Field Strength: 57650.491 nT Date Of Magnetic Data: 01 Feb 2012 Wellhead Coordinates N: North 70° 33’ 27.74” Wellhead Coordinates W: West 149° 54’ 21.22“ Drill Floor Elevation: 54.02’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Zachary Beekman, Emil Opitz, Leigh Ann Rasher, Mark Hubert Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SP23-N3 02/05/2012 Rig is being moved. Mudloggers are on standby. 02/06/2012 Rig is being moved. Mudloggers are on standby. 02/07/2012 Mudloggers and loader operator got the mudlogging unit spotted. Mudloggers got with the rig electrician to get the unit plugged in and powered up so the heat and lights could be turned on. Once the unit and equipment were warmed up, the mudloggers were able to rig up their computers and gas equipment. The rig crew began to nipple up the flow line and completes the berm and ramps to the rock washer and pits. The mud lines from the mezzanine to the rig floor were connected. Rig crew began loading 5” drill pipe into the pipe shed and strapping lengths. Fill and pressure test the cement line. The oil in the top drive was changed out and all of the gas alarms were calibrated and tested. The crew then cut and slipped the drill line. They installed the mouse hole in the rotary table. Finally, as of midnight, BHAs #1 and #2 were bright into the pipe shed. 02/08/2012 Mudloggers continued to rig up remaining equipment to get ready for spud. All equipment was tested and ready for drilling out the conductor. The rig crew picked up 5” heavy weight drill pipe and racked back stands into the derrick. Jars were made up and 5” drill pipe was also picked up. Mud was taken on into the pits. All drill collars were then picked up along with the mud motor and drill bit. The hole was filled. Test flow equipment, function test surface equipment, mud pumps and pressure test the mud lines. Clean out the conductor and picked up BHA #2. Run in hole to 160’ MD and run gyro survey as per direction driller. Drilling ahead from 160’ MD to 288’ MD / 288’ TVD as of midnight. 02/09/2012 Pulled out of the hole from 288’ MD to 94’ MD. Two stands of heavy weight drill pipe were racked back and two crossover subs were laid down from spud. The flex stand, jar stand, float/saver sub and crossover sub were picked up. Tripped in the hole to 286’ MD and took a gyro survey. Drilling ahead from 288’ MD to 1865’ MD as of midnight. Average background gas for the day was 50 units. 02/10/2012 Continued to rotate and slide while drilling ahead from 1865’ MD to 3525’ MD as of midnight. Max gas observed for the last 24 hours was 514 units. The average background gas for the day was 100 units. 02/11/2012 Continued drilling ahead from 3525’ MD to TD of the surface section at 4372’ MD / 2403’ TVD. TD was reached at 1130 hours. Two MWD surveys were taken then began to backream out of the hole. Max gas observed while drilling to TD was 284 units. The average background was 130 units. Max gas observed while backreaming out of the hole was 576 units. 02/12/2012 Backreamed out of the hole from 1776’ MD to 780’ MD. Pulled out of the hole on elevators from 780’ MD to 735’ MD then the decision was made to pump out of the hole. Washed BHA #2 to 280’ MD. Laid down BHA #2 and prepped to run casing. Run casing while breaking circulation at 2122’ MD. Continue to run casing from 2122’ MD to 2738’ MD as of midnight. 02/13/2012 Continue running the 13 3/8” casing from 2738’ MD to 4357’ MD. Circulate and condition the mud for the cement job. Trouble picking off and starting the head. Laid down the Franks tools and rigged up the cement head. Pumped cement at 7.5 bpm, bumped the plug at 6170 strokes. Nipple down the stack. Set the emergency slips. Began working on cleaning out the pits and the cuttings box as of midnight. 02/14/2012 Pulled the 20” riser adapter to the BOP landing. Prepare the hanger and the pup and cut with Vetco Gray. Install the multibowl and test to 1800 psi. Continue to nipple up the BOP. Continue cleaning the pits and rock washer for LSND mud. Pick up the test joint and test plug and install in the stack. Change out the saver sub. Test the stack to 3500 psi. Pick up the long mouse hole and install in the hole. Start picking up singles from the pipe shed and make up stands and rack them back into the derrick. 02/15/2012 Pick up and stand back 5” drill pipe in the derrick. Drain the stack. Pick up the test plug and 5” test joint and run in the hole in preparation for testing the BOP. Test the BOPE. Pull test plug and install the wear bushing. Test the new section of stand pipe needed for WEI to 7500 psi. Install the new section of stand pipe in the derrick. Bring on 700 bbls of LSND mud at 9.25 ppg. Begin picking up BHA #3 as of midnight. 02/16/2012 Continue picking up BHA #3. Pressure test the stand pipe. Trip in the hole with BHA #3 to 4009’ MD. Break circulation and wash to 4193’ MD. Cut and slip the drill line. Test the casing to 2500 psi. Wash down to 4260’ MD and tag the cement at 4267’ MD. Drill out the plug and float to 4271’ MD. Drill out the shoe to 4397’ MD. Displace the mud to 9.2 ppg LSND. Perform a successful LOT to 11.6 ppg EMW. Continue to drill ahead from 4397’ MD to 4540’ MD as of midnight. Max gas observed for the day was 70 units and the average background gas was 30 units. 02/17/2012 Continue drilling ahead from 4791’ MD to 5641’ MD. Troubleshoot stand pipe psi loss. Check all pumps, screens, and all rig equipment and it all checks out OK. Ream up from 5641’ MD to 5504’ MD. Drop a carbide bomb to locate a possible washout, but the carbide came back to surface at the correct number of strokes. Wash and ream to bottom. The decision was made to drill ahead. Drilling from 5641’ MD to 5778’ MD as of midnight. Max gas observed throughout the day was 150 units and the average background was 25 units. 02/18/2012 Continue drilling ahead from 5767’ MD to 6888’ MD as of midnight. Max gas observed for the day was 18 units and the average background was 10 units. 02/19/2012 Continued drilling ahead from 6888’ MD to 7268’ MD. Pumped out of the hole from 7268’ MD to 7181’ MD. Found a loose connection, racked back stand #75, screw back into the drill string. Backream out of the hole from 7181’ MD to 6810’ MD. Circulate one stand per bottoms up. Observed a 750 psi loss. Shut down rotating and pumping and notified the Co Rep. Pulled out of the hole on elevators form 6810’ MD to the shoe at 4350’ MD. After the BHA cleared the shoe, pulling speed was increased to two minutes per stand to 3916’ MD as of midnight. Max gas observed for the day was 70 units. 02/20/2012 Continued to pull out of the hole on the elevators from 3916’ MD to 156’ MD. Pulled up the jar stand and found the jars had failed. Recovered 24.93’ of the jar assembly. 183.76’ of BHA left to fish for in the hole. Picked up a single of 5” drill pipe and stand back the heavy weight. Lay down the jar assembly. Bring in fishing tools to rig up on the floor. Load the collars in the pipe shed. Pick up an make up the fishing BHA assembly per Baker representative. Run in the hole from 419’ MD to 3781’ MD. Break out clean and inspect every connection. Lay down the bottom two joints on stand #17 and replace with two others from the pipe shed. 02/21/2012 Continue running in hole with the Baker fishing assembly from 3781’ MD to 4339’ MD. Break circulation at 3.5 bpm. Run in hole. At 4794’ MD, the sting took weight. Break circulation. Overshot packing off. Circulate until clean hole. Run in hole to 4894’ MD, string taking weight of 80-90K. Ream to 4899’ MD. Pull out of the hole to 2751’ MD. Run in hole to inspect pipe to 4899’ MD. Wash and ream to 7087’ MD at 2 bpm. Tag at 7087’ MD and latch onto fish. Pick up off bottom, weight observed at 220K. Pull out of hole on elevators to 6150’ MD. Pump out of hole at 2 bpm to 4808’ MD as of midnight. The hole took 6 bbls while tripping. 02/22/2012 Pump out of the hole with the fish assembly from 4808’ MD to 4058’ MD at 2 bpm. Monitor the well. Static. Pull out of the hole on the elevators to 695’ MD. Rack the drill collars and heavy weight drill pipe. Lay down the fishing BHA and SLB BHA. Lay out the manifold frame on the rig floor for WII reps. Lay down the 8” drill collar and heavy weight. Lay down the washed out 5” drill pipe. Make up the 12.25” BHA #4. Shallow test the MWD. Run in the hole to 1588’ MD as of midnight checking every 5” drill pipe connection. Lay down damaged 5” drill pipe as needed. 02/23/2012 Run in hole from 1588’ MD while checking each connection. At 4350’ MD, circulate a bottoms up. Run in hole, at 4443’ MD, string began to take weight. Work a tight spot to 5044’ MD. Wash and ream to 7268’ MD. Drill ahead from 7268’ MD to 7752’ MD as of midnight. Max gas observed for the day was 45 units. 02/24/2012 Drill ahead from 7752’ MD to 7843’ MD and circulate. Continue drilling ahead to 8740’ MD as of midnight. Max gas observed throughout the day was 675 units. The average background gas for the day is 40 units. The lithology was predominantly sandstone with thinner layers of interbedded siltstone. Mudlogger Leigh Ann Rasher left location, leaving Mark Hubert as the day logger. 02/25/2012 Drill ahead from 8740’ MD to TD of the intermediate section at 8908’ MD. Monitor the well as static. Circulate one bottoms up and backream at 900 gpm and 120 rpm per stand per K&M clean up cycle. Monitor the well periodically and find it to be static. Backream to a depth of 5508’ MD as of midnight. The max gas observed before reaching TD was 44 units with an average background of 30 units. 02/26/2012 Backream from 5508’ MD to 281’ MD at 900 gpm and 120 rpm per stand per K&M. Monitor well periodically – Static. Lay down BHA #4 per SLB. Drain the stack and prepare to remove wear ring. 02/27/2012 Pull wear ring and set test plug. Change top RAMS and test. R/U Tesco casing. Float in 9 5/8” 40lb casing per K&M. Monitor well with periodic checks – static. Rotate from 3373’ to 8892’ MD per K&M. Correct displacements observed. Max trip gas of 15 units. 02/28/2012 R/D Tesco casing. Fill casing – 676 bbls @ 2.5 bbl/min. Circulate and condition mud. Losses of <4 bbl/hr when pumping at 4 bbl/min. PJSM for cementing casing. Pump 70 bbl mudpush and 10 bbl water. Mix cement batch. Max trip gas of 14 units. 02/29/2012 Pump 154 bbls of cement @ 4bbl/min. Chased with LSND mud. Bumped plug at calculated strokes, no losses observed. Pressure up – floats OK. Confirm injectivity test after 2nd attempt. R/D cement head. R/D BOPs. Set slips and cut casing. Set packoff. N/U BOPs. Chante top RAMS. Freeze protect w/ 260 bbls diesel @ 2 bbl/min. Prepare to test BOPs. 03/01/2012 Test BOPs. Change variable front packers and top seals. Finish testing BOPs. Work on DriLink. P/U and rack back 33 joints of 5” DP. P/U 132 joints of 4.5” DP. CBU 1x. Rack back 4.5” DP. Filled pits 1-4 and trip tank with FazePro LVT. 03/02/2012 Finish P/U and racking back 4.5” DP. Cut and slip drill line. Pressure up casing to 1000psi for 15 min – OK. Change top saver sub and hydraulic hose. M/U BHA #5. 03/03/2012 P/U BHA #5 and RIH. Shallow test MWD – OK. RIH to 4325’ MD, filling every 20 stands. CBL to 8670’ MD. Work on top drive. Circulate and condition mud in preparation for casing test. 03/04/2012 Conduct casing test for 30 min @ 3000psi – OK. Flush pump #3 with LVT. Displace to OBM. Send LSND to WIF. Drill out cement and 20’ of new hole to 8928’ MD. Perform FIT to 13.1 ppg EMW. Drill ahead. Max Gas of 750 units with average gas of 314 units. Cuttings consisted primarily unconsolidated sands with occasional calcareously cemented sandstone cuttings. Siltstone cuttings were also observed. 03/05/2012 Drill to 9507’ MD. BROOH as per plan to swap out 5” DP with remaining 4.5” DP. BROOH to 9414’ MD, CBU 1.5x per K&M. Pump out of hold at 2.5 bbl/min, racking back 5” DP. RIH to 9495’ MD w/ 4.5” DP. Fill pipe. Drill ahead. Max gas encountered was 1093 units with an average gas of 400 units. Cuttings consisted primarily of unconsolidated sands with occasional calcareously cemented sandstone cuttings. Siltstone and silty sand/sandy silt was also encountered. Two unplanned faults were crossed, at approximately 9710’ MD and 10475’ MD – these faults were crossed from sand to sand. 03/06/2012 Continue to drill ahead. Samples consist primarily of unconsolidated sands with lesser amounts of siltstone and calcareously cemented sandstone cuttings. Max gas encountered was 1142 units with an average gas of 634. 03/07/2012 Drill ahead. Stop and monitor well due to losses noted at 13975’ MD. Continue drilling ahead. Noticed rubber hole cover missing from rig floor. Jetted flow line and drained stack to look for cover. Not found. Noted connection gasses of approximately 200 units while circulating/BROOH while looking for rubber cover. Troubleshoot SLB tools while circulating. Total fluid losses for the day were 90bbl. Samples consist mainly of unconsolidated sands with minor amounts of calcareously cemented sandstone cuttings and lesser amounts of siltstone. Max gas was 1253 units with an average gas of 606 units. 03/08/2012 Continue drilling ahead. Cuttings consisted of primarily unconsolidated sands with lesser amounts of calcareously cemented sandstone and siltstone (silty sandstone and sandy siltstone). Max gas of 1013 units with an average gas reading of 486 units. 03/09/2012 Continue to drill ahead to 17432’ MD. BROOH 2 stands to 17245’ MD to work dogleg. Ream back to bottom and resume drilling. Cuttings consist mainly of unconsolidated sands with zones of silty sandstone and sandy siltstone encountered. Max gas of 1290 units with an average gas of 637 units. 03/10/2012 Continue drilling ahead. Cuttings continue to be primarily unconsolidated sands with minimal amounts of silty sandstone. Max gas reading of 1432 units with an average gas of 692 units. 03/11/2012 Continue drilling ahead to production TD of 19,464’ MD. BROOH as per K&M rep. Cuttings samples were predominantly unconsolidated sands with minor amounts of siltstone. Max gas of 1422 units with an average gas reading of 796 units. 03/12/2012 Continue to BROOH per K&M. Max gas encountered of 232 units. 03/13/2012 Continue to BROOH to intermediate casing shoe. POOH. Cut and slip drill line. Resume to POOH. 03/14/2012 L/D BHA #5. R/U for BOP testing. Test BOPs. Change saver sub. R/U BHA #6 for cleanout run. 03/15/2012 P/U BHA #6 and TIH to 5600’ MD, filling pipe every 20 stands. Continue to TIH with mixed string DP to 16803’ MD. TIH rotating to 19464’ MD TD, making top drive connections and rotating 20-25 RPM. Circulate and weight up mud system from 9.2 to 9.4 ppg. 03/16/2012 Circulate and weight up mud to 9.4 ppg. Displace 9.4 ppg FazePro with 800 bbl 9.5 ppg Fazeaway breaker, followed by 109 bbl 9.4 ppg FazePro, and then 15 bbl of 10.7 ppg FazePro. Pump rate was 200 gpm. POOH on elevators to 14500’ MD. Calculated hole fill 37.5 bbl. Actual hole fill is 165 bbl. 03/17/2012 POOH on elevators per K&M. Monitor well – static. Calculated hole fill of 58 bbl. Actual hole fill of 143 bbl. Displace from 9.4 ppg FazePro to 9.2 ppg Brine. L/D BHA #6. R/U to run 4.5” liner. 03/18/2012 Continue to RIH with 4.5” liner. 03/19/2012 RIH with liner. Rotate liner in hole from 16868’ to 19390’ MD. Tag bottom. Locate packer set depth, drop ball, and set packer as per baker rep. POOH and L/D 5” DP. 03/20/2012 Continue to L/D DP using mouse hole. Pull wear ring. Mobilize completion tubing equipment. R/U SLB electrical spooler. R/U and run 4.5” 12.6 lb/ft L-80 H563 completion tubing per well plan. Testing every 25 joints. . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade Mud Data ROP Set At Size Bit # Current in Drilling All Circ Area: Location: 0' to 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 0' Depth Daily Charges: Max @ ft 4.23 Hours Depth in / out Footage WOB % -- ROP (ft/hr) 0' 0' 0' Flow In (gpm) Current Pump & Flow Data: - Rigging Up Rig Activity: Flow In (spm) $1,900.00 $3,800.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max -Min - Avg Bit Type TFA - pH Chlorides Tuff Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 Customer: Well: Avg 1 6-Feb-2012 24:00:00 Time: Report #: Date: Size Weight Coal Gvl API FL Lst YP Cor Solids (lb/100ft 2) mg/l ml/30min Depth Mud Type * 10000 units = 100% Gas In Air 0 Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman (max) (current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 getting it warmed up inside to prepare for rigging up the computers and gas equipment. Two days of standby were charged, one Rig spotted over the well. Prepare rig for pre spud acceptance. Had rig electrician plug power into our unit to start md. day for the fifth and one for today, the sixth. C-5n 0 C-4i C-4n 0 0 Gas Summary 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade Mud Data ROP Set At Size Bit # Current in Drilling All Circ Area: Location: 0' to 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 0' Depth Daily Charges: Max @ ft 4.23 Hours Depth in / out Footage WOB % -- ROP (ft/hr) 0' 0' 0' Flow In (gpm) Current Pump & Flow Data: - Rigging Up Rig Activity: Flow In (spm) $2,810.00 $6,610.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max -Min - Avg Bit Type TFA - pH Chlorides Tuff Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 Customer: Well: Avg 2 7-Feb-2012 24:00:00 Time: Report #: Date: Size Weight Coal Gvl API FL Lst YP Cor Solids (lb/100ft 2) mg/l ml/30min Depth Mud Type * 10000 units = 100% Gas In Air 0 Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman (max) (current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 mezzanine to the rig floor. Begin to load and tally 5" drill pipe into the pipe shed. Fill and pressure test the cement line. Change the Nipple up the flow line. Complete the berm and ramps to the rock washer and pits. Connect the mud lines from the md. the oil in the top drive. Calibrate and test the gas alarms. Cut and slip drill line. Install mouse hole in the rotary tabel. Bring in BHA #1 and #2 into the pipe shed as of midnight. C-5n 0 C-4i C-4n 0 0 Gas Summary 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade 20" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 0' to 96% 604 127 SPP (psi) Gallons/stroke 647 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 288' Depth Daily Charges: 0.0 Max @ ft 4.23 Hours Depth in / out Footage WOB % -- ROP (ft/hr) 278'46.0 0' 288' 288' Flow In (gpm) Current Pump & Flow Data: - Drilling ahead Rig Activity: Flow In (spm) 523.0 $2,810.00 $9,420.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 3.0 -Min - Avg Bit Type TFA - pH Chlorides Tuff Hughes MX-1 Mill Tooth 160' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 3 8-Feb-2012 24:00:00 Time: Report #: Date: 2.00 20.0 29 1.117 24 Size 160' 128' Weight Coal Gvl API FL 5.8 Lst 1 8.80 85 16" YP Cor Solids (lb/100ft 2) 1,800 9.00 mg/l ml/30min 288' Gel Mud Depth Mud Type * 10000 units = 100% Gas In Air 0 Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Dave Lasalle (max) (current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Pick up drill collars. Pick up motor and bit. Fill hole, test flow equipment, function test surface equipment, mud pumps and pressure Pick up 5" heavy weight drill pipe and stand back into derrick. Make up jars. Pick up 5" drill pipe. Take on mud into pits. md. and pressure test the mud line. Clean out the conductor and pick up BHA #2. Run in hole to 160' MD and run gyro survey as per DD. Drilling from 160' MD to 288' MD / 288' TVD as of midnight. C-5n 0 C-4i C-4n 0 0 Gas Summary 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Gel Mud Depth Mud Type mg/l ml/30min 1865'- 16" YP Cor Solids (lb/100ft 2) 2,200 9.10 Coal Gvl API FL 5.0 Lst 1 60.0 9.30 Weight 160' 1705'19.00 20.0 27 1.117 24 Size 4 9-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Hughes MX-1 Mill Tooth 160' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 5.0 -Min - Avg - Drilling ahead Rig Activity: Flow In (spm) 433.0 $2,810.00 $12,230.00 Report For: Keener/Smith/Buchanan 75.0 288' 1865' 1577' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) 1500' % -- Hours Depth in / out Footage WOB 20.0 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 1865' Depth Daily Charges: 129.0 Max @ ft 96% 656 155 SPP (psi) Gallons/stroke 1021 @4.23 Area: Location: 288' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade 20" * 10000 units = 100% Gas In Air 24 hr Recap: 200 Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary Gyro survey. Drilling from 288' MD to 1865' MD as of midnight. Max gas for the day was 514 units at a depth of 1962 and the average background for the day was 50 units. over subs from spud. Picked up flex stan, jar stand, float/saver sub and crossover sub. Tripped in the hole to 286' MD and took a Pulled out of the hole from 288' MD to 94' MD. Stand back 2 stands of heavy weight drill pipe. Layed down two cross- 44 md. 514 Chromatograph (ppm) 5266 19 65755 Maximum Minimum Average 1962' 1863' 0 Depth 0 0 0 0 0 00 Units* 0 000852 C-2 Logging Engineers: Zach Beekman/Dave Lasalle (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade 20" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 1865' to 96% 799 189 SPP (psi) Gallons/stroke 1605 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 3525' Depth Daily Charges: 221.0 Max @ ft Hours Depth in / out Footage WOB 20.0 % -- ROP (ft/hr) 72.0 1865' 3525' 1660' Flow In (gpm) Current Pump & Flow Data: - Drilling ahead Rig Activity: Flow In (spm) 531.0 $2,810.00 $15,040.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 6.5 -Min - Avg Bit Type TFA - pH Chlorides Tuff Hughes MX-1 Mill Tooth 160' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 5 10-Feb-2012 24:00:00 Time: Report #: Date: 35.00 20.0 28 1.117 21 Size Weight 160' 3365' Gvl API FL 5.0 Lst 1 85.0 9.45 16" YP Cor Solids (lb/100ft 2) 1,300 9.00 Coal mg/l ml/30min 3525' Gel Mud Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 000340 C-2 0 Depth 0 0 0 0 0 65755 Maximum Minimum Average 1962' 3303' 19332 11 Chromatograph (ppm) was 514 units. The average background gas for the day was 100 units. Continue to rotate and slide while drilling ahead from 1865' MD to 3525' MD. Max gas observed for the last 24 hours 171 md. 514 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: 165 Background . . Density (ppg) Viscosity out (sec/qt) Gel Mud Depth Mud Type - mg/l ml/30min 4372' 16" YP Cor Solids (lb/100ft 2) 800 8.90 Coal Gvl API FL 5.0 Lst 1 85.0 9.50 Weight 160' 4372' 4212'41.00 18.5 36 1.117 23 Size 6 11-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Hughes MX-1 Mill Tooth 160' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 7.5 -Min - Avg - Backreaming Rig Activity: Flow In (spm) 563.0 $2,810.00 $17,850.00 Report For: Keener/Smith/Buchanan 44.6 3525' 4372' 847' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) 3924' % -- Hours Depth in / out Footage WOB 20.0 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4372' Depth Daily Charges: 0.0 Max @ ft 96% 614 145 SPP (psi) Gallons/stroke 862 @4.23 Area: Location: 3525' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade 20" * 10000 units = 100% Gas In Air 24 hr Recap: 130 Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary Max gas observed while backreaming was 576 units. begin backreaming out of the hole. Max gas observed while drilling was 284 units. The average background gas was 130 units. Continue drilling ahead from 3525' MD to TD of surface section at 4372' MD / 2403' TVD. Run two MWD surveys and 146 md. 284 Chromatograph (ppm) 16421 8 36542 Maximum Minimum Average 3853' 4018' 0 Depth 0 0 0 0 0 00 Units* 0 0004629 C-2 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade 20" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 4372' to 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4372' Depth Daily Charges: 0.0 Max @ ft Hours Depth in / out Footage WOB 20.0 % -- ROP (ft/hr) 0'0.0 4372' 4372' 0' Flow In (gpm) Current Pump & Flow Data: - RIH w/ 13 3/8" casing Rig Activity: Flow In (spm) 0.0 $2,810.00 $20,660.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 6.5 -Min - Avg Bit Type TFA - pH Chlorides Tuff Hughes MX-1 Mill Tooth 160' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 7 12-Feb-2012 24:00:00 Time: Report #: Date: 29.60 16.0 20 1.117 20 Size Weight 160' 4372' 4212' Gvl API FL 5.2 Lst 1 85.0 9.45 16" YP 2-1-WT-A-E-1-SD-TD Cor Solids (lb/100ft 2) 700 9.00 Coal mg/l ml/30min 4372' Gel Mud Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) decision was made to pump out of the hole. Wash BHA #2 to 280' MD. Laid down BHA #2 and prepped to run casing. Run casing Backream out of hole form 1776' MD to 780' MD. Pulled out of hole on elevators from 780' MD to 735' MD then the md. breaking circulation at 2122' MD. Continue to run casing from 2122' MD to 2738' MD as of midnight. 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Gel Mud Depth Mud Type - mg/l ml/30min 4372' 16" YP 2-1-WT-A-E-1-SD-TD Cor Solids (lb/100ft 2) -7.70 Coal Gvl API FL - Lst 1 85.0 9.45 68.0 Weight 160' 4372' 4212'29.60 - 12 1.117 17 Size 8 13-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Hughes MX-1 Mill Tooth 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max - -Min - Avg - N/D BOP Rig Activity: Flow In (spm) 0.0 $2,810.00 $23,470.00 Report For: Keener/Smith/Buchanan 0.0 4372' 4372' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) 0' % -- Hours Depth in / out Footage WOB 20.0 EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4372' Depth Daily Charges: 0.0 Max @ ft 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Area: Location: 4372' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary 6170 strokes. Nipple down surface stack. Set emergency slips. Working on cleaning out pits and cuttings box as of midnight. Trouble picking off and starting the head. Lay down Franks tool, rig up cement head. Pump cement at 7.5 bpm, bump plug at Continue running 13 3/8" casing from 2378' MD to 4357' MD. Circulate and condition the mud for the cement job. md. Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 4372' to 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4372' Depth Daily Charges: 0.0 Max @ ft Hours Depth in / out Footage WOB 20.0 EVAMAR % -- ROP (ft/hr) 0'0.0 4372' 4372' 0' Flow In (gpm) Current Pump & Flow Data: - N/D BOP Rig Activity: Flow In (spm) 0.0 $2,810.00 $26,280.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max - -Min - Avg Bit Type TFA - pH Chlorides Tuff Hughes MX-1 Mill Tooth 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 9 14-Feb-2012 24:00:00 Time: Report #: Date: 29.60 - 13 1.117 17 Size 68.0 Weight 160' 4372' 4212' Gvl API FL - Lst 1 85.0 9.45 16" YP 2-1-WT-A-E-1-SD-TD Cor Solids (lb/100ft 2) -7.70 Coal mg/l ml/30min 4372' Gel Mud Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) test to 1800 psi. Continue to nipple up the BOP. Continue cleaning the pits and rock washer for LSND mud. Pick up the test joint Pull 20" riser adapter to BOP landing. Prepare the hanger and pup and cut with Vetco Gray. Install the multibowl and md. and test plug and install in the stack. Change out the saver sub. Test the stack to 3500 psi. Pick up the long mouse hole and install in the hole. Start picking up singles from the pipe shed and make up stands and rack them back in the derrick. 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Gel Mud Depth Mud Type - mg/l ml/30min 4372' 12.25" YP Cor Solids (lb/100ft 2) -7.50 Coal Gvl API FL - Lst 2 9.45 68.0 Weight 4372' - 13 1.107 17 Size 10 15-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max - -Min - Avg - P/U BHA #3 Rig Activity: Flow In (spm) 0.0 $3,410.00 $29,690.00 Report For: Keener/Smith/Buchanan 0.0 4372' 4372' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) 0' % -- Hours Depth in / out Footage WOB EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4372' Depth Daily Charges: 0.0 Max @ ft 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Area: Location: 4372' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary needed for WEI to 7500 psi. Install the new section of stand pipe in the derrick. Bring on 700 bbls of LSND mud at 9.25 ppg. Begin picking up BHA #3 as of midnight. hole in preparation to test the BOP. Test BOPE. Pull test plug and install the wear bushing. Test the new section of stand pipe Pick up and stand back 5" drill pipe in the derrick. Drain the stack. Pick up the test plug and 5" test joint and run in the md. Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 4372' to 96% 605 143 SPP (psi) Gallons/stroke 783 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4542' Depth Daily Charges: 20.0 Max @ ft Hours Depth in / out Footage WOB 18.0 EVAMAR % -- ROP (ft/hr) 4377'42.0 4372' 4542' 170' Flow In (gpm) Current Pump & Flow Data: - Drilling Ahead Rig Activity: Flow In (spm) 637.0 $3,410.00 $33,100.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 2.0 -Min - Avg Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 11 16-Feb-2012 24:00:00 Time: Report #: Date: 3.00 2.0 23 1.107 8 Size 100 68.0 Weight 4372' 170' Gvl API FL 7.0 Lst 2 85.0 9.20 12.25" YP Cor Solids (lb/100ft 2) 750 10.00 Coal mg/l ml/30min 4542' Gel Mud Depth Mud Type 52 * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 000129 C-2 0 Depth 0 0 0 0 0 7053 Maximum Minimum Average 4590' 4383' 3431 6 Chromatograph (ppm) to 4193' MD. Cut and slip the drill line. Test casing to 2500 psi. Wash down to 4260' MD and tag cement at 4267' MD. Drill out the Pick up BHA #3. Pressure test the stand pipe. Trip in the hole with BHA #3 to 4009' MD. Break circulation and wash 36 md. 70 plug and float to 4271' MD. Drill out the shoe to 4397' MD. Displace the mud to 9.2 ppg LSND. Perform a successful LOT to 11.6 ppg EMW. Continue to drill ahead from 4397' MD to 4540' MD as of midnight. Max gas observed for the day was 70 units, and the average background gas was 30 units. 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: 31 Background . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 4542' to 96% 880 208 SPP (psi) Gallons/stroke 1619 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 5778' Depth Daily Charges: 131.0 Max @ ft Hours Depth in / out Footage WOB 19.0 EVAMAR % -- ROP (ft/hr) 5751'61.0 4542' 5778' 1236' Flow In (gpm) Current Pump & Flow Data: - Drilling Ahead Rig Activity: Flow In (spm) 826.0 $3,410.00 $36,510.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 5.0 -Min - Avg Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly 10 Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 12 17-Feb-2012 24:00:00 Time: Report #: Date: 16.00 9.5 30 1.107 13 Size 90 68.0 Weight 4372' 1406' Gvl API FL 5.5 Lst 2 65.0 9.30 12.25" YP Cor Solids (lb/100ft 2) 800 10.00 Coal mg/l ml/30min 5778' LSND Depth Mud Type 53 * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 00095 C-2 0 Depth 0 0 0 0 0 18646 Maximum Minimum Average 4864' 5752' 3283 5 Chromatograph (ppm) and all rig equipment and it all checks out OK. Ream up from 5641' MD to 5504' MD. Drop a carbide bomb to locate a possible Continue drilling ahead from 4791' MD to 5641' MD. Trouble shoot stand pipe psi loss. Check all pumps, screens, 38 md. 150 washout, but the carbide came back to surface at the correct number of strokes. Wash and ream to bottom. The decision was made to drill ahead. Drilling from 5641' MD to 5778' MD as of midnight. Max gas observed throughout the day was 150 units and the average background was 25 units. 0 C-4i C-4n Gas Summary 0 0 0 3 Trip 24 hr Recap: 9Background . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 5778' to 96% 888 220 SPP (psi) Gallons/stroke 1817 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 6888' Depth Daily Charges: 65.0 Max @ ft Hours Depth in / out Footage WOB 20.0 EVAMAR % -- ROP (ft/hr) 5787'68.3 5778' 6888' 1110' Flow In (gpm) Current Pump & Flow Data: - Drilling Ahead Rig Activity: Flow In (spm) 678.0 $3,410.00 $39,920.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 5.0 -Min - Avg Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 13 18-Feb-2012 24:00:00 Time: Report #: Date: 27.80 11.3 28 1.107 12 Size 100 68.0 Weight 4372' 2516' Gvl API FL 5.0 Lst 2 0.0 9.20 12.25" YP Cor Solids (lb/100ft 2) 1,100 9.90 Coal mg/l ml/30min 6888' LSND Depth Mud Type 53 * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 000265 C-2 0 Depth 0 0 0 0 0 1896 Maximum Minimum Average 5951' 6221' 516 3 Chromatograph (ppm) average background was 10 units. Continue driling ahead from 5767' MD to 6888' MD as of midnight. Max gas observed for the day was 28 units and the 8 md. 18 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: 8Background . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type - mg/l ml/30min 7268' 12.25" YP Cor Solids (lb/100ft 2) 1,300 9.80 Coal Gvl API FL 5.0 Lst 2 0.0 9.25 68.0 Weight 4372' 7268' 2896' 85 31.00 10.5 27 1.107 13 Size 14 19-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly 15 Cht Condition RPM Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 5.5 -Min - Avg - POOH Rig Activity: Flow In (spm) 422.0 $3,410.00 $43,330.00 Report For: Keener/Smith/Buchanan 26.5 6888' 7268' 380' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) 7010' % -- Hours Depth in / out Footage WOB 30.0 EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 7268' Depth Daily Charges: - Max @ ft 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Area: Location: 6888' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary Circulate one stand per bottoms up. Observed a 750 psi loss. Shut down rotating and pumping and notified the Co Rep. Pulled out of the hole on elevators from 6810' MD to the shoe at 4350' MD. After the BHA cleared the shoe, pulling speed was increased to two minutes per stand to 3916' MD as of midnight. Max gas observed for the day was 70 units. loose connection, racked back stand #75, screw back into the drill string. Backream out of the hole from 7181' MD to 6810' MD. Continued drilling ahead from 6888' MD to 7268' MD. Pumped out of the hole from 7268' MD to 7181' MD. Found a 11 md. 70 Chromatograph (ppm) 954 6 8873 Maximum Minimum Average 7126' 7262' 0 Depth 0 0 0 0 0 00 Units* 0 000328 C-2 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 7268' to 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 7268' Depth Daily Charges: Max @ ft Hours Depth in / out Footage WOB 30.0 EVAMAR % -- ROP (ft/hr) 7268' 7268' 0' Flow In (gpm) Current Pump & Flow Data: - Fishing Rig Activity: Flow In (spm) $3,410.00 $46,740.00 Report For: Keener/Smith/Buchanan Total Charges: Avg Min Max Max 5.5 -Min - Avg Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 15 20-Feb-2012 24:00:00 Time: Report #: Date: 31.00 10.5 15 1.107 9 Size 68.0 Weight 4372' 7268' 2896' Gvl API FL 5.5 Lst 2 0.0 9.25 12.25" YP Cor Solids (lb/100ft 2) 1,300 9.50 Coal mg/l ml/30min 7268' LSND Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) jars had failed. Recovered 24.93' of the jar assembly. 183.76' of BHA left to fish for in the hole. Picked up a single of 5" drill pipe Continued to pull out of the hole on the elevators from 3916' MD to 156' MD. Pulled up the jar stand and found the md. and stand back heavy weight. Lay down the jar assembly. Bring in fishing tools to rig up the floor. Load the collars in the pipe shed. Pick up and make up the fishing BHA assembly per Baker representative. Run in the hole from 419' MD to 3781' MD. Break out clean and inspect every connection. Lay down bottom two joints on stand #17 and replace with two others from the pipe shed. 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type - mg/l ml/30min 7268' 12.25" YP Cor Solids (lb/100ft 2) 1,300 9.70 Coal Gvl API FL 4.8 Lst 2 0.0 9.30 68.0 Weight 4372' 7268' 2896'31.00 10.5 26 1.107 15 Size 16 21-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 6.0 -Min - Avg - POOH, Fishing Rig Activity: Flow In (spm) $3,410.00 $45,740.00 Report For: Ross/Wimmer/Buchanan 7268' 7268' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) % -- Hours Depth in / out Footage WOB 30.0 EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 7268' Depth Daily Charges: Max @ ft 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Area: Location: 7268' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary 4894' MD, string taking weight of 80-90K. Ream to 4899' MD. Pull out of the hole to 2751' MD. Run in hole to inspect pipe to 4899' Wash and ream to 7087' MD at 2 bpm. Tag at 7087' MD and latch onto fish. Pick up off bottom, weight observed at 220K. Pull out of hole on elevators to 6150' MD. Pump out of hole at 2 bpm to 4808' MD as of midnight. The hole took 6 bbls while tripping. Run in hole. At 4794' MD, the string took weight. Break circulation. Overshot packing off. Circulate until clean hole. Run in hole to Continue running in hole with the Baker fishing assembly from 3781' MD to 4339' MD. Break circulation at 3.5 bpm. md. Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type - mg/l ml/30min 7268' 12.25" YP 2-4-LT-A-E-1-RG-BHA Cor Solids (lb/100ft 2) 1,300 9.70 Coal Gvl API FL 4.8 Lst 2 3 Smith GF15B Insert 80.0 9.30 12.25" 1.107 68.0 Weight 4372' 7268' 2896' 7268' 33.60 11.5 22 1.107 12 Size 17 22-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 6.0 -Min - Avg - RIH w/ BHA #4 Rig Activity: Flow In (spm) $3,410.00 $49,150.00 Report For: Ross/Wimmer/Buchanan 7268' 7268' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) % -- Hours Depth in / out Footage WOB 25.0 EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 7268' Depth Daily Charges: Max @ ft 96% 0 0 SPP (psi) Gallons/stroke 0 @4.23 Area: Location: 7268' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary Lay out the manifold frame on the rig floor for WII reps. Lay down the 8" drill collar and heavy weight. Lay down the washed out 5" drill pipe. Make up the 12.25" BHA #4. Shallow test the MWD. Run in the hole to 1588' MD as of midnight checking every 5" drill pipe connection. Lay down damaged 5" drill pipe as needed. the hole on the elevators to 695' MD. Rack the drill collars and heavy weight drill pipe. Lay down the fishing BHA and SLB BHA. Pump out of the hole with the fish assembly from 4808' MD to 4058' MD at 2 bpm. Monitor the well. Static. Pull out of md. Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 7268' to 96% 706 168 SPP (psi) Gallons/stroke 1315 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 7752' Depth Daily Charges: 63.0 Max @ ft Hours Depth in / out Footage WOB 25.0 EVAMAR % -- ROP (ft/hr) 7582'38.0 7268' 7752' 484' Flow In (gpm) Current Pump & Flow Data: - Drill Ahead Rig Activity: Flow In (spm) 544.0 $3,410.00 $52,560.00 Report For: Ross/Wimmer/Buchanan Total Charges: Avg Min Max Max 6.0 -Min - Avg Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly 20 Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 18 23-Feb-2012 24:00:00 Time: Report #: Date: 10.70 11.5 28 1.107 15 Size 80 68.0 Weight 7268' 484' Gvl API FL 4.0 Lst 3 46.0 9.30 12.25" YP Cor Solids (lb/100ft 2) 1,200 9.50 Coal mg/l ml/30min 7654' LSND Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) Report By: 00 Units* 0 000236 C-2 0 Depth 0 0 0 0 0 5498 Maximum Minimum Average 7670' 7624' 1177 6 Chromatograph (ppm) 4443' MD, string began to take weight. Work a tight spot to 5044' MD. Wash and ream to 7268' MD. Drill ahead from 7268' MD to Run in hole from 1588' MD while checking each connection. At 4350' MD, circulate a bottoms up. Run in hole, at 14 md. 45 7752' MD as of midnight. Max gas observed for the day was 45 units. 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: 9Background . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type - mg/l ml/30min 8709' 12.25" YP Cor Solids (lb/100ft 2) 1,300 9.70 Coal Gvl API FL 3.8 Lst 3 45.0 9.40 68.0 Weight 7268' 1472' 80 27.50 13.5 28 1.107 14 Size 19 24-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly 20 Cht Condition RPM Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 6.0 -Min - Avg - Drill Ahead Rig Activity: Flow In (spm) 716.0 $4,410.00 $56,970.00 Report For: Ross/Wimmer/Buchanan 45.0 7752' 8740' 988' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) 8521' % -- Hours Depth in / out Footage WOB 25.0 EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8740' Depth Daily Charges: 63.0 Max @ ft 96% 651 153 SPP (psi) Gallons/stroke 1235 @4.23 Area: Location: 7752' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: 28 Background Trip 87 27 879 156 2 C-4i C-4n Gas Summary sandstone with thinner layers of interbedded siltstone. observed throughout the day was 675 units. The average background gas for the day is 40 units. The lithology was predominantly Drill ahead from 7752' MD to 7843' MD and circulate. Continue drilling ahead to 8740' MD as of midnight. Max gas 100 md. 675 Chromatograph (ppm) 7447 25 80920 Maximum Minimum Average 8185' 8702' 1 Depth 59 20 17 78 45 35 29 Units* 116 26 17 21 1628 C-2 Logging Engineers: Zach Beekman/Mark Hubert (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 8740' to 96% 909 215 SPP (psi) Gallons/stroke 1602 @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: 0.0 Max @ ft Hours Depth in / out Footage WOB 25.0 EVAMAR % -- ROP (ft/hr) 8783'21.8 8740' 8908' 168' Flow In (gpm) Current Pump & Flow Data: - Backream out of hole Rig Activity: Flow In (spm) 333.8 $3,410.00 $60,380.00 Report For: Ross/Wimmer/Buchanan Total Charges: Avg Min Max Max 6.0 -Min - Avg Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Condition RPM (current) Ss Sh Clyst Cly 20 Cht (ppb Eq) cP PV PWD MBT Tools MWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 20 25-Feb-2012 24:00:00 Time: Report #: Date: 28.60 14.0 29 1.107 14 Size 80 68.0 Weight 7268' 8908' 1640' Gvl API FL 4.0 Lst 3 45.0 9.40 12.25" YP Cor Solids (lb/100ft 2) 1,300 10.00 Coal mg/l ml/30min 8908' LSND Depth Mud Type - * 10000 units = 100% Gas In Air 16 C-5n Zach Beekman C-3 C-5i C-1 Logging Engineers: Zach Beekman/Mark Hubert (max) (current) Report By: 40 24 Units* 42 320322 C-2 9 Depth 40 4 24 61 1 3628 Maximum Minimum Average 8777' 8908' 1949 11 Chromatograph (ppm) bottoms up and backream at 900 gpm and 120 rpm per stand per K&M clean up cycle. Monitor the well periodically and fine it Dril ahead from 8740' MD to TD of the intermediate section at 8908' MD. Monitor the well as static. Circulate one 28 md. 44 to be static. Backreamed to a depth of 5508' MD as of midnight. The max gas observed before reaching TD was 44 units with an average background of 30 units. 0 C-4i C-4n Gas Summary 39 31 20 17 Trip 24 hr Recap: 7Background . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type - mg/l ml/30min 8908' 12.25" YP Cor Solids (lb/100ft 2) 1,150 9.70 Coal Gvl API FL 5.1 Lst 3 45.0 9.40 68.0 Weight 7268' 8908' 1640'28.60 15.0 23 1.107 13 Size 21 26-Feb-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq) cP PV PWD MBT Tools MWD Summary (current) Ss Sh Clyst Cly Cht Condition RPM Smith GF15B Insert 160' 4350' Lithology (%) Silt Siltst Make Bit Type TFA - pH Chlorides Tuff Total Charges: Avg Min Max Max 5.5 -Min - Avg - R/U for 9 5/8" casing Rig Activity: Flow In (spm) $3,410.00 $63,790.00 Report For: Ross/Wimmer/Buchanan 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) % -- Hours Depth in / out Footage WOB 25.0 EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft 96% SPP (psi) Gallons/stroke @4.23 Area: Location: 8908' to ROP Set At Size 178.9 X-65 Bit # Current in Drilling All Circ Mud Data Casing Summary Grade L-80 20" 13.3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary periodically as static. Lay down BHA #4 per SLB. Drain the stack and prepare to remove wear ring. Backream from 5508' MD to 281' MD at 900 gpm and 120 rpm per stand per K&M clean up cycle. Monitor well md. Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers: Zach Beekman/Mark Hubert (max) (current) Report By: Zach Beekman C-3 C-5i C-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13.3/8" Mud Data ROP Set AtSize 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 8908' to 96% SPP (psi) Gallons/stroke @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft Hours Depth in / out Footage WOB 35.0 EVAMAR % -- ROP (ft/hr) 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: - RIH w/ 9 5/8" casingRig Activity: Flow In (spm) $3,410.00 $67,200.00 Report For:Ross/Wimmer/BuchananTotal Charges: AvgMin Max Max 5.5 -Min -A v g Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%)Silt Siltst Make ConditionRPM (current) Ss ShClystClyCht (ppb Eq)cP PV PWD MBT ToolsMWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 22 27-Feb-2012 24:00:00Time: Report #: Date: 27.90 14.0 22 1.107 13 Size 68.0 Weight 7268' 8908' 1640' Gvl API FL 4.9 Lst 3 60.0 9.40 12.25" YP 2-4-WT-H-E-0-NO-TD Cor Solids (lb/100ft2) 1,2509.70 Coal mg/lml/30min 8908' LSND Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Emil Opitz C-3 C-5iC-1 Logging Engineers:Emil Opitz / Mark Hubert (max)(current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) well with periodic checks - static. Rotate from 3373' to 8892' MD per K&M. Correct displacements observed. Pull wear ring and set test plug. Change top RAMS and test. R/U Tesco. Float in 9 5/8" 40lb casing per K&M. Monitor md 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 15 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 20" 13 3/8" Mud Data BTC ROP Set AtSize 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 8908' to 96% SPP (psi) Gallons/stroke @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft Hours Depth in / out Footage WOB 35.0 EVAMAR % -- ROP (ft/hr) 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: - Prepare to CementRig Activity: Flow In (spm) $3,410.00 $75,220.00 Report For:Ross/Wimmer/BuchananTotal Charges: AvgMin Max Max -Min -A v g Bit Type TFA - pH Chlorides Tuff Smith GF15B Insert 160' 4350' Lithology (%)Silt Siltst Make ConditionRPM (current) Ss ShClystClyCht (ppb Eq)cP PV PWD MBT ToolsMWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 23 28-Feb-2012 24:00:00Time: Report #: Date: 27.90 19 1.107 13 Size 68.0 Weight 7268' 8908' 1640' Gvl API FL Lst 3 60.0 9.30 12.25" YP 2-4-WT-H-E-0-NO-TD Cor Solids (lb/100ft2) 9.60 Coal mg/lml/30min 8908' LSND Depth Mud Type - * 10000 units = 100% Gas In Air 0 C-5n Emil Opitz C-3 C-5iC-1 Logging Engineers:Emil Opitz / Mark Hubert (max)(current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) pumping at 4 bbl/min. PJSM for cementing casing. Pump 70 bbl Mudpush & 10 bbl water. Mix cement. R/D Tesco casing. Fill casing - 676 bbls @ 2.5 bbl/min. Circulate and condition mud. Losses of <4 bbl/hr when md Note: Total Charges updated. 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 14 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type - mg/lml/30min 8908' YP Cor Solids (lb/100ft2) 9.60 Coal Gvl API FL Lst 9.30 8892' 68.0 Weight 1913 Size 24 29-Feb-2012 24:00:00Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq)cP PV PWD MBT ToolsMWD Summary (current) Ss ShClystClyCht ConditionRPM 160' 4350' Lithology (%)Silt Siltst 9 5/8" Make Bit Type TFA - pH Chlorides Tuff Total Charges: AvgMin Max Max -Min -A v g - Prepare BOP testRig Activity: Flow In (spm) $3,410.00 $78,630.00 Report For:Ross/Wimmer/Buchanan 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) % -- Hours Depth in / out Footage WOB EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft 96% SPP (psi) Gallons/stroke @4.23 Area: Location: 8908' to ROP Set AtSize 178.9 X-65 Bit # Current in Drilling All Circ Mud Data BTC Hydril 563 Casing Summary Grade L-80 40.0 L-80 20" 13 3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary casing. Set packoff. N/U BOPs. Change top RAMs. Freeze protect w/ 260 bbl diesel @ 2 bbl/min. Prepare to test BOPs. observed. Pressure up - floats OK. Confirm injectivity test after 2nd attempt. R/D cement head. R/D BOPs. Set slips and cut Pump 154 bbl of cement @ 4bbl/min. Chased with LSND mud. Bumped plug at calculated strokes, no losses md Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers:Emil Opitz / Mark Hubert (max)(current) Report By: Emil Opitz C-3 C-5iC-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 40.0 L-80 20" 13 3/8" Mud Data BTC Hydril 563 ROP Set AtSize 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 8908' to 96% SPP (psi) Gallons/stroke @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft Hours Depth in / out Footage WOB EVAMAR % -- ROP (ft/hr) 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: - P/U 4.5" DPRig Activity: Flow In (spm) $3,410.00 $82,040.00 Report For:Ross/Wimmer/BuchananTotal Charges: AvgMin Max Max -Min -A v g Bit Type TFA - pH Chlorides Tuff 160' 4350' Lithology (%)Silt Siltst 9 5/8" Make ConditionRPM (current) Ss ShClystClyCht (ppb Eq)cP PV PWD MBT ToolsMWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 25 1-Mar-2012 24:00:00Time: Report #: Date: 1814 Size 8892' 68.0 Weight Gvl API FL Lst 9.35 YP Cor Solids (lb/100ft2) 9.40 Coal mg/lml/30min 8908' LSND Depth Mud Type * 10000 units = 100% Gas In Air 0 C-5n Emil Opitz C-3 C-5iC-1 Logging Engineers:Emil Opitz / Mark Hubert (max)(current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) 33 joints of 5" DP. P/U 132 joints 4.5" DP. CBU 1x. Rack back 4.5" DP. Filled pits 1-4 and trip tank with FazePro LVT. Test BOPs. Change variable front packers and top seals. Finish testing BOPs. Work in DriLink. P/U and rack back md 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) LSND Depth Mud Type mg/lml/30min 8908' YP Cor Solids (lb/100ft2) 9.20 Coal Gvl API FL Lst 9.25 8892' 68.0 Weight 1815 Size 26 2-Mar-2012 24:00:00Time: Report #: Date: ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg (ppb Eq)cP PV PWD MBT ToolsMWD Summary (current) Ss ShClystClyCht ConditionRPM 160' 4350' Lithology (%)Silt Siltst 9 5/8" Make Bit Type TFA - pH Chlorides Tuff Total Charges: AvgMin Max Max -Min -A v g - M/U BHA #5Rig Activity: Flow In (spm) $3,410.00 $85,450.00 Report For:Ross/Wimmer/Buchanan 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: ROP (ft/hr) % -- Hours Depth in / out Footage WOB EVAMAR Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft 96% SPP (psi) Gallons/stroke @4.23 Area: Location: 8908' to ROP Set AtSize 178.9 X-65 Bit # Current in Drilling All Circ Mud Data BTC Hydril 563 Casing Summary Grade L-80 40.0 L-80 20" 13 3/8" * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip 0 0 0 0 0 C-4i C-4n Gas Summary top saver sub and hydraulic hose. M/U BHA #5. Finish P/U and racking back 4.5" DP. Cut and slip drill line. Pressure up casing to 1000psi for 15 min - OK. Change md Chromatograph (ppm) 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 Logging Engineers:Emil Opitz / Mark Hubert (max)(current) Report By: Emil Opitz C-3 C-5iC-1 0 C-5n . . Density (ppg) Viscosity out (sec/qt) Casing Summary Grade L-80 40.0 L-80 20" 13 3/8" Mud Data BTC Hydril 563 ROP Set AtSize 178.9 X-65 Bit # Current in Drilling All Circ Area: Location: 8908' to 96% SPP (psi) Gallons/stroke @4.23 Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8908' Depth Daily Charges: Max @ ft Hours Depth in / out Footage WOB EVAMAR % -- ROP (ft/hr) 8908' 8908' 0' Flow In (gpm) Current Pump & Flow Data: - Circulate and ConditionRig Activity: Flow In (spm) $3,410.00 $88,860.00 Report For:Ross/Wimmer/BuchananTotal Charges: AvgMin Max Max -Min -A v g Bit Type TFA - pH Chlorides Tuff 160' 4350' Lithology (%)Silt Siltst 9 5/8" Make ConditionRPM (current) Ss ShClystClyCht (ppb Eq)cP PV PWD MBT ToolsMWD Summary ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 27 3-Mar-2012 24:00:00Time: Report #: Date: 1812 Size 8892' 68.0 Weight Gvl API FL Lst 9.20 YP Cor Solids (lb/100ft2) Coal mg/lml/30min 8908' LSND Depth Mud Type * 10000 units = 100% Gas In Air 0 C-5n Emil Opitz C-3 C-5iC-1 Logging Engineers:Emil Opitz / Mark Hubert (max)(current) Report By: 00 Units* 0 0000 C-2 0 Depth 0 0 0 0 0 0Maximum Minimum Average 0 Chromatograph (ppm) Work on top drive. Circulate mud and prepare for casing test. P/U BHA #5 and RIH. Shallow test MWD - OK. RIH to 4325' MD, filling every 20 stands. CBL to 8670' MD. md 0 C-4i C-4n Gas Summary 0 0 0 0 Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC Hydril 563 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Casing Summary L-80 9498' Depth Area: Location: 96% 493 117 SPP (psi) Gallons/stroke 2273 @ Yesterday's Depth: Daily Charges: 45.0 Rig: Job No.: to ROP (ft/hr) Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 8908' in Drilling All Circ Min - % -MWD Summary 9427'181.1 Bit Type TFA Cly Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current AvgMin Max Max $92,270.00 Report For:Ross/Wimmer/BuchananTotal Charges: 8908' 9498' 590' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Flow In (spm) 333.8 $3,410.00 7.2 - Alkal Lime -A v g TuffGvlCoal Size Hughes QD506X PDC 160' 2664' 8892' ShClyst Lithology (%) (current) 68.0 Weight Ratio cP PV PWD Oil / Water Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113840 Customer: Well: Avg 0.902 16- 12 3/4" 28 4-Mar-2012 24:00:00Time: Report #: Date: 9.30 63/37 22 8908' EVAMAR Make 9.20 Ss - Lst API FL 4 Cht Silt Siltst 100 YP Cor Solids (lb/100ft2) 3.772.90 Mud (lb/bbl)ml/30min 9490' FazePro Depth Mud Type * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) 907-685-0772Unit Phone: 56 Report By: Emil Opitz C-2 C-3 C-5iC-1 114 0 3475 Units* 239 000 Maximum Minimum Average 1528276 Depth 251 0 78 84642 6959431' 8925'1136 750 8 cement and 20' new hole to 8928' MD. Perform FIT to 13.1 ppg EMW. Drill ahead. Casing test for 30 min @ 3000psi - OK. Flush pump #3 with LVT. Displace to OBM. Send LSND to WIF. Drill out 314 md C-5n 0 Gas Summary 404 C-4i C-4n 223 128 Chromatograph (ppm) Trip 24 hr Recap: 85Background . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC Hydril 563 L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 550 130 SPP (psi) Gallons/stroke 2824 @ Yesterday's Depth: 184.0 Rig: Job No.: ROP (ft/hr) Casing Summary Condition in Mud Data Hours Depth in / out % MWD Summary RPMBit Type TFA Cly Flow In (gpm) Current Pump & Flow Data: Max @ ft Current 10246'230.3 4.23 Flow In (spm) Total Charges: 9498' 10521' 1023' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: 506.4 $3,410.00 7.4 Alkal Lime $95,680.00 Report For: Ratio cP Ross/Wimmer/Buchanan TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' Lithology (%) (current) ShClyst Oil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope AK-AM-0009113840 Customer: Well: Avg 0.902 16 12 3/4" PV 29 5-Mar-2012 24:00:00Time: Report #: Date: 63/37 22 8908' WOB Make 9.25 9.30 Ss 4.6 Lst EVAMAR API FL 4 Cht Silt Siltst 100 YP Cor Solids (lb/100ft2) 3.903.00 Mud (lb/bbl)ml/30min 10473' FazePro Depth Mud Type 11.0410.2710.66 Avg Min MaxECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision Depth 10521'to9498' * 10000 units = 100% Gas In Air Report By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) 907-685-0772Unit Phone: 95 Emil Opitz C-5iC-1 183308 383734 Depth C-2 C-3 Maximum Minimum Average 3828822 346 2804 51 122105 10375' 10069' 1093 Units* 35 K&M. Pump out of hole at 2.5 bbl/min, racking back 5" DP. RIH to 9495' MD w/ 4.5" DP. Fill pipe. Drill ahead. Drill to 9507' MD. BROOH as per plan to swap out 5" DP with remaining 4.5" DP. BROOH to 9414' MD, CBU 1.5x per 400 md 113192 806 C-5n 2240 Gas Summary C-4i C-4n 228 145 72 464 Chromatograph (ppm) Trip 24 hr Recap: 65Background . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision Depth 12669'to10521' 11.139.9910.77 Avg Min Max 12668' FazePro Depth Mud Type YP Cor Solids (lb/100ft2) 3.772.90 Mud (lb/bbl)ml/30min API FL 4 Cht Silt Siltst 100 Ss 5.0 Lst EVAMAR Make 9.20 64/36 19 8908' WOB 30 6-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg 0.902 15 12 3/4" PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' TuffGvlCoal 614.1 $3,410.00 7.3 Alkal Lime $99,090.00 Report For: Ratio cP Keener/Smith/BuchananTotal Charges: 10521' 12669' 2148' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: Flow In (gpm) Current Pump & Flow Data: Max @ ft Current 11831'267.5 4.23 Flow In (spm) Bit Type TFA Cly % MWD Summary RPM Condition in Mud Data Hours Depth in / out 254.3 Rig: Job No.: ROP (ft/hr) Casing Summary Area: Location: 96% 550 130 SPP (psi) Gallons/stroke 2952 @ Yesterday's Depth: ROP Set AtSize 178.9 X-65 Bit # Hydril 563 L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air 24 hr Recap: 86Background Trip Chromatograph (ppm) 363 350 218 122 C-4i C-4n Gas Summary C-5n 3152 115289 635 calcareously cemented sandstone cuttings. Continue to drill ahead. Samples consist primarily of unconsolidated sands with lesser amounts of siltstone and 634 md 37 1142 Units* 12553' 10890' 64 199168 Maximum Minimum Average 6753267 312272 484339 Depth C-2 C-3 2386 C-5iC-1 188 907-685-0772Unit Phone: 101 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC Hydril 563 L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 520 122 SPP (psi) Gallons/stroke 2903 @ Yesterday's Depth: 218.6 Rig: Job No.: ROP (ft/hr) Casing Summary Condition in Mud Data Hours Depth in / out % MWD Summary RPMBit Type TFA Cly Flow In (gpm) Current Pump & Flow Data: Max @ ft Current 13044'286.8 4.23 Flow In (spm) Total Charges: 12669' 14442' 1773' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: 514.3 $3,410.00 10.2 Alkal Lime $102,500.00 Report For: Ratio cP Keener/Smith/Buchanan TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' Lithology (%) (current) ShClyst Oil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope AK-AM-0009113840 Customer: Well: Avg 0.902 14 12 3/4" PV 31 7-Mar-2012 24:00:00Time: Report #: Date: 66/34 19 8908' WOB Make 9.20 Ss Lst EVAMAR API FL 4 Cht Silt Siltst 100 YP Cor Solids (lb/100ft2) 2.341.80 Mud (lb/bbl)ml/30min 14443' FazePro Depth Mud Type 11.2010.3110.89 Avg Min MaxECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision Depth 14442'to12669' * 10000 units = 100% Gas In Air Report By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) 907-685-0772Unit Phone: 111 Emil Opitz C-5iC-1 203 31 Depth C-2 C-3 820 Maximum Minimum Average 7653953 337 174 302 6544 13973' 14071' 1253 Units* 50 missing from rig floor. Jetted flow line and drained stack to look for cover. Noted connection gasses of approximately 200 units Drill ahead. Monitor well due to losses noted at 13975' MD. Continue drilling ahead. Noticed rubber hole cover 606 md while circulating/BROOH while looking for rubber cover. Nothing found. Troubleshoot SLB tools while circulating. Total fluid losses for the day were 90bbl. Samples consist mainly of unconsolidated sands with minor amounts of calcareously cemented sandstone cuttings and lesser amounts of siltstone. 127283 801 C-5n 5288 Gas Summary C-4i C-4n 365 211 135 90 204 395 Chromatograph (ppm) Trip 24 hr Recap: 78Background . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 518 124 SPP (psi) Gallons/stroke 3018 @ Yesterday's Depth: 153.6 Rig: Job No.: ROP (ft/hr) Casing Summary Condition in Mud Data Hours Depth in / out % MWD Summary RPMBit Type TFA Cly Flow In (gpm) Current Pump & Flow Data: Max @ ft Current 15098'248.9 4.23 Flow In (spm) Total Charges: 14442' 15970' 1528' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: 428.1 $3,410.00 11.3 Alkal Lime $105,910.00 Report For: Ratio cP Keener/Smith/Buchanan TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' Lithology (%) (current) ShClyst Oil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope AK-AM-0009113840 Customer: Well: Avg 0.902 14 12 3/4" PV 17 8908' WOB 32 8-Mar-2012 24:00:00Time: Report #: Date: 67/33 Ss 5.4 Lst EVAMAR Make 9.20 4 Cht Silt Siltst 100 Hydril 563 YP Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl)ml/30min 15969' FazePro Depth Mud Type Depth 15970'to14442' 11.7810.7211.06 Avg Min MaxECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) 907-685-0772Unit Phone: 79 Emil OpitzReport By: C-5iC-1 142 39 Depth C-2 C-3 2115 Maximum Minimum Average 4938140 252 117 236 3935 15360' 15555' 1013 Units* 47 calcareously cemented sandstone and siltstone (silty sandstone and sandy siltstone generally). Continue to drill ahead. Cuttings samples consisted primarily of unconsolidated sands, with lesser amounts of 486 md 104941 783 C-5n 2645 Gas Summary C-4i C-4n 311 159 87 50 132 365 Trip 24 hr Recap: 45Background 631Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision API FL Depth 17610'to15970' 11.5410.6611.19 Avg Min Max 17432' FazePro Depth Mud Type YP Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl)ml/30min 4 Cht Silt Siltst 100 Hydril 563 Ss 5.0 Lst EVAMAR Make 9.20 9.40 68/32 18 8908' WOB 33 9-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg 0.902 13 12 3/4" PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' TuffGvlCoal 493.8 $3,410.00 10.2 Alkal Lime $109,320.00 Report For: Ratio cP Keener/Smith/BuchananTotal Charges: 15970' 17610' 1640' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: Flow In (gpm) Current Pump & Flow Data: Max @ ft Current 17435'250.4 4.23 Flow In (spm) Bit Type TFA Cly MWD Summary RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 153.6 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 521 125 SPP (psi) Gallons/stroke 3144 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air 632Connection(max) Chromatograph (ppm) 24 hr Recap: 130Background Trip 386 386 169 76 60 127 C-4i C-4n C-5n 2443 131496 926 Gas Summary md encountered. resume drilling. Cuttings consist mainly of unconsolidated sandstone, with zones of silty sandstone and sandy siltstone Continue to drill ahead to 17432' MD. BROOH 2 stands to 17245' MD to work dogleg. Ream back to bottom, and 637 Units* 83 1290 16345' 16794' 116 236 5056Minimum Average 4354457 80 Depth C-2 C-3 4616 C-1 131Maximum248 907-685-0772Unit Phone: 71 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision API FL Depth 18895'to17610' 11.6111.0511.34 Avg Min Max 18898' FazePro Depth Mud Type YP Cor Solids (lb/100ft2) 2.471.90 Mud (lb/bbl)ml/30min 4 Cht Silt Siltst 100 Hydril 563 Ss 5.0 Lst EVAMAR Make 9.20 9.35 69/31 17 8908' WOB 34 10-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg 0.902 13 12 3/4" PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope 552.7 Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' TuffGvlCoal $3,410.00 12.1 Alkal Lime $112,730.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 17610' 18895' 1285' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 17805'240.9 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 3.7 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 519 124 SPP (psi) Gallons/stroke 3236 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air 414Connection(max) Chromatograph (ppm) 24 hr Recap: 80Background Trip 253 353 138 63 54 106 C-4i C-4n C-5n 2440 148164 723 Gas Summary md sandstone. Continue to drill ahead. Cuttings continue to be primarily unconsolidated sands with minimal amounts of silty 692 Units* 63 18778'1432 18140' 99 180 4137Minimum Average 3461686 46 Depth C-2 C-3 3376 C-1 100Maximum182 907-685-0772Unit Phone: 53 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision API FL Depth 19464'to18895' 11.5311.0811.37 Avg Min Max Depth Mud Type YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min 4 Cht Silt Siltst 100 Hydril 563 Ss Lst EVAMAR Make 8908' WOB 35 11-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg 0.90212 3/4" PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope 417.1 Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' TuffGvlCoal $3,410.00 Alkal Lime $116,140.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 18895' 19464' 569' Current Depth: 24 Hour Progress: BROOHRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 18911'238.7 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 523 125 SPP (psi) Gallons/stroke 3177 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 299 24 hr Recap: 77Background Trip 187 332 116 58 33 97 C-4i C-4n C-5n 1327 149967 590 Gas Summary md unconsolidated sands with minor amounts of siltstone. Continue drilling ahead to TD of 19464' MD. BROOH as per K&M. Cuttings samples were predominantly 796 Units* 72 19393'1422 19236' 91 140 2724Minimum Average 3175417 38 Depth C-2 C-3 3512 C-1 83Maximum146 907-685-0772Unit Phone: 44 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision API FL Depth 19464'to19464' Avg Min Max Depth Mud Type YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min 4 Cht Silt Siltst Hydril 563 Ss Lst EVAMAR Make 8908' WOB 36 12-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg 0.90212 3/4" PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' TuffGvlCoal $3,410.00 Alkal Lime $119,550.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: BROOHRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% 527 129 SPP (psi) Gallons/stroke 2580 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 232 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md Continue to BROOH as per K&M. Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: POOHRig Activity: Doyon 15 Daily Charges:$2,810.00 Alkal Lime $122,360.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' Lithology (%) (current) ShClyst Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.90212 3/4" PVOil / Water 8908' WOB 37 13-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Ss Lst EVAMAR Make 4 Cht Silt Siltst Hydril 563 YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30minDepth Mud Type Depth 19464'to19464' Avg Min MaxECD (ppg) Tools Xceed, PeriScope, TeleScope, SonicVision, AdnVision API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* Continue to BROOH to shoe. POOH. Cut and slip drill line. Resume POOH. md NOTE: Daily price changed to reflect Sample Catchers leaving location. 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 232 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: BOP TestingRig Activity: Doyon 15 Daily Charges:$2,810.00 11.2 Alkal Lime $125,170.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' Lithology (%) (current) ShClyst Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 1448 12 3/4" 10556' PVOil / Water 8908' 19464' WOB 38 14-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 81.20 67/33 17 Ss Lst EVAMAR Make 9.20 135.04 Cht Silt Siltst Hydril 563 YP 3-1-BT-C-X-I-RO-TD Cor Solids (lb/100ft2) 2.732.10 Mud (lb/bbl)ml/30min 19464' FazePro Depth Mud Type Depth 19464'to19464' Avg Min MaxECD (ppg) Tools API FL 12.0 * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* L/D BHA #5. R/U for BOP testing. Test BOPs. Change saver sub. R/U BHA #6 for cleanout run. md 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 197 47 SPP (psi) Gallons/stroke 694 @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: Circulate on bottomRig Activity: Doyon 15 Daily Charges:$2,810.00 13.0 Alkal Lime $127,980.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 2664' 8892' Lithology (%) (current) ShClyst Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 1448 12 3/4" 10556' PVOil / Water 8908' 19464' WOB 39 15-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 81.20 65/35 21 Ss Lst EVAMAR Make 9.40 135.04 Cht Silt Siltst Hydril 563 YP 3-1-BT-C-X-I-RO-TD Cor Solids (lb/100ft2) 3.252.50 Mud (lb/bbl)ml/30min 19464' FazePro Depth Mud Type Depth 19464'to19464' Avg Min MaxECD (ppg) Tools 8.75" Hole opener API FL 12.0 * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* rotating to 19464' MD making top drive connections and rotating 20-25 RPM. Circulate and weight up mud system from 9.2 to 9.4 P/U BHA #6. TIH to 5600' MD, filling pipe every 20 stands. Continue to TIH with mixed string DP to 16803' MD. TIH md ppg. 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 53 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools 8.75" Hole opener API FL Depth 19464'to19464' Avg Min Max 19464' FazePro Depth Mud Type YP Cor Solids (lb/100ft2) 2.992.30 Mud (lb/bbl)ml/30min Cht Silt Siltst Hydril 563 Ss Lst EVAMAR Make 9.40 65/35 18 WOB 40 16-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg 1655 PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size 160' 2664' 8892' TuffGvlCoal $2,810.00 13.1 Alkal Lime $130,790.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: POOHRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md Calculated to fill hole 37.5 bbl, actual to fill hole is 165 bbl. Followed by 109 bbl 9.4 ppg FazePro, 15 bbl of 10.7 ppg FazePro. Pump rate was 200 gpm. POOH on elevators to 14500' MD. Circulate and weight up mud from 9.2 to 9.4 ppg. Displace 9.4 ppg FazePro w/ 800 bbl 9.5 ppg Fazeaway breaker. Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 19464'to19464' Avg Min Max 19464'KCl/NaCl Brine Depth Mud Type YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min Cht Silt Siltst Hydril 563 Ss Lst EVAMAR Make 9.20 WOB 41 17-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size 160' 2664' 8892' TuffGvlCoal $2,810.00 Alkal Lime $133,600.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: RIH w/ 4.5" linerRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md 9.4 ppg FazePro to 9.2 ppg Brine. L/D BHA #6. R/U to run 4.5" production liner. POOH on elevators per K&M. Monitor well-static. Calculated hole fill of 58 bbl - Actual hole fill 143 bbl. Displace from Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: RIH w/ 4.5" linerRig Activity: Doyon 15 Daily Charges:$2,810.00 Alkal Lime $136,410.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size 160' 2664' 8892' Lithology (%) (current) ShClyst Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Customer: Well: Avg PVOil / Water WOB 42 18-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Ss Lst EVAMAR Make 9.20 Cht Silt Siltst Hydril 563 YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min 19464'KCl/NaCl Brine Depth Mud Type Depth 19464'to19464' Avg Min MaxECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* Continue to RIH w/ 4.5" liner. md 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: L/D DPRig Activity: Doyon 15 Daily Charges:$5,623.50 Alkal Lime $142,033.50 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size 160' 2664' 8892' Lithology (%) (current) ShClyst Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Customer: Well: Avg PVOil / Water WOB 43 19-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Ss Lst EVAMAR Make 9.20 Cht Silt Siltst Hydril 563 YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min 19464'KCl/NaCl Brine Depth Mud Type Depth 19464'to19464' Avg Min MaxECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Mark Hubert (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* set packer as per baker rep. POOH and L/D 5" DP. RIH with liner. Rotate liner in hiole from 16868' to 19390' MD. Tag bottom. Locate packer set depth, drop ball and md Note: Daily charges contain consumables for SI29-S2. 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 19464'to19464' Avg Min Max 19464'KCl/NaCl Brine Depth Mud Type YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min Cht Silt Siltst Hydril 563 Ss Lst EVAMAR Make 9.20 WOB 44 20-Mar-2012 24:00:00Time: Report #: Date: AK-AM-0009113840 Customer: Well: Avg PVOil / Water Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size 160' 2664' 8892' TuffGvlCoal $2,810.00 Alkal Lime $144,843.50 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 19464' 19464' 0' Current Depth: 24 Hour Progress: RIH injector tubingRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md spooler. R/U and run 4.5" 12.6 lb/f L-80 H563 completion tubing per well plan. Testing line every 25 joints. Continue to L/D DP using mouse hole. Pull wear ring. Mobilize completion tubing equipment. R/U SLB electrical Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Zach Beekman (max)(current) C-5i W E L L N A M E : SI 2 9 - S 2 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 : 8-Feb-12 SP E R R Y J O B : AK - A M - 0 0 0 9 1 1 3 8 4 0 TD : 11-Mar-12 BI T R E C O R D MW D BH A # SD L RU N # Bi t # B i t T y p e B i t Si z e De p t h In ( f t ) De p t h Ou t ( f 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 M i l l t o o t h 1 6 " 1 6 0 4 3 7 2 4 2 1 2 2 9 . 6 0 1 . 1 1 7 1 4 2 . 2 40 80 1 8 5 0 8 0 0 2- 1 - W T - A - E - 1 - S D - T D Surface TD reached 3 2 0 0 2 S m i t h G F 1 5 B I n s e r t B i t 1 2 . 2 5 " 4 3 7 2 7 2 6 8 2 8 9 6 3 3 . 6 0 1 . 1 0 7 8 6 . 2 25 80 1 8 0 0 9 0 0 2- 4 - L T - A - E - 1 - R G - B H A Pulled for bit change, had to fish for 183' of BHA left in the hole 4 3 0 0 3 S m i t h G F 1 5 B I n s e r t B i t 1 2 . 2 5 " 7 2 6 8 8 9 0 8 1 6 4 0 2 7 . 9 0 1 . 1 0 7 5 8 . 7 35 60 2 1 3 0 7 0 0 2- 4 - W T - H - E - 0 - N O - T D Intermediate TD reached. Wear on outside of all cones. 5 4 0 0 4 H u g h e s Q D 5 0 6 X P D C 8 . 7 5 " 8 9 0 8 1 9 4 6 4 1 0 5 5 6 8 1 . 2 0 0 . 9 0 2 1 3 0 . 1 12 13 5 3 3 6 0 5 3 0 3 - 1 - B T - C - X - I - R O - T D Production TD reached. Wear into matrix of bit face. WE L L N A M E : L O C A T I O N : OP E R A T O R : A R E A : MU D C O : S T A T E : RI G : S P U D : SP E R R Y J O B : T D : 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 4 , 3 7 2 ' 4, 3 7 2 ' t o 8 , 9 0 8 ' 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 + + 8- F e b 2 8 8 8 . 8 0 8 5 2 4 2 9 1 7 / 3 3 / 3 9 5 . 8 7 7 / 5 3 / 4 2 / 3 0 / 1 3 / 1 2 1 / - 3 . 0 3 / 9 4 0 . 0 0 0 . 0 2 9 . 0 2 0 . 0 . 0 1 / . 4 5 1 8 0 0 1 2 0 D r illing 16" Hole 9- F e b 1 8 3 7 9 . 3 0 - 2 4 2 7 2 1 / 4 5 / 5 5 5 . 0 7 5 / 5 1 / 4 2 / 3 1 / 1 7 / 1 6 1 / - 5 . 0 1/ 9 5 0 . 0 5 0 . 0 4 9 . 1 2 0 . 0 . 0 2 / . 4 8 2 2 0 0 8 0 D r ill 16" Hole 10 - F e b 3 4 5 5 9 . 4 5 - 2 1 2 8 1 7 / 3 3 / 4 1 5 . 0 7 0 / 4 9 / 4 0 / 3 0 / 1 6 / 1 4 1 / - 6 . 5 1/ 9 3 0 . 1 0 0 . 0 4 9 . 0 2 0 . 0 . 0 4 / . 4 8 1 3 0 0 8 0 D r illing 16" Hole 11 - F e b 4 3 7 2 9 . 5 0 - 2 3 3 6 1 8 / 3 3 / 4 0 5. 0 8 2 / 5 9 / 4 8 / 3 5 / 1 6 / 1 4 1 / - 7 .5 1 / 9 2 0 . 0 5 0 . 0 4 8 . 9 1 8 . 5 . 0 1 / . 4 4 8 0 0 1 0 B R O O H 12 - F e b 4 3 7 2 9 . 4 5 - 2 0 2 0 1 3 / 3 1 / 4 0 5 . 2 6 0 / 4 0 / 3 2 / 2 3 / 1 3 / 1 1 1 / - 6 . 5 1 / 9 3 0 . 1 0 . 0 5 9 . 0 1 6 . 0 1 / . 4 2 7 0 0 1 0 R u n n i n g C S G 13 - F e b 4 3 7 2 9 . 4 5 - 1 7 1 2 5 / 8 / - - 4 6 / 29 / 2 3 / 1 6 / 5 / 4 - - - - - 8 . 3 - - - - N / D B O P 14 - F e b 4 3 7 2 9 . 4 5 - 1 7 1 3 5 / 8 / - - 4 7 / 30 / 2 3 / 1 5 / 6 / 4 - - - - - 7 . 7 - - - - P / U D r ill Pipe 15 - F e b 4 3 7 2 9 . 4 5 - 1 7 1 3 5 / 8 / - - 4 7 / 3 0 / 23 / 1 5 / 6 / 4 - - - - - 7 . 5 - - - - P / U B H A # 3 16 - F e b 4 5 4 2 9 . 2 0 5 2 8 2 3 1 0 / 1 2 / 1 3 7 . 0 3 9 / 3 1 / 2 7 / 2 2 / 1 2 / 1 0 1 / - 2 . 0 2 / 9 6 0 . 0 0 0 . 1 9 1 0 . 0 2 . 0 .1 0 / 1 . 4 0 7 5 0 4 0 D r illing 12.25 Hole 17 - F e b 5 7 7 8 9 . 3 0 5 3 1 3 3 0 1 3 / 2 3 / 2 6 5 . 5 5 6 / 4 3 / 3 7 / 2 9 / 1 3 / 1 2 1 / - 5 . 0 2 / 9 3 0 . 1 0 0 . 1 9 1 0 . 0 9 . 5 .1 2 / 1 . 4 0 8 0 0 5 0 D r illing 12.25 Hole 18 - F e b 6 8 8 8 9 . 2 0 5 3 1 2 2 8 1 2 / 2 6 / 2 8 5 . 0 5 2 / 4 0 / 3 4 / 2 6 / 1 2 / 1 0 1 / - 5 . 0 2 / 9 3 0 . 0 5 0 . 1 5 9 . 9 1 1 . 3 .1 1 / 1 . 4 4 1 1 0 0 6 0 D r illing 12.25 Hole 19 - F e b 7 2 6 8 9 . 2 5 - 1 3 2 7 1 2 / 2 3 / 2 7 5 . 0 5 3 / 4 0 / 3 4 / 2 6 / 1 2 / 1 0 1 / - 5 . 5 2/ 9 3 0 . 1 0 0 . 1 8 9 . 8 1 0 . 5 . 09 / 1 . 4 6 1 3 0 0 6 0 P O O H 20 - F e b 7 2 6 8 9 . 2 5 - 9 2 5 1 0 / 1 5 / 1 8 5 . 5 43 / 3 4 / 3 0 / 2 3 / 1 1 / 9 1 / - 5 . 5 2 / 9 3 0. 1 0 0 . 0 8 9 . 5 1 0 . 5 . 0 6 / 1 . 10 1 3 0 0 6 0 F i s h i n g 21 - F e b 7 2 6 8 9 . 3 0 - 1 5 2 6 1 1 / 2 4 / 3 1 4 . 8 56 / 4 1 / 3 5 / 2 7 / 1 2 / 1 1 1 / - 6 . 0 2 / 92 0 . 1 0 0 . 1 1 9 . 7 1 0 . 5 . 1 0 / 1. 2 0 1 3 0 0 6 0 P O H : F i s h 22 - F e b 7 2 6 8 9 . 3 0 - 1 2 2 2 9 / 2 3 / 2 8 4 . 8 4 6 / 34 / 2 9 / 2 2 / 1 0 / 9 1 / - 6 . 0 2 / 9 2 0 . 1 0 0. 1 0 9 . 7 1 1 . 5 . 1 0 / 1 . 2 0 1 3 0 0 6 0 R I H w / B H A # 4 23 - F e b 7 6 5 4 9 . 3 0 - 1 5 2 8 1 3 / 3 1 / 3 8 4 . 0 5 8 / 4 3 / 3 6 / 2 9 / 1 3 / 1 2 1 / - 6 . 0 2/ 9 2 0 . 0 5 0 . 0 7 9 . 5 1 1 . 5 .0 8 / 1 . 3 2 1 2 0 0 6 0 D r illing 12.25 Hole 24 - F e b 8 7 0 9 9 . 4 0 - 1 4 2 8 1 3 / 2 9 / 3 8 3 . 8 5 6 / 4 2 / 3 6 / 2 8 / 1 4 / 1 3 1 / - 6 . 0 2/ 9 2 0 . 0 5 0 . 1 2 9 . 7 1 3 . 5 .1 1 / 1 . 3 5 1 3 0 0 4 0 D r illing 12.25 Hole 25 - F e b 8 9 0 8 9 . 4 0 - 1 4 2 9 1 3 / 2 9 / 3 8 4 . 0 5 7 / 4 3 / 3 5 / 2 8 / 1 3 / 1 2 1 / - 6 . 0 2/ 9 2 0 . 0 5 0 . 1 4 1 0 . 0 1 4 . 0 . 16 / 1 . 5 3 1 3 0 0 4 0 B R O O H 26 - F e b 8 9 0 8 9 . 4 0 - 1 3 2 3 1 1 / 2 6 / 3 2 5 . 1 4 9 / 36 / 3 0 / 2 3 / 1 1 / 1 0 1 / - 5 . 5 2 / 9 2 . 5 0 . 0 5 0 . 1 1 9 . 7 1 5 . 0 . 0 9 / 1 . 3 6 1 1 5 0 6 0 L / D B H A # 4 27 - F e b 8 9 0 8 9 . 4 0 - 1 3 2 2 1 0 / 2 7 / 3 3 4 . 9 4 8 / 3 5 / 3 1 / 2 4 / 1 1 / 1 0 1 / - 5 . 5 2 / 9 2 . 5 0 . 0 5 0 . 1 1 9 . 7 1 4 . 0 . 0 6 / 1 . 6 2 12 5 0 6 0 R I H w / 9 5 / 8 " c a s i n g 28 - F e b 8 9 0 8 9 . 3 0 1 3 1 9 8 / 2 0 / - - 45 / 3 2 / 2 8 / 2 1 / 8 / 7 - - - - - 9 . 6 - - - - Pr e p a r e t o c e m e n t c a s i n g 29 - F e b 8 9 0 8 9 . 3 0 1 3 1 9 8 / 2 0 / - - 4 5 / 3 2 / 2 8 / 2 1 / 8 / 7 - - - - - 9 . 6 - - - - P r e p a r e f o r B O P t e s t i n g 1- M a r 8 9 0 8 9 . 3 5 1 4 1 8 8 / 2 0 / - - 4 6 / 3 2 / 2 8 / 22 / 9 / 7 - - - - - 9 . 4 - - - - P / U 4 . 5 " D P 2- M a r 8 9 0 8 9 . 2 5 1 5 1 8 8 / 2 3 / - - 4 8 / 3 3 / 29 / 2 3 / 9 / 8 - - - - - 9 . 2 - - - - P / U B H A # 5 3- M a r 8 9 0 8 9 . 2 0 1 2 1 8 8 / 2 0 / - - 4 2 / 3 0 / 2 4 / 1 8 / 9 / 8 - - - - - - - - - - C i r c u l a t e a n d C o n d i t i o n m u d Oi l B a s e d M u d R e c o r d 8, 9 0 8 ' t o 1 9 , 4 6 4 ' 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 Co r r . So l i d 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- M a r 9 4 9 0 9 . 2 0 - 1 6 2 2 8 / 1 0 / 10 - 5 4 / 3 8 / 3 1 / 2 3 / 1 0 / 8 - / 1 7. 2 6 3 / 3 7 5 7 2 . 9 0 3 . 7 7 2 5 . 1 9 7 1 0 0 0 5 4 0 - D r illing ahead 5- M a r 1 0 4 7 3 9 . 2 5 - 1 6 2 2 9 / 1 0 / 1 0 4. 6 5 4 / 3 8 / 3 2 / 2 4 / 1 0 / 9 - / 1 7. 4 6 3 / 3 7 5 7 3 . 0 0 3 . 9 0 25 . 3 1 7 2 0 0 0 5 9 0 0 . 0 1 D r illing ahead 6- M a r 1 2 6 6 8 9 . 2 0 - 1 5 1 9 9 / 1 0 / 1 0 5. 0 4 9 / 3 4 / 2 8 / 2 1 / 8 / 7 - /1 7 . 3 6 4 / 3 6 5 7 2 . 9 0 3 . 7 7 2 4 . 6 5 6 9 0 0 0 7 3 5 - D r illing ahead 7- M a r 1 4 4 4 3 9 . 2 0 - 1 4 1 9 9 / 1 0 / 1 0 - 47 / 3 3 / 2 7 / 1 9 / 8 / 7 - / - 1 0 . 2 6 6 / 34 5 7 1 . 8 0 2 . 3 4 2 6 . 7 5 7 0 0 0 0 7 4 3 - C i r c u l a t i n g 8- M a r 1 5 9 6 9 9 . 2 0 - 1 4 1 7 9 / 9 / 1 0 5. 4 4 5 / 3 1 / 2 5 / 1 7 / 8 / 7 1 11 . 3 6 7 / 3 3 5 8 2 . 0 0 2 . 6 0 2 7 . 5 4 6 8 0 0 0 7 7 3 - D r illing ahead 9- M a r 1 7 4 3 2 9 . 2 0 - 1 3 1 8 8 / 9 / 9 5 . 0 4 4 / 3 1 / 2 5 / 1 7 / 8/ 7 - / 1 1 0 . 2 6 8 / 3 2 5 9 2 . 0 0 2 . 6 0 2 7 . 8 3 6 9 0 0 0 7 8 5 - D r illing ahead 10 - M a r 1 8 8 9 8 9 . 2 0 - 1 3 1 7 8 / 9 / 9 5 . 0 4 3 / 3 0 / 2 6 / 18 / 8 / 7 1 1 2 . 1 6 9 / 3 1 5 9 1 . 9 0 2. 4 7 2 8 . 9 5 6 9 0 0 0 8 3 6 - D r illing ahead 11 - M a r 1 9 4 6 4 9 . 2 0 - 1 3 1 7 8 / 9 / 9 5 . 0 4 3 / 3 0 / 2 5 / 1 8 / 8/ 7 / 1 1 2 . 1 6 9 / 3 1 5 9 2 . 0 0 2 . 6 0 2 7 . 6 7 6 6 0 0 0 8 2 2 - B R O O H 12 - M a r 1 9 4 6 4 9 . 2 0 - 1 3 1 9 8 / 9 / 1 0 5 . 2 4 5 / 3 2 / 2 6 / 1 9 / 8 / 7 - / 1 1 1 . 0 6 7 / 3 3 5 8 2 . 2 0 2 . 8 6 2 8 . 6 9 7 2 0 0 0 8 1 5 0 . 1 0 B R O O H 13 - M a r 1 9 4 6 4 9 . 2 0 - 1 4 1 7 9 / 9 / 1 0 - 4 5 / 3 1 / 2 5 / 1 8 / 9 / 8 - / - 1 1 . 2 6 6 / 3 4 5 7 2 . 1 0 2 . 7 3 2 7 . 4 2 7 0 0 0 0 8 0 0 0 . 1 0 P O O H 14 - M a r 1 9 4 6 4 9 . 2 0 - 1 4 1 7 9 / 9 / 1 0 - 45 / 3 1 / 2 5 / 1 9 / 9 / 8 - / - 1 1 . 2 6 7 / 33 5 8 2 . 1 0 2 . 7 3 2 7 . 7 7 7 0 0 0 0 7 8 0 0 . 1 0 P / U B H A # 6 15 - M a r 1 9 4 6 4 9 . 4 0 - 1 4 2 1 9 / - / - - 49 / 3 5 / 2 9 / 2 2 / 9 / 8 - / - 1 3 . 0 65 / 3 5 5 5 2 . 5 0 3 . 2 5 2 8 . 2 6 7 3 0 0 0 6 1 0 0 . 1 0 T I H 16 - M a r 1 9 4 6 4 9 . 4 0 5 5 1 6 1 8 9 / 9 / 10 - 5 0 / 3 4 / 2 9 / 2 2 / 9 / 8 - / - 1 3 . 1 6 5 / 3 5 5 5 2 . 3 0 2 . 9 9 2 7 . 9 8 7 2 0 0 0 6 0 0 . 0 0 . 1 0 T O O H 17 - M a r 1 9 4 6 4 9 . 2 0 - - - - - - - - - - - - 10 0 . 0 0 93 5 0 0 - - L / D B H A # 6 18 - M a r 1 9 4 6 4 9 . 2 0 - - - - - - - - - - - - - 9 4 0 0 0 - - R I H w / 4 . 5 " L i n e r 19 - M a r 1 9 4 6 4 9 . 2 0 - - - - - - - - - - - - - 9 4 0 0 0 - - L / D 4 . 5 " D P 20 - M a r 1 9 4 6 4 9 . 2 0 - - - - - - - - - - - - - 9 4 0 0 0 - - R I H w / 4 . 5 " c o m p l e t i o n t u b i n g SI 2 9 - S 2 EN I P e t r o l e u m MI S w a c o Do y o n 1 5 9 5 / 8 " I n t e r m e d i a t e @ 8 , 8 9 2 ' M D Su r f a c e S e c t i o n Fa z e P r o MI S p u d M u d LS N D AK - A M - 0 0 0 9 1 1 3 8 4 0 13 3 / 8 " S u r f a c e @ 4 , 3 5 0 ' M D 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 In t e r m e d i a t e S e c t i o n Sp y I s l a n d No r t h S l o p e Al a s k a 8- F e b - 1 2 11 - M a r - 1 2 20 " C o n d u c t o r @ 1 6 0 ' M D Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.00 1.13 347.41 160.00 -105.98 SV-4 781.00 19.46 288.73 770.94 -716.92 SV-3 1179.00 36.44 290.82 1119.96 -1065.94 SV-2 1520.00 48.63 293.77 1372.07 -1318.05 Permafrost Base 2129.00 53.70 287.30 1760.58 -1706.56 SV-1 2450.00 58.79 282.76 1925.93 -1871.91 Ugnu Top (UG4)3149.00 78.06 268.84 2198.92 -2144.90 13 3/8" Casing Shoe 4350.00 77.90 265.90 2401.06 -2347.04 TD 16" Borehole 4372.00 77.70 266.30 2405.80 -2351.78 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 5486.00 76.63 254.13 2648.79 -2594.77 Lower Ugnu 7107.00 68.38 193.26 3194.86 -3140.84 Schrader Bluff 7820.00 72.04 166.08 3448.27 -3394.25 N Sequence Top 7980.00 73.50 157.76 3496.02 -3442.00 N Sand Top 8148.00 73.27 150.17 3543.49 -3489.47 N Sand Bottom 8276.00 73.55 146.50 3580.36 -3526.34 N Sequence Base 8548.00 78.14 132.69 3647.84 -3593.82 9 5/8" Intermediate Casing 8892.00 84.90 119.75 3688.10 -3634.08 TD 12 1/4" Borehole 8908.00 84.50 119.30 3689.50 -3635.48 8 3/4" Lateral Borehole OA Sand Top 9001.00 83.60 118.33 3699.99 -3645.97 OA-sbl2 9075.00 86.54 120.03 3706.33 -3652.31 OA-sbl3 9202.00 87.33 118.26 3712.85 -3658.83 OA-sbl4 9603.00 86.71 113.48 3733.57 -3679.55 Fault A (subseismic)9714.00 89.62 115.54 3737.53 -3683.51 Fault B (subseismic)10475.00 87.37 120.58 3759.52 -3705.50 Fault C (subseismic)13173.00 89.57 118.82 3838.21 -3784.19 OA-sbl3 14260.00 92.20 118.65 3861.84 -3807.82 OA-sbl2 14370.00 91.86 117.83 3857.67 -3803.65 OA-sbl2 15370.00 88.95 119.34 3874.37 -3820.35 Fault D (subseismic)15600.00 87.11 119.34 3884.14 -3830.12 OA-sbl4 15844.00 90.45 120.83 3891.46 -3837.44 OA-sbl4 15948.00 92.40 120.28 3889.07 -3835.05 OA-sbl3 16888.00 92.18 133.67 3871.74 -3817.72 OA-sbl2 17116.00 92.20 136.79 3864.39 -3810.37 Fault E (prognosed)18133.00 91.14 138.62 3853.05 -3799.03 OA-sbl4 18234.00 92.23 136.94 3850.11 -3796.09 TD 8 3/4" Borehole 19464.00 90.30 130.20 3833.79 -3779.77 SI29-S2 Interpolated Tops 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: 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 - = Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 - =C1/C2 = C2 - =C1/C3 = SI29-S2 Hydrocarbon Ratios 1150 3587 1 3544 Andrew Buchanan No producible oil within these zones based upon gas and chromatograph data collected. 91 512 8150 8300 1150 Mud Chlorides (mg/L) = Spy Island ENI Petroleum Emil Opitz 1 61 Mud Chlorides (mg/L) = 24-Feb-12 N Sands 14 116 709 58 6532 64762 89 872 8186 80274 651 674 58 6532 62 144 955 130 522 126 10 58230 502 448 8172 Interpretation: Gas Units Gas Units 73742 814 2 1 10 100 1000 Gas NPH C3 - =C1/C4 = C4 - =C1/C5 = C5 - = Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 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 - = Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 - =C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = C5 - = Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Mud Chlorides (mg/L) = 1150 39 Mud Chlorides (mg/L) = 1150 144 103 39601 59 439 15396 528 716 39 22 17 60 1 112 56080 82 44 608 178 618 178 8249 110 79 54997 15396 35 10 117 14 154 8234 22 38 2393 1131 2329 92 1250 0.00 44 35 35 77 528 1071 92 40684 17 450 440 Gas Units Gas Units 430 Hydrocarbon Ratios 3 4 75 1 Oil NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas 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: 3/4/2012 to 3/5/2012 OA Sands 9000 10500 Spy Island ENI Petroleum Emil Opitz SI29-S2 3761 2 3700 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 9265 Interpretation: GU i t 547 74000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 9265 Gas Units 545274 547 284 48 53375 226 195 126 422 107 328 54 236 505 83 10322 63697 9 98 74000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 76241 598 695 9431 84642 747 97 8401 Mud Chlorides (mg/L) = 127 227 71000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 340 68 239 90 404 10261 251 27 512336 149 224 890 Mud Chlorides (mg/L) =73500 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 4 340 646 143 210 602 44188 154 63 242 94960 2287 35 675 29 375 273 273 92673 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 760 Gas Units 260 524 109434 1048 394 144 43 421 209 308 99 806 46 10368 346 68 278 464 113192 3758 Mud Chlorides (mg/L) =73500 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 346 68 278 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: 6-Mar-12 OA Sands 10500 12000 Spy Island ENI Petroleum Emil Opitz SI29-S2 3790 3 3760 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 11052 Interpretation: GU i t 1070 73000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 11052 Gas Units 745424 1070 368 38 113283 343 267 172 657 231 526 102 330 695 38 3339 116622 79 152 73000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 106469 606 634 11131 108825 1008 28 2356 Mud Chlorides (mg/L) = 176 347 73000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 560 33 233 95 340 11779 267 77 772307 138 190 1057 Mud Chlorides (mg/L) =68000 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 4 294 557 185 196 1612 526227 64 138 291 111316 8123 105 672 115 399 351 334 103193 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 592 Gas Units 320 1244 104481 1075 477 176 103 326 84 319 235 699 107 11958 363 144 219 429 111125 6644 Mud Chlorides (mg/L) =68000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 363 144 219 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: 3/6/2012 to 3/7/2012 OA Sands 12000 13000 Spy Island ENI Petroleum Emil Opitz SI29-S2 3834 4 3790 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 12128 Interpretation: GU i t 718 68000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 12128 Gas Units 627290 718 320 108 68332 322 236 175 390 271 544 254 212 499 109 7981 76313 162 109 68000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 105326 565 635 12552 115289 1139 70 9963 Mud Chlorides (mg/L) = 186 338 68000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 428 51 272 103 363 12726 312 66 623312 169 246 1250 Mud Chlorides (mg/L) =69000 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 4 332 631 187 207 967 570174 122 131 296 121839 3884 63 690 59 395 355 338 117955 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 666 Gas Units 330 819 117101 1201 505 176 63 355 143 317 174 725 59 12903 363 131 232 418 120985 3884 Mud Chlorides (mg/L) =69000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 363 131 232 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: 7-Mar-12 OA Sands 13000 14000 Spy Island ENI Petroleum Emil Opitz SI29-S2 3870 5 3834 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 13400 Interpretation: GU i t 942 68000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 13400 Gas Units 750337 942 348 97 89295 356 265 174 514 295 581 244 251 613 99 7790 97085 176 119 68000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 100781 634 674 13591 106578 1031 40 5797 Mud Chlorides (mg/L) = 159 302 68000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 422 31 283 83 365 13787 320 81 504334 200 239 1071 Mud Chlorides (mg/L) =70000 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 4 341 676 160 254 504 42666 215 60 281 112071 3763 24 708 32 365 318 314 108308 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 702 Gas Units 394 1959 119506 1248 699 170 92 303 61 302 241 801 99 13973 337 166 171 395 127283 7777 Mud Chlorides (mg/L) =70000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 337 166 171 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: 3/7/2012 to 3/8/2012 OA Sands 14000 16000 Spy Island ENI Petroleum Emil Opitz SI29-S2 3886 6 3870 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 14486 Interpretation: GU i t 926 70000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 14486 Gas Units 588405 926 340 38 95870 317 237 142 675 251 507 102 302 720 45 2999 98869 88 163 70000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 93122 674 719 14858 96121 927 45 2999 Mud Chlorides (mg/L) = 138 311 70000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 575 38 230 102 337 15239 250 88 728299 128 162 986 Mud Chlorides (mg/L) =69000 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 4 314 727 136 160 791 618103 125 84 228 103502 4585 41 777 50 355 315 244 98917 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 672 Gas Units 303 687 88634 868 565 132 32 293 129 211 82 706 34 15712 226 69 157 325 91331 2697 Mud Chlorides (mg/L) =68000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 226 69 157 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: 9-Mar-12 OA Sands 16000 17000 Spy Island ENI Petroleum Emil Opitz SI29-S2 3868 7 3886 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 16120 Interpretation: GU i t 1114 68000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 16120 Gas Units 755401 1114 388 44 111033 323 277 133 835 218 500 99 344 889 54 3372 114405 71 147 68000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 128644 893 926 16344 131496 1285 33 2852 Mud Chlorides (mg/L) = 144 357 68000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 660 26 236 65 386 16646 248 53 752360 171 195 1209 Mud Chlorides (mg/L) =68000 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 4 293 783 157 165 898 74664 137 46 201 125103 2061 27 815 32 320 420 211 123042 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 533 Gas Units 418 973 83669 800 728 157 27 200 86 150 64 565 32 16927 161 46 115 227 85730 2061 Mud Chlorides (mg/L) =70000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 161 46 115 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: 3/9/2012 to 3/10/2012 OA Sands 17000 18250 Spy Island ENI Petroleum Emil Opitz SI29-S2 3849 8 3868 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 17456 Interpretation: GU i t 1099 69000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 17456 Gas Units 1246264 1099 278 48 110881 482 420 165 671 156 366 102 230 745 74 5805 116686 67 89 69000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 123932 705 738 17642 126179 1199 33 2247 Mud Chlorides (mg/L) = 176 510 69000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 905 26 174 63 269 17944 179 42 1117243 111 137 906 Mud Chlorides (mg/L) =69000 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 4 194 536 171 109 1312 84390 70 57 160 98153 6284 43 610 74 237 474 166 91869 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 464 Gas Units 480 1408 81684 838 825 176 43 170 58 148 90 538 74 18106 156 57 99 213 87968 6284 Mud Chlorides (mg/L) =69000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 156 57 99 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: 3/10/2012 to 3/11/2012 OA Sands 18250 19025 Spy Island ENI Petroleum Emil Opitz SI29-S2 3832 9 3849 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 18337 Interpretation: GU i t 1100 69000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 18337 Gas Units 1579223 1100 228 36 113672 592 510 196 581 135 313 90 192 630 49 2944 116616 63 72 69000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 87287 432 466 18604 90551 834 34 3264 Mud Chlorides (mg/L) = 202 598 69000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 1119 23 120 59 169 18778 124 46 1431146 61 78 1429 Mud Chlorides (mg/L) =69000 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 4 211 650 218 129 1540 109888 92 53 180 148164 6496 42 723 73 253 671 182 141668 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 451 Gas Units 798 2343 110108 1074 1327 244 35 138 47 127 80 511 60 19010 132 49 83 173 115599 5491 Mud Chlorides (mg/L) =69000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 132 49 83 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: 11-Mar-12 OA Sands 19025 19454 Spy Island ENI Petroleum Emil Opitz SI29-S2 3833 10 3832 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 19052 Interpretation: GU i t 1067 69000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 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 -= 19052 Gas Units 1989160 1067 160 36 109422 882 684 258 424 111 244 84 124 478 54 3615 113037 56 55 69000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 97826 404 436 19137 101776 973 32 3950 Mud Chlorides (mg/L) = 242 783 69000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 1322 23 114 60 148 19285 118 44 1812125 54 74 1381 Mud Chlorides (mg/L) =69000 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 4 167 553 252 114 1787 122380 78 50 158 145715 6304 36 616 63 203 835 164 139411 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 540 Gas Units 918 2073 145113 1417 1451 269 29 158 70 140 70 590 50 19387 146 46 100 187 149967 4854 Mud Chlorides (mg/L) =69000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 146 46 100 1.0 NPH DIRECTIONAL SURVEY REPORT Eni Petroleum SI29-S2 Nikaitchuq Alaska United States AK-XX-0009113840 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 58.00 0.22 48.72 58.00 0.07 N 0.08 E -0.03 0.38 118.00 0.32 4.61 118.00 0.32 N 0.18 E -0.20 0.37 178.00 1.49 345.85 177.99 1.24 N 0.01 E -1.11 1.99 273.00 3.79 335.22 272.88 5.29 N 1.61 W -5.45 2.46 365.00 6.63 320.08 364.50 12.12 N 6.30 W -13.66 3.40 459.00 8.91 308.13 457.64 20.78 N 15.51 W -25.53 2.96 491.07 9.57 303.98 489.29 23.81 N 19.67 W -30.09 2.92 583.92 10.10 296.96 580.78 31.81 N 33.33 W -43.37 1.41 676.95 14.96 288.57 671.57 39.34 N 51.99 W -58.46 5.57 768.38 18.90 288.73 759.02 47.85 N 77.21 W -77.36 4.31 862.98 23.12 288.75 847.31 58.75 N 109.33 W -101.48 4.46 955.84 28.09 288.69 931.03 71.62 N 147.32 W -130.01 5.35 1049.14 31.03 288.90 1012.18 86.45 N 190.89 W -162.78 3.15 1142.28 35.18 289.35 1090.18 103.13 N 238.94 W -199.20 4.46 1235.90 38.42 292.83 1165.14 123.36 N 291.21 W -240.69 4.11 1329.62 41.55 292.87 1236.94 146.74 N 346.70 W -286.45 3.34 1422.25 44.23 294.55 1304.80 172.11 N 404.41 W -334.97 3.15 1509.57 48.31 293.54 1365.15 197.80 N 462.02 W -383.73 4.75 1609.28 51.39 295.62 1429.44 229.52 N 531.30 W -443.12 3.48 1703.32 47.48 295.12 1490.59 260.13 N 595.84 W -499.39 4.18 1796.55 50.55 292.91 1551.73 288.74 N 660.12 W -553.75 3.75 1889.85 51.88 292.93 1610.17 317.06 N 727.10 W -609.07 1.43 1983.96 49.27 292.30 1669.93 345.02 N 794.20 W -664.11 2.82 2076.03 51.73 289.20 1728.50 370.15 N 860.63 W -716.32 3.73 2170.02 55.30 285.97 1784.39 392.92 N 932.65 W -768.94 4.70 2261.82 60.10 283.85 1833.43 412.84 N 1007.62 W -820.32 5.58 2356.77 61.66 282.66 1879.64 431.86 N 1088.35 W -873.47 1.97 2450.08 58.79 282.76 1925.97 449.67 N 1167.35 W -924.77 3.08 2541.78 61.10 279.38 1971.90 464.88 N 1245.23 W -973.24 4.06 2637.17 60.82 278.47 2018.21 477.82 N 1327.61 W -1021.70 0.88 2730.34 64.01 276.68 2061.35 488.69 N 1409.46 W -1068.06 3.82 2823.08 65.91 275.68 2100.60 497.72 N 1492.99 W -1113.54 2.27 2915.24 69.85 272.50 2135.30 503.78 N 1578.12 W -1157.07 5.34 3010.82 73.31 271.68 2165.50 507.08 N 1668.73 W -1200.60 3.71 3103.95 77.14 269.35 2189.25 507.87 N 1758.75 W -1241.61 4.77 3197.28 79.05 268.29 2208.50 505.99 N 1850.05 W -1280.81 2.33 3290.66 79.83 267.12 2225.62 502.31 N 1941.77 W -1318.59 1.49 3384.51 81.80 264.02 2240.60 495.15 N 2034.12 W -1353.54 3.88 3477.22 81.31 262.59 2254.22 484.46 N 2125.20 W -1384.76 1.61 3570.95 80.22 262.52 2269.26 472.47 N 2216.94 W -1415.12 1.17 3664.20 78.67 263.36 2286.34 461.20 N 2307.91 W -1445.77 1.88 3757.31 79.75 260.84 2303.77 448.63 N 2398.49 W -1475.09 2.90 3850.75 82.59 259.92 2318.11 433.20 N 2489.52 W -1502.05 3.19 3944.07 82.21 259.79 2330.46 416.90 N 2580.57 W -1528.25 0.43 4037.95 81.30 260.32 2343.92 400.86 N 2672.08 W -1554.88 1.12 4129.85 79.92 260.39 2358.91 385.67 N 2761.47 W -1581.32 1.50 4224.39 79.09 264.73 2376.14 373.63 N 2853.62 W -1611.82 4.60 4300.54 78.48 265.02 2390.95 366.96 N 2928.02 W -1639.16 0.88 4378.67 77.53 268.47 2407.19 362.61 N 3004.30 W -1669.44 4.49 4410.31 77.11 266.92 2414.14 361.37 N 3035.15 W -1682.14 4.96 4503.16 76.50 266.80 2435.33 356.42 N 3125.41 W -1718.13 0.67 4596.58 77.17 263.85 2456.62 349.01 N 3216.06 W -1752.09 3.16 4689.94 77.14 263.13 2477.37 338.69 N 3306.49 W -1783.35 0.75 4783.62 77.20 261.17 2498.18 326.21 N 3396.98 W -1812.71 2.04 4877.86 77.46 261.00 2518.85 311.96 N 3487.81 W -1840.64 0.33 4970.60 78.03 261.15 2538.53 297.90 N 3577.34 W -1868.16 0.63 5063.95 78.17 261.27 2557.78 283.94 N 3667.61 W -1896.10 0.20 5157.96 78.43 261.76 2576.84 270.36 N 3758.66 W -1924.72 0.58 5251.02 77.44 260.76 2596.30 256.53 N 3848.60 W -1952.63 1.50 5345.43 76.98 257.27 2617.20 239.00 N 3938.97 W -1977.41 3.64 5438.34 77.18 255.48 2637.98 217.66 N 4026.97 W -1997.74 1.89 5530.51 76.07 252.74 2659.30 193.12 N 4113.21 W -2014.41 3.13 5624.47 76.11 248.42 2681.90 162.80 N 4199.20 W -2025.80 4.46 5717.27 75.11 245.29 2704.97 127.48 N 4281.84 W -2031.23 3.44 5811.19 74.06 242.35 2729.94 87.55 N 4363.09 W -2031.90 3.22 5904.88 72.86 239.43 2756.61 43.87 N 4441.55 W -2027.97 3.25 5998.48 70.52 235.72 2786.03 3.75 S 4516.55 W -2018.97 4.52 6091.06 69.74 232.56 2817.50 54.74 S 4587.10 W -2004.97 3.32 6184.56 69.15 227.71 2850.35 110.83 S 4654.28 W -1984.90 4.90 6278.58 69.58 224.19 2883.49 172.00 S 4717.50 W -1958.51 3.53 6371.17 68.82 221.99 2916.37 235.20 S 4776.63 W -1928.48 2.37 6464.73 68.60 220.22 2950.34 300.88 S 4833.94 W -1895.41 1.78 6564.00 67.25 213.66 2987.69 374.34 S 4889.21 W -1854.47 6.27 6651.07 66.56 211.30 3021.84 441.90 S 4932.22 W -1813.32 2.62 6744.14 68.03 210.36 3057.77 515.62 S 4976.21 W -1767.10 1.83 6837.96 67.60 207.21 3093.20 591.75 S 5018.04 W -1717.76 3.14 6931.25 67.49 203.80 3128.84 669.55 S 5055.16 W -1664.82 3.38 7024.52 67.99 198.12 3164.20 750.11 S 5086.01 W -1606.59 5.66 7117.11 68.44 192.68 3198.58 832.97 S 5108.83 W -1542.73 5.48 7197.41 67.57 190.77 3228.66 905.86 S 5123.96 W -1484.32 2.46 7236.16 67.26 188.76 3243.54 941.12 S 5130.03 W -1455.51 4.86 7331.56 68.12 185.54 3279.77 1028.68 S 5141.01 W -1382.14 3.25 7425.04 69.09 183.50 3313.87 1115.44 S 5147.86 W -1307.63 2.28 7517.77 69.39 178.05 3346.76 1202.10 S 5149.03 W -1230.66 5.50 7610.37 69.74 174.60 3379.10 1288.68 S 5143.46 W -1150.76 3.51 7705.63 70.37 171.15 3411.60 1377.51 S 5132.35 W -1066.35 3.47 7799.47 71.94 167.22 3441.93 1464.72 S 5115.68 W -980.91 4.30 7890.85 72.45 162.17 3469.88 1548.60 S 5092.72 W -895.62 5.29 7984.04 73.51 157.56 3497.17 1632.23 S 5062.05 W -807.11 4.86 8079.81 73.79 152.24 3524.15 1715.42 S 5023.08 W -715.28 5.34 8171.81 73.09 149.44 3550.38 1792.42 S 4980.12 W -627.20 3.01 8261.01 73.40 147.10 3576.10 1865.06 S 4935.20 W -542.13 2.54 8359.16 74.44 143.18 3603.29 1942.42 S 4881.30 W -448.82 3.98 8453.16 76.44 137.93 3626.94 2012.64 S 4823.51 W -360.16 5.81 8546.42 78.08 132.74 3647.51 2077.30 S 4759.58 W -273.72 5.71 8637.46 81.37 129.80 3663.76 2136.36 S 4692.26 W -190.77 4.81 8724.83 84.15 125.99 3674.77 2189.57 S 4623.88 W -112.57 5.37 8822.64 86.38 122.51 3682.84 2244.42 S 4543.32 W -27.46 4.22 8856.59 85.75 120.82 3685.17 2262.20 S 4514.49 W 1.35 5.30 8954.58 83.40 117.85 3694.44 2309.99 S 4429.47 W 82.15 3.85 8980.46 82.77 117.84 3697.56 2321.99 S 4406.75 W 103.05 2.43 9073.69 86.53 120.05 3706.25 2366.90 S 4325.55 W 179.57 4.67 9167.46 87.36 118.79 3711.25 2412.90 S 4243.99 W 257.22 1.61 9260.28 87.27 117.36 3715.59 2456.53 S 4162.18 W 332.86 1.54 9353.63 86.78 115.40 3720.44 2497.95 S 4078.67 W 407.29 2.16 9445.96 87.52 115.82 3725.03 2537.81 S 3995.51 W 480.16 0.92 9526.26 86.64 113.43 3729.12 2571.22 S 3922.62 W 542.68 3.17 9619.87 86.72 113.49 3734.54 2608.43 S 3836.89 W 614.33 0.11 9713.36 89.62 115.56 3737.53 2647.21 S 3751.89 W 687.07 3.81 9807.59 89.49 113.13 3738.26 2686.05 S 3666.05 W 760.23 2.58 9900.87 89.35 116.14 3739.21 2724.93 S 3581.27 W 832.95 3.23 9993.89 89.17 118.35 3740.41 2767.50 S 3498.58 W 908.05 2.38 10087.83 86.58 119.47 3743.89 2812.88 S 3416.42 W 985.42 3.00 10181.41 87.67 121.71 3748.58 2860.44 S 3335.97 W 1063.96 2.66 10274.21 88.31 123.58 3751.84 2910.47 S 3257.88 W 1143.66 2.13 10367.47 87.86 124.36 3754.96 2962.55 S 3180.58 W 1224.84 0.97 10459.99 87.34 120.65 3758.83 3012.21 S 3102.64 W 1304.15 4.05 10553.33 87.55 120.19 3762.99 3059.43 S 3022.23 W 1382.37 0.54 10646.79 87.54 121.31 3767.00 3107.17 S 2941.98 W 1460.99 1.20 10740.22 86.49 121.77 3771.86 3155.97 S 2862.46 W 1540.23 1.23 10833.85 88.60 122.60 3775.87 3205.80 S 2783.30 W 1620.23 2.42 10927.21 87.71 122.04 3778.88 3255.69 S 2704.44 W 1700.14 1.13 11020.58 87.84 123.07 3782.50 3305.89 S 2625.81 W 1780.25 1.11 11114.03 87.86 123.79 3786.01 3357.34 S 2547.87 W 1861.14 0.77 11207.14 89.87 125.14 3787.85 3410.01 S 2471.13 W 1942.61 2.60 11300.64 91.40 126.41 3786.82 3464.67 S 2395.28 W 2025.44 2.13 11394.01 89.85 125.55 3785.80 3519.52 S 2319.73 W 2108.31 1.90 11488.39 89.21 124.02 3786.57 3573.36 S 2242.22 W 2191.16 1.76 11581.11 90.06 122.11 3787.16 3623.94 S 2164.52 W 2271.18 2.25 11674.85 89.22 118.40 3787.75 3671.16 S 2083.56 W 2349.65 4.06 11767.95 89.32 119.36 3788.94 3716.12 S 2002.05 W 2426.35 1.04 11861.72 89.61 118.97 3789.81 3761.82 S 1920.17 W 2503.87 0.52 11954.98 89.48 118.39 3790.55 3806.57 S 1838.36 W 2580.52 0.64 12047.48 90.21 117.66 3790.80 3850.03 S 1756.70 W 2655.94 1.12 12140.51 89.08 119.06 3791.38 3894.22 S 1674.84 W 2732.11 1.93 12234.14 87.33 118.90 3794.31 3939.56 S 1592.98 W 2809.30 1.88 12327.72 86.81 120.88 3799.10 3986.13 S 1511.96 W 2887.22 2.18 12421.58 87.70 121.14 3803.59 4034.43 S 1431.61 W 2966.39 0.99 12514.64 86.36 120.23 3808.41 4081.86 S 1351.69 W 3044.58 1.74 12608.07 84.55 118.86 3815.82 4127.78 S 1270.67 W 3121.92 2.43 12700.72 85.40 118.88 3823.93 4172.34 S 1189.84 W 3197.95 0.92 12794.14 89.24 120.52 3828.30 4218.57 S 1108.81 W 3275.57 4.47 12887.77 87.54 118.64 3830.93 4264.77 S 1027.42 W 3353.32 2.71 12980.89 88.45 118.75 3834.19 4309.45 S 945.78 W 3429.83 0.98 13074.42 88.56 119.11 3836.63 4354.68 S 863.95 W 3506.91 0.40 13170.33 89.57 118.79 3838.20 4401.10 S 780.04 W 3585.99 1.10 13261.01 89.41 119.94 3839.00 4445.56 S 701.02 W 3661.13 1.28 13354.74 87.83 119.62 3841.26 4492.10 S 619.69 W 3739.16 1.72 13448.03 86.67 120.54 3845.74 4538.80 S 539.06 W 3817.02 1.59 13541.39 86.82 120.80 3851.04 4586.35 S 458.89 W 3895.43 0.32 13635.09 86.15 120.53 3856.78 4634.05 S 378.44 W 3974.10 0.77 13728.35 87.26 120.50 3862.14 4681.32 S 298.23 W 4052.28 1.19 13821.54 88.01 121.53 3865.99 4729.30 S 218.44 W 4130.91 1.37 13914.34 88.41 121.51 3868.89 4777.79 S 139.37 W 4209.67 0.43 14008.71 90.10 121.61 3870.11 4827.17 S 58.97 W 4289.83 1.79 14101.77 92.78 121.26 3867.77 4875.69 S 20.40 E 4368.75 2.90 14195.92 91.75 119.90 3864.05 4923.55 S 101.39 E 4447.81 1.81 14289.35 92.40 118.07 3860.67 4968.79 S 183.06 E 4524.83 2.08 14382.70 91.77 117.79 3857.27 5012.48 S 265.48 E 4600.81 0.74 14474.80 88.72 116.41 3856.88 5054.43 S 347.46 E 4675.02 3.63 14568.87 89.41 116.08 3858.42 5096.03 S 431.82 E 4749.98 0.81 14662.41 86.42 115.18 3861.82 5136.46 S 516.09 E 4823.87 3.34 14755.69 87.30 118.08 3866.93 5178.20 S 599.34 E 4898.47 3.24 14849.05 89.07 121.40 3869.89 5224.48 S 680.35 E 4976.12 4.03 14942.62 88.38 121.41 3871.97 5273.23 S 760.19 E 5055.46 0.74 15036.31 90.59 120.34 3872.81 5321.30 S 840.59 E 5134.45 2.62 15129.53 89.96 119.63 3872.36 5367.89 S 921.34 E 5212.26 1.02 15223.51 88.76 118.08 3873.41 5413.24 S 1003.64 E 5289.66 2.09 15316.78 90.42 118.59 3874.08 5457.50 S 1085.73 E 5365.99 1.86 15410.63 87.83 119.91 3875.51 5503.35 S 1167.59 E 5443.64 3.10 15503.75 87.31 118.60 3879.46 5548.82 S 1248.76 E 5520.64 1.51 15597.09 87.12 119.35 3884.00 5593.98 S 1330.32 E 5597.54 0.83 15690.09 86.92 119.12 3888.83 5639.34 S 1411.36 E 5674.39 0.33 15783.69 89.74 121.38 3891.56 5686.46 S 1492.17 E 5752.71 3.86 15876.84 90.84 120.53 3891.09 5734.38 S 1572.05 E 5831.32 1.49 15970.18 92.89 120.20 3888.05 5781.53 S 1652.54 E 5909.52 2.22 16063.27 93.48 121.38 3882.88 5829.11 S 1732.38 E 5987.81 1.42 16156.39 90.34 121.10 3879.78 5877.37 S 1811.95 E 6066.59 3.39 16250.31 88.12 120.57 3881.04 5925.50 S 1892.58 E 6145.73 2.43 16343.87 87.74 123.13 3884.42 5974.84 S 1971.99 E 6225.40 2.76 16436.93 89.37 128.09 3886.77 6028.99 S 2047.60 E 6307.68 5.61 16530.36 90.76 129.40 3886.66 6087.46 S 2120.47 E 6392.58 2.04 16623.77 92.97 131.01 3883.62 6147.72 S 2191.76 E 6478.39 2.93 16717.33 92.12 133.13 3879.47 6210.34 S 2261.14 E 6565.45 2.44 16810.73 93.04 134.47 3875.26 6274.92 S 2328.48 E 6653.35 1.74 16904.35 92.00 133.50 3871.14 6339.87 S 2395.78 E 6741.56 1.52 16997.41 91.50 133.28 3868.30 6403.77 S 2463.37 E 6828.96 0.59 17090.62 92.13 135.71 3865.35 6469.06 S 2529.82 E 6917.09 2.69 17184.08 92.37 139.69 3861.68 6538.12 S 2592.66 E 7006.97 4.26 17277.30 89.75 142.01 3859.95 6610.39 S 2651.50 E 7097.94 3.75 17372.25 91.91 148.95 3858.58 6688.56 S 2705.26 E 7191.91 7.65 17465.48 92.50 151.76 3854.99 6769.51 S 2751.34 E 7284.93 3.08 17559.39 89.08 148.48 3853.70 6850.91 S 2798.11 E 7378.65 5.05 17651.34 88.54 147.26 3855.60 6928.76 S 2847.00 E 7470.15 1.45 17744 42 88 63 145 91 3857 90 7006 43 S 2898 24 E 7562 54 14 5 17744.42 88.63 145.91 3857.90 7006.43 S 2898.24 E 7562.54 1.45 17837.90 90.42 145.40 3858.68 7083.60 S 2950.98 E 7655.16 1.99 17931.37 91.13 144.23 3857.41 7159.99 S 3004.83 E 7747.57 1.46 18024.74 91.45 142.17 3855.31 7234.73 S 3060.74 E 7839.44 2.23 18118.01 90.98 139.03 3853.33 7306.78 S 3119.92 E 7930.36 3.40 18212.26 91.97 136.45 3850.91 7376.50 S 3183.28 E 8021.07 2.93 18304.96 93.08 138.54 3846.82 7444.77 S 3245.85 E 8110.13 2.55 18398.32 93.20 138.68 3841.71 7514.70 S 3307.48 E 8200.26 0.20 18490.03 93.48 133.80 3836.36 7580.81 S 3370.78 E 8287.71 5.32 18585.79 89.85 130.82 3833.58 7645.22 S 3441.55 E 8376.99 4.90 18679.19 89.50 128.54 3834.11 7704.85 S 3513.43 E 8462.50 2.47 18771.65 88.92 127.51 3835.39 7761.80 S 3586.25 E 8546.03 1.28 18864.44 91.48 128.62 3835.06 7819.01 S 3659.30 E 8629.88 3.01 18957.65 90.92 128.18 3833.11 7876.89 S 3732.33 E 8714.34 0.76 19051.14 88.83 125.83 3833.31 7933.15 S 3806.98 E 8798.07 3.36 19144.33 88.98 125.09 3835.09 7987.21 S 3882.87 E 8880.39 0.81 19237.49 90.70 125.63 3835.35 8041.12 S 3958.85 E 8962.61 1.94 19331.19 90.38 127.36 3834.47 8096.84 S 4034.17 E 9046.16 1.88 19402.43 90.26 130.19 3834.07 8141.45 S 4089.70 E 9110.91 3.98 19464.00 90.26 130.19 3833.79 8181.18 S 4136.73 E 9167.50 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 153.40 DEGREES (TRUE) A TOTAL CORRECTION OF 20.71 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 19464.00 FEET IS 9167.57 FEET ALONG 153.18 DEGREES (TRUE) Date Printed:18 March 2012 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000 12,000 13,000 14,000 15,000 16,000 17,000 18,000 19,000 20,000 0 5 10 15 20 25 30 35 Me a s u r e d D e p t h Rig Days Prognosed Actual SI29-S2 Days vs. Depth 11 Feb 2012 Reached surface TD at 1130 hrs 4372 MD / 2402' TVD 27 Feb 2012 Run & Land 9 5/8 casing to 8892' MD 11 Mar 2012 TD reached 19,464' MD, 3833' TVD 13 Feb 2012 Run & Land 13 3/8 casing to 4350' MD 16 Feb 2012 RIH, LOT 11.6 ppg EMW, Drill ahead 7 Feb 2012 SDL rig up unit and gas equipment 8 Feb 2012 Pre Spud meeting and spud the well 19 Feb 2012 Drilled to 7268' MD POOH at 1230 hrs for bit trip, had to fish for BHA left in the hole 22 Feb 2012 RIH and resume drilling at 1004 hrs with BHA #4 25 Feb 2012 Reached intermediate TD at 0415 hrs 8908 MD / 3681' TVD 4 Mar 2012 Perform FIT to 13.1 ppg EMW. Drill ahead Surface Data Logging After Action Review Employee Name: Emil Opitz Date: 18-Mar-2012 Well: SI29-S2 Hole Section: Production What went as, or better than, planned: Gas traps functioned well. Insite functioned well. Difficulties experienced: 8800 THA began to self-extinguish for no apparent reason. Sample catchers were not drying samples thoroughly. Oven temperature knob broke off (this is a new oven last well), and temperature was set too high in oven burning the samples. Recommendations: Always have backup gas gear on location. Innovations and/or cost savings: None for this hole section.