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Home My WebLink About213-043MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI19-FN2 NIKAITCHUQ SI19-FN2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 SI19-FN2 50-629-23487-00-00 213-043-0 W SPT 3718 2130430 1500 677 677 677 677 210 390 390 390 4YRTST P Sully Sullivan 4/15/2025 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 SI19-FN2 Inspection Date: Tubing OA Packer Depth 5 1701 1676 1667IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250416120350 BBL Pumped:6.2 BBL Returned:4.7 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 99 999 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 12:36:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 5, 2021 TO: Jim Regg l� P.I. Supervisor 1�esf� '5/(4TcE,j SUBJECT: Mechanical Integrity Tests Em US Operating Company Inc. SII9-FN2 FROM: Guy Cook NIKAITCHUQ 5119-FN2 Petroleum Inspector Ste: Inspector Reviewed By: P.1. Supry J' NON -CONFIDENTIAL Comm Well Name NIKAITCHUQ SII9-FN2 Insp Num: mitGDC210501112859 Rel Insp Num: API Well Number 50-629-23487-00-00 Inspector Name: Guy Cook Permit Number: 213-043-0 Inspection Date: 4/30/2021 i Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WellDSU9-FN2 . TypeInj 3t' --TVD 3218 —Tubing 391 392 - 390- 391D130430 Type Test si'l-Test psi 1500 -', IA 831 1220 - n03 - 16981698 BBL Pumped: 2 2 BBL Returned: 2.4 OA 330_ 420 - 420 - L 420 Interval I3RI r P/F P Notes: resting dmre with a triples pump, calibrated gauges and a bleed trailer. ec 7vz o Wednesday, May 5, 2021 Page I of I • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 TO: Jim Regg P.I.Supervisor Reel t Z( u. SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC SI19-FN2 FROM: Jeff Jones NIKAITCHUQ S119-FN2 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv ,. NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI19-FN2 API Well Number 50-629-23487-00-00 Inspector Name: Jeff Jones Permit Number: 213-043-0 Inspection Date: 12/10/2016 Insp Num: mitJJ161212170754 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI19-FN2 Type Inj W TVD 3718 - - Tubing 91 - 87 86 - 86 PTD 2130430 ' Type Test SPT Test psi l 1500 IA 112 1661 1646 " 1636 ' Interval j4YRTST P/F P OA 270 400 ' 400 - 380 " Notes: 4.3 barrels diesel pumped. 1 well inspected,no exceptions noted. SCANNED APR 0 5 2 ?. Wednesday,December 28,2016 Page 1 of 1 a M 9 1 I I _N 0 0 ON O y O O N DI > DI > N ri � 0 8 O 01 5 I- S I— X N L. 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O a7 C`J a 0 o s a m v E Q O E m 0 E 2 a)a) i 0 0 aai n E I EO d a 2 0 a 0 i 0 0 C 0 ! 0 MEMORANDUM State of Alaska /----- Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,August 08,2013 P.I.Supervisor 1 e-e,l 01 131(3 SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC S119-FN2 FROM: Bob Noble NIKAITCHUQ 5119-FN2 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:J P,C- NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI19-FN2 API Well Number 50-029-23487-00-00 Inspector Name: Bob Noble Permit Number: 213-043-0 Inspection Date: 8/1/2013 Insp Num: mitRCNl30804101532 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S119-FN2 Type Inj W TVD 3718 IA 1122 1708 1700 _ 1696 - SPT PTD i -- Type Test, _ 1500 - - OA - 2130430 � yp (Test psi' -, OA 240 310 � 310 310 • ' L Interval INITAL --- P/F P — Tubin g i 97 r 97 97 97 Notes: I Thursday,August 08,2013 Page 1 of 1 HALLIBURTON � `9 3 DATA LOGGED /��2013 MKB NDER perry Drilling l' ri. l AUG 12 2013 To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 AOGCC 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 -S119-FN2 AFE #6105 Rig - Doyon 15 Spy Island -Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports 1 Final Data Listing on CD-ROM 1 Sets of Final Logs -for each well 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 P'71L Sign Name €6/12-/IS Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. I 3 - Schiumberger / 7 Drilling &Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No S119-FN2 Date Dispatched: 11-Jul-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs S119-FN2 Log 1 2 in MD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 Received By: Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 7 /5J// hecheto aC�slb.com Hector Echeto Fax:907-561-8317 Transmittal#:6155 RECEIVED STATE OF ALASKA AUG O Z O13 ALASKA OIL AND GAS CONSERVATION COMMISSION la.Well StatuWEL❑L COM❑PLETIO❑N OR R❑ECOMPL❑ETIOpNdREPORT AND LC lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ • GINJ ❑ WINJ 0 WAG ❑ WDSPL❑ No.of Completions: Service Z31.1 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 6/27/2013 • 213-043 • 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 5/29/2013 i 50-629-23487-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4455.8 FSL 1342.7 FEL S19 T14N R9E UM 6/19/2013 SI19-FN2 ' Top of Productive Horizon: 8.KB(ft above MSL): 53.8 15.Field/Pool(s): 3864 FSL 5222 FEL 13 T14N R8EUM • GL(ft above MSL): 13.1 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool '' 5176 FSL 1443 FEL 10 T14N R8EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511567.11 y- 6053637.52 Zone- 4 21258'MD/3744'TVD • ADL 0391283,0388583,0388574,0388571,0388572 • TPI: x- 502601.79 y- 6058316.58 Zone- 4 • 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 495815.14 y- 6064908.93 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) N/A (ft MSL) 1948 MD/ 1747 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 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 36.85 3950 36.85 2443 16 10.7 ppg ASL: 578 bbls N/A 12.5 Doa LiteCRETE:67 bbls 9.625 40 L-80 35.53 • 11731 - 35.53 3745 " 12.25 12.5 ppg LiteCRETE:199 bbls N/A 4.5 11.6 L-80 14469 21230 3754 3744 8.75 Blank Liner with ICD's N/A 7 24.Open to production or injection? Yes Q No If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Blank liner with ICD's COI(P iii 4.5 14479 11337 MD/ 3721 TVD ill LICI - 2 1 2.30 ' li"b (olt3 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 375`-1- 3741 • 7 V1 y 'iliv 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 -.p-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 0. Sidewall Cores Acquired? Yes ❑ No CI • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS AUG - 8 2 Form 10-407 Revised 12/2009 C114 0 r//3 CONTINUED ON REVERSE I (b•13 Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? LJ Yes I No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. SV4 762 758 SV3 1150 1116 SV2 1454 1369 Permafrost-Base 1948 1747 SV1 2230 1930 Ugnu Top 2914 2252 UG-2 Coal Bed Marker 5406 2705 Lower Ugnu 8689 3299 Schrader Bluff Top 10062 3541 . N Sequence Top 10176 3562 N top 10440 3609 N bottom 10800 3659 N sequence Base 11176 3702 OA sand top 11880 3756 Formation at total depth: OA sand 21258 3744 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: James right . ! Title: Drilling and Completion Engineering Manager Signature. --7.11111W-", �( Phone Contact: (907)865-3338 Date: 8/5/2013 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 O C > O O N E •e�Ul zs M Z t V ED o N O V1� _ =in M N CI W 'p 4....~R EN Q : 5 a %— Q N H C O i N V C O 1.-- ° O g J el •c -,.0 a -NC �� C a3 O m a) o V N > o v Q maim, = M Aw m > _ C o 5 - B o c 2 v a c = ai v N . 2 O J C) (B CD d .� N ell a In co N U Cl) 0) .� Cl) Z c C 11111 * a x u x as at X J Y Y Y Y Y Y Y E a m m o- m a n. _ r X Y p .. N A L A ,A O J moms � fV fV . 'NJ W fV fV 0 u) a) Z > a m e4 m ' a) 4 a X ~ H I N Y c ', C CD V Q C) 'E Lo CO I -a X I� C N . = cr) M - a) O 0 Z _ 1 a ti N ,.... D e�i > c .3 M co ci> > 1 2 N _� (7) I— ca a `n M V 't cn L O) > to _ 4 ti C� In L ch Q M =CO � � N 0 . 000 _ p a _ o // � °) � o Q v" v) c Lc) N .N ♦. N N Q ' 4‘1% 0 r tp '" v Zr' m m CN N� c co 0 C '- Y r E ° .~-1 .N-1 .M-1 .a.1 .`-1 .4-1 .n-1 a Q O O N " u c e c c c c o cn Q D s M C e u u u u u u u N O a Q 0 N M N C 00 ! HH 27 tl. ..N- M .-1 N M a In .O N 03 O1 .( d � ap O Tr 01 d co w a x sc u u x at a x -Y I — M O Re n -' - 0 0 0 CI O G O 0 C 2 M M N u u u u u u U u u M N � Eni E&P Division Well Name:SI19-FN2 1 EN/Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUO • • APIIUW:50-629-23487-00-00 2^ Date:5/26/2013 - Report#: 1 �� I page 1 of 1 Wellbore name. SI19-FN2 Well Header Permit/Concession N° I Operator 'ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 5362 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(Er) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.0 -2.02 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ftJhr) POB Temperature(°F) Weather Wind 0.0 102.0 32,0 Cloudy,WC 21` SW @ 15 MPH Daily summary operation 24h Summary Slickline operations.RIH&retrieve Catch Basket.R/D Halliburton Slickline Equip.Well SI32 secure&Clean©08:30 Hrs.Verified W/Production Rep and Vetco Grey Rep.Freeze Protect well W/LRS with a total of 158 bbl Diesel in 9 5/8"X 4.5"IA 250 PSI @ 1.5 bpm.Begin rig down operations W/disconnect D.S&O.D.S suitcases.Move MP#3.Begin moving Mat Boards&remove ice from top of Herculite.Begin removing Herculite and ice below it.Begin clean up operation on Rock Washer side of dg with ACS Rep onsite.Work on disconnects and interconnects.Blow down Steam line in POs. Perform welding in the Pits and Rig Floor.Clean ice off Herculite.Pull out D.S.Suit Cases,remove Herculite and lay down new Herculite.Begin work on Beaver Slide door safety gate.Prep Rig Floor for skidding.Cont.clean up operations on Rock Washer side Mats as per ACS Rep.Lay new Herculite,begin spotting Mats.Work on hand rails for Rock Washer Roof.Skid Rig Floor.Cont.laying Mats. Cont.clean up operations. Raise Stompers,Cont.laying Mat Boards,work on interconnects.Work on Beaver slide Gate.Cont.clean up operations.P/U move Pits 7'to West.P/U Sub and move to SI19- FN2.Spot Sub moved 127'.Set down Stompers.Move Pits East for Rig Mats access,move Mats.Skid Rig Floor.Cont.moving Mats&prep for spotting Pits. Operation at 07.00 Move Rig over SI19-FN2. 24h Forecast Cont.spotting Rig over SI19-FN2.N/U Well Head and Stack. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Aet. Plan Oper.Descr. 06:00 08:30 2.50 2.50 MOB K 19 P PJSA Slickline operations.RIH&retrieve Catch Basket.R/D Halliburton Slickline Equip.Well SI32 secure&Clean @ 08:30 Hrs.Verified W/Production Rep and Vetco Grey Rep.Freeze Protect well W/LRS with a total of 158 bbl Diesel in 9 5/8"X 4.5"IA 250 PSI @ 1.5 bpm. 08:30 12:00 3.50 6.00 MOB A 2 P PJSA Begin rig down operations W/disconnect D.S&O.D.S suitcases.Move MP#3.Begin moving Mat Boards&remove ice from top of Herculite.Begin removing Herculite and ice below it.Begin clean up operation on Rock Washer side of rig with ACS Rep onsite.Work on disconnects and interconnects.Blow down Steam line in Pits.Perform welding in the Pits and Rig Floor. 12:00 16:00 4.00 10.00 MOB A 2 •P 'PJSA Clean ice off Herculite.Pull out D.S.Suit Cases,remove Herculite and lay down new Herculite.Begin work on Beaver Slide door safety gate.Prep Rig Floor for skidding.Cont.clean up operations on Rock Washer side Mats as per ACS Rep.Lay new Hematite,begin spotting Mats.Work on hand rails for Rock Washer Roof. • 16:00 17:00 1.00 11.00 MOB A 2 -P PJSA Skid Rig Floor.Cont.laying Mats.Cont.clean up operations. 17:00 20:00 3.00 14.00 MOB A 2 P PJSA Raise Stompers,Cont.laying Mat Boards,work on interconnects.Work on Beaver slide Gate.Cont.clean up operations.P/U move POs 7'to West. 20:00 21:30 1.50 15.50 MOB A 2 P -PJSA P/U Sub and move to SI19-FN2.Spot Sub moved 127'. 21:30 22:30 1.00 16.50 MOB A 2 'P PJSA Set down Stompers.Move Pits East for Rig Mats access,move Mats. 22:30 23:30 1.00 17.50 MOB A 2 'P PJSA Skid Rig Floor. 23:30 00:00 0.50 18.00 MOB A 2 P PJSA Cont.moving Mats&prep for spotting POs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnfling @enipetroleum.com 907-685-0715 715-6434 Em representative Oliver Amend ENI Drilling Supv. 907-685-0715 Em representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) ITV.(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division Well Name:SI19-FN2 10* ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • API/UWI:50-629-23487-00-00 2^n Date:5/27/2013 - Report#: 2 II 'I II page 1 of 1 Wellbore name: S)19-FN2 Well Header PermiVConcession N° I Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(tt) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) !RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.01 2,454.0 21,238.00 118.02 180.0 -1.02 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB_._ Temperature(°F) Weather Wind 0.0 104.0 32.0 Cloudy,WC 21° NE @ 14 MPH Daily summary operation 24h Summary Move Pits towards Sub Base.P/U M/U Diverter W/Crane.Cont.to work on Suit Cases.Work on interconnects on the Rig Floor.Move Pits away from Sub Base to finish installing Diverter line.De icing top and bottom of Mat Boards and Herculite. P/U Mat Boards on O.D.S.for ice removal. L/D Herculite for Rock Washer&Mat Boards.Load Well Head Equip.in BOP landing and Well Bay. N/U Starter Head.Surface Riser,Diverter Tee and Annular Preventer.Test connections to 500 PSI F/10 Min as per Vetco Grey Rep onsite.Finish Laying Mat Boards for MP#3 and Rock Washer.Spot MP#3 and work on berming.Test D.S.Suit Case lines W/air.Weld Diverter Tee.Spot Rock Washer.Load BHA in Pipe Shed.Cont.to work on berming.Work on spill cleanup from SI32-W2. Operation at 07.00 Cont.Rig up. 24h Forecast Finish R/U and inconnects.Clean up Mats F/SI32-W2 spill.Load Pipe shed W/5'D.P.Function test Annular Diverter and Knife Valve.P/U M/U 5'D.P.Take on Spud Mud.P/U M/U BHA#1. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur)hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 MOB A 2 P PJSA Move Pits towards Sub Base.P/U M/U Diverter W/Crane.Cont.to work on Suit Cases.Work on interconnects on the Rig Floor.Move Pits away from Sub Base to finish installing Diverter line.De icing top and bottom of Mat Boards and Herculite. 06:00 12:00 6.00 12.00 MOB A 2 P PJSA Cont.P/U M/U Diverter line.Spot Pits in place.P/U Mat Boards on O.D.S.for ice removal. 12.00 15:00 3.00 15.00 MOB A 2 P 'PJSA Cont.work on Diverter Line.C/O valves in Pits.Cont.work on Suit Cases.L/D Herculite for Rock Washer&Mat Boards.Load Well Head Equip.in BOP landing and Well Bay. 15.00 19:00 4.00 19.00'MOB C '20 P 'PJSA N/U Starter Head,Surface Riser,Diverter Tee and Annular Preventer.Test connections to 500 PSI F/10 Min as per Vetco Grey Rep onsite.Finish Laying Mat Boards for MP#3 and Rock Washer.Spot MP#3 and work on berming.Test D.S.Suit Case lines W/air. • 19:00 00.00 5.00 24.00 MOB C 20 'P PJSA Weld Diverter Tee,Spot Rock Washer.Load BHA in Pipe Shed.Cont.to work on berming.Work on spill cleanup from SI32-W2. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling @enipetroleum.com '907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) (TVD(ftKB) Fluid Type Fluid Density(Ib/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division 'Well Name:SI19-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUC • API/UWI:50-629-23487-00-00 2^ Date:5/28/2013 - Report#: 3 �' II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator I EM Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) ' -FrJ2 DRILLING 5/29/2013 3,982.0 2.454.01 21,238.00 118.02 180.0 -0.02 Daily Information End Depth(11KB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 104.0 32.0 Cloudy,WC 21' NE @ 16 MPH Daily summary operation 24h Summary Cont,cleanup on SI32-W2 W/ACS Rep onsite.Load 45 joints 5"D.P.in Pipe Shed.Finish Diverter Tee to Diverter Stack.Work on O.D.S.Suitcases.Bring up BHA 1&2 components to Rig Floor. P/U M/U 45 joints 5"D.P.and rack back in Derrick.Cont.work on O.D.S.Suitcases.Load Pipe Shed&M/U 13 3/8"Hanger on Landing Joint.P/U and make dummy run as per Vetco Grey Rep onsite. Load Pipe Shed W/5"HWDP.Work on O.D.S.Suitcases scarf ice and clear suit case zone. Work on Rock Washer Suitcases,interconnects and Berming.P/U M/U 14 joints 5"HWDP and rack back in Derrick.UD Mouse Hole and clear Rig Floor. P/U M/U 1 stand of 8"NMFDC and rack back in Derrick.Cont.work on Suitcases,Berming and load 13 3/8"Csg.in Pipe Shed.Service Top Drive, Drawworks,Blocks and Crown.Test Cement line&Rock Washer Suitcase lines.Took on 740 bbl 8.7 ppg 92 Vis Spud Mud F/Mud Plant @ 19:00 Hrs. Fill surface Equip.and check for leaks.P/U M/U BHA#1 as per Sclumberger DD Rep onsite.RIH and tag @ 62'MD.HST 82K,SLK 63K. Break Circ.close IBOP and PT mud lines to 3,000 PSI. Drain Stack below Knife valve and perform Diverter test. PSI before function 2,900 PSI,after function 1,800 PSI.200 PSI increase 35 Sec.total recharge 135 Sec.5 Nitrogen Bottles Average 2,350 PSI.Annular close 33 Sec.Knife Valve open 21 Sec.Diverter length 568'.Test waived by Louis Gimaldi on 5/28/13 05:32 Hrs. ✓ Operation at 07.00 Drill ahead F/161'MD. 24h Forecast Have pre Spud meeting with all essential personnel.Drill out 160'conductor,POOH and M/U BHA#2.Drill down to-230'POOH and P/U HWDP&Jars.Cont.dulling ahead as per Schlumberger MWD, DD and Gyro Data Rep onsite to TD @ 3,982'MD. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 I 4.00 MOB A 20 P PJSA Cont.cleanup on SI32-W2 W/ACS Rep onsite.Load 45 joints 5"D.P.in Pipe Shed.Finish Diverter Tee to Diverter Stack. 04:00 07:00 3.00' 7.00 MOB A 20 P -PJSA Work on O.D.S.Suitcases.Bring up BHA 1&2 components to Rig Floor. 07:00 08:30 1.50' 8.50 DRILL E 20 P PJSA P/U M/U 45 joints 5"D.P.and rack back in Derrick.Cont,work on O.D.S.Suitcases. 08:30 09:30 1.00 9.50 DRILL E 20 P -PJSA Load Pipe Shed&M/U 13 3/8"Hanger on Landing Joint.P/U and make dummy run as per Vetco Grey Rep onsite. 09:30 12:00 ' 2.50 12.00 DRILL E 20 'P 'PJSA Load Pipe Shed W/5"HWDP.Work on O.D.S.Suitcases scarf ice and clear suit case zone. 12:00 13:00 1.00 13.00 DRILL E 20 P 'PJSA Work on Rock Washer Suitcases,interconnects and Berming. 13:00 14:00 ' 1.00 14.00 DRILL E 20 'P -PJSA P/U M/U 14 joints 5"HWDP and rack back in Derrick. 14:00 14:30 ' 0.50 14.50 DRILL E 20 'P 'PJSA UD Mouse Hole and clear Rig Floor. 14:30 15:00 0.50 15.00 DRILL E 20 P PJSA P/U M/U 1 stand of 8"NMFDC and rack back in Derrick. 15:00 21:00 ' 6.00 21.00 DRILL E 20 P -PJSA Cont.wotk on Suitcases,Berming and load 13 3/8"Csg,in Pipe Shed.Service Top Drive,Drawworks,Blocks and Crown.Test Cement line&Rock Washer Suitcase lines.Took on 740 bbl 8.7 ppg 92 Vis Spud Mud F/Mud Plant @ 19:00 Hrs. 21:00 21:30 - 0.50 21.50 DRILL E 20 P PJSA Fill surface Equip,and check for leaks. 21:30 22:30 ' 1.00 22.50 DRILL E 20 P PJSA P/U M/U BHA#1 as per Sclumberger DD Rep onsite.RIH and tag @ 62'MD.HST 82K,SLK 63K. 22:30 23:00 ' 0.50 23.00 DRILL E 7 P 'PJSA Break Circ.close IBOP and PT mud lines to 3,000 PSI. 23:00 00:00 - 1.00 24.00 DRILL C 12 P PJSA Drain Stack below Knife valve and perform Diverter test.PSI before function 2,900 PSI,after function 1,800 PSI.200 PSI increase 35 Sec,total recharge 135 Sec.5 Nitrogen Bottles Average 2,350 PSI.Annular close 33 Sec.Knife Valve open 21 Sec.Diverter length 568'.Test waived by Louis Gimaldi on 5/28/13 05:32 Hrs. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipettoleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HOE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(MB) Run Date Last Leakoff Test Depth(ttKB) 'TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) 'P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division (Well Name:5119-FN2 fa* ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • APIIUWI:50-629-23487-00-00 2^r, Date:5/29/2013 - Report#: 4 I' II II page 1 of 1 Wellbore name: SI19-FN2 Well Header PermiVConcession N° (Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(tVhr) DES(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21.238.00 118.02 180.0 0.98 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 1,520.0 1,420.8 1.520.00 7.41 205,1 102.0 29.0 Scattered Clouds WC NW @ 6 MPH 23' Daily summary operation 24h Summary Pm Spud Meeting with all essential parties.Topics discussed as outlined in Well Plan. As per Schlumberger DD&MWD clean out conductor W/16"BHA#1 F/62'to 160'MD.HST 80K,SLK 81K,500 GPM,220 PSI,50 RPM As per Schlumberger DD,MWD&Gyro Data Rep onsite POOH F/160'P/U M/U second half of 16"BHA#1 to 124'MD.Perform shallow hole test as per Schlumberger OD, MWD&Gyro Data Rep onsite.650 GPM.Drill ahead 16"Surface F/160'to 310'MD.POOH as per Schlumberger DD F/310'MD&P/U M/U BHA#2.Drill ahead 16"Surface F/310'to 1,520'MD(1,407' ND)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.660 GPM,1,360 PSI,40 RPM,TQN 7-8K,TOF 3-4K,WOB 20-50K,HST 139K,SLK 121K.ROT 129K.ECD 10.23 ppg W.9.25 ppg MW.Max Gas 36 units.ADT 3.26 Hrs,TOT 2.91 Hrs,TRT.35 Hrs,Bit Hrs 7.41,JAR Hrs 7.41.Monitor wet,static. Operation at 07.00 Drill 16"Surface hole to 1,550'MD. 24h Forecast Due to 9 to 10 degree dog leg seen at 1,600'MD and falling behind from predicted line.POOH to 1,300'MD and try to regain directional work back to line.Cont.drilling ahead as per Well Program F/ 1,300'to 3,982'MD. Lithology 'Shows I MAASP Pressure(psi) Mud Weight(Ib/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P Pre Spud Meeting with all essential parties.Topics discussed as outlined in Well Plan. 00:30 01:30 1.00 1.50 DRILL E 3 P PJSA As per Schlumberger DD&MWD clean out conductor W/16"BHA#1 F/62'to 160'MD.HST 80K,SLK 81K,500 GPM,220 PSI,50 RPM 01:30 03:30 2.00 3.50 DRILL E 4 P PJSA As per Schlumberger DD,MWD&Gyro Data Rep onsite POOH F/160'P/U M/U second hat of 16"BHA#1 to 124' MD. 03:30 05:00 1.50 5.00 DRILL E 7 P PJSA Perform shallow hole test as per Schlumberger DD,MWD&Gyro Data Rep onsite.650 GPM. 05:00 07:00 2.00 7.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/160'to 310'MD as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.650 GPM,740 PSI.50 RPM,TQN 3K,TQF 2K,WOB 5-10K,HST 98K.SLK 99K,ROT 98K.ECD 9.7 ppg W.8.95 ppg MW. Max Gas 5 units.ADT.62 Hrs,TST.23 Hrs,TRT.39 Hrs,Bit Hrs.62,JAR Hrs.62.Monitor well,static. 07:00 08:00 1.00 8.00 DRILL E 4 P PJSA POOH as per Schlumberger DD F/310'MD&P/U M/U BHA#2. 08:00 12:00 4.00 12.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/310'to 496'MD(496'ND)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.650 GPM,840 PSI,40 RPM,TON 3K,TOP 3K,WOB 20-30K,HST 122K,SLK 120K,ROT 120K.ECD 9.68 ppg W. 8.95 ppg MW.Max Gas 4 units.ADT.71 Hrs,TST.56 Hrs,TRT.15 Hrs,Bit Hrs 1.33.JAR Hrs 1.33.Monitor well static. 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/496'to 994'MD(976'TVD)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.650 GPM,1,280 PSI,40 RPM,TON 8-10K,TQF 2-3K,WOB 20-40K,HST 130K,SLK 123K,ROT 127K.ECD 9.85 ppg W.9.3 ppg MW.Max Gas 25 units.ADT 2.82 Hrs,TST 2.53 Hrs,TRT.29 Hrs,Bit Hrs 4.15,JAR Hrs 4.15.Monitor well,static. 18.00 00:00 6.00 24.00 DRILL E 3 P +PJSA Drill ahead 16"Surface F/994'to 1,520'MD(1,407'ND)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.660 GPM,1,360 PSI,40 RPM,TON 7-8K,TOP 3-4K,WOB 20-50K,HST 139K,SLK 121K,ROT 129K.ECD 10.23 ppg W.9.25 ppg MW.Max Gas 36 units.ADT 3.26 Hrs,TST 2.91 Hrs,TRT.35 Hrs,Bit Hrs 7.41,JAR Hrs 7.41.Monitor well,static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Em representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Steve Milieu ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15@doyondrilling com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division 'Well Name:SI19-FN2 011* EN/Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • APIIUW1:50-629-23487-00-00 2^„I Date:5/30/2013 - Report#: 5 If 'I I page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° 'Operator I ENI Share(%( Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21,238.00 118.02 180.0 1.98 Daily Information End Depth(ftKB) End Depth(TVD)(t.. Depth Progress(ft) 'Drilling Hours(hr( Avg ROP(ft/hr) POB Temperature(°F) Weather Wed 3.109.0 2,299.8 1.589.00 10.71 146.4 105.0 31.0 Overcast WC 26" N©5 MPH Daily summary operation 24h Summary Pump out of hole as per Schlumberger DD&MWD F/1,522'to 1,300'MD&adjust tragectory due to dog leg.Drill ahead 16"Surface F/1,520'to 3,109'MD(2,299'TVD)as per Schlumberger DD,MWD, Gyro Data and K&M Rep onsite.745 GPM,1,800 PSI,40 RPM,TQN 8-9K,TQF 5K,WOB 20-40K.HST 175K,SLK 105K,ROT 129K.ECD 10.11 ppg W.9.3 ppg MW.Max Gas 515 units.ADT 10.71 Hrs.TST 8.55 Hrs,TRT 2.16 Hrs,Bit Hrs 18.12,JAR Hrs 18.12.Monitor well,static. Operation at 07.00 Drill 16"Surface hole to 3,448'MD. 24h Forecast Drill 16"Surface F/3,109'MD to estimated TD 3,982'as per Well Plan.At TD BROOH as per K&M BROOH schedule. Lithology Shows MAASP Pressure(psi) I Mud Weight(1b/gall 9.20 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 PJSA Pump out of hole as per Schlumberger DD&MWD F/1,522'to 1,300'MD&adjust tragectory due to dog leg.Drill ahead 16"Surface 1,520' 1,737 MD(1,589'TVD)as per Schlumberger DD,MWD,Gym Data and K&M Rep onsite.684 GPM,1.340 P51,40 RPM,TQN 5K,TQF 5K,WOB 20-40K,HST 150K,SLK 119K,ROT 131K.ECD 9.99 ppg W.9.2 ppg MW.Max Gas 55 units.ADT 1.69 Hrs,TST 1.51 Hrs,TRT.18 Hrs,Bit Hrs 9.10,JAR Hrs 9.10.Monitor well,static. 06.00 12.00 6.00 12.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/1,737'to 2,144'MD(1,879'TVD)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.601 GPM,1,120 PSI,40 RPM,TQN 8-10K,TQF 5-8K,WOB 15K,HST 150K,SLK 122K,ROT 136K.ECD 9.84 ppg W.9.2 ppg MW.Max Gas 269 units.ADT 2.68 Hrs,TST 2.29 Hrs,TRT.39 Hrs.Bit Hrs 11.78,JAR Hrs 11.78.Monitor well,static. 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/2,144'to 2,756'MD(2,197'TVD)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.750 GPM,1,910 PSI,40 RPM,TQN 9-10K,TQF 5-8K,WOB 20-40K,HST 152K,SLK 121K,ROT 136K.ECD 10.04 ppg W.9.25 ppg MW.Max Gas 515 units.ADT 3.36 Hrs,TST 2.59 Hrs,TRT.77 Hrs,Bit Hrs 15.14.JAR Hrs 15.14, Monitor well,static. 1800 00:00 6.00 24.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/2,756'to 3,109'MD(2,299'TVD)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.745 GPM,1,800 PSI,40 RPM,TON 8-9K,TQF 5K,WOB 20-40K,HST 175K,SLK 105K,ROT 129K.ECD 10.11 ppg W.9.3 ppg MW.Max Gas 212 units.ADT 2.98 Hrs,TOT 2.06 Hrs,TRT.92 Hrs,Bit Hrs 18.12,JAR Hrs 18.12. Monitor well,static. Daily Contacts Position Contact Name Company I Title E-mail Office Mobile Em representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Em representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon 15 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type I OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB( Run Date Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type (Fluid Density(Iblgal) IP Surf Applied(psi) Eq.Mud Weight(1b/gal) Leak Off Pressure(psi) �� Eni E&P Division 'Well Name: SI19-FN2 ENI Petroleum Co.Inc. Daily Repo..}` Well Code:27161 Field Name:NIKAITCHUQ • API/l1WI:50-629-23487-00-00 2^ Date:5/31/2013 - Report#: 6 II I� page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...IDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5I19-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21,238.00 118.02 180.0 2.98 Daily Information End Depth(ftKB) End Depth(TVD)(f..r Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB 'Wind Temperature(°F) Weather 3.960.0 2,445.3 851.00 4.59 185.4 108.0 34.0 Cloudy WC 26' I SSW @ 12 MPH Daily summary operation 24h Summary Drill ahead 16"Surface F/3,109'to 3,960'MD(2,445'TVD)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.625 GPM,2,460 PSI,60 RPM,TON 11-12K,TQF 8K,WOB 20-40K,HST 155K,SLK 105K,ROT 129K.ECD 10.0 ppg W.9.35 ppg MW.Max Gas 221 units.ADT 4.59 Hrs,TST 2.18 Hrs,TRT 2.41 Hrs,Bit Hrs 22.71 JAR Hrs 22.71.Monitor well,static.Well TD @ 08:43 Hrs. Shoot survey as per Schlumberger DD&MWD,send down link to Gyro tools for continuous survey mode as per Gyro Data Rep onsite.CBU as per K&M BROOH schedule F/3,960'to 3,762'MD 900 GPM,2,500 PSI,80 RPM,TRQ 8-9K,ECD 10.33 ppg W/9.3 ppg MW.Pumps on ROT WT 128K.BROOH as per K&M BROOH schedule F/3,109'to 252'MD 900 GPM,1,670 PSI,80 RPM,TRQ 3K, ROT 108K,ECD 10.57 ppg W/9.5 ppg MW.Max Gas 615 units.At 1,700'to 1,650'MD and @ 1,100'observed substantial hole unloading of clay and sand at the Shakers.Stand back 8"NM Flex Collars. L/D BHA#2 NM Stab,ARC,Power Pulse,Gyro Pulse 825,String Stab,Mud Motor&16"Milltooth Bit.Monitor well for 15 Min.,static.Clean and clear Rig Floor of BHA tools. Operation at 07.00 ' PJSM,prepare to start running 13 3/8"casing 24h Forecast Service Rig.R/U GBR Volant tools and Csg Equip.RIH 13 3/8"Csg.as per Tally and K&M RIH schedule.Circ.and condition Spud Mud to<20 YP.Perform Cement Job as per Schlumberger Rep onsite. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/3,109'to 3,592'MD(2,391'TVD)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.700 GPM,1,750 PSI,40 RPM,TON 11-12K,TQF 7-8K,WOB 20-40K,HST 155K,SLK 105K,ROT 130K.ECD 9.98 ppg W.9.35 ppg MW.Max Gas 160 units.ADT 2.72 Hrs,TST 1.79 Hrs,TRT.93 Hrs,Bit Hrs 20.84,JAR Hrs 20.84. Monitor well,static. 0600 09:00 3.00 9.00 DRILL E 3 P PJSA Drill ahead 16"Surface F/3,592'to 3,960'MD(2,445'ND)as per Schlumberger DD,MWD,Gyro Data and K&M Rep onsite.825 GPM,2,460 PSI,60 RPM,TON 11-12K,TQF 8K,WOB 20-40K,HST 155K,SLK 105K,ROT 129K.ECD 10.0 ppg W.9.35 ppg MW.Max Gas 221 units.ADT 1.87 Hrs,TST.39 Hrs,TRT 1.48 Hrs,Bit Hrs 22.71 JAR Hrs 22.71. Monitor well,static.Well TD @ 08:43 Hrs. 09.00 09.30 0.50- 9.50 DRILL E 11 P PJSA Shoot survey as per Schlumberger DD&MWD,send down link to Gyro tools for continuous survey mode as per 1 Gyro Data Rep onsite. 09.30 11:00 1.50 11.00 DRILL E 6 P PJSA CBU as per K&M BROOH schedule F/3,960'to 3,762'MD 900 GPM,2,500 PSI,80 RPM,TRO 8-9K,ECD 10.33 ppg W/9.3 ppg MW.Pumps on ROT WT 128K. 11 00 1700 1.00 12.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/3,762'to 3,109'MD 900 GPM,2,440 PSI.80 RPM,TRQ 8-9K,ECD 10.64 ppg W/9.35 ppg MW. 1200 18 30 7.50 19.50 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/3,109'to 252'MD 900 GPM.1,670 PSI,80 RPM,TRQ 3K,ROT 108K, ECD 10.57 ppg W/9.5 ppg MW.Max Gas 615 units.At 1,700'to 1,650'MD and @ 1,100'observed substantial hole unloading of clay and sand at the Shakers. 19.30 23-.30 4.00 23.50 DRILL E 4 P PJSA Stand back 8"NM Flex Collars.UD BHA#2 NM Stab,ARC,Power Pulse.Gyro Pulse 825,String Stab,Mud Motor& 16"Milltooth Bit.Monitor well for 15 Min.,static. 23:30 00.00 0.50 24.00 DRILL E 20 -P PJSA Clean and clear Rig Floor of BHA tools. Daily Contacts Position Contact Name Company Title Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv °SIDDrilling @enipetroleum.com -907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Torn Klein ENI Maas Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 3.950.0 6/1/2013 Last Leakoff Test Depth(11KB) TVD(ftKB) Fluid Type 'Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) Eni E&P Division I Well Name:SI19-FN2 PI* ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUO • API/UWI:50-629-23487-00-00 2 Date:6/1/2013 - Report#: 7 II II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21,238.00 118.02 180.0 3.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) (Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather [Wind 3,960.0 2,445.3 0.00 105.0 37.0 Clear WC 32' IESE @ 7 MPH Daily summary operation 24h Summary Finish clean and clear Rig Floor of 5"D.P.handling Equip.&Surface BHA components.Service Rig,Top Drive,Drawworks and Traveling Equip. R/U Volant Tool Csg.Equip.Remove drilling bails and link clamps.Install Csg.bails and tilt clamps.M/U Volant Csg.running tool as per Volant Rep onsite.Install link extensions and 13.375"100 Ton side door elevators.P/U M/U Shoe Track&Float Collar 13.375"688 L-80 BTC F/Pipe Shed to 158'MD.Baker Loc Shoe Track.Ran 2 Centralizers on Shoe joint and 1 above Float Collar as per Well Plan.Attempt to adjust links due to inability to release Volant tool F/stump.Wait on 250 Ton 13.375"side door elevators.Service Rig,grease crown and all handling Equip.Complete work orders.Install 250 Ton side door elevators.Cont.to RIH W/13.375" Csg.as per tally F/158'to 3,901'MD.SLK 170K Check Float Collar.Install Centralizers as per tally running order.Seen minor losses,slowed down running speed to control losses.Lost 27 bbls to formation.Filling every joint and topping of every 10 joints.P/U M/U Landing Joint and Hanger as per Vetco Grey Rep and use GBR power tongs W/GBR Rep onsite.Break Circ.@ 1 bpm 110 PSI, stage up to 2 bpm 80 PSI.No losses,wash down and set Hanger.Casing Shoe @ 3,944'MD SLK 170K.Stage up pumps to 5 bpm with no losses while conditioning mud as per MI Swaco plan forward for cement job.Circ.2X BU 130 PSI.SIMOPS L/D GBR Csg.Equip.as per GBR Rep onsite. Operation at 07.00 Perform cement job. 24h Forecast Condition mud as per MI Swaco plan forward for cement job.Perform cement job as per Schlumberger Cementers onsite.Clean all surface Equip.of cement.N/D Diverter Stack. Lithology [Shows I MAASP Pressure(psi) Mud Weight(Ib/gal) 9.50 Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL E 20 'P 'PJSA Finish clean and clear Rig Floor of 5"D.P.handling Equip.&Surface BHA components. 00.30 01 30 1.00 1.50 DRILL E 20 P Service Rig,Top Drive,Drawworks and Traveling Equip. 01 30 04:30 3.00 4.50 DRILL G 20 'P PJSA R/U Volant Tool Csg.Equip.Remove drilling bails and link clamps.Install Csg.bails and tilt clamps.M/U Volant Csg. running tool as per Volant Rep onsite.Install link extentions and 13.375"100 Ton side door elevators.-04.30 08-.30 4.00 8.50 DRILL G 4 P 'PJSA P/U M/U Shoe Track&Float Collar 13.375"688 L-80 BTC F/Pipe Shed to 158'MD.Baker Loc Shoe Track.Ran 2 Centralizers on Shoe joint and 1 above Float Collar as per Well Plan.Attempt to adjust links due to inability to release Volant tool F/stump. 08.30 10.00 1.50 10.00 DRILL G 20 P Wait on 250 Ton 13.375"side door elevators.Service Rig,grease crown and all handling Equip.Complete work orders. 10.00 12.30 2.50 12.50 DRILL G 4 P 'PJSA Install 250 Ton side door elevators.Cont.to RIH W/13.375"Csg.as per tally F/158'to 391'MD.Check Float Collar. Install Centralizers as per tally running order.Seen minor losses,slowed down running speed to control losses.Lost 10 bbls to formation.Filling every joint and topping of every 10 joints. 130 21 30 ' 9.00 21.50 DRILL G 4 " 2. P PJSA RIH W/13.375"Csg W/Valont running tool F/391'_to 3,910'MD filling every joint and topping every 10 joints.SLK 170K.Total lost 17 bbl. 2130 2200 0.50 22.00 DRILL G 4 'P -PJSA P/U M/U Landing Joint and Hanger as per Vetco Grey Rep and use GBR power tongs W/GBR Rep onsite.Break Circ.@ 1 bpm 110 PSI,stage up to 2 bpm 80 PSI.No losses,wash down and set Hanger.Casing Shoe @ 3,950'MD SLK 170K.•22:00 00.30 2.50 24.50 DRILL G 8 'P "PJSA Stage up pumps to 5 bpm with no losses while conditioning mud as per MI Swaco plan forward for cement job.Circ. 2X BU 130 PSI.SIMOPS L/D GBR Csg.Equip.as per GBR Rep onsite. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDriting @enipetrokum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Mods Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 3.950.0 6/1/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) ft* Eni E&P Division Well Name:S119-FN2 ENI Petroleum Co.Inc. Daily Report l Well Code:27161 Field Name:NIKAITCHUO • API/UWI:50-629-23487-00-00 2^n Date:6/2/2013 - Report#: 8 II fl II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 ILAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) 'DFS(days) SI19-FN2 DRILLING 5/29/2013 I 3,982.01 2.454.0 21,238.00 118.02 180.0 4.98 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,960.0 2,445.3 0.00 105.0 41.0 Clear WC 36' SW @ 7 MPH Daily summary operation 24h Summary Circulate and condition Spud Mud to<20 YP as per MI Swaco plan forward @ 5 bpm 160 PSI.Break down Top Drive for cement job.Close upper and lower'BOP,R/U Cement Line and manifold.PJSM W/all essential personnel.Shut down rig pumps and Schlumberger pumped S bbls.H2O to fill lines and tested lines t/700psi.low&3,000 PSI high,good.Pump 2 bbl H2O to clear line.Switched back rig pumping 100 bbls.of 10.1 ppg Mud Push II rate of 5 bpm @ 130 psi.Shut-down&release from Volant tool and drop bottom plug.Set Volant tool,SLB mix&pump Lead slurry 578 bbls.10.7 ppg Lead Slurry pump rate of 5 bpm @ 157 psi.SLB mix and pump 67 bbls 12.5 ppg Tail Slurry pump rate of 5.0 bpm @ 304 psi.Shut down release Volant tool&drop top plug.Set Volant tool,SLB pump 10 bbls H2O and wash up.Displace with 562.4 bbls 9.4 ppg treated mud with rig pump at 4.5 bpm w l 300 psi,slow to 3 bpm at 300 bbl away,FCP 530 psi.,Bump Plug PSI up to 1000 psi held 5 Min.Bleed off floats holding Cement in place @ 09:30 hrs.242 bbls cement to surface.R/D Cement Lines&manifold.Release F/Volant tool,break out of Landing Joint and L/D.Set Volant tool in cradle,break from Top Drive and L/D.Remove Csg.Bails and Link Tilt Clamps.Install drilling Bails and Link Tilt Clamps. R/U Bails,flush and rinse Stack.P/U stand and M/U Johnny Whacker&wash F/90'to upper riser W/90 bbl Contam Pill @ 8 bpm,170 PSI 90 RPM.L/D Johnny Whacker&clean Drip Pan. Remove Diverter line F/Tee,N/D upper riser,surface stack,lower riser and Starter Head.Clean up as per Vetco Grey Rep onsite.SIMOPS begin cleaning Pits and haul off surface mud.Load 252 joints of 5"D.P.into Pipe Shed. N/U and orientate Multi Bowl as per Vetco Grey Rep onsite. N/U high Press. drilling riser.N/U BOPE, Operation at 07.00 P/U M/U 5"D.P.and stand back in Derrick. 24h Forecast P/U M/U 252 Joints 5"D.P.and stand back in Derrick.Test BOPE as per AOGCC.P/U M/U BHA#3. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.50 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 H 8 P PJSA Circulate and condition Spud Mud to<20 YP as per MI Swaco plan forward @ 5 bpm 160 PSI. 02:00 02:30 0.50 2.50 DRILL H 20 P PJSA Break down Top Drive for cement job.Cloae upper and lower'BOP.R/U Cement Line and manifold. SW! 02:30 09:30 7.00 9.50 DRILL H 9 P PJSM W/all essential personnel.Shut down rig pumps and Schlumberger pumped 8 bbls.H2O to fill lines and tested lines t/700psi.low&3,000 PSI high,good.Pump 2 bbl H2O to clear line.Switched back rig pumping 100 bbls.of 10.1 ppg Mud l'A:-C- Push II rate of 5 bpm @ 130 psi.Shut-down&release from Volant tool and drop bottom plug.Set Volant tool,SLB mix& C., pump Lead slgrry 578 bbls.10.7 ppg Lead Slurry pump rate of 5 bpm @.157 psi.SLB mix and pump 67 bbls 12.5 ppg Tad Slurry pump rate of 5.0 bpm @ 304 psi.Shut down release Volant tool&drop top plug.Set Volant tool,SLB pump 10 bbls H2O and wash up.Displace with 562.4 bbls 9.4 ppg treated mud with rig pump at 4.5 bpm W 300 psi,slow to 3 bpm at 300 bbl away,FCP 530 psi.,Bump Plug PSI up to 1000 psi held 5 Min.Bleed off floats holding Cement in place @ 09:30 hrs. 242 bbls cement to surface. 0930 12-.00 2.50 12.00 DRILL H 20 P PJSA R/D Cement Lines&manifold.Release F/Volant tool,break out of Landing Joint and LID.Set Volant tool in cradle. break from Top Drive and L/D.Remove Csg.Bails and Link Tilt Clamps.Install drilling Bails and Link Tilt Clamps. 1200 15.00 3.00 15.00 DRILL H 20 P PJSA R/U Bails,flush and rinse Stack.P/U stand and M/U Johnny Whacker&wash F/90'to upper riser W/90 bbl Contam Pill @ 8 bpm,170 PSI 90 RPM.L/D Johnny Whacker&clean Drip Pan. 15.00 19.00 4.00 19.00 DRILL C 20 P PJSA Remove Diverter line F/Tee,N/D upper riser,surface stack,lower riser and Starter Head.Clean up as per Vetco Grey Rep onsite.SIMOPS begin cleaning Pits and haul off surface mud.Load 252 joints of 5"D.P.into Pipe Shed. 1900 20.30 1.50 20.50 DRILL C 20 P PJSA N/U and orientate Multi Bowl as per Vetco Grey Rep onsite.Test seals between Hanger and Well Head to 5,000 PSI F/10 Min.witnessed by Company Rep onsite.RKB to top flange 31.34'.Cont.cleaning Pits. 20:30 00:00 3.50 24.00 DRILL C '20 P PJSA N/U high Press.drilling riser,N/U BOPE,install Bell Nipple and Flow Line.R/U Kill Line and Choke Line.Install secondary valves on IA&OA.Cont.cleaning Pits. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @ enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson •Doyon Dolling Tool Pusher rig15 @doyondolling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 3.950.0 6/1/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) 'Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division !Well Name:S119-FN2 fli* EN!Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUO • APIIUWI:50-629-23487-00-00 2^ Date:6/3/2013 - Report#: 9 II I' page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° I Operator ENI Share(%) 1Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2454.0 21,238.00 118.02 180.01 5.98 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,960.0 2,445.31 0.001 106.0 25.0 Overcast WC 13" IENE @ 14 MPH Daily summary operation 24h Summary Clean and clear rig floor of all nonessential tools and Equip.C/O Saver Sub to new TT525.Tap threads on Grab Head retainer bolt holes and C/O bolts.SIMOPS Clean Pits.P/U Mouse Hole and install in Rotary Table.LJD 4 stands of 5"HWDP to Pipe Shed. P/U&drift 252 joints 5"D.P.F/Pipe Shed via Mouse Hole and stand back in Derrick.Clean and clear rig floor and L/D Mouse Hole. Set test plug as per Vetco Grey Rep onsite.R/U test Equip.Fill stack and purge air.Perform BOPE test.Test waived by Bob Noble of AOGCC @ 05:00.6-3-13.Pull test plug&install Wear Ring as per Vetco Grey Rep ensile.Wear Ring length 53.31",13.438"OD,12.31"ID.SIMOPS R/D test Equip.R/U and test 13 3/8"Csg.to 2,500 PSI for 30 Min.on chart witnessed by company Rep.(Good)RID test equip. Clear and clean rig floor.P/U items for dumb iron run BHA#3. Operation at 07.00 P/U BHA#3 24h Forecast Service Rig and Cut and slip drilling line.P/U M/U 12.25"Bit BHA#3.RIH to top of cement and wait for bridge out or helicopter operations.Drill out Shoe Track and 20'of new hole to 3,980'MD.Displace Spud Mud W/new 9.3 ppg LSND.Clean surface Equip.Perform FIT to 13 ppg to LOT minimum 11 ppg.POOH and P/U M/U BHA#4 W/smart tools. 'Lithology Shows MAASP Pressure(psi) !Mud Weight(Iblgal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P PJSA Clean and clear rig floor of all nonessential tools and Equip. 00:30 03:00 2.50 3.00 DRILL E 20 P PJSA 0/0 Saver Sub to new TT525.Tap threads on Grab Head retainer bolt holes and C/O bolts.SIMOPS Clean Pits. 03:00 04:00 1.00 4.00 DRILL E 20 P PJSA P/U Mouse Hole and install in Rotary Table.LJD 4 stands of 5"HWDP to Pipe Shed. 04:00 12:00 ' 8.00 12.00 DRILL E 20 P PJSA P/U&drift 204 joints 5"D.P.F/Pipe Shed via Mouse Hole and stand back in Derrick.SIMOPS Clean Pits. 12:00 13:00 1.00' 13.00 DRILL 'E 20 P PJSA P/U&drift 48 joints.252 total joints 5"D.P.F/Pipe Shed via Mouse Hole and stand back in Derrick.SIMOPS Clean Pits, 13:00 13:30 0.50 13.50 DRILL E 20 P PJSA Clean and clear rig floor and L/D Mouse Hole. 13:30 14:30 1.00 14.50 DRILL C 20 P PJSA Set test plug as per Vetco Grey Rep onsite.R/U test Equip.Fill stack and purge air. 14.30 21:00 6.50 21.00 DRILL C 12 P PJSA Test Annulus Preventer W/5"test joint to 250 PSI low and 2,500 PSI high for 5 Min.Test Upper 3.5"X 6"VBR& Lower 4.5"X 7"VBR WI 5"test joint,Choke valves 1-18,upper and lower IBOP,Manual Choke&Kill,Choke&Kill HCR's, Kill Line Demco,TT525 Dart and TIW,NC50 Dart and TIW&Blind Rams to 250 PSI low and 3,500 PSI high.Test Super- I LS Choke.A&B manual Chokes to 1,500 PSI.Volume check Poor Boy.(Good)Perform Koomey draw down test,start 2,950 PSI,PSI after function 1,450 PSI.200 PSO increase 43 Sec.Total recharge 203 Sec.5 Nitrogen bottles average 2,350 PSI.Test waived by Bob Noble of AOGCC @ 05:00,6-3-13.Test PVT alarms,calibrate LEL&H2S Gas detectors.Took on 700 bbl 9.3 ppg 54 Vis LSND to Mud Pits @ 16:00. 21:00 22:00 1.00" 22.00 DRILL C 20 P PJSA Pull test plug&install Wear Ring as per Vetco Grey Rep onsite.Wear Ring length 53.31".13.438"OD,12.31"ID. SIMOPS R/D test Equip. 22:00 23:30 1.50' 23.50 DRILL E 12 P PJSA R/U and test 13 3/8"Csg.to 2,500 PSI for 30 Min.on chart witnessed by company Rep.(Good)R/D test equip. 23.30 00:00 0.50' 24.00 DRILL E 20 P PJSA Clear and clean rig floor.P/U items for dumb iron run BHA#3. 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 Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 3,950.0 6/1/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) 1Fluid Type l Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,950.0 2,443.60 spud 9.30 440.0 12.77 1,620.5 Ili* Eni E&P Division .} I Well Name:Sl19-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUO • API/UWI:50-629-23487-00-00 eno Date:6/4/2013 - Report#: 10 II 'I page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share)%) I Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI19-FN2 DRILLING 5/29/2013 3,982.0 2454.0 21,238.00 118.02 180.0 6.98 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,960.0 2,445.3 0.00 104.0 25.0 Overcast WC 12° ENE @ 16 MPH Daily summary operation 24h Summary Service rig.Drill shoe track and 20'of new hole.Displace well to 9.25 ppg LSND Mud.Perform FIT Test to 13.0 ppg.POOH LD BHA#3 and MU BHA#4 and perform shallow hole test. Operation at 07.00 Drill ahead in 12.25"intermediate hole @ 4,072'MD. 24h Forecast RIH w/BHA#4 to 3980'and set drilling parameters.Drill ahead in 12.25"intermediate hole as per SLB DD and Geologist. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 25 P PJSA cut and slip 94'of drlg.line,adjust brakes,MP2 on drawvorks and calibrate block height. 02:00 03:00 1.00 3.00 DRILL E 25 P Lubricate rig. 03:00 04:00 1.00 4.00 DRILL E 4 P PJSA P/U&M/U BHA#3 and RIH to 195'. 04 f00 0730 3.50 7.50 DRILL E 4 P PJSA RIH f/195'-3744'filling pipe every 1500'.Wash down to top of plug @ 3865'.125k puw,98k sow. 07:30 08:15 0.75 8.25 DRILL E 7 'P CBU @ 3858'390 gpm,420 psi. 0815 11:00 2.75 11.00 DRILL E 3 P Drill shoe track 6 3868'-3950'@ 600 gpm,840 psi,70 rpm,8-10k tq,14k wob.Drill rat hole to 3980'@ 700 gpm,970 psi, 80 rpm,-12k tq,10k wob,125k puw,98k sow.125k rotw,.1 ADT. 11:00 1230 1.50 12.50 DRILL E 7 -P CBU @ 700 gpm.970 psi,80 rpm,8-12k tq,125k puw,99k sow.112k rotw. 12:30 14:00 1.50 14.00 DRILL E 7 P PJSA Pump 50 bbl hi-vis water @ 6 bpm,260 psi followed w/580 bbls 9.25 ppg LSND mud @ 12 bpm,400 psi,80 rpm,6k tq,142k puw,110k sow,127k rotw.POOH to 3930'and monitor well. 14:00 14:30 0.50 14.50 DRILL E 20 P PJSA Blow down top-drive and clean surface equipment. 14.30 1530 1.00 15.50 DRILL E 11 P PJSA RU and perform FIT test to 13.0 ppg.BD lines. 15:30 18:00 2.50 18.00 DRILL E 4 P PJSA POOH f/3930'-3463',pump dry job and blow down top-drive.POOH 6 3463'-195'. 18:00 19:00 1.00 19.00 DRILL E 4 -P PJSA Monitor well and LD BHA#3 as per SLB DD. 19:00 20:00 1.00 20.00 DRILL E 20 P PJSA Clear rig floor of old BHA and load new BHA. 20:00 23:00 3.00 23.00 DRILL E 4 'P PJSA P/U&M/U BHA#4 as per SLB DD&RIH to 254'.Change out Jars-leaking. 23:00 00:00 1.00 24.00 DRILL E 4 P RIH to 1183'.Perform shallow hole test @ 600 gpm,610 psi as per SLB. 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 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5 @enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HOE 907-685-0721 907-:398-8770 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 3,950.0 6/1/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(Iblgal) P Surf Applied(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,950.0 2,443.60 spud 9.30 440.0 12.77 1,620.5 f Eni E&P Division (Well Name:5119-FN2 ENI Petroleum Co.Inc. Daily Report 'Well Code:27161 Field Name: NIKAITCHUQ 2�,r, Date:6/5/2013 - Report#: 11 API/UWI:50-629-23487-00-00 '( II II page 1 of 1 Wellbore name: S)19-FN2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) (Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 36,83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) 5119-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.0 7.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather I Wind 6,650.0 2,924.7 2,670.00 12.84 207.9 104.0 28.0 Overcast WC 19' E @ 9 MPH Daily summary operation 24h Summary RIH to 3897'and wash down to 3980'.Drill ahead to 6650'@ 900 gpm 120-190 rpm. Operation at 07.00 Drilling ahead at 6,882'MD. 24h Forecast Dug ahead as per SLB to a casing depth of 11,745'. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03:00 3.00 3.00 DRILL E -4 P PJSA RIH f/1183'-389T.Wash down to 3980'@ 650 gpm,790 psi,100 rpm,5-10k tq,138k puw,112k sow,125k rotw. 03.00 06:00 3.00 6.00 DRILL E 3 P PJSA Ddg.f/3980'-4361'(2517 ND),900 gpm,1330 psi,160 rpm.9k tqn.6k tqf,6-10k wob,140k puw,112k sow,125k rotw,9.8 ECD,26 Max Gas,1.3 ADT. 06.00 12:00 6.00 12.00 DRILL E .3 P DrIg.f/4361'-5109'(2651'ND),900 gpm,1500 psi,160 rpm,10-12 tqn,8k tqf,10k wob,160k puw,100k sow,130k rotw, 10.02 ECD,200 Max Gas,2.83 ADT,4.13134/Jars. 12:00 18:00 6.00 18.00 DRILL E -3 P DrIg.f/5109'-5762'(2770'ND),900 gpm,1610 psi,140-180 rpm,10-14k tqn,9k tqf,2-12k wob,165k puw.103k sow, 130k rotw,9.99 ECD,96 Max Gas,5.18 ADT,9.31 Bit/Jars. 18.00 00:00 6.00 24.00 DRILL 0 '3 P Ddg.f/5762'-6650'(2926'ND)@ 900 gpm,1830 psi,120-190 rpm,11-14k tqn,7-8k tqf,2-12k wob,168k puw,108k sow.136k rotw,10.32 ECD,33 Max Gas,3.53 ADT,12.84 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone 'ENI 'Project Manager • ° Eni representative Nelson Carballo ENI Dilling Superintenda Eni representative Lara Occhionero ENI Drilling Engineer Eni representative Mike Ross ENI 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 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com .907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Dolling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 3,950.0 6/1/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,950.0 2,443.60 spud 9.30 440.0 12.77 1620.5 Eni E&P Division I Well Name:SI19-FN2 11* EN!Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • API/UWI:50-629-23487-00-00 2^n Date:616/2013 - Report#: 12 I' II I' page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(11KB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.0 8.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) IPOB Temperature(°F) Weather Wind 9,027.0 3,356.2 2.377.00 15.71 151.3 105.0 28.0 Overcast WC 18" E @ 12 MPH Daily summary operation 24h Summary Drill(16650i-9027'(3357'ND)@ 900 gpm,2220 psi,120-190 rpm. Operation at 07.00 Drilling ahead at 9,441'MD 24h Forecast Drill intermediate hole to est.TD 11,724'. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg.5 6650'-7117'(3004'ND)@ 904 gpm,1930 psi.190 rpm,12-14k tqn.5-9k tqf,10-12k wob,172k puw,108k sow.138k rotw,10.37 ECD,19 Max Gas,4.12 ADT. 06:00 12:00 6.00 12.00 DRILL E 3 P Ddg.f/7117'-7630'(3101'ND)@ 904 gpm,1920 psi.190 rpm.10-12k tqn,8-10k tqf,8-10k wob,168k puw.102k sow. 139k rotw,10.23 ECD.19 Max Gas,3.18 ADT,20.14 Bit/Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P Ddg.f/7630'-8380'(3245'ND)@ 900 gpm,2140 psi,120-190 rpm.11-12k tqn,8-9k tqf,4-12k wob,179k puw.110k sow,144k rotw,10.23 ECD,34 Max Gas,4.31 ADT,24.45 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P 'Ddg.f/8380'-9027'(3357'ND)@ 900 gpm,2220 psi,120-190 rpm,14-15k tqn.8-9k tqf,4-12k wob,181k puw,108k sow.145k rotw,10.09 ECD,49 Max Gas,4.1 ADT,28.55 Bit/Jars. SPR @ 8563'(2978'ND)w/9.25 MW#2 @ 30-270,@ 40-310,#3 @ 30-270,@ 40-310. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone ENI Project Manager Eni representative Nelson Carballo ENI Dilling Superintenda Eni representative Lara Occhionero ENI Drilling Engineer Eni representative Mike Ross ENI Senior Dolling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15 @doyondnlhng.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0' 3,950.0 6/1/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,950.0 2.443.60 spud 9.30 440.0 12.77 1,620.5 Eni E&P Division Well Name: St19-FN2 EN!Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • APIIUWI:50-629-23487-00-00 2�, Date:6/7/2013 - Report#: 13 II II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° !Operator ENI Share(%) !Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL ' Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 ILAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) !Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fflhr) IDFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21,238.00 118.02 180.0 9.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather !Wind 11,746.0 3,746.1 2.719.00 12.20 222.9 103.0 30.0,Freezing Fog WC 21'IENE @ 10 MPH Daily summary operation 24h Summary Drill ahead f/9027'-11,746'TD pick per Geologist. Operation at 07.00 Backream out of hole. 24h Forecast Perform cleanup cycle per KOM and backream out of hole. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log ' Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00- 6.00'DRILL E 3 P PJSA DrIg.f/9027'-9778'(3483'TVD)@ 907 gpm.2200 psi,190 rpm,13k tqn,8k tqf,8-12k wob.188k puw,116k sow, 148k rotes 10.22 ECD,32 Max Gas,4.01 ADT,32.56 Bit/Jars.SPR @ 9778'(3483'TVD)w/9.25 MW:#2 @ 30-280,@ 40-320.#3 @ 30-280,@ 40-320. 06.00 12:00 6.00' 12.00'DRILL E 3 P Ddg.f/9778'-10,244'(3575'TVD)@ 905 gpm,2500 psi,13k tqn.9k tqf.10-12k vob.182k puw,110k sow.149k rotw. 10.25 ECD,232 Max Gas,2.1 ADT,34.66 Bit/Jars. 12:00 '18:00 6.00 18.00'DRILL E 3 P Ddg.f/10,244'-10,897',(3670'ND)@ 900 gpm,2730 psi,160 rpm,14k tqn,8-9k lqt,10-12k wob,182k puw,114k sow. 150k rotw,10.6 ECD,1051 Max Gas,2.66 ADT,37.32 Bit/Jars. 18:00 00:00 6.00 24.00'DRILL E 3 P Ddg.f/10,897'-11,746'(3745'ND)@ 900 gpm,2860 psi,160-190 rpm,16k tqn,10k tqf.10-16k wob,189k puw,108k sow,150k rotw,10.78 ECD,1080 Max Gas,3.43 ADT,40.75 Bit/Jars.Monitor well-static. 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 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon l 5 @enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 3,950.0 6/1/2013 Last Leakoff Test Depth(f1KB) •ND(ftKB) Fluid Type I Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,950.0 2,443.60 spud 9.301 440.0 12.77 1.620.5 Eni E&P Division 'Well Name:S119-FN2 If ff#1 EN!Petroleum Co.Inc. Daily Report 'Well Code:27161 Field Name:NIKAITCHUO • APIIUWI:50-629-23487-00-00 2^n Date:6/8/2013 - Report#: 14 II II II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) rater Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 36.83 40.5511 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 (LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2,454.01 21,238.00 118.02 180.0 10.98 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11.746.0 3,746.1 0.00 108.0 38.0 Overcast WC 34` E @ 6 MPH Daily summary operation 24h Summary Perform K&M cleanup cycle and BROOH. Operation at 07.00 BROOH,at 3,600'MD 24h Forecast BROOH to 1200'then circ.hole clean.POOH on elevators and LD BHA. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 940 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 19 P PJSA SLB shoot survey and down link. 00:30 01:30 1.00 1.50 DRILL E 4 P CBU while POOH f/11746'-11,647'@ 900 gpm,2860 psi,120 rpm,12k tq,10,63 ECD,141k rotw,102 Max Gas.SPR @ 11,746'(3745'TVD)w/9.45 MW;#2 @ 30-370,@ 40-420,#3 @ 30-370,@ 40-420. 01:30 06:00 4.50' 6.00 DRILL E 4 P PJSA BROOH as per K&M schedule f/11.647'-10,620'@ 900 gpm,2620 psi,120 rpm,10-12k tq.10.63 ECD,140k rotw. 42 Max Gas. 06:00 12:00 6.00' 12.00 DRILL E 4 P BROOH f/10,620'-8753'@ 900 gpm.2530 psi,120 rpm,11-13k tq,10.51 ECD.137k rotw,35 Max Gas. 12:00 18:00 6.00- 18.00 DRILL E 4 P BROOH f/8753'-6045'@ 900 gpm.2100 psi,120 rpm,8-9k tq,128k rotw. 18:00 00:00 6.00 24.00 DRILL E 4 P BROOH 1/6045'-4550'@ 900 gpm,2000 psi,120 rpm,8-15k tq,122k rotw.Tourly fluid losses of 18 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDnlling @enipetroleum.com '907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling @enipetroleum,com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type __ OD(in) ID(in) _ Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 3,950.0 6/1/2013 Last Leakoff Test Depth(6KB) ITVD(ftKB) Fluid Type 'Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 3,950.0 2,443.60 spud 9.30 440.0 12.77 1,620.5 iEni E&P Division } I Well Name:SI19-FN2 I EN!Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUO • API/Mgt 50-629-23487-00-00 2^ Date:6/9/2013 - Report#: 15 _ �' II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° 'Operator ENI Share)%) /Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDES(days) 0119-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21.238.00 118.02 180.0 11.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11,746.0 3,746.1 0.00 108.0 37.0 Cloudy/Rain WC WSW @ 15 MPH 28- Daily summary operation 24h Summary POOH and L/D BHA#4.C/O Upper rams to 9 5/8"and test.R/U Tesco casing running system and M/U and RIH w/9 5/8"4014 L-80 Hydril 563 casing. Operation at 07.00 M/U and RIH wl 9 5/8"casing at 4,871'MD 24h Forecast M/U and run 9 5/8"casing to 11,731'.R/U and fill 9 5/8"casing w/LSND mud as per schedule. _ Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL E 4 P 'PJSA BROOH f/4550'-1188'@ 900 gpm,1410 psi,120 rpm,2.5k tq.114k puw,110k sow,112k rotes. 08:30 09:30 1.00 9.50 DRILL E 7 P CBU X 4.5 @ 900 gpm,1410 psi,120 rpm,2.5k tq.Monitor well-static.Blow down Top-drive. 0930 10:30 1.00 10.50 DRILL E 4 .P PJSA POOH 0 1188'-254'. 1030 13:30 3.00 13.50 DRILL E 4 P PJSA POOH L/D BHA#4 as per SLB. 13.30 14:30 100 14.50 DRILL E 20 P PJSA clear and clean rig floor. 14:30 15:30 1.00 15.50 DRILL E 19 P PJSA Pull wear bushing and set test plug as per Vetco. 15:30 17:30 2.00 17.50 DRILL E 19 P PJSA C/O top rams to 9 5/8"and test to 250/3500 psi. r,. Y 17:30 18:00 0.50 18.00 DRILL E 19 P Pull test plug and set modified wear bushing. 1800 19:30 1.50 19.50 DRILL E 20 P PJSA UD bails and R/U Tesco casing running equipment. 19.30 00:00 4.50 24.00 DRILL G 4 P PJSA W/all hands.M/U 9 5/8'shoe track and RIH to 167'and tested floats.Cont.to M/U and RIH floating 9 5/8"40#L-80 .. Hydril 563 casing to 1624'. - 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. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Mails Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5 @enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikott ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher •Doyon Drilling Tool Pusher dg15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 3,950.0 6/1/2013 Last Leakoff Test Depth(ftKB) •TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,9500 2,443.60 spud 9.30 440.0 12.77 1,620.5 I Eni E&P Division ,, 'Well Name:SI19-FN2 ENI Petroleum Co,Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • APIIUWI:50-629-23487-00-00 2^n Date:6/10/2013 - Report#: 16 'III II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name IRig Type DOYON DRILLING DOYON 15 ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) 5I19-FN2 DRILLING 5/29/2013 3,982.01 2,454.0 21,238.00 118.02 180.0 12.98 Daily Information End Depth(RKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11.746.0 3,746.1 0.00 107.0 46.0 Overcast WC 45° E @ 4 MPH Daily summary operation 24h Summary M/U and RIH w/9 5/8"404 L-80 Hydril 563 casing to 11,731'.Begin rotating csg @ 5158'.R/U and fill casing with mud as per schedule.Break circulaion and condition mud. Operation at 07.00 Circulate and condition mud for cement job. 24h Forecast Circ.&condition mud and cement casing as per plan.R/D from cement job and perform injectivity test.N/D BOPE stack and set Vetco emergency slips.Cut and remove 9 5/8"casing.Install Vetco Multibowl wellhead and N/U BOPE and test. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 06.00 6.00 6.00 DRILL G 4 P PJSA RIH wd 9 5/8"casing f/1624'-6386'.Obtain TO values at the shoe @ 30 rpm,5k tq.50 rpm.6k tq as per K&M.Start to rotate in hole @ 5158'@ 50 rpm,6k tq,96k puw,60k sow,78k rotw. 06:00 12:00 6.00 12.00 DRILL G 4 P Rotate in hole w/9 5/8"csg f/6386'-10,53'@ 60 rpm,9.5k Iq,84k rotw. 12:00 13:30 1.50 13.50 DRILL G 4 P Cont.Rotate in hole w/9 5/8"csg.f/10,153'-11,731'shoe depth,@ 60 rpm,10k tq. 13:30 15:00 1.50 15.00 DRILL G 20 P PJSA,R/D Tesco casing equipment and clear floor. 15:00 1630 1.50 16.50 DRILL G 20 P PJSA R/U long bails and install cement head. 16:30 23:00 6.50 23.00 DRILL G 7 P PJSA Fill 9 5/8"casing as per plan @ 2-3 bpm,30 psi. 23:00 00:00 1.00 24.00 DRILL G 7 P Break circulation @ 1 bpm,390 psi.Circulate and condition mud for cementing. 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 Dulling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoft ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15 @doyondnlling.com 907-685-0716 Tool Push Pete Maninusen Doyon Dulling Tour Pusher ng15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(RKB) IND(ftKB) Fluid Type I Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,9500 2,443.60 spud 9.30 440.0 12.77 1,620.5 Eni E&P Division I Well Name: SI19-F52 ENI Petroleum Co.Inc. Daily Report` Well Code:27161 Field Name:NIKAITCHUQ • APIIUWI:50-629-23487-00-00 2^r, Date:6/11/2013 - Report#: 17 II II II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share)%) I Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING _ _ _ _ _ _DOYON 15 LAND RIG Job Information • Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2.454.0 21,238.00 118.02 180.0 13.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(f lhr) POB Temperature(°F) Weather Wind 11,746.0 3,746.1 0.00 104.0 48.9 Clear Calm Daily summary operation 24h Summary Circ.and condition mud.Mix and pump 199 bbls of DeepCrete 12.5 ppg cement and displace w/867 bbls of 9.4 ppg LSND Mud and bump plug @ 700 psi and pressure to 1200 psi.Floats held and CIP @ 1300 hrs.N/D and set emergency Vetco slips w/100k overpull.Cut 9 5/8"csg.,install packoff and N/U Multibowl wellhead and test to 2472 psi.N/U BOPE.R/U LRS to freeze protect. Operation at 07.00 P/U 4.5"DP. 24h Forecast Complete N/U BOPE.Freeze protect 13 3/B"X 9 5/8"ann.w/236 bbls of diesel.P/U and M/U 4.5"DP and rack back in derrick.R/U and test BOPE as per State Rep. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase_ Opr. Act. Plan - Oper.Descr. 00:00 06.30 6.50 6.50 DRILL G 7 P PJSA Circulate BU X 3.5 staging rates @.25 bpm up to 7 bpm,390 psi,obtaining 18 YP. Y0T, 06:30 13'30 7.00 13.50 DRILL H 9 P PJSA Load cement plugs,blow air through cement line and SLB pump 10 bbls FW and test lines to 500/3000 psi f/5 min.. •r Rig pump 100 bbls 10.5 ppg MudPush II spacer @ 5 bpm,drop Btm Plug and SLB pump 199 bbls 12.5 ppg DeepCrete Gas Cmt @ 5.8 bpm.Drop Top Plug and SLB kick out w/10 bbls FW.Rig displace cement w/867 bbls of 9.4 ppg LSND mud @ 5/2 bpm.275/700 psi.Increase pressure to 1200 psi and hold for 5 min.Bleed pressure and floats held.Line up and L, perform infectivity test down annulus w/40 bbls of 9.5 ppg LSND Mud.Break down formation©450 psi and pump 1/2 bpm,250/400 psi.2 bbls bleed back.R/D testing equipment. t,.. 13:30 15.00 1.50 15.00 DRILL H 20 P PJSA R/D cement head and equipment.Drain and flush stack 15:00 17:00 2.00 17.00 DRILL C 20 P PJSA N/D BOPE and raise stack and secure. 17:00 1930 2.50 19.50 DRILL C 20 P Set Vetco emergency slips with 100k overpull.Cut 9 5/8"casing as per Vetco.L/D landing it w/3.81'cut-off. R/D Casing slips. 19:30 22:30 3.00 22.50 DRILL C 20 P Pull wear bushing,prep and set 9 5/8"pack-off.N/U Multibowl well head.R/U and test pack-off to 2472 psi f/10 min. 22:30 00.00 1.50 24.00 DRILL C 20 P PJSA N/U BOPE.Simops with R/U LRS to freeze protect. 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 Dolling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test -Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall f P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 3,9500 2,443.60 spud 9.30 440.0 12.77 1,620.5 Eni E&P Division I Well Name:S119-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUO • API/UWI:50-629-23487-00-00 2^n Date:6/12/2013 - Report#: 18 II 'I ii page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3.982.0 2,454.0 21,238.00 118.02 180.0 14.98 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11.746.0 3.746.1 0.00 106.0 45.0 Partly Cloudy.WC NNE @ 9 MPH 39` Daily summary operation 24h Summary Prep rig for drilling operations.P/U 102 stands of 4.5"DP and rack in derrick.Rig maintenance and service.RIU and test BOPE as per State Regs.Witness waived by Jeff Turkington. Operation at 07.00 M/U BHA#5. 24h Forecast Complete BOPE testing.M/U BHA#5 and RIH Logging Cement Bonding from 8900'to TO Float collar.Test/Chart casing to 3000 psi f/30 min.Displace LSND Mud w/OBM.Ddg.shoe track plus 20'of new formation. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 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 C 20 'P PJSA C/O Top Rams to 3.5 X 6 VBR's.Simops.LRS freeze protect Ann.wl 236 bbls of diesel @ 1.5 bpm.1000 psi.OA @ 750 psi. 01:30 02.30 1.00 2.50 DRILL E 20 P PJSA clear and clean rig floor,C/O bails,install bell guide on Top-drive and 4.5"elevators. 02:30 14.30 12.00 14.50 DRILL E 20 P PJSM P/U 8 M/U 4.5"DP in mousehole and rack back in derrick.Total of 102 stands. 14.30 16:00 1.50 16.00 DRILL E 25 P PJSM Cut and slip 141'of drilling line. 16:00 18.00 2.00 18.00 DRILL E 25 P PJSA C/O wash pipe and service Top-drive. 18:00 19:30 1.50 19.50 DRILL C 20 i P PJSA Set test plug and R/U to test BOPE. ' 19:30 0 .00 4.50 24.00 DRILL C 0 12 P PJSA Test BOPE w/5"test jt,Ann.@ 250/2500 psi,All other tests @ 250/3500 psi.Perform Draw Down Test,200 increase @ 48 sec.Full @ 3 min.28 sec.,5-N2 bottle avg=2400 psi. Note;BOPE Test Witness Waived by AOGCC Rep.Jeff Turkington. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bemie Leas ENI Rig Clerk akngclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondnlling corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) 'Leak Off Pressure(psi) 3,950.0 2443.60 spud 9.30 440.0 12.77 1,620.5 Eni E&P Division . I Well Name: 5119-FN2 ENI Petroleum Co.Inc. Daily Repot 1 Well Code:27161 Field Name: NIKAITCHUO � API/UWI:50-629-23487-00-00 2 rift*^ Date:6/13/2013 - Report#: 19 II " page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) SI19-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.01 15.98 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11,746.0 3,746.1 0.00 105.0 51.0 Partly Cloudy.WC SW @ 5 MPH 45' Daily summary operation 24h Summary Complete BOPE Testing.M/U BHA#5 and RIH logging w/Sonic f/8824'to TO Float collar @ 11,642'.Perform casing test to 3000 psi 1/30 min. Operation at 07.00 Doling shoe track. 24h Forecast Displace LSND Mud to OBM.Ddg out shoe track plus 20'of open hole and perform FIT/LOT.Drill ahead in production hole as per SLB and Geologist. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL C 12 P Complete testing of BOPE as per State Regs. 02.00 03:00 1.00 3.00 DRILL C 20 P PJSA Pull test plug and set 9"wear bushing.R/D and B/D from test.Clear and clean rig floor 8 bung up BHA#5 parts. 03:00 06:30 3.50 6.50 DRILL E 4 P PJSA P/U 8 M/U BHA#5 and RIH to 280'. 06.30 07:30 1.00 7.50 DRILL E 4 P PJSA RIH w/4.5"DP on elevators to 1229'.Perform shallow hole test @ 350 gpm,420 psi. 07:30 08:30 1.00 8.50 DRILL E 4 P RIH f/1229'-2176'.Shallow hole test @ 425 gpm,770 psi. 08.30 13:00 4.50 13.00 DRILL E 4 P RIH f/2176'-8824'190k puw,85k sow. 13:00 18:00 5.00 18.00 DRILL E 4 P Break circulation @ 425 gpm,1470 psi.Log in hole @ 650-700 fph f/8824'-10,712'.215k puw,80k sow. 18:00 22:30 4.50 22.50 DRILL E 4 P Cont.to log in hole f/10,712'-to TO Float Collar @ 11,642'@ 650-700 fph. 22.30 23:30 1.00 23.50 DRILL E 7 P CBU and balance mud.R/U to test casing. 23.30 00:00 0.50 24.00 DRILL E 12 P Pressure up and test casing to 3000 psi f/30 charted min. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon 15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8,835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) !TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak OH Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2.559.3 Eni E&P Division I Well Name:SI19-FN2 riii* ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • API/UWI:50-629-23487-00-00 2^n Date:6/14/2013 - Report#: 20 II 'I II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(1t) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.01 2.454.0 21,238.00 118.02 180.0 16.98 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12.881.0 3,765.4 1.135.00 7.35 154.4 102.0 41.0 Mostly Cloudy,WC NNW @ 7 MPH 35" Daily summary operation 24h Summary Displace LSND Mud from well w/9.4 ppg FazePro OBM.Drig.shoe track and 20'of new hole and perform FIT to 13 ppg Equiv.Drig ahead to 12,881'. Operation at 07.00 Duling ahead in 8.75"production hole at 13,273'MD. 24h Forecast Drig ahead in 8.75"production zone as per SLB/Geologists. Lithology Shows MAASP Pressure(psi) 'Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P PJSA R/D Test equip.and B/D Kill line. 00:30 04:30 4.00 4.50 DRILL E 7 P PJSA Displace well wl 9.4 ppg FazePro OEM:Pump 50 bbls HLVis spacer,40 bbls LVT followed with 790 bbls of OBM @ 5 bpm,640 ICP,80 rpm,20k tq,610 FCP,80 rpm,9.5k tq.185k puw,110k sow,148k rotw.Clean surface equipment of interface mud. 04:30 06:00 1.50 6.00 DRILL E 3 P Break circulation and establish doll out parameters @ 430 gpm.2160 psi,80 rpm,8/14k tq,2-6k wob,clean out shoe track f/Float collar to Rat hole @ 11,642'-11,746'. 06:00 06:30 0.50 6.50 DRILL E 3 P DrIg.1/11,746'-11,766'@ 430 gpm,2060 psi,60 rpm. 06.30 08:00 1.50 8.00 DRILL E 7 P Circ.&condition mud while BROOH to 11,736'and rack back stand.Reciprocate pipe f/11,646'-11,766'while circ.@ 430 �- gpm,2060 psi,60 rpm,11k tq.R/U for FIT/LOT Test. f 08.00 09:00 1.00 9.00 DRILL E 9 P Perform FIT test to 13.0 ppg by pressuring up closed system to 715 psi.R/D from test. i., 0900 12:00 3.00 12.00 DRILL E 3 'P Ddg.5 11,766'-11,988'(3761.4'TVD)@ 550 gpm.3200 psi,150 rpm,9-13 tqn,9k tqf,200k pow,90k sow,147k rotw, 1000 Max Gas,11.23 ECD,1.80 ADT,1.80 Bit/Jars. 12:00 18:00 ' 6.00 18.00 DRILL E 3 P PJSA drlg.f/11,988'-12,483'(3765'TVD)@ 550 GPM.3200 PSI,150 RPM.2-10K WOB,10K TON,9K TQF,1000 MAX GAS,11.14 ECD,3.19 ADT,4.99 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P Drip.f/12,483'-12,881'(3766'TVD)@ 550 gpm.3200 psi,160-180 rpm,4-10k wob.14-16k tqn.10-12k tqf,195k puw. 90k sow.144k rotw,712 Max Gas,11.32 ECD,2.36 ADT,7.35 Bit/Jars. SPR @ 12,764'(3767'TVD)wy 9.4 MW. #2 @ 20-230,@ 30-320;#3 @ 20-230,@ 30-320. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em 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 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 Eni E&P Division 'Well Name:8119-FN2 Pi* EN/Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • APIIUW:50-629-23487-00-00 2 n g Date:611512013 - Report#: 21 II II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name IRig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI19-FN2 DRILLING 5/29/2013 3.982.0 2454,0 21,238.00 118.02 180.0 17.98 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15,295.0 3,743.6 2.414.00 11.36 212.5 104,0 42.0 Cloudy/Fog,WC SSW @ 16 MPH 32` Daily summary operation 24h Summary Ddg,ahead in 8.75"production hole f/12.881'-15,295'(3745'TVD)as per SLB and Geologist. Operation at 07.00 Drill ahead in 8.75"production hole at 15,562'MD. 24h Forecast Ddg.ahead in 8.75"production hole as per SLB and Geologist. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum • • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E '3 P PJSA Drtg.f/12.881'-13,417'(3776'TVD)@ 550 gpm,3260 psi,160 rpm,14-16k tqn,10-11k tgf,6-10k wob,195k puw, 80k sow.145k rotw,11.51 ECD,1100 Max Gas,2.12 ADT,9.47 Bit/Jars, 06:00 12:00 6.00 1200 DRILL 'E 3 'P Ddg.f/13,417'-14,071'(3763'TVD)@ 550 gpm,3390 psi,160 rpm,15k tqn,14k tqf,8-10k wob,199k puw,sow N/A, 142k rotw,11.62 ECD,844 Max Gas,2.85 ADT,12,32 Bit/Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg.f/14.071'-14,725'(3753'TVD)@ 550 gpm,3400 psi,160 rpm,2-14k wob,15-16k tqn,11k tqf,210k puw,143k rotw,750 Max Gas,11.86 ECD,3.53 ADT,15.85 Bit/Jars. 18:00 00.00 6.00 2400 DRILL E '3 -P Ddg.f/14,725'-15,295'(3745'TVD)@ 550 gpm,3460 psi,160 rpm,2-14k wob,14k tqn,11k tqf,205k puw,143k rotw. 750 Max Gas,11.78 ECD,2.86 ADT,18.71 Bit/Jars.SPR @ 14,725'(3753'TVD)w/9.4 MW; #2 @ 20-270,@ 30-380;#3 @ 20-280,@ 30-380. 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 Dnlling Supv. SIDDnIling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15 @doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 11.731.0 6/10/2013 Last Leakoff Test Depth(RKB) 'ND(ftKB) Fluid Type 'Fluid Density(1b/gal) 'P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 10* Eni E&P Division Name:S119-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • APIIUWI:50-629-23487-00-00 2^ Date:6/16/2013 - Report#: 22 II II page 1 of 1 Wellbore name: SI19-FN2 Well Header PermiUConcession N° Operator ENI Share(%( Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI19-FN2 DRILLING 5/29/2013 3,982.0 2454.0 21,238.00 118.02 180.0 18.98 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftihr) POB Temperature(°F) Weather Wind 17.024.0 3,766.9 1.729.00 11.89 145.4 103.0 29.0 Partly Cloudy/Fog, ESE @ 8 MPH WC 23" Daily summary operation 24h Summary Drill ahead in 8.75"Production hole f/15.295'-17,024'(3768'TVD).Well breathing.Total losses for day=845 bbls. Operation at 07.00 -- Drill ahead in 8.75"Production Hole at 17,525'MD. 24h Forecast Drill ahead in 8.75"production hole as per SLB/Geologists to Est TD @ 21.233'. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P PJSA Dig.f/15,295'-15,659'(3750'TVD)@ 533 gpm,3300 psi,162 rpm,8-12k mob,16-17k tqn,15k tqf,199k puw,138k rotw,1.48 ECD,428 Max Gas,4.37 ADT,23.08 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P Ddg.f/15,659'-16,033'(3763'TVD)@ 488 gpm,3010 psi,130 rpm,10-14k wob,15-16k tqn, 10-11k tql,200k puw,139k rotw,11.49 ECD,718 Max Gas,2.79 ADT,25.87 Bit/Jars.540 bbls Toady Fluid Loss. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drlg.f/16.033'-16,680'(3765'TVD)@ 525 gpm,3480 psi,130 rpm 2-2k wob,15k tqn,10k tqf,210k puw,139k rotw,11.81 ECD,1100 Max Gas,2.93 ADT,28.80 Bit/Jars.Note;Well breathing,with pumps shut down for 30 min,160 bbls flowed back. 18:00 00:00 6.00 24.00 DRILL E 3 P Ddg.f/16,680'-17,024'(3768'TVD)@ 530 gpm,3540 psi.160 rpm,2-14k wob.16k tqn,11-12k tqf,210k puw,140k rotw. 11.62 ECD,750 Max Gas,1.8 ADT,30.60 Bit/Jars.Note;Well still breathing up to 220 bbls/30 min.305bbls Tourfy Fluid Loss.SPR @ 16.686'(3765'TVD)@ 9.4 MW#1©20-440,@ 30-540,#3 @ 20-430,@ 30-500. 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. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoft ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.401 730.0 13.15 2,559.3 Eni E&P Division 'Well Name:SI19-FN2 EN!Petroleum Co.Inc. • Daily Report Well Code:27161 Field Name:NIKAITCHUQ • APIIUWI:50-629-23487-00-00 2 1319411^n Date:6/17/2013 - Report#: 23 In II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator EM Share(%) IWell Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3.982.01 2.454.0 21,238.00 118.02 180.0 19.98 - Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,834.0 3,752.9 1.810.00 9.43 191.9 103.0 32.0 Partly Cloudy.WC NE @ 12 MPH 24' Daily summary operation 24h Summary Drill 8.75"Production hole f/17,024'-18,834'(3754'TVD).Well breathing back fluids from 270 bbls in 60 min.Total fluid losses from day=1099 bbls. Operation at 07.00 Drill ahead in 8.75"Production hole at 19,018'MD. 24h Forecast Drill ahead in 8.75"production hole as per SLB and Geologists to Est TD of 21,233'. Lithology Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Due(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 0600 6.00 6.00 DRILL E 3 P PJSA Drill 1/17024'-17,620'(3768'TVD)@ 484 gpm,3110 psi.162 rpm,8-10k wob.15-16k tqn,10-12k tqf,195k puw. 140k rotw,11.48 ECD,1000 Max Gas,2.31 ADT,32.91 Bit/Jars. 06'00 1200 6.00 12.00 DRILL E 3 P Dig.1/17,620'-18,181'(3764'TVD)@ 483 gpm,3140 psi,160 rpm,8-10k wob.15-17k tqn,14-15k tqf,210k puw,140k rotw,11.75 ECD,834 Max Gas,2.05 ADT,34.96 Bit/Jars.522 bbls Total Fluid Loss/Well Bore Breathing and monitored. 12'00 18.00 6.00 18.00 DRILL E 3 P PJSA Complete exhale test from 18,181'@ 276 bbls in 60 min.Ddg.f/18,181'-18,647'(3753'TVD)@ 435 gpm,2700 psi, 130 rpm,2-14k wob,15k tqn,12k tqf,210k puw,135k rotw,11.6 ECD,297 Max Gas,3.38 ADT,38.34 Bit/Jars. 1800 23'00 5.00 23.00 DRILL E 3 P Perform exhale test with 278 bbls retuming in 60 min.Ddg.0 18,647'-18,834'(3754'TVD)@ 435 gpm,2850 psi,130 rpm. 2-18k wob,15-18k tqn,13k tqf.22ok puw,135k rotw,1.69 ADT,40.03 Bit/Jars.SPR @ 18.741'(3752'TVD)9.4 MW. #1 @ 20-460,@ 30-560,#2 @ 20-490,@ 30-560,#3 @ 20-460,@ 30-540. 2300 00:00 1.00 24.00 DRILL E 19 P Perform exhale test @ 18,834'wy 277 bbls retumed in 60 min. 577 bbls Tourty loss.1099 bbls for Day. 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 Dolling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.cow 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) !Fluid Type 'Fluid Density(lb/gal) ! Off P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak O Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2.559.3 Eni E&P Division [Well Name:SI19-FN2 diiiiii- ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • API/UWI:50-629-23487-00-00 2^g Date:6/18/2013 - Report#: 24 'I II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62_ Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.0 20.98 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 20,514.0 3,762.7 1,680.00 9.76 172.1 104.0 34.0 Mostly Clear,WC 25` NE @ 15 MPH Daily summary operation 24h Summary Drill 8.75"Production hole f/18,834'- 20,514'Perform 3 Exhale tests with a gain of 863 bbls.Total Daily fluid losses were 775 bbls.2719 bbls,Total Well fluid losses. Operation at 07.00 Drill ahead in 8.75"Production hole at 20,785'MD. 24h Forecast Drill ahead in 8.75"Production hole as per SLB/Geologists to an Est TD of 21,233'.TD will be picked by Geologist. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr( Phase Opr. Act. Plan Oper.Descr. 0000 06.00 6.00 6.00 DRILL E 3 P PJSA Ddg.f/18,834'-19,208'(3755'ND)@ 435 gpm,2810 psi,130 rpm,10-12k wob.16k tqn,14k tqf,217k puw,140k rotw,11.50 ECD,258 Max Gas,3.06 ADT,43.09 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P Drig.f/19,208'-19,675'(3754'TVD)©448 gpm, 3040 psi.130 rpm,10-12k wob,16-17k tqn.14k tqf, 225k puw,138k rotw,12.01 ECD,402k Max Gas,2.26 ADT,45.35 Bib Jars.Performed 2-exhales w/540 bbls returned.326 bbls Tourly fluid losses. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg.f/19,675'-20,144'(3758'ND)@ 435 gpm, 2930 psi,130 rpm,2-2k wob,16k tqn,13k tqf,220k puw,138k rotw,11.97 ECD,650 Max Gas,2.45 ADT,47.80 Bit/Jars. 18:00 19:00 1.00 19.00 DRILL E 11 P Perform exhale test @ 332 bbls in 60 min. 19.00 23:00 4.00 23.00 DRILL E 3 P DrIg.f/20,144'- 20,514'(3765'ND)@ 435 gpm,2960 psi,130 rpm,2-17k wob,15k tqn,12k tqf,220k puw,139k rotw, 12.04 ECD,1100 Max Gas,1.99 ADT,49.79 Bit/Jars.SPR @ 20,431'(3761'ND)w/9.4 MW;#2 @ 20-580,@ 30-690, #3 @ 20-580,@ 30-680. 23.00 00:00 1.00 24.00 DRILL E 11 P Perform exhale test @ 282 bbls in 60 min.449 bbls Tourty fluid losses.775 bbls Daily fluid losses.2719 bbls Total Well fluid losses. 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 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HOE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftK8) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 Eni E&P Division I Well Name:SI19-FN2 rif* EN!Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUO • APIIUWI:50-629-23487-00-00 2�, Date:6119/2013 - Report#: 25 II I� page 1 of 1 Wellbore name: 5119-FN2 Well Header 21 043 Permit/Concession N° 'Orator EENI PETROLEUM 'ENI Share(%) 100.00'Well type Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOVON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29!2013 3,982.0 2454.0 21,238.00 118.02 180.0 21.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather rind 21,258.0 3,742.6 744.00 4.77 156.0 103.0 36.0 Clear,WC 25° NE @ 17 MPH Daily summary operation 24h Summary Drilled to Geologist's TD @ 21,258'(3744'TVD).Perform Exhale Test for 2 hrs w/340 bbls bleed back and well static.BROOH f/21,258'-7,623'@ 400 gpm,2400 psi,130 rpm,20-25 fpm.Total fluid losses for day=734 bbls.Well losses @ 3453 bbls. Operation at 07.00 BROOH at 16,035'MD. 24h Forecast BROOH f/17.623'-11,731'(Csg.Shoe).Perform Exhale test until static.Cont.BROOH to top of 4.5"DP @ 9964'and circulate hole clean.POOH on elevators and UD BHA.M/U Dummy iron BHA and RIH filling DP to 21,258'. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 10.00 10.00 DRILL 'E 3 P PJSA Drtg.f/20.154'-21,258'(3744'TVD)@ 449 gpm,3020 psi,130 rpm,10-12k wob,17k tqn,15-16k tqf,210k puw, 138k rotw,12.11 ECD,963 Max Gas,4.77 ADT,54.56 Bit/Jars.TD called by Geologist and ExCeed placed in Neutral. SPR @ 21,258'(3744'TVD)w/9.35 MW,#1 @ 20-630,@ 30-730.92 @ 20-630,@ 30-730,#3 20-630.@ 30-730. 10:00 12:00 2.00 12.00 DRILL 'E 11 'P PJSA Perform exhale test for 2 hrs with 340 bbls of returns.Static.Total fluid losses for tour=382 bbls. 12:00 14:00 2.00 14.00 DRILL •E '7 P 'PJSA,Perform K&M clean up cycle @ 450 gpm,3020 psi,130 rpm,16k tq,135k rotw.Monitor losses of 496 bbls at 1360 bbls pumped.Reduced to 400 gpm,2670 psi,with no change in loss rate.Shut down and perform Exhale test for 35 min. and retums of 232 bbls. 14:00 18:00 4.00 18.00 DRILL •E 4 P 'BROOH f/21,258'-20,144'@ 400 gpm.2400 psi,130 rpm,14k tq,20-25 fpm. 18:00 00:00 6.00 24.00 DRILL •E 4 .P BROOH f/20,144'-17.623'@ 400 gpm.2360 psi,130 rpm,16k tq.32k rotes.20-25 fpm.Total fluid losses for tour=352 bbls. Total daily losses=734 bbls. Total well losses=3453 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 Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikog ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 Eni E&P Division 'Well Name:0119-FN2 Oil* ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name: NIKAITCHUQ • API/UWI:50-629-23487-00-00 2^n Date:6/20/2013 - Report#: 26 _ 'I I'II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.0 22.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,258.0 3,742.6 0.00 106.0 49.0 Mostly Cloudy.WC NW @ 21 MPH 36" Daily summary operation 24h Summary BROOH f/17,623'-9965' At shoe,perform Exhale test until static.BROOH to TO 4.5"DP, CBU and perform Exhale test.Daily fluid losses=98 bbls.Total Well losses=3551 bbls. Operation at 07.00 POOH on elevators at 5,901'MD. 24h Forecast POOH on elevators and L/D BHA#5.P/U&M/U BHA#6 and RIH w/hole opener filling pipe.Circulate @ shoe(11,731)and cont.RIH to 21,258'.CBU. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 4 P PJSA BROOH f/17,623'-15.289'@ 400 gpm,2100 psi,130 rpm,13k tq,190k puw,140k rotw.Encountered tight spot @ 15,875'.Worked through twice. 06:00 12:00 6.00 12.00 DRILL E 4 P BROOH f/15,289'-13,328'@ 400 gpm,1950 psi,130 rpm,13k tq,185k puw,141k rotw.Total fluid loss for tour=69 bbls. Fluid loss greatly reduced above 15,200'. 12:00 15:00 3.00 15.00 DRILL E 4 P PJSA BROOH 1/13.328'-11,709'@ 400 gpm,1840 psi,130 rpm,10k tq.20-25 fpm. 15:00 18:00 3.00 18.00 DRILL E 11 P 11,709'(Csg shoe)perform Exhale test w/31 bbls retum then static for 15 min. 18:00 21:00 3.00 21.00 DRILL E 4 P BROOH f/11,709'-9962'(TO 4.5"DP)@ 400 gpm.1760 psi,130 rpm,9k tq. 21:00 22:30 1.50 22.50 DRILL E 7 P Circulate and reciprocate f/9965'-9868'@ 400 gpm,1740 psi,130 rpm.9k tq,Loss of 41 bbls while circulating. 22:30 00:00 1.50 24.00 DRILL E 11 P Perform Exhale test @ 9965'with 12 bbls retumed.Static.Total fluid loss for tour=29 bbbls.Daily fluid loss=98 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling 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 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikofl ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 Eni E&P Division ., 'Well Name:SI19-FN2 ft* ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ Date:6/21/2013 - Report#: 27 APIIIJWI:50-629-23487-00-00 2I1 "Ii page 1 of 1 Wellbore name: SI19-FN2 • Well Header Permit/Concession N° (Operator I ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3.982.0 2,454.0 21238.00 118.02 180.0 23.98 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 21.258.0 3,742.6 0.00 105.0 38.0 Partly Cloudy,WC NNW @ 8 MPH 31" Daily summary operation 24h Summary POOH and LD BHA#5.P/U&M/U BHA#6 and RIH w/Hole opener to 15,875'(Tight spot). Operation at 07.00 RIH w/Hole Opener at 17,760'. 24h Forecast RIH to 21,258'and CBU and Prepare Faze Away Breaker.Spot breaker in open hole and POOH to casing shoe at 11,731'and displace OBM w/brine. Lithology Shows MAASP Pressure(psi) 'Mud Weight(113/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 ' 7.00 7.00 DRILL E 4 'P PJSA POOH f/9965'-280'90k puw,89k sow. 07:00 09:30 2.50 9.50'DRILL E 4 'P PJSA POOH and L/D BHA#5. 09:30 10:00 ' 0.50 10.00 DRILL E 20 P PJSA clean and clear dg floor. 1000 10.30 0.50 10.50 DRILL E 25 P PJSA service draw works,top-drive and traveling equipment. 10:30 11'.30 1.00 11.50 DRILL E 4 'P PJSA P/U&M/U BHA#6 and RIH to 140'w/hole opener. 11,30 12:00 ' 0.50 12.00 DRILL E 4 P PJSA RIH w/hole opener on 4.5"DP to 1200'.Tourly fluid loss of 7 bbls. 12:00 17:30 5.50 17.50 DRILL E 4 P PJSA R11-1(/1200'-11,502'filling pipe,172k puw,118k sow. 17:30 19:00 1.50 19.00 DRILL E 25 P PJSA Cut and slip 144'of ddg.line,adjust brakes and brake rollers,and gauge crown and block sheaves. 19:00 21:30 ' 2.50 21.50 DRILL E 7 P CBU @ 350 gpm,1170 psi. 21:30 00:00 2.50 24.00 DRILL E 4 P RIH f/11,502'-15.875'.Tag up on tight spot @ 15,875',190k puw,92k sow.Tourly fluid loss of 21 bbls. Daily Contacts Position r Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Dolling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2.559.3 fill* Eni E&P Division I Well Name:SI19-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • API/UWI:50-629-23487-00-00 2^ Date:6/22/2013 - Report#: 28 II II page 1 of 1 Wellbore name: SI19-FN2 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5119-FN2 DRILLING 5/29/2013 3.982.0 2.454.0 21.238.00 118.02 180.0 24.98 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,258.0 3,742.6 0.00 106.0 32.0 Partly Cloudy.WC NE @ 7 MPH 2T Daily summary operation 24h Summary Wash and ream through tight spot @ 15,875'and coot in hole to 21.244'.Circ.&condition mud and have PJSA for spotting breaker fluid.Mud plant pump 15 bbls of 9.0 ppg brine followed w/750 bbls of 9.3 ppg FazeAway Breaker.20 bbls 9.0 ppg KCL Brine.Rig displace w/120 bbls 9.3 ppg FazePro mud @ 2.5 bpm,630 psi,60 rpm.16k tq.142k rotw. Operation at 07.00 POOH per K&M schedule at 20,120'MD. 24h Forecast Monitor well and POOH as per K&M schedule starling @ 16 min/std.Pull into csg.shoe @ 11,741'and have PJSA.Displace well w/9.0 ppg KCL Brine until clean.Clean surface equipment.POOH and L/D BHA#6.Prep to run 4.5"liner. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) . 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 4 P PJSA Wash and ream through hard spot @ 15.875'and cont.in hole to 18,850'@ 210 gpm,830 psi,60 rpm,13k tq,200k puw,95k sow,135k rotes. 06:00 10:30 4.50 10.50 DRILL E 4 P Wash&ream f/18,650'-21,244'@ 210 gpm.900 psi.62 rpm,14k tq,205k puw.N/A sow, 147k rotes. 10:30 12.00 1.50 12.00 DRILL 'E 7 P PJSA Circulatend condition mud @ 178 gpm,860 psi,62 rpm,13-14k tq,205k puw.147k rotw.Tourty fluid loss=142 bbls. 12:00 16:00 4.00 16.00 DRILL E 7 P PJSA Slow pumps to 150 gpm,800 psi,60 rpm.15k tq,142k rotw. 16:00 17:00 1.00 17.00 DRILL E 12 P Monitor well for 30 min.and have PJSA on spotting breaker fluid.Pressure test transfer lines w/brine. 17:00 00:00 7.00 24.00 DRILL E 7 P PJSA Pump 15 bbls 9.0 KCL Brine @ 2.5 bpm,600 psi,followed by 770 bbls 9.3 ppg FazeAway breaker @ 2.5 bpm,670 psi,then 20 bbls 9.0 ppg KCL Brine.Rig pump 120 bbls 9.35 ppg FazePro mud @ 2.5 bpm,630 psi,60 rpm,16k tq,142k rotw.Toady fluid loss=67 bbls.Daily loss=209 bbls.SPR @ 21,244'(3744'TVD)w/9.3 MW; #1 @ 30-720,@ 40-860,#2 @ 30-720,©40-880. - 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 Drilling Supv. SIDDnIling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Mails Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikofl ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 11,746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 1"1* Eni E&P Division . I Well Name:SI19-FN2 ENI Petroleum Co.Inc. Daily Report l Well Code:27161 Field Name:NIKAITCHUO • API/UWI:50-629-23487-00-00 2^n Date:6/23/2013 - Report#: 29 " 'III page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ttKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI19-FN2 DRILLING 5/29/2013 3,982.0_ 2454.0 21,238.00 118.02 180.0 25.98 Daily Information End Depth(ttKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,258.0 3,742.6 0.00 106.0 35.0 Fog.WC 27' NNW@ 10 MPH Daily summary operation 24h Summary POOH 1121,244'as per K&M schedule to 11,502'and begin to displace well to brine. Operation at 07.00 Cleaning surface equipment after displacement. 24h Forecast Complete displacement to 950 bbls of 9.0 ppg KCL brine.Clean surface equipment and POOH and LID BHA•6.R/U to run 4.5"liner. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00-DRILL E 4 -P PJSA POOH 1/21244'-19.537'as per K&M schedule of 16 min/std.205k puw. 06:00 12.00 6.00 12.00 DRILL E 4 P POOH f/19,537'-18,044'@ 18 min/std,204k puw.Toudy fluid loos=24 bls. 12:00 18.00 6.00 18.00 DRILL E 4 P PJSA POOH f/18,044'-15,300'as per K&M pulling schedule.198k puw. 18:00 22:00 4.00 22.00 DRILL E 4 P POOH f/15.300'-11,731' 190k puw,118k sow.At 11,731'Casing shoe had 30k overpull. 22:00 23:00 1.00 23.00 DRILL E 7 'P PJSA Ream thru shoe @ 11,731'-11,723'@ 40 rpm,9k-15k tq.138k rotw.Attempt 10 slack off back thru and tagged up w/ 30k.PU and pumping @ 2 bpm,280 psi.40 rpm,9k tq.and wash and ream thru tight spot X 2,and PU to 11,720'with no problem. 23:00 00.00 1.00 24.00 DRILL E 4 P POOH f/11,720'-11,502',188k puw,118k sow.Monitor well for 15 min and have PJSA for displacing w/bone.Displace well by pumping 33 bbls of LVT @ 3 bpm,340 psi.Toudy fluid loss=73 bbls.Daily loss=97 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv -SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ttKB) Bottom(ttKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) TVD(ttKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11.746.0 3,746.15 OBM 9.40 730.0 13.15 2,559.3 c Eni E&P Division f Well Name: SI19-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • Date:6/24/2013 - Report#: 30 API/UVO1:50 629-23487-00-00 e h Ii page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 DRILLING 5/29/2013 3,982.0 2.454.011 21,238.00 118.02 180.0 26.98 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) 'POB Temperature(°F) Weather 'Wind 21,258.0 3,742.6 0.00 105.0 33.0 Light Rain,WC 23° NE @ 23 MPH Daily summary operation 24h Summary Complete displacing well to 9.0 ppg KCL Brine.POOH and L/D BHA#6.R/U and P/U 8 M/U 4.5" 11.69,L-80,H521 Liner and RIH to 7350'.Daily fluid loss=163 bbls. Operation at 07.00 RIH w/4.5"Liner on 5"DP.Rabbit stands from derrick. 24h Forecast Complete P/U 4.5"Liner and M/U Baker Hanger/Packer assy and service.RIH w/4.5"Liner on 5"DP to 21,258'and pull up to setting depth.Baker to drop ball and set hanger/packer assy and test backside to 1500 psi.Release from hanger and POOH. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 7 IP PJSA Pump 85 bbls of viscosified spacer followed w/840 bbls 9.0 ppg KCL Brine @ 170 gpm,150 psi,50 rpm,13k tq, 195k puw,90k sow. 04:00 05:00 1.00 5.00 DRILL E 20 P Monitor well and clean surface equipment. 05:00 06:00 1.00 6.00 DRILL 'E 4 P PJSA POOH f/11,502'-9825'.200k puw,100k sow. 06:00 11:00 5.00 11.00 DRILL E 4 P PJSA C/O handling equipment to 4.5"and cont.POOH f/9825'-140'. 11:00 11:30 0.50 11.50 DRILL 'E 4 P PJSA L/D BHA#6. 11:30 12:00 0.50 12.00 DRILL 'E 20 P Clear and clean rig floor and prep.for Liner run.Toady fluid loss=86 bbls. 12:00 13:30 1.50 13.50 DRILL G 20 P PJSA w/GBR Casing.Load floor and R/U 4.5"Casing equipment. 13:30 00:00 10.50 24.00 DRILL 'G 4 P PJSA M/U Liner shoe to first jt.of liner.RIH w/4.5"11.6#,L-80,H521 Liner to 7350'.90k sow.Toady fluid loss=77 bbls. Daily Contacts Position Contact Name Company Title E-mail Office I- Mobile Eni representative I Jack Keener ENI "Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Sups. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268.9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rigt5 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrdling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 11,731.0 6/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) I Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal)JLeak Ott Pressure(psi) ' 11,746.0 3,746.15 OBM 9.40 730.0 13.151 2,559.3 If* Eni E&P Division 'Well Name:5119-FN2 ENI Petroleum Co.Inc. Daily Report Well Code: 27161 Field Name: NIKAITCHUQ • 2�, Date:6/25/2013 - Report#: 31 APIIUW1:5D 629-23487-00-00 II 'I page 1 of 1 Wellbore name. SI19-FN2 Well Header Permit/Concession N° I Operator ENI Share(00) 'Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(it) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) !Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) SI19-FN2 DRILLING 5/29/2013 3,982.0 2,454.0 21,238.00 118.02 180.0 27.98 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) 'Avg ROP(ft/hr) IPOB Temperature("F) Weather 'Wind 21,258.0 3,742.6 0.00 107.0 32.0 Cloudy,WC 22' NE @ 13 MPH Daily summary operation 24h Summary RIH 4.5"Liner as per K&M Schedule and Tally with GBR Reps onsite F/7,350'to 9,730'MD HST 135K,SLK 90K.Total 237 joints of 4.5"Liner in hole.Calculated displacement 13 bbl,actual displacement 14 bbl.Total fluid lost 27 bbl. M/U Liner Hanger Assy.as per Baker Hughes Rep onsite.Mix&pour PAL mix,M/U one stand&pump thru Hanger Assy.HST 136K,SLK 98K.Total fluid lost waiting for PAL mix to set 8 bbl. RIH 4.5"Liner on 5"D.P. as per K&M Schedule and Tally F/9,730'to 17,245'MD HST 200K,SLK 70K.Calculated displacement 61 bbl,actual displacement 15 bbl.Total of 80 stands of 5"D.P.in hole.SIMOPS clean Pits.RIH W/4.5"Liner on 5"D.P.as per K&M schedule and Tally F/17,245'to 19,575'MD Rebating 5"D.P.F/Derrick.HST 210K,SLK 70K.Begin rotating in hole @ 19,575'MD and tag bottom @ 21,258'MD RPM 30,TRQ 24K,ROT WT 140K.P/U to set depth @ 21,230'MD HST 232K.Drop ball and pump down @ 3 bpm 280 PSI,slow pumps to 2 bpm 160 PSI,Press.up to 3,000 PSI and hold for 5 Min.stage up to 4,000 PSI and hold for 5 Min.Bleed off Press.,close upper pipe rams&test Packer to 1,500 PSI for 10 Min.(Good)Bleed off Press&open pipe rams.Test witnessed by Company Rep onsite.P/U and unsling from Packer @ 11,469'MD and POOH to 11,235'MD HST 192K,SLK 90K.Monitor well for 10 Min.static loss 5-9 bph Cut and sip drilling line and adjust Brakes. POOH on Elevators F/11,235'to 6,150'MD HST 181K,SLK 103K.Calculated displacement 34 bbl,actual displacement 42 bbl.Lost 7 bbl on trip,total lost today 153 bbl. Operation at 07.00 R/U GBR and P/U M/U 4/5"Tubing BHA. 24h Forecast Cont.POOH 5"D.P.Pull Wear Ring.R/U GBR.P/U M/U Baker Tieback Assy and 4.5"Tubing BHA as per Hallibunon Rep onsite.RIH as per Tally and land 4.5"Tubing. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 03.00 3.00 3.00 DRILL G -4 P PJSA RIH 4.5"Liner as per K&M Schedule and Tally with GBR Reps onsite F/7,350'10 9,730'MD HST 135K,SLK 90K. Total 237 joints of 4.5"Liner in hole.Calculated displacement 13 bbl,actual displacement 14 bbl.Total fluid lost 27 bbl. 03:00 04 30 1.50 4.50 DRILL G 20 P PJSA M/U Liner Hanger Assy.as per Baker Hughes Rep onsite.Mix&pour PAL mix,M/U one stand&pump thru Hanger Assy.HST 136K,SLK 98K.Total fluid lost waiting for PAL mix to set 8 bbl. 04:30 1200 7.50 12.00 DRILL G 4 P PJSA RIH 4.5"Liner on 5"D.P. as per K&M Schedule and Tally F/9,730'to 17,245'MD HST 200K.SLK 70K Calculated displacement 61 bbl,actual displacement 15 bbl.Total of 80 stands of 5"D.P.in hole.Total lost to formation 81 bbl for this tour.Begin Rebating 5"D.P.in Derrick @ 11,548'MD stand#19 W/2.9"OD Rabbit.SIMOPS clean Pits. 12 00 100 5.00 17.00 DRILL G ' 7. 4 'P PJSA RIH W/4.5"Liner on 5"D.P.as per K&M schedule and Tally F/17,245'to 19,575'MD Rebating 5"D.P.F/Derrick. HST 210K,SLK 70K.Begin rotating in hole @ 19,575'MD and tag bottom @ 21,258'MD RPM 30.TRQ 24K,ROT WT 140K.P/U to set depth @ 21,230'MD HST 232K.Calculated displacement 34 bbl.actual displacement-5 bbl.Total lost 39 bbl. 17.00 1900 2.00 19.00 DRILL G '19 P PJSA Drop ball and pump down @ 3 bpm 280 PSI.slow pumps to 2 bpm 160 PSI.Press.up to 3,000 PSI and hold for 5 Min.stage up to 4.000 PSI and hold for 5 Min.Bleed off Press.,close upper pipe rams&test Packer to 1.500 PSI for 10 Min.(Good)Bleed off Press&open pipe rams.Test witnessed by Company Rep onsite. 19:00 19:30 0.50 19.50 DRILL G 19 P PJSA P/U and unsting from Packer @ TOP 11,469'MD and POOH to 11,235'MD HST 192K,SLK 90K.Monitor well for 10 MM.static loss 5-9 bph. 19:30 -21:00 1.50 21.00 DRILL G 20 P PJSA Cut and slip drilling line and adjust Brakes. 21:00 00:00 3.00 24.00 DRILL G 4 P PJSA POOH on Elevators F/11,235'to 6,150'MD HST 181K,SLK 103K.Calculated displacement 34 bbl,actual displacement 42 bbl.Lost 7 bbl on trip,total lost 72 bbl for tour. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @erupetroleumcom 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.corn 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15 @doyondrifling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 114694 212300 6/25/2013 Last Leakoff Test Depth(ftKB) lTVD(ftKB) Fluid Type 'Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11,746.01 3,746.15 OBM 940 730.0 13.15 2,559.3 • f Eni E&P Division (Wall Name:SI19-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • APIIUWI:50-629-23487-00-00 2^ Date:612612013 - Report#: 1 II II page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S119-FN2 COMPLETION 5/29/2013 29.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather red 0.0 107.0 54.0 Clear ESE @ 7 MPH Daily summary operation 24h Summary POOH on elevators F/6,150'to 0'MD.HST 76K,SLK 78K.Calculated displacement 57 bbl,actual displacement 85 bbl.Lost 28 bbl to formation.Monitor well.L/D HRD running tool as per Baker Hughes Rep onsite.Pull Wear Bushing as per Vetco Gray Rep onsite.Clean and clear Rig Floor.Have PJSM W/all essential personnel for running 4.5"Tubing.R/U to run 4.5"Tubing as per Tally.Fluid loss 26 bbl. Run 4.5"Tubing as per Tally,W/Halliburton and Baker Hughes Rep onsite Torque turn as per GBR Rep onsite F/0'to 5.888'to 11,469'MD.POOH to 11,404'MD and space out as per Halliburton Rep onsite.RIH 11,418'MD add 9.82'4.5"Pup.P/U M/U Hanger and landing joint as per Vetco Gray Rep onsite.Drain Stack and blow down lines.Land Hanger and drive down lock down screws.Land 4.5"Tubing @ 11,469.40'MD off 1.28'from No Go.HST 135K,SLK 98K.Total of 282 joints in hole.Total lost 161 bbl.R/U test Equip.to set Packer and Press.test tubing and IA. Test surface lines for tubing to 5,000 PSI.Test LA lines to 3,000 PSI.Press,up 4.5"Tubing to 1,200 PSI&hold for 5 Min.Auto Fill Valve closed @ 950 PSI.Cont.to Press.up 4.5"Tubing to set Packer.Packer set at 2,050 PSI and Cont.to Press.up to 3,600 PSI for 30 Min.Bleed 4.5"Tubing down to 2,300 PSI.Press.up IA to 2,500 PSI for 30 Min.Bleed down IA to zero.Press.up 4.5"Tubing F/2,300 PSI to 4,400 PSI and shear Mirage Plug.Press.up IA to 2,000 PSI and shear GLM.R/D&blow down lines.Pull Landing Joint as per Vetco Gray.Clear Rig Floor of Csg.Equip.P/U Tee bar and set BPV as per Vetco Gray Rep onsite. Install Mouse Hole&R/U to UD D.P.UD 6 joints of 5"D.P. Operation at 07.00 L/D 5"D.P. 24h Forecast L/D 5"&4.5"D.P. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 900 Time Log Start End 1 I Cum 1 Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02:30 2.50 2.50 DRILL G 4 P PJSA POOH on elevators F/6,150'to 0'MD.HST 76K.SLK 78K.Calculated displacement 57 bbl,actual displacement 85 bbl.Lost 28 bbl to formation.Monitor well.L/D HRD running tool as per Baker Hughes Rep onsite. 02:30 03:00 ' 0.50 3.00 COMP 'C 19 P -PJSA Pull Wear Bushing as per Vetco Gray Rep onsite. 03.00 04:00 ' 1.00 4.00 COMP 'K 20 P PJSA Clean and dear Rig Floor.Have PJSM W/all essential personnel for running 4.5`Tubing.R/U to run 4.5"Tubing as per Tally.Fluid loss 26 bbl. 0400 12:00 8.00 12.00 COMP 'K 4 P PJSA Run 4.5"Tubing as per Tally,W/Halliburton and Baker Hughes Rep onsite Torque turn as per GBR Rep onsite F/0' to 5,888'MD.Calculated displacement 27 bbl,actual displacement 58 bbl.Total fluid lost for Tour 85 bbl.Total joints in the hole 135. 12 00 19.30 ' 7.50 19.50'COMP K 4 P -PJSA RIH 4.5"Tubing as per tally F/5,888'to 11,469'MD.POOH to 11,404'MD and space out as per Halliburton Rep onsite.RIH 11,418'MD add 9.82'4.5"Pup.P/U M/U Hanger and landing joint as per Vetco Gray Rep onsite.Drain Stack and blow down lines.Land Hanger and drive down lock down screws.Land 4.5"Tubing @ 11,469.40'MD off 1.28'from No Go.HST 135K,SLK 98K.Total of 282 joints in hole.Calculated displacement 29.3 bbl,actual displacement-46.5 bbl total lost 76 bbl. l� 19:30 20:00 0.50 20.00 COMP 'K 20 P PJSA R/U test Equip.to set Packer and Press.test tubing and IA. Pr 20:00 22:30 - 2.50 22.50 COMP 'K 12 P 'PJSA Test surface lines for tubing to 5,000 PSI.Test IA lines to 3,000 PSI.Press.up 4.5"Tubing to 1,200 PSI&hold for 5� AA., Min.Auto Fill Valve closed @ 950 PSI.Cont.to Press.up 4.5"Tubing to set Packer.Packer set at 2,050 PSI and Cont.to Press.up to 3,800 PSI for 30 Min.Bleed 4.5"Tubing down to 2,300 PSI.Press.up IA to 2,500 PSI for 30 Min.Bleed down IA to zero.Press.up 4.5"Tubing F/2,300 PSI to 4,400 PSI and shear Mirage Plug.Press.up IA to 2,000 PSI and shear GLM. 22.30 23:30 - 1.00 23.50-COMP 'K 20 P PJSA R/D&blow down lines.Pull Landing Joint as per Vetco Gray.Clear Rig Floor of Csg.Equip.P/U Tee bar and set BPV as per Vetco Gray Rep onsite. 2330 00:00 0.50 24.00 COMP K 20 P PJSA Install Mouse Hole&R/U to L/D D.P.UD 6 joints of 5"D.P. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDdlling @enipetroleum.com 907.685-0715 715-5434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher ng15 @doyondrilling com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 4112 3.960 L80 11.469.4 21,230.0 6/25/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(11a/gall Leak Off Pressure(psi) 11.746.0 3,746.15 OBM 9.40 730.0 13.15 2.559.3 I� Eni E&P Division 'Well Name:5119-FN2 ENI Petroleum Co.Inc. Daily Report Well Code:27161 Field Name:NIKAITCHUQ • APIIUWI:50-629-23487-00-00 en11 Date:6/27/2013 - Report#: 2 II ') page 1 of 1 Wellbore name: SI19-FN2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-043 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 36.83 40.55 53.62 Rig Information Contractor Rig Name IRig Type DOYON DRILLING DOYON 15 1LAND RIG Job Information Wellbore Job Phase Spud Date 1Target Depth(ftKB) Target Depth)TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) S119-FN2 COMPLETION 5/29/2013 I 30.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours)hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 100.0 46.0 Mostly Cloudy N @ 6 MPH Daily summary operation 24h Summary L/D 5"D.P.from Derrick utilizing Mouse Hole.Total number 5"D.P.UD 282 joints.Total bad joints 2.C/O 5"D.P.handling Equip.to 4.5"D.P.handling Equip. UD 4.5"D.P.from Derrick utilizing Mouse Hole.Total 4.5"D.P.UD 306,total bad 93 joints. UD 4.5"D.P.from Denick utilizing Mouse Hole.Total 4.5"D.P.UD 306,total bad 93 joints.Transfer 13 stands 5"D.P.to DS in Derrick.Pull and UD Mouse Hole.N/D BOPE.SIMOPS R/D Suitcases on ODS&remove 4.5"D.P.from Pipe Shed. N/U Tree W/Vetco Gray Rep onsite.Test adapter void to 5,000 PSI for 10 Min.Test Tree 500 PSI for 5 Min.low,5,000 PSI for 15 Min.high all charted and witnessed by Company Rep onsite.SIMOPS R/D Suitcases ODS.Remove 4.5"D.P.from Pipe Shed.Well secure @ 24:00 with visual inspection by Vetco Gray,ACS and production Rep.Rig released 24:00. Operation at 07.00 Move Rig to SP36-W2 24h Forecast Move Rig to SP36-W2(THIS IS FINAL COMPLETION REPORT) Lithology 'Shows MAASP Pressure(psi) IMud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 COMP K '4 P PJSA UD 5"D.P.from Denick utilizing Mouse Hole,Total number 5"D.P.UD 282 joints.Total bad joints 2. 08:30 09:00 0.50 9.00 COMP K 20 P PJSA C/O 5"D.P.handling Equip.to 4.5"D.P.handling Equip. 09:00 17:30 8.50" 17.50 COMP K 4 P PJSA UD 4.5"D.P.from Derrick utilizing Mouse Hole.Total 4.5"D.P.UD 306,total bad 93 joints. 17:30 18:00 0.50 18.00 COMP 'K '4 P PJSA Transfer 13 stands 5"D.P.to DS in Derrick.Pull and UD Mouse Hole.• 18:00 20:30 2.50 20.50 COMP C 20 P PJSA N/D BOPE.SIMOPS R/D Suitcases on ODS&remove 4.5"D.P.from Pipe Shed. 20:30 00:00 3.50 24.00 COMP C 20 P PJSA N/U Tree W/Vetco Gray Rep onsite.Test adapter void to 5,000 PSI for 10 Min.Test Tree 500 PSI for 5 Min.low, 5.000 PSI for 15 Min.high all charted and witnessed by Company Rep onsite.SIMOPS R/D Suitcases ODS.Remove 4.5" D.P.from Pipe Shed.Well secure @ 24:00 with visual inspection by Vetco Gray,ACS and production Rep.Rig released 24:00. 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 Oliver Amend ENI Dolling Sup, 907-685-0715 Eni representative Satch Bowe ENI Mats Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Bitington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher og15 @doyondrtlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher Irig15 @doyondrdling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 11,469.4 21,230.0 6/25/2013 Last Leakoff Test Depth(ftKB) ITVD(ftKB) Fluid Type Fluid Density)Iblgal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 11.746.0E 3,746.15 OBM 9.40 730.0 13.15 2.559.3 - • • V° Q V O t+J N temp M 00 N U8) QPGp N N U)� 2O QNp 0 0 0 �D�2Q{r yyn rn �tN1tpp N N Q M R°"1:-.0 f7�0 V 0 0 Ot�rn QN .- J nA W W §XPi n OEmOW)� .73011a N1Ort0i .1mNciN mNg W NNNOn �1+J1�1NO0i O W N N N N N Nml+) 0Ae N�W N W mn�N 00..., 11111000 0.0 0. 0000. 0 0 0 0 0 N 0 0 O 3.000 W W W r r O W W W M M O M M p0.0,- G 8i8ioiSi8 888888 Sigi8S8 888888 88888 888888 88885 888888 mrnmrnm O "� 66666 of of 6 6 of 66666 6 6 of 6 of 66666 66666 of of 6 6 of 66666 66666 M e Q e.1 e 'resew., Q.1.1.1.1 .1 e e.1 e e v e e e v e e e e Q Q e.1 Q Q Q.1.1.1 e e.1.1.1 �1 , , . , . 1 . , . . . �1' , . pp , . . 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N N M• 00 M0 o N 00 0 N 0mCmp 0 ;j LL 61Mm+ln -g14 Q co,.. mp�� J W I J t7 W40 N W 111 CCppmm N E 42, 2 (0 0(400,7 0 m'-M N M ,R m o o "' 0 01 O 0,000) 'N N 0 3 r m 0 N N N N N N N N N N N N N N 0 m d W (0 o a 0 0 C J (G ° fV v E o m a 8 o 0 0 w a E ' r . C o Z Z '0 v (W N 0 y \o V7, • THE STATE Alaska Oil and Gas pf LASKA Conservation Commission� GOVERNOR SEAN PARNELL 333 West Seventh Avenue .■ Anchorage, Alaska 99501-3572 ALAS- Main: 907.279.1433 Fax: 907.276.7542 Davide Simeone Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300\ Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI19-FN2 ENI US Operating Co. Inc. Permit No: 213-043 Surface Location: 4455.8' FSL, 1342.7, FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 5153' FSL, 1472' FEL, SEC. 10, T14N, R8E, UM Dear Mr. Simeone: 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. Sincerely, Cathy P. oerster Chair DATED this 3 day of April, 2013. fiteZIVED STATE OF ALASKA MAR 15 20i3 AL. A OIL AND GAS CONSERVATION COMM, JN PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj 0• Single Zone 0• 1 c.Specify if well is proposed for: Drill • 0 Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627. SI19-FN2. 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 21284 • TVD: 3763' Nikaitchuq/Schrader Bluff 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number):3ggsg! Surface: 4455.8 FSL 1342.7 FEL S19 T14N R9E UM• ADL0391283;ADL0388574;ADL0388571;ADL0388572 ?iVI'J Top of Productive Horizon: 8.Land Use Permit: 13.(Approximate Spud Date: 3953 FSL 5269 FEL 13 T14N R8EUM _ ADL 417493 4/11/2013 Total Depth: 9.Acres in Property: o 14.Distance to Nearest Property: 5153 FSL 1472 FEL 10 T14N R8EUM -5760' 1 ■I 3 V 'C.0 \'� 550'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 54.1 feet- 15.Distance to Nearest Well Open Surface:x- 511567 y- 6053638 Zone- 4 t GL Elevation above MSL: 13.1 feet. to Same Pool: 1000'to SP16-FN3 16.Deviated wells: Kickoff depth: 200 feet- 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.35 degrees Downhole: 1542 psig Surface: 1168 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 1473 TOTAL sx 16" 13-3/8" 68 L-80 BTC 3575 35 35 3610 2454 LEAD:1265 sx 10.7 ppg ASL TAIL:208 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 11762 33 33 11795 3750 716 TOTAL sx 716 sx 12.5 ppg DeepCrete 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 9688 11595 3736 21284 3763 300 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 ND Conductor/Structural Surface Intermediate - Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 , BOP Sketch .i- • Drilling Program ../ ' Time v.Depth Plot _ Shallow Hazard Analysis Diverter Sketch 4-v Seabed Report ` Drilling Fluid Program ✓ 20 MC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 3/18/2013 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni 907-865-3328 Email Iuca.borri @enipetroleum.com Printed Name David Simeone Title Well Operation Project Manager Signature Phone (907)865-3320 Date 3/18/2013 Commission Use Only Permit to Drill API Number: Permit Approv�I t See cover letter for other Number: a 13 OL13 50-(0azq-e2_3 Li g� - 00 -0O Date: L{`V \ V 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: d Other*"c3c S` So P ---7 -----; ,--- Samples req'd: Yes❑ No[l Mud log req'd: Yes ❑ No E ',k c Q L P ( ( - (A to H2S measures: Yes❑ No Z Directional svy req'd: Yes L No❑ �t / L` 1 _ f paci i7 A(Dreq'3�es❑ No El Inclination-only svy req'd:Yes❑ No� l T D �/t i dL. tn... LL cL0/' c,J _- APPROVED BY Approved n: ' ! . -- COMMISSIONER THE COMMISSION Date: 4- -3 /3 L(-(• /3 -;/. nn qq0�\Submit Form and o Rn .A,,) This permit is valid for 24 months from the date of approval 2C 25.005(g))�VVVV! y�l s Enn 'tr • H um 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907)865-3323 Email: Davide.Simeone @enipetroleum.com March 18,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI19-FN2 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the Offshore Injector well SI19-FN2. This well will be drilled and completed using Doyon 15. The planned spud date could be as early as 4/11/2013. _ Please find attached for the review of the Commission forms 10-401 as well as the information required by 20 ACC 25.005. If you have any questions or require further information,please contact Luca Borri 907-865-3328. Sincerely, Davide Sim-one elll Op-rat o Project Manager 0.1;0tAo • • Eni Petrolleuim 2no Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 Application for Permit to Drill Document Injector Well S119-FN2 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please 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 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 8. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25 005(c)(9) 6 9. Seismic Analysis 7 Requirements of 20 MC 25.005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 10 Printed: 15-Mar-13 vot em • Enfl PetiroHeum Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 10. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 11. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 12. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 MC 25.005(c)(14) 9 14. Area of Review 9 15. Attachments 10 Attachment 1 Drilling Procedure 10 Attachment 2 Directional Plan 10 Attachment 3 Drilling Hazards Summary 10 Attachment 4 BOP and Diverter Configuration 10 Attachment 5 Cement Loads and CemCADE Summary 10 Attachment 6 Formation Integrity And Leak Off Test Procedure 10 Attachment 7 Surface Platt 10 Attachment 8 % Mile Scan Report 10 Attachment 9 Casing Design Program 10 AOGCC PERMIT Document.doe Page 2 of 10 Printed:15-Mar-13 J� 1 • En ' Petirolleuirn can Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 1. Well Name Requirements of 20 MC 25.005(i 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: SI19-FN2 2. Location Summary Requirements of 20 MC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4455.8 FSL 1342.7 FEL S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation feet'AMSL Northing: 6,053,638' Easting:511,567' Pad Elevation feet'AMSL Location at Top of Productive Interval 3953 FSL 5269 FEL 13 T14N R8EUM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 11,795' Northing: 6,058,406' Easting: 502,555' Total Vertical Depth, RKB: 3,750' Total Vertical Depth, 55: 3,696' Location at Total Depth 5153 FSL 1472 FEL 10 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 21,284' s Northing: 6,064,886' Easting: 495,786' Total Vertical Depth, RKB: 3,763' Total Vertical Depth, 55: 3,709' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 MC 25.050(6) 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 2: Directional Plan AOGCC PERMIT Document.doc Page 3 of 10 Printed: 15-Mar-13 r� 2rnn� Einii PtiroIkiuim Application for Permit to Drill SI 19-FN2 Saved: 15-Mar-13 (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (8)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(ROPE)as required by 20 AAC 25.035,20 MC 25.036, or 20 MC 25.037,as applicable; Please see Attachment 4: 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/fl:, 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 = (3,400'TVDss)(0.45 - 0.11 psi/ft) = 1168 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 appucauon fora Permit to urui must ye 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(0; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 10 Printed: 15-Mar-13 vitit enll Enff Petirolleuirn Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) ON (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 1607 160' Pre-Installed 1473 TOTAL sx LEAD: 1265 sx 10.7 ppg 13-3/8 16 68 L-80 BTC 3575' 35/ 35 3610'/ 2454' ASL TAIL: 208 sx 12.5 ppg DeepCrete 716 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 11762' 33/ 33 11795'/ 3750' 716 sx 12.5 ppg DeepCrete TOC: 9,489'MD/3,394'TVD 8-3/4"OA 4-1/2 Sand 11.6 L-80 Hydril 521 9688' 11595'/ 3736' 21284'/ 3763' Liner in Open Hole-no cement Lateral 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 4: BOP Configuration. AOGCC PERMIT Document.doc Page 5 of 10 Printed: 15-Mar-13 co* • Erni PtiroIItuim enll Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bent:onite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Densi (ppg) 8.7 -9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy �5 Funnel Viscosity CP) 45 - 60 (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 - 18 lb/100 sf) (CP) HTHP Fluid loss Yield Point (ml/30 mein <5.0 (lb/100 st) 18-24 200•si& 100°F API Filtrate 4 - 6 Oil/ Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/I) <500 Electrical >600 pH 9.0 - 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. AOGCC PERMIT Document.doc Page 6 of 10 Printed: 15-Mar-13 coos eng • Enli PtiroIIeum Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 9. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the and identified in the application: Please refer also to Attachment 1 — Drilling Procedure 1) Move in / rig up Doyon 15. 2) RU Diverter and test as per AOGCC requirements` 3) Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5) Install and test wellhead to 5000 PSI. 6) Nipple up 13-5/8" 5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 7) Pressure test casing to 2500 psi per AOGCC regulations. Record results. /3s/8 6-°''7" Sd� �wrs 8) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 11.00 ppg 10) Directionally drill to 9-5/8" casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. AOGCC PERMIT Document.doc Page 7 of 10 Printed: 15-Mar-13 • Eni Petrolleum ego Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 12) RU casing drive system. 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8" Emergency Slips. 15) Install 9-5/8" packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17) Pressure test casing to 3000 psi per AOGCC regula_ tions. Record results. 18) PU 8-3/4" bit and directional drilling assembliincluding MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 19) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 12.00 ppg 20) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 21) PU dumb iron assembly and TIH to TD 22) Displace well to 9.5 ppg FazeAway Delayed Breaker 23) POOH on elevators to intermediate casing shoe and displace to 9.0 ppg KCI brine. 24) POOH on elevators and LD BHA. RU to run 4-1/2" liner. 25) PU and run 4-1/2"liner to TD. Ensure cross over and FOSV is on the floor. 26) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8"intermediate casing. 27) Bleed DP pressure to zero, close annular and test annulus to 1500 psi for 10 min on chart. 28) POOH laying down DP as required. 29) RU tubing running equipment and run 4-1/2"tubing. Land tubing. 30)Test upper and lower seals to 5000 psi for 10 min. 31) RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. 32) Pressure down tubing string to 1200 psi to close autofill valve and monitor for leaks. 33) Increase pressure down tubing to 3,500 psi to set packer and hold for 30 minutes. Record on chart as tubing integrity test. Ensure inner annulus is open and monitor for returns. 34) Reduce tubing pressure to 2,000 psi. Rig up and pressure inner annulus to 2,500 and hold for 30 minutes. Record annulus pressure on chart as inner annulus integrity test. Bleed annulus pressure to zero. M 1"--$ 35) Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 36) Pressure inner annulus to 2,500 to shear valve in GLM. If valve does not open, cycle annular pressure from 0 to 2,500 psi several times while allowing tubing to bleed pressure. 37) Pull landing joint and set BPV. AOGCC PERMIT Document.doc Page 8 of 10 Printed: 15-Mar-13 a �\ 0151*• Enil PtiroIIeum 2n� Application for Permit to Drill SI19-FN2 Saved: 15-Mar-13 38) 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 AAC 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. r • Wellhead schematics should be on file with the AOGCC. 39) Pull BPV and set TWCV. 40) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree 4,€:5 to 5000 psi for 15 min. 41) Pull TWCV. 42) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 43) Set BPV and secure tree and wellhead. 44) RDMO ' 57i`�L� w�iNGSsE� n t - �J� • 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. 14. Area of Review Requirements of 20 MC 25 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 1/4 mile radius said herein have been drilled and completed in the Schrader Bluff formation in accordance with 20 AAC 25 AOGCC regulations. Please See attachment 8 — 1/4 Mile Scan Report AOGCC PERMIT Document.doc Page 9 of 10 Printed: 15-Mar-13 troio, • Enli PetiroHeum Application for Permit to Drill SI 19-FN2 Saved: 15-Mar-13 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Cement Loads and CemCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 % Mile Scan Report Attachment 9 Casing Design Program AOGCC PERMIT Document.doc Page 10 of 10 Printed: 15-Mar-13 en us operating WELL SI19-FN2 Drilling Procedure SI19-FN2 Spy Island Conductor slot #19 Reservoir location #FN2 Injector (Schrader Bluff) Nikaitchuq Project SI19-FN2 Drilling Wellplan Page 1 of 39 03/15/13 � i • 2no us op rahns WELL SI19-FN2 ItiAs Spy Island Nikaitchuq Field en° pe rrol*Um North Slope - Alaska SI19-FN2 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD TVD SIZE SPECS INFO Cement to Surface 20" ii o Hole Angle X-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A 0 GR/Res v Surface Csa Dir/PWD °a o 13-3/8" ° 680 MW(ppg) Wellbore Stability Mud Motor B/Permafrost 2,000' 1,779' L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning `2. Casing Sections KOP:200' ° Casing Wear DLS: Surface T/Tail Cement 3,156' 2,376' • 0-3.8°/100' •J • Hole Angle 80.18 Deg 13-3/8"Csg 3,610' 2,454' 16" 50°F WBM - GR/RES/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 86.00 Deg BHA Expense Intermediate TOC 9,489' 3,394' Pick-up Top of Sand i H Lu c a N Top 10,489' 3,627' O PHL Injection Packer 11,495' 3,829' gl Hole Angle TOL 11,595' 3,736' 2 app 86.00 Deg 9-5/8"Csg 11,795' 3,750' = r 12.25" 85°F _ WBM GR/RES Ec0SCOPE/PWD B 21 Wellbore Stability cuiatlon ICD Lind Hole Cleaning 4-1/2" Torque&Drag lig El 11.6# MW(Ppg) Casing Sections Cil Xceed 675 L-80,Hydril 521 8.7-9.4 Casing Wear ICD BHA Expense F4' ia ICD E El l Hole Angle 92.31 Deg 4 1/2"liner 21,284' 3,763' 8-3/4" 85°F MOBM SI19-FN2 Drilling Wellplan Page 2 of 39 03/15/13 411W eni US operrafi nng WELL SI19-FN2 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 29 ATTACHMENTS 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 SI19-FN2 Drilling Wellplan Page 3 of 39 03/15/13 IA 2rr110 us operrafins - WELL SI19-FN2 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 Pro2ram& 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 Pro2ram Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SI19-FN2 Drilling Wellplan Page 4 of 39 03/15/13 wio, ern ii us operrahng WELL SI19-FN2 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. SI19-FN2 Drilling Wellplan Page 5 of 39 03/15/13 2rn1 n us op rr tC ng WELL SI19-FN2 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPt) 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 D Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. D Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area D 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: D Assist in washing out surface casing hanger on cement jobs D Take returns to Vac trucks while cementing D Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SI19-FN2 Drilling Wellplan Page 6 of 39 03/15/13 em us operating WELL SI19-FN2 SURFACE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (5) True Formation Tops Measured Vertical Comments Depth, ft Depth, ft SV-4 775 769 SV-3 1159 1122 SV-2 1471 1378 B/Permafrost 2000 1779 SV-1 2206 1930 Ugnu Top(UG4) 2747 2246 13-3/8" Csg 3610 2454 SCP UG-2 Coal Bed Marker 5217 2728 Lower Ugnu 8700 3322 Schrader Bluff Top 10143 3568 N Sequence Top 10297 3594 N Top 10489 3627 ReCalc Intermediate Cement w/Actual N-2 Top 10521 3632 N-3 Top 10588 3642 N Bottom 10733 3663 N Sequence Base 11081 3699 9-5/8" Csg 11795 3750 ICP- Set ABOVE OA Sand Top OA Top 11867 3755 OA-2 Top 12029 3763 Total Depth 4 1/2" liner 21284 3763 SI19-FN2 Drilling Wellplan Page 7 of 39 03/15 13 •evil ass operrafi nng WELL SI19-FN2 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 diagram 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 (ppg) Reading Loss (mg/1) PH (ml/30min) 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) 0.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 SI19-FN2 Drilling Wellplan Page 8 of 39 03/15/13 r1� • 2nn us operreins WELL S I 19-FN2 Surface Hole Procedure: 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 D 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. • 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: D 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. SI19-FN2 Drilling Wellplan Page 9 of 39 03/15/13 1 2rn10 us operate - WELL SI19-FN2 • 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. SI19-FN2 Drilling Wellplan Page 10 of 39 03/15/13 eno us operr inng WELL SI19-FN2 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PPI) 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) Opt. OD WT Grade Conn.Type Make Up (in) (ppf) 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. I. 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 SI19-FN2 Drilling Wellplan Page 11 of 39 03/15/13 roks 2rn1u us op rrahngj WELL SI19-FN2 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock _ 2 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 rotary table. 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 +1- 18 13-3/8"Tandem Rise _ Weatherford J S119-FN2 Drilling Wellplan Page 12 of 39 03/15/13 VW* • en o us opperreonc - WELL SI19-FN2 Surface Centralizer Placement 10' 11101- 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 1"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. 8' 5' A SI19-FN2 Drilling Wellplan Page 13 of 39 03/15/13 2rn1� us operating WELL SI19-FN2 Surface Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Mudpush I1 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 541 bbls Yield 2.40 ft3/sk Tail Slurry (DeepCRETE) 58 bbls Density 12.5 ppg Top of Tail @ 3,156'MD Yield 1.56 ft/sk Surface Cementing Casing Cementing Notes 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. D 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 D 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: D Task one person to be in charge of monitoring for cement returns and volume of cement returns D 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. D Do not over displace the cement(no more than%2 the shoe joint volume). SI19-FN2 Drilling Wellplan Page 14 of 39 03/15/13 emm us operating WELL S119-FN2 ➢ 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 SI19-FN2 Drilling Wellplan Page 15 of 39 03/15/13 2rnl11 ass operr[ins WELL SI19-FN2 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. SI19-FN2 Drilling Wellplan Page 16 of 39 03/15/13 Tv* 2rnl� us oper inns WELL S119-FN2 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Formation Tops Measured Vertical Comments Depth, ft Depth, ft SV-4 775 769 SV-3 1159 1122 SV-2 1471 1378 B/Permafrost 2000 1779 SV-1 2206 1930 Ugnu Top(UG4) 2747 2246 13-3/8" Csg 3610 2454 SCP UG-2 Coal Bed Marker 5217 2728 Lower Ugnu 8700 3322 Schrader Bluff Top 10143 3568 N Sequence Top 10297 3594 N Top 10489 3627 ReCalc Intermediate Cement w/Actual N-2 Top 10521 3632 N-3 Top 10588 3642 N Bottom 10733 3663 N Sequence Base 11081 3699 9-5/8" Csg 11795 3750 ICP- Set ABOVE OA Sand Top OA Top 11867 3755 OA-2 Top 12029 3763 Total Depth 4 1/2" liner 21284 3763 SI19-FN2 Drilling Wellplan Page 17 of 39 03 15 13 1 2nd us operaHns WELL SI19-FN2 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 (mU3Omin) (%) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate 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) (ft.lbs) (ft Ibs) (ft.lbs) (gal/ft) (fps) 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. SI19-FN2 Drilling Wellplan Page 18 of 39 03/15/13 ern g u5 operrafing WELL SI19-FN2 Intermediate Drilling 1. Directionally Drill 12-1/4"hole ➢ Use the following Parameters: • Flow rate of 900 GPM • 120—140 RPM 2. Casine 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 Casinz 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-S 1: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. SI19-FN2 Drilling Wellplan Page 19 of 39 03/15/13 1 n us op rr t ns WELL SI19-FN2 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (pp� Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 10.625 8.835 Drift 3090 5750 916 563 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max. OD (!VT Grade Conn. Type Torque,Uft- Make Up Make Up Yield Torque lbs Torque Torque 9-5/8 40 L-80 5631 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: 1. 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 1/2"after the second torque application,continue running the rest of the string normally using the published target torque. D If the drawn line moves more than 1/2"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 1/2",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than 1/4",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%". SI19-FN2 Drilling Wellplan Page 20 of 39 03/15/13 en us operafing WELL S119-FN2 • 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 Hydroforms(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. SI19-FN2 Drilling Wellplan Page 21 of 39 03/15/13 los 2nd us operrfinng WELL SI19-FN2 Intermediate Centralizer Placement / G C1 , T 1.111 I Float I 9-5/8" x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. 111111 10' • No centralizer 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 fr'* km. I I a b A L 5' SI19-FN2 Drilling Wellplan Page 22 of 39 03/15/13 eni us operating WELL SI19-FN2 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9-5/8" Mudpush II 100 bbls Density 10.5 ppg DeepCrete 199 bbls Density 12.5 ppg Top of Cement @ 9,489'MD (716 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'A the shoe joint volume). c. For 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. 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 SI19-FN2 Drilling Wellplan Page 23 of 39 03/15/13 roi1/4 • 2rn1� us operat'ng WELL SI19-FN2 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ 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) ➢ 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) ➢ 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 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite SI19-FN2 Drilling Wellplan Page 24 of 39 03/15/13 ft* 2n11 GIs operahns WELL S119-FN2 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 D 120—140 RPM 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ 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 ➢ 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. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50'of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ 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 (attached). ➢ 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 SI 19-FN2 Drilling Wellplan Page 25 of 39 03/15/13 iffy* en us opera6ns WELL SI19-FN2 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Formation Tops Measured Vertical Comments Depth, ft Depth, ft SV-4 775 769 SV-3 1159 1122 SV-2 1471 1378 B/Permafrost 2000 1779 SV-1 2206 1930 Ugnu Top (UG4) 2747 2246 13-3/8" Csg 3610 2454 SCP UG-2 Coal Bed Marker 5217 2728 Lower Ugnu 8700 3322 Schrader Bluff Top 10143 3568 N Sequence Top 10297 3594 N Top 10489 3627 ReCalc Intermediate Cement w/Actual N-2 Top 10521 3632 N-3 Top 10588 3642 N Bottom 10733 3663 N Sequence Base 11081 3699 9-5/8" Csg 11795 3750 ICP- Set ABOVE OA Sand Top OA Top 11867 3755 OA-2 Top 12029 3763 Total Depth 4 1/2" liner 21284 3763 SI19-FN2 Drilling Wellplan Page 26 of 39 03/15/13 PYlik 2nD us operahng WELL S119-FN2 Production Mud Program: FazePro Density HTHP FL Electrical Interval (ppg) YP (mU30min) Oil:water Stability mlVolts Production 9.2 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/EcoSCOPE Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile WT Conn. Joint Body Torsion Torsional capacity Pipe (ppJ) Grade type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity ID(in) (Albs) (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 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. SI19-FN2 Drilling Wellplan Page 27 of 39 03/15/13 I en us operating WELL SI19-FN2 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 ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ 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 ➢ 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 it is 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. ➢ 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 ➢ When out of hole,down load the recorded tool data and send to the Geologist in town SI19-FN2 Drilling Wellplan Page 28 of 39 03/15/13 en1° us operreClins WELL S119-FN2 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(ppfi Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 4-1/2 11.6 L-80 H521 4.695 4.000 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Mm. Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield (in) (pp) 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 and FOSV is on the rig floor in case of a well control situation. • The liner will be run in FazeAway Delayed Breaker. 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: SI19-FN2 Drilling Wellplan Page 29 of 39 03/15/13 Iff* 2r110 us operrahns WELL SI19-FN2 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" 15.5#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,3 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. RIH 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. SI19-FN2 Drilling Wellplan Page 30 of 39 03/15/13 Iff* 2nll us operating WELL SI19-FN2 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, 6,795 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 ppg KC1 brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. SI19-FN2 Drilling Wellplan Page 31 of 39 03/15/13 Tv* 2n11 us operrafins WELL SI19-FN2 ATTACHMENTS 1. Recommended Drilling Practices 2. Health,Safety,and Environment 3. Safety Meeting P Meetin Topics 4. Well Shut In Procedure While Running Tubing 5. Conductor Broaching Contingency Plan 6. Port Collar Decision Tree SI19-FN2 Drilling Wellplan Page 32 of 39 03/15/13 n H us operaung WELL S119-FN2 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 RIH 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 find 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. SI19-FN2 Drilling Wellplan Page 33 of 39 03/15/13 em us operating WELL SI19-FN2 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. SI19-FN2 Drilling Wellplan Page 34 of 39 03/15/13 2n us operating WELL S119-FN2 Safety Meeting Topics Move In, Rig Up D 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. D 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. D Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. D 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 D 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. D Potential formation pressures and mud weight,Well control procedures. D Hole cleaning best practices,flow rates. D Stuck pipe,Lost circulation. D Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production D 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. D Hole cleaning best practices,flow rates. D Stuck pipe,Lost circulation. SI19-FN2 Drilling Wellplan Page 35 of 39 03/15/13 If* rnlEl �s operrang I WELL SI19-FN2 > Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion ➢ Operation of the control line spooler. ➢ Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. > Well control practices while running production tubing with control line. ➢ Pressure testing and minimizing personnel exposure to pressurized lines. SI19-FN2 Drilling Wellplan Page 36 of 39 03/15/13 •ertlo us operraIt nc WELL SI19-FN2 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 TIW 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. SI19-FN2 Drilling Wellplan Page 37 of 39 03/15/13 trot en �s opeir nng WELL SI19-FN2 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. SI19-FN2 Drilling Wellplan Page 38 of 39 03/15/13 PI* • 2no us operr Inns WELL SI19-FN2 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job - --- . __ No Cement Cement to to Surface Surface Drilling Foreman and Nipple Up and Engineer determine the X Test BOP's Top of Cement __I_ -I TV 1 Top f / `�--,-- Cement Cement Continue with above Port below Port Completion Collar / Collar (1000'TVD) / 1000'TVD) X Indicators of Cement Top Perform Top Job as per P-----------------------► Open Port Col- 1. Observation of Tracers in Spacer ahead of lead cement If To Job is ineffective or P requirements of using drillpi. 2. Calculated Displacement AOGCC unacceptable to AOGCC P 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface • Nipple Up and Circulate Ce Test BOP's to Surface a close Port Co • Continue with Nipple Up and Completion Test BOP's V Continue with Completion SI19-FN2 Drilling Wellplan Page 39 of 39 03/15/13 W n M W_ .-, NO NM Md m 'oN d o O m Q O N E N<T m N28In_ N h O b p r,i 0 Ii E NN mN N C,Ci EA MN Eyn m �!E rim OMOO _d NN NNN NNy�NN NNhNN NNy�NN NNNN N N NNNN N NNN y� NNN N N a 2 c m N v :=rvma v''°2n °ingP+ E22 n°n m',;;7:-'82.2 1:=Z7,22 2 22 1 Q 7 o X n R°A N ^ m n Obn f!!!! !!!!! �Nn Om !=222g1 N22 A _ O �!N CC mmmm W 7'tp:0 gggigM gfgA 1N ",0,M.2 r N N NNN M M M M M M MMM O O O O O N N N 2 b f7 O W C O N .t lQ o v W R 000 NI <roa'N NOp"NN 242104 W b,t r' 2 Y,m O M 8:22,1 C OMM MM,M V stNNNI? M N m m W 00 on=C (V f V�ry M M M M�.j M V O O y V V v a a a a a s.*a v a v a u i v S N N N N u g' G f, m O pp CID J c Q o 2 2 M !!2!! M NNN M !P!! E E E E E !,",'M'M M MMM n M M G Z O M r j M C C C G G ��.j CD CID e i s KKelKK .1Q ..r",M ;:::::N . 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Z .; �§ e � - - | • I .io ! - - ; {| \ ( � �CO CNI CO m \ ° § «< N Um2a=oleos S »> Sl hlumherger S119-FN2 (P5)Anti-Collision Summary Report (p(f n Analysis Date-24hr Time: March 11,2013-11:12 Analysis Method: Normal Plane Client: Eni Petroleum Reference Trajectory: 5119-FN2(P5)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(It) Structure: Spy Island Rule Set: O&M AmiColl'slon Standard S002 95.1(5.2 ' Slot: SP19 Min Pts: NI local minima indicated. Well: SI19-FN2 ■ Borehole: 8119-FN2 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude defintwe plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Del Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dec.(f t) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major S117-SE2(P2)(Del Plan) Fad Major 24.03 19.47 22.81 4.56 NIA MAS=5.94(m) 5.00 5.00 CtCt<=15m<15.00 Enter Alert MEM 19.47 22.0'MEM 28.04 MAS=5.94(m) 200.00 200.00 MinPts 19.42 19.47 1528 -0.05 6.23 MAS=5.94(m) 542.87 542.08 St0Rul=5.94 Enter Major Man 19.47 14.181 -0.501 4.95 MAS=5.94(m) 602.57 601.04 McPle 19.28 19.471 13.90 -0.21 4.36 MAS=5.94(m) 642.45 640.20 MINPT-O-EOU 19.42 19.47 13.92 -0.06 4,26 MAS=5.94(m) 852.43 649.98 SfcRul>5.94 Exit Major 22.52 19.47 15.81 3.0 11111/11MI MAS=5.94(m) 742.41 737.50 MinPt-OSF 48.75 19.47 38,88 29.27 5.50 MAS=5,94(m) 1035.17 1012.06 CtCt<=15m,15.00 Exit Alert 212.53 66.07 168.12 146.46 4.88 OSF 1.50 3012.97 2342.84 OSF<5.00 Enter Alert MIINEMIE 117.89 64.25 25.31 1.82 OSF 1.50 3168.78 2378.73 MinPt-CtCt 143.30 1182.man Implual 1.82 OSF 1.50 3171.55 2379.23 MinPIs 143.53 118.41 64.23 25.12 1.82 OSF 1.50 3174.29 2379.72 1.4iPt-OSF 25008 77.50 198.88 173.38 4.90 OSF 1.50 3276.81 2397.25 OSF,5.00 Exit Alert 645.00 36.50 620.31 608.50 27.26 OSF 1.50 3359.45 2411.34 TO MILE, 36.21 j OSF 1.50 3358.45 2411.33 MinPts SP22-FN1(Def Survey) Fel Myer 23.97 19.42 22.74 4.55 NIA MAO=5.92(m) 0.28 0.28 C1Ct<=15m<15.00 Enter Alert ® 19.42 20.7 - 17.16 MAS=5.92(m) 320.86 320.84 MinPts 23.34 19.4.IIIIIIIIII ljbE 3.92 15.86 MAS=5.92(m) 340.95 340.92 MINPT-O-EOU 29.88 19.4.IIIIIIIIII Efifi 10.46 4.42 MAS=5.92(m) 654.55 852.06 MINPT-D-EOU 31.41 19.42 22.82 11.9•MIME) MAS=5.92(m) 697.01 693.49 MinPFOSF 49.05 19.42 39.82 29.64 5.97 MAS=5.92(m) 981.59 963.22 CtCt<=15m>15.00 Exit Alert 57.12 18.42 46.94 37.7.Illllllllllll_ MAS=5.92(m) 1128.58 1095.38 MinPt-OSF 69.98 19.51 56.57 50.4 IIIIIIIIIEM OSF 1.50 1402.30 1323.94 MInPt-OSF 72.20 20.08 58,40 521.'ice OSF 1.50 1448.83 1380.02 MinPtASF 91.80 28.37 72.28 63.23 4.99 OSF 1.50 1813.40 1838.79 OSF<5.00 Enter Alert 66.37 67.47 20.99 -1.10 1.48 OSF 1.50 2652.94 2201.93 OSF<1.50 Enter Minor 51.05 77.38 -0.94 -26.33 0.98 OSF 1.50 2727.54 2237.43 OSF<1.00 Enter Major 31.88 95.82 -32.411 -63.941 0.49 OSF 1.50 2875.00 2297.96 MnPt-O-ADP 31.74 95.611 -32.41 43.88 0.48 OSF 1.50 2878.88 2299.74 MI5PT-O-EOU 31.64 95.31 -32.31 .83.68 jjjjjjjjjjjjjj OSF 1.50 2884.75 2301.51 MnPt-0SF Main 94.42 -31.80 -62.86 0.49 OSF 1.50 2894.50 2304.99 MinPt-CtCt 43.03 84.39' -0.31 -21.36 0.99 OSF 1.50 3009.95 2341.80 OSF>1.00 Ext Major 53.70 53.81 17.47 -0.11 1.50 OSF 1.50 3057.05 2354.42 OSF,1.50 Exit Minor 148.58 45.41 117.98 103.18 4.99 OSF 1.50 3356.25 2410.79 OSF,5.00 Exit Alert 243.45 73.85 193.88 189.60 5.00 OSF 1.50 3722.79 2473.28 OSF<5.00 Enter Alert 312.42 128.31 226.:MIME. 3.67 OSF 1.50 4253.34 2563.73 MinPt-0-ADP 355.89 152.33 249.00 198.5 MEW OSF 1.50 4595.73 2622.11 MnPtaSF 1002.44 301.42 801.17 701.02 5.00 OSF 1.50 9008.52 3374.43 OSF,5.00 Exit Alert 1299.52 348.99 1066.54 950. '.lam OSF 1.50 11034.67 3895.57 MnPt-04F 1244.08 367.43 998.80 876.65 ilti OSF 1.50 11919.88 3758.29 MnP[-0-SF 1236.72 363.90 993.7: 872.81 5.11 OSF 1.50 12025.24 3762.74 MnPt-0,4DP 1236.29 383.40k 993.6: 872.89 5.11 OSF 1.50 12038.42 3762.91 MINPT-O-EO6 MEW 369.95 987.16 864.17 5.01 OSF 1.50 12278.85 3763.17 MinPt-CtCt 1234.19 370.95 986.57 883.24 5.00 OSF 1.50 12308.80 3763.19 OSF<5.00 Enter Alert 1235.76 375.68 own 860.08 4.94 OSF 1.50 12433.56 3763.91 MINPT-D-EOU 1240.53 393.061 ! 857.47 4.87 OSF 1.50 12683.34 3766.17 MINPT-0-EOU IIKIEDIE 487.16 778.72 616.66 3.40 OSF 1.50 15311.47 3774.29 MinPt-C1Ct 1104.32 488.76IMEIFE 615.56 3.39 OSF 1.50 15358.47 3773.60 MINPT-O-EOU 1105.05 489.66 778.28 MEC 3.39 OSF 1.50 15381.46 3773.52 M.P1-0-4DP 111111/101 504.56 772.05 604.19 3.30 DSP 1.50 15696.28 3769.65 MinPt-CtCt 1108 49 509.65 768.39 598.83 3.27 OSF 1.50 15836.28 3767.80 MinPt-CtCt 1109.53 516.63M: 07 592.89 3.22 OSF 1.50 18041.68 3765.30 MINPT-O-EOU 1109.91 517.08 764.8,111111113:f3E 3.22 OSF 1.50 16063.87 3765.41 MnPt-O-ADP 1112.55 519.74 765.7'moil 3.21 OSF 1.50 16154.52 3767.33 MnPt-O-ADP 1140.12 538.1.IIIIIIII 23K' 802.01 3.18 OSF 1.50 16603.88 3776.12 MINPT-O-EOU 1145.49 548.9 MIMEO 598.57 3.13 OSF 1.50 16893.79 3771.91 MINPT-D-EOU MEM11 566.60 769.70 580.49 3.03 OSF 1.50 17389.43 3765.91 MinPt-CtCt MI= 615.68 677.26 472.36 2.65 OSF 1.50 18666.48 3754.54 MinPt-CtCt 1088.04 615.7 677.24 472.34 2.65 OSF 1.50 18669.93 3754.57 MINPT-O-EOU 1086.06 615.73 677.25 472.33 2.65 OSF 1.50 18673.38 3754.60 Min%-0-ADP 1088.08 615.75 677.26 472.341 2 651 OSF 1.50 18676.83 3754.63 MinP1-0SF 1089.33 617.723MMIR 471.61 2.65 OSF 1.50 18740.53 3755.06 MINPT-O-EOU 1090.92 619.62 677.51=He 2.64 OSF 1.50 18790.50 3755.39 MinP10-ADP 1095.33 624.42 678.72 MIMI 2.63 OSF 1.50 18920.38 3756.23 MnPt-O-ADP 1097.90 626.25 680.07 471.65® OSF 1.50 1897029 3756.56 MinPt-OSF 1115.59 639.30 689.0 IIIIIII=jjj® OSF 1.50 19239.05 3759.51 MinPts 1249.03 675.98 798.05 573.05®, OSF 1.50 20170.91 3779.82 MinPt-O-SF 1470.41 718.85 990.85 751.56 3.07 OSF 1.50 21283.50 3762.80 TD SP22-FN 1 PB4(Def Survey) Fai Major 23.97 19.42 22.74 4.55 N.rA MAO=5.92(m) 0.28 0.28 CtCt<=15m<l5.00 Enter Alert MEM 19.42 20.7 1111111111113;L''' 17.16 MAS=5.92(m) 320.86 320.84 MinPts 23.34 19.4.MECE 3.92 15.66 MAS=5.92(m) 340.95 340.92 MINPT-O.EOU 29.88 19.4.MEM 10.46 4.42 MAS=5.92(m) 654.55 652.06 MINPT-O-EOU 31.41 19.42 22.82 11.9 1111111111113fI MAS=5.92(m) 697.01 693.49 MnPt-OSF 49.05 19.42 39.82 29.64 5.97 MAS=5.92(m) 981.59 963.22 CtCt<=15m)15.00 Exit Alert 5712 19.42 46.94 37.7.IIIIIIIIIIII. MAS=5.92(m) 1128.58 1095.38 MnPt-O-SF 8098 19.51 56.57 50.4 IIIIIIIIIIII.3r" OSF 1.50 1402.30 1323.94 MnPt-DSF 72.20 20.08 58.40 52.1'NOM OSF 1.50 1448.63 1380.02 MnPt-OSF 91.60 28.37 72.28 63.23 4.99 OSF 1.50 1813.40 1638.79 OSF<5.00 Enter Alert 66.37 67.47 20.99 -1.10 1.48 OSF 1.50 2652.94 2201.93 OSF<1.50 Enter Minor 51.05 77.38 -0.94 -26.33 0.98 OSF 1.50 2727.54 2237.43 OSF<1.00 Enter Major 31.88 95.82 -32.41 mu= 0.49 OSP 1.50 2875.00 2297.96 MnPI-O-ADP 31.74 95.61=MB 43.88 0.48 OSF 1.50 2879.88 2299.74 MINPT-O-EOU 31.64 95.31 -32.31 63.8: 7E0 OSF 1.50 2884.75 2301.51 MnPt-D-SF giLEI 94.42 -3100 -62.86 0.49 OSF 1.50 2894.50 2304.99 MinPt.CtCt Drilling Office 2.6.1166.0 43.03 64.39 -0.31 -21.36 Nile@Rtithuq\Spfs9S4dd\SPP9 Y N2\S1161FN2\SI19-FN2(P5) osF,1.63/11/2013 44MoVAM Page 1 of 12 Offset Trajectory I Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(R) Den.(ft) Fact. Rule MD(ft) I ND(ft) Alert I Minor I Major 53.70 53.81 17.47 -0.11 1.50 OSF 1.50 3057.05 2354.42 OSF>1.50 Exit Minor 148.58 45.41 117.96 103.18 4.99 OSF 1.50 3356.25 2410.79 OSF>5.00 Exit Alen 243.45 73.85 193.88 169.60 5.00 OSF 1.50 3722.79 2473.28 OSF55.00 Enter Alert 312.42 128.31 226..mom, 3.67 OSF 1.50 4253.34 2563.73 MnPt-O-ADP 350.89 152.33 249.00 198.5 3.4 OSF 1.50 4595.73 2622.11 MnPt-0-SF 1002.44 301.42 801.17 701.02 500 OSF 1.50 9008.52 337443 OSF>5.00 Exit Alert 1299.52 348.99 1066.54 950.541 5.601 OSF 1.50 11034.67 3695.57 MnPt-OSF 1244.08 387.43 998.80 876.65 5.091 OSF 1.50 11919.96 3758.29 M.rP8-0SF 1236.72 363.90 993.7 872.81 5.11 085 1.50 12025.24 3762.74 MnPt-0-ADP 1236.29 363.4 993.6 872.89 5.11 OSF 1.50 12038.42 3762.91 MINPT-O-EOU 369.95 987.16 864.17 5.01 OSF 1.50 12278.85 3763.17 MinPtCtCt 1234.19 370.95 986.57 863.24 5.00 OSF 1.50 12308.80 3763.19 OSF55.00 Enter Alert 1235.76 375.68'= 860.08 4.94 OSF 1.50 12433.58 3763.91 MINPT-0EOU 1240.53 383.061 857.47 4.87 OSF 1.50 12663.34 3766.17 MINPT-0-EOU J 487.16 778.72 616.66 3.40 OSF 1.50 15311.47 3774.29 MnPFCICt 1104.32 488.76r 78.151 615.569 3.39 OSF 1.50 1535647 3773.80 MINPT-O-EOU 1105.05 489.66 778.28! 615.3911 3.39 OSF 1.50 15381.46 3773.52 MiPt-0ADP Ir 1108 751 504.56 772.05 604.19 3.30 OSF 1.50 15696.29 3769.65 M.rPICICt Ile 1108.491 509.85 768.39 598.83 3.27 OSF 1.50 15836.28 3767.80 MnPI-CtCt 1109.53 516.8 MEM 592.89 3.22 OSF 1.50 18041.68 3785.30 MINPT-0-EOU 1109.91 517.08 764.86 MIME, OSF 1.50 16063.87 3765.41 MInPt-0-ADP 1112.55 519.74 765.73 M:11M 3.21 OSF 1.50 18154.52 3767.33 MinPl-0ADP 1140.12 538.1-=ME 602.01 3.18 OSF 1.50 18603.88 3776.12 MINP1-0-EOU 114549 548.92.E 598.57 3.13 OSF 1.50 16893.79 3771.91 MINPT-0EOU 1 1149.091 588.60 769.70 580.49 3.03 036 1.50 17389.43 3765.91 MEP8-CIC8 I 1088.041 615.68 677.26 472.38 2.65 OSF 1.50 18666.48 3754.54 MnPFCtCt 1088.04 615.701.02M 472.34 2.65 086 1.50 18669.93 3754.57 MINPT-0-EOU 1088.06 615.73 677.25=MI 2.65 086 1.50 18673.38 3754.60 MinP40.4DP 1088.08 615.75 677.26 472.34 .- OSF 1.50 18676.83 3754.63 MinPWSF 1089.33 817.7.1'' 471.61 2.85 OSF 1.50 18740.53 3755.06 MINPT-0-EOU 1000.92 819.82 877.51 471.301 2.64 OSF 1.50 18790.50 3755.39 MnPt-0ADP 1005.33 624.42 678.7. 470.91 2.63 OSF 1.50 18920.38 3756.23 MnP40,ADP 1007.80 626.25 680.07 471.65 2.6 OSF 1.50 18970.29 3756.56 Mn19404F 1115.59 639.30 889.071 ' 476.29. 2.6 OSF 1.50 19239.05 3759.51 MnPt MEM 718.371 911.92 672.79 2.91 OSF 1.50 21283.50 3762.80 MnPle SP22-FN1PBI(Del Survey) FY Major 23.97 19.42 2274 4.55 N/A MAS=5.92(m) 0,28 0.28 CtCt<=15m515.00 Enter Alert 19.42 20.7 3.8, 17.16 MAS=5.92(m) 320.86 320.84 MnPts 23.34 19.4 MOE 3.92 15.66 MAS=5.92(m) 340.95 340.92 MINPT-O-EOU 29.88 19.4. j 10.46 4.42 MAO=5.92(m) 854,55 652.06 MINPT-O-EOU 31.41 19.42 22.82 11.9x,1111111CM MAS=5.92(m) 697.01 693.49 MnPt-0SF 49.05 10.42 39.82 29.64 5.97 MAS=5.92(m) 981.59 963.22 CtC15a15m>15.00 Exit Alert 57.12 19.42 48.94 37.7.■Zj MAS=5.92(m) 1128.58 1095.38 McPtQSF 69.98 19.51 56.57 50.4 NEM OSF 1.50 1402.30 1323.94 McPt-0-SF 72.20 20.08 58.40 52.1. OSF 1.50 1448.63 1360.02 MnPt-0SF 91.60 28.37 72.28 63.23 4.99 OSF 1.50 1813.40 1638.79 OSF55.00 Enter Alert 88.37 67.47 20.99 -1.10 1.48 OSF 1.50 2852.94 2201.83 OSF51.50 Enter Minor 51.05 77.38 -0.94 -28.33 0.98 OSF 1.50 2727.54 2237.43 OSF51.00 Enter Major 31.88 95.82 -32.41 .83.941 0.49 OSF 1.50 2875.00 2297.96 MnPt-0-ADP 31.74 95.611 42.41 .63.88 0.48 0561.50 2879.88 2299.74 MINPT-0EOU 31.64 95.31 42.31 63.• OSF 1.50 2884.75 2301.51 MnP[-0SF MINEEKE 94.42 41.80 62.86 0.49 OSF 1.50 2894.50 2304.99 MinPt-CtCt 43.03 64.39 -0.31 -21.36 0.99 OSF 1.50 3009.95 2341.80 OSF>1.00 Exit Major 53.70 53.81 17.47 -0.11 1.50 OSF 1.50 3057.05 2354.42 OSF>1.50 Exit Minor 148.58 4541 117.96 103.18 4.99 OSF 1.50 3356.25 2410.79 OSF>5.00 Eat Alert 243.45 73.85 193.86 109.80 5.00 OSF1.50 3722.79 2473.28 OSF55.00 Enter Alert 312.42 128.31 226..MEM, 3.87 OSF 1.50 4253.34 2583.73 MinPt-0-ADP 350.89 152.33 249.00 198.5-mil• 0561.50 4595.73 2822.11 MnPt-0-SF ' 1002.14 301.42 801.17 701.02 5.00 OSF 1.50 9008,52 3374.43 OSF>5.00 Eat Alert 1299.52 348.99 1066.54 950.5- ( OSF 1.50 11034.87 3895.57 MnPt-0SF 1244.08 387.43 998.80 87665® OSF 1.50 11919.98 3758.29 MnPt-0SF 1238.72 363.90 993.79 5.11 OSF 1.50 12025.24 3762.74 McPt-0-ADP 1238.29 363.4.WIME 872.89 611 OSF 1.50 12038.42 3762.91 MINPT-0EOU MIME 369.95 987.16 864.17 5.01 OSF 1.50 12278.85 3783.17 MnPtCtCt 1234.19 370.95 986.57 86324 5.00 OSF1.50 12308.80 3763.19 OSF55.00 Enter Alert 1235.76 375.6, 860.08 4.94 OSF 1.50 12433.56 3763.91 MINPT-0EOU 1238.39 379.5 IMMO 858.86 4.90 OSF 1.50 12553.41 3765.09 MINPT-0-EOU 1239.70 381.11 985.3•WEE, 4.89 OSF 1.50 12803.30 3765.58 MiP1-0ADP 1251.90 388.57 992.53 833.' tin OSF 1.50 12897.55 3767.89 MnP1-04F MEM 413.37 945.48 808.01 4.44 OSF 1.50 1987720 3794.08 Mn141-C1Ct 1222.04 415.3 11111111=1 806.69 4.42 OSF 1.50 13737.19 3794.29 MINPT-0-EOU 122174 444.821MMIMIMEIMMISE OSF 1.50 13807.13 3794.53 MinPls SP22-FNIPB3(Def Survey) Fail Major 23.97 19.42 22.74 4.55 N/A MAS=5.92(m) 0.28 0.28 CtCt<=15m<15.00 Enter Alert NEM 19.42 20.75= 17.16 MAS=5.92(m) 320.86 320.84 MinPts 23.34 19.4.' '".., 3.92 1566 MAS=5.92(m) 340.95 340.92 MINPT-0-EOU 29.88 19.4. EIEKE 10.46 4.42 MAS=5.92(m) 654.55 652.06 MINPT-0-EOU 31.41 19,42 22.82 11.991 4.10i1 MAS=5.92(m) 697.01 693.49 MnPt-0SF 49.05 19.42 39.82 29.64 5.97 MAS=5.92(m) 981.59 963.22 CtCt5=15m>15.00 Exit Alert 57.12 19.42 46.94 37.7.MEM MAS=5.92(m) 1128.58 1095.38 MnPtOSF 69.98 19.51 56.57 50.4 1.1.21M OSF 1.50 1402.30 1323.94 MnP14SF 72.20 20.08 58.40 521.MIIII'' OSF 1.50 1448.63 1360.02 MnPI-0SF 91.60 28.37 72.28 83.23 4.99 OSF 1.50 1813.40 1638.79 OSF55.00 Enter Alert 66.37 67.47 20.99 -1.10 1.48 OSF 1.50 2652.94 2201.93 OSF51.50 Enter Minor 51.05 77.38 -0.94 -26.33 0.98 OSF 1.50 2727.54 2237.43 OSF51.00 Enter Major 31.88 95.82 42.41=EI1E 0.49 OSF 1.50 2875.00 2297.96 MnPF6ADP 31.74 95.61® 63.88 0.48 OSF 1.50 2879.88 2299.74 MINPT-0EOU 3164 95.31 -32.31 63.6 ■ OSF 1,50 2884.75 2301.51 MinPt-0SF IL 3r.55i1 94.42 41.80 62.86 0.49 OSF 1.50 2894.50 2304.99 MinPt-CtCt 43.03 84.39 -0.31 -21.36 0.99 OSF 1,50 3009.95 2341.80 OSF>1.00 Exit Major 53.70 53.81 17.47 -0.11 1.50 OSF 1.50 3057.05 2354.42 00601.50 Eat Miter 148.58 45.41 117.96 103.18 4.99 OSF 1.50 3356.25 2410.79 00F>5.00 Exit Alert i 243.45 73.85 193.86 169.60 5.00 0561.50 3722.79 2473.28 OSF55.00 Enter Alert 312.42 128.31 226..=Mt 3.67 OSF 1.50 4253.34 2563.73 MnP1-0ADP 350.89 152.33 249.00 198.5 Mtn OSF 1.50 4595.73 2622.11 MnPt-0SF 1002.44 301.42 801.17 701.02 5.00 OSF 1.50 9008.52 3374.43 OSF>5.00 Exit Alert 1299.52 348.99 1066.54 950. ' 5.6. OSF 1.50 11034.67 3695.57 MnP90-SF 1244.08 367.43 998.80 876.6 5.0' OSF 1.50 11919.96 3758.29 Mnp1-04F 1236.72 363.90 993.79= 5.11 OSF 1.50 1202524 3762.74 MnFI-0-ADP 1236.29 383.4. 993.69 87289 5.11 OSF 1.50 12038.42 3762.91 MINPT-0-EOU MEM 369.95 987.16 864.17 5.01 OSF 1.50 12278.85 3763.17 MnPtC1Ct 1234.19 370.95 986.57 863.24 5.00 OSF 1.50 12308.80 3763.19 OSF<5.00 Enter Alert 1235.78 375.6 WIffil 860.08 4.94 OSF 1.50 12433.56 3763.91 MINPT-0-EOU 1240.53 383..MEME 857.47 4.87 OSF 1.50 12663.34 3766.17 MINPT-0EOU C®. i 487.16 778.72 616.66 3.40 OSF 1.50 15311.47 3774.29 MnF-CtCt 1104.32 488.7:111111FEMI 615.56 3.39 OSF 1.50 15356.47 3773.80 MINPT-0E05 1105.05 489.66 77828'11111BSEI 3.39 OSF 1.50 15381.48 3773.52 MnPt-0-ADP Drilling Office 2.6.11661 110874 504.56 77265 604.19 Nikh ifchug\SffFs4LIHd\SNQ5-PN2\ST1 N2\SI19-FN2(P5) 3/11/2013m1"P S4M Page 2 of 12 Offset Trajectory MllrnrnllMMIII o. Sap. Controlling INIMMIZTEM Ris.. Alert Status t1MENZIETTII Dev.ft Fact. Role 11112TMEME Alert Minor 1 Major 1 110849j 509.65 768.39 59183 3.27 OSF 1.50 15838.28 3767.80 MInPtCtCt 1109.53 518.631, 592.89 3.22 OSF 1.50 18041.68 3765.30 MINPT-O-EOU 1109.91 517.08 764.86 r'r 3.22 OSF 1.50 18083.87 3785.41 M6Pt-0-ADP 1112.55 519.74 76573 MERE 3.21 OSF 1.50 18154,52 3767.33 MInP1.-0-ADP 1140.12 538.12®. r 602.01 3.18 OSF 1.50 16803.88 3778.12 MINPT-O-EOU 1145.49 548.92 MEM 596.57 3.13 OSF 1.50 18893.79 3771.91 MINPT-0-EOU II 1149.0911 568.60 769.70 58049 3.03 OSF 1.50 17389,43 3765.91 MInPtCtCt 1150.23 574.43 766.95 57580 3.01 OSF 1.50 17549.40 3764.21 MINPT-O-EOU 1150.97 575.33 767.09=ME 3.00 OSF 1.50 17574.37 3763.95 MnPt-0-ADP 1151.57 575.86 767.34 5757 11111111113E OSF 1.50 17589,27 3783.79 MinPt-0SF II 1163321 637.591 737.9411 5257311 2.74 OSF 1.50 18771.61 3755.27 MinPta SP22-FN1 P82(Def Survey) FY Moor 23.97 19.42 22.74 4.55 N/A MAS=5.92(m) 0.28 0.28 CtCt<=15m<15.00 Enter Alert 19.42 20.7 17.16 MAS=5.92(m) 320.86 320.84 MinPts 23.34 19.4 ' 20.7. 3.92 15.66 MAS=5.92(m) 340.95 340.92 MINPT-0-EOU 29.88 19.421 22.1 10.46 442 MAS=5.92(m) 654.55 652.06 MINPT-0-EOU 31.41 19.42 22.82 11.99 4.101 MAS=5.92(m) 697.01 693.49 MnPFO-SF 49.05 19.42 39.82 29.64 5.97 MAS=5.92(m) 981.59 983.22 CtCt<=15m;15.00 Exit Alert 57.12 19.42 46.94 37.7 6.24 MAS=5.92(m) 1128.58 1095.38 MnPt-OSF 69.98 19.51 56.57 50.4 564 OSF 1.50 1402.30 1323.94 MnPt-O-SF 72.20 20.08 58.40 52.1 1641 OSF 1.50 1448.63 1360.02 MInPt-OSF 91.60 28.37 72.28 63.23 4.99 OSF 1.50 1813.40 1638.79 OSF<5.00 Enter Alert 66.37 67.47 20.99 -1.10 1.48 OSF 1.50 2652.94 2201.93 OSF<1.50 Enter Minor 51.05 77.38 -0.94 -26.33 0.98 OSF 1.50 2727.54 2237.43 OSF<1.00 Enter Major 31.86 95.82 32.41 .63.941 0.49 OSF 1.50 2875.00 2297.98 MnPI-0-ADP 31.74 95.611 -32.41 -63.88 0.48 OSF 1.50 2879.88 2299.74 MINPT-O-EOU 31.64 95.31 -32.31 -83.68 OSF 1.50 2884.75 2301.51 MnPt-O-SF 94.42 -31.80 -82.86 0.49 OSF 1.50 2894.50 2304.99 MinPtCtCt 43.03 64.39 -0.31 -21.36 0.99 OSF 1.50 3009.95 2341.80 OSF;1.00 Exit Major 53.70 53.81 17.47 -0.11 1.50 OSF 1.50 3057.05 2354.42 OSF;1.50 Exit Minor 149.58 45.41 117.96 103.18 4.99 OSF 1.50 3356.25 2410.79 OSF>5.00 Exit Alert 243.45 73.85 193.86 169.60 5.00 OSF 1.50 3722.79 2473.28 OSF<5.00 Enter Alert 312.42 128.31 228.5;� 3.67 OSF 1.50 4253.34 2563.73 MinPt-0-ADP 350.89 152.33 249.00 198.5 ICI OSF 1.50 4595.73 2622.11 MnPPOSF 1002.44 301.42 801.17 701.02 5.00 OSF 1.50 9008.52 3374.43 OSF;5.00 but Alert 1299.52 348.99 1066.54 950. • q�. OSF 1.50 11034.67 3695.57 MnPt-0-SF• 1244.08 367.43 996.80 876.6', 2 OSF 1.50 11919.96 375829 MinPt-OSF 1236.72 363.90 993.79 872.811 5.11 OSF 1.50 12025.24 3762.74 MinPtC-ADP 1236.29 363.4. 993.61 872.89 5.11 OSF 1.50 12038.42 3762.91 MINPT-O-EOU MitallEi 369.95 987.16 864.17 5.01 OSF 1.50 12278.85 3763.17 MinPt-CtCt 1234.19 370.95 986.57 863.24 5.00 OSF 1.50 12308.80 3763.19 OSF<5.00 Enter Alert 1235.76 375.6 984.98 860.08 4.94 OSF 1.50 12433.56 3763.91 MINPT-O-EOU 1240.53 383.061 984 83 857.47 4.87 OSF 1.50 12663.34 3766.17 MINPT-0-EOU U 1181621 458.80 87143 724.82 187 OSF 1.50 14747.76 3788.23 MnPt-CtCt 1184.26 480.6'1..4 723.67 3.86 OSF 1.50 14798.23 3786.16 MINPT-O-EOU 1185.03 461.49 877.5 1.1117130 3.86 OSF 1.50 14823.18 3785.13 Mi1P1-9-ADP II 1177 331 491.74 849.18 685.59 160 OSF 1.50 15426.03 3773.03 MltPI-CtCl 1177.74 492.9;=am 684.76 3.59 OSF 1.50 15461.02 3772.64 MINPT-0-E00 ®I 532.4,MEM 1111112ZETWEI OSF 1.50 15818.38 3768.04 MnPts 5120-N4PB1(Def Survey) Warring AMt 6.6 6.811 1.361 N/A MAS=2.03(m) 0.11 0.11 CtC1<=15m<15.00 Enter Alert 8.16 6.67 6.561 1,49 18.44 MAS=2.03(m) 150.11 150.11 MINPT-O-EOU 11.65 6.67 9.31 4.98- MAO=2.03(m) 299.90 299.89 MnPt-OSF 48.16 6.67 44.23 41.48 17.36 MAS=2.03(m) 483.58 483.22 Ctet<=15m>15.00 Exit Alert 2729.12 46.61 2697.69 2682.51 M.'.3, OSF 1.50 244747 2088.48 MnPt-OSF 6120•N4(Def Survey) %Wring AMR 6.6 8.81 1.361 NiA MAS=2.03(m) 0.11 0.11 C1Ct<=15m<15.00 Enter Alert 8.16 6.67, 6.561 1.49 18.44 MAS=2.03On) 150.11 150.11 MINPT-O-EOU 11.65 6.67 9.31 4.9.l�"1 MAS=2.03(m) 299.90 299.89 MnPt-OSF 48.16 6.67 44.23 41.48 17.38 MAS=2.03(m) 483.58 48322 Clet<e15rn>15.00 Exit Alert 1809.03 17.15 1797.24 1791.8;MOM OSF 1.50 2102.42 1855.48 MnPt-OSF 1604.04 31.00 1583.01 1579.. ' OSF 1.50 3174.79 2379.81 MnPt-O-OF 1®" 83.51 1315.09 1287.58 24.90 OSF 1.50 511423 2710.50 MnPtCtCI E 107.38 1291.10 1255.64 19.20 OSF 1.50 5506.47 2777.37 MnPFCtCt 1966.80 118.7 MEM 1248.08 17.40 OSF 1.50 5883.62 2807.58 MINPT-O-EOU 1375.15 132.3 MIME 1242.80 15.69 OSF 1.50 588620 2842.11 MINPT-O-EOU 1377.84 135.57 1267.13 MIME§ 15.35 OSF 1.50 5936.21 2850.64 Mn%-0-ADP 1833.72 280.09 1646.66 1553.6' lIE OSF 1.50 8788.53 3336.92 MIrPt-0SF 1905.03 290.74 1710.88 1614.2•iii OSF 1.50 9034.45 3378.85 Mi1Pt-0SF 2008.92 304.90 1805.32 1704.01 fll OSF 1.50 9379.15 3437.61 MnPt-OSF 2190.90 360.1 MEE=MEM OSF 1.50 9953.10 3535.47 MinPte SP18-N5(Def Survey) Waning Alert MEM 13..,MIKEllMELEI WA MAS=3.98(m) 0.23 0.23 ClCt<=15m<15.00 Enter Alert 16.40 13.06®' 3.33 17.40 MAO=3.98(m) 220.13 220.13 MINPT-O-EOU 22.03 13.06 18.95 8.97 I®' MAO=3.98(m) 374.01 373.95 MFPt-OSF 48.28 13.06 43.92 35.22 15.02 MAS=3.98(m) 533.43 532.72 CICt<=15m;15.00 Exit Alert 1751.34 58.83 1711.76 1692.51 Main OSF 1.50 1627.63 1497.54 MnPR0.SF ( 2192 411 97.45 2127.11 2094.95 3407 OSF 1.50 3171.51 2379.22 MnPt-CtCt j 2196.581 134.86 2106.35 2061.72 24.60 OSF 1.50 3756.28 2478.99 MnPt-CtCt 2199.09 142.8 2056.46 2128 OSF 1.50 3874.00 2499.06 MINPT-O-EOU 2199.70 143.27 2103.:,MEM, 23.18 OSF 1.50 3888.54 2501.54 MinN-0-ADP 3452.17 331.42 3230.90 3120.7'MEOW OSF 1.50 9554.93 3467.58 MnPI-0SF SP18-N5P81(Def Survey) Waning Alert MED 13..; N/A MAS=3.98(m) 0.23 0.23 CIC1<=15m<15.00 Enter Alert 16.40 13.06 I®' 3.33 17.40 MAS=3.98(m) 220.13 220.13 MINPT-0-EOU 22.03 13.06 18.95 8.97 I®' MAS=3.98(m) 374.01 373.95 WIN-0-6F 48.28 13.06 43.92 35.22 1502 MAS=3.98(m) 533.43 532.72 CtCt<=15m;15.00 Exit Alert 1751.34 58.83 1711.76 1692.5111 45451 OSF 1.50 1627.63 1497.54 MnPt-0SF II 97.45 2127.11 2094.95 34.07 OSF 1.50 3171.51 2379.22 MinPICtCt stem3 134.88 2106.35 2061.72 24.60 OSF 1.50 375628 2478.99 MinPICtCt 2199.09 142.8'wan 2056.46 23.28 OSF 1.50 3874.00 2499.06 MINPT-O-EOU 2199.70 143.27 2103.:. .�. rl 2118 OSF 1.50 3888.54 2501.54 MnP1-04DP 2500.10 200.55 2366.07 2299.5. 18.78' OSF 1.50 5682.81 2807.44 MnPt-OSF SP16-F N3(Def Survey) Waning Alert 31.96 25.76 30.73 6.20 N/A MAS=7.85(m) 0.18 0.18 CtCt<=15m<15.00 Enter Alert 25.76 27.101 17.67 MAS=7.85(m) 329.39 329.36 MnPts 30.23 25.76 MEM 4.47 13.69 MAS=7.85(m) 403.89 403.80 MINPT-0-EOU 49.12 25.76 41.94 23.36 8.04 MAS=7.85(m) 857.80 847.83 CtCt<=15m;15.00 Exit Alert 71.11 25.76 55.81 45.35 4.97 MAS=7.85(m) 1273.21 1219.29 OSFx5.00 Enter Alert 71.49 25.7, cli 45.73 4.86 MAS=7.85(m) 1288.50 1231.99 MINPT-O-EOU 74.92 25.76 57.36 49.1; MAS=7.85(m) 1400.70 1322.69 MnPt-0.SF 97.44 30.11 76.95 67.33 5.00 OSF 1.50 171729 1585.90 OSF>5.00 Exit Alert 110.63 34.09 87.50 76.54 4.99 OSF 1.50 1918.60 1718.10 OSF<5.00 Enter Alert Drilling Office 2.6.1166.0 117.90 40.•. 77.10 Nikaitchuq\Spy Island\S1138 N2\5119995FN2\SI19-FN2(P5) 3/11/2013 11#.14 AM Page 3 of 12 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) ,Den.(fAL Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major 128.47 54.40 91.80 74.071 3.59 OSF 1.50 2392.34 2054.59 McPt-0-ADP 129.54 55.47 92.15 7411 3.55 OSF 1.50 2407.32 2063.93 MnPI-0-ADP 170.34 86.74 112.11 83.6 OSF 1.50 2762.44 2252.92 MnPt.O-SF 398.26 162.29 289.71 235.9 37 OSF 1.50 3871.20 2498.58 MnP40-SF 768.85 231.37 614.28 537.49 5.00 OSF 1.50 6825.28 3002.21 OS8>500 Exit Alert 1150.49 319.39 937.23 831.1. ZIES OSF 1.50 9522.75 3462.10 MnPt-OSF 1206.33 334.86 982.76 871.4 MIME OSF 1.50 9958.27 3536.35 MnPt-O-SF 1222.74 339.49 996.09 883.2 iln OSF 1.50 10088.05 3558.47 MnPt-O-SF 1283.68 357.51 1045.01 926.1 .- OSF 1.50 10698.44 3657.99 MnPt-0-SF IMEM 362.12 994.81 874.43 5.13 OSF 1.50 11641.77 3738.89 MinPtCCt 1237.02 371.19 OSF 1.50 11916.73 3758.07 MinPtc 1227.82 369.20 981.35 858.61 5.00 OSF 1.50 12195.22 3763.08 056<5.00 Enter Alert II 1192.6811 390.54 932.00 802.14 4.59 OSF 1.50 12779.41 3767.32 MinPt-CtCt 1193.22 392.3 =ME 800.89 4.57 OSF 1.50 12834.40 3767.86 MINPT-O-EOU 1193.31 392.45 9311 800.84. 4.57 OSF 1.50 12839.76 3767.91 MnP1O-ADP I 1172.331 421.23 891.18 751.10 4.18 OSF 1.50 13727.54 3794.26 MnPt-CICt I 1173.461 431.02 885.79 742.44 4.09 OSF 1.50 14001.31 3795.19 MnPFCICt I ^t 15.161 518.07 771.79 600.09 3.25 OSF 1.50 15875.15 3767.29 MnPt-CCt I 15.401 532.85 759.84 582.55 3.14 OSF 1.50 16381.60 3772.27 MnPILYCt 1115141 537.93 756.59 577.60 3.11 OSF 1.50 16501.59 3775.61 MnPt-C1Ct 1116.97 542.33=EMI 574.64 3.09 OSF 1.50 16582.55 3776.35 MINPT-0-EOU 1117.97 543.59 755.25=EEO 3.09 OSF 1.50 18607.19 3776.07 MinPt-O-ADP 11 1066 6511 580.91 679.05 485.74 2.78 OSF 1.50 17596.25 3763.71 MnPtCCt 1067.62 583.91 11.I 483.71 2.74 OSF 1.50 17696.56 3760.98 MINPT-0-EOU 1 1045 621 614.89 635.37 430.74 2.55 OSF 1.50 18534.61 3753.00 MnPtCCt I 1039791 825.16 622.68 414.63 2.50 OSF 1.50 18840.33 3755.71 MnPt-CICt I 1040.891 633.58 818.19 407.32 2.47 OSF 1.50 19065.31 3757.18 MinPFC1C1 1041.93 636.9'jjjjjjE 404.94 2.46 OSF 1.50 19134.16 3757.67 MINPT-O-EOU 1043.27 638.59 617. •Mr= 2.45 OSF 1.50 19158.70 3757.96 MnPtO-ADP 1047.15 641.56 619.11 405.58 2. OSF 1.50 19207.72 3758.80 MnPWSF 1323.80 715.47 846.49 608.33 2.78 056 1.50 21161.95 3767.69 TD 01=23-N3(Def Survey) Weming Alert 32.06 25.87 30.83 6.19 WA MAS=7.83(m) 0.11 0.11 CtCt<=15m<15.00 Enter Alert 1®, 25.87 29.6.MIMI 33.00 MAS=7.88(m) 190.10 190.10 MinPts MEM 25.87 28.31 IED 15.57 MAS=7.88(m) 305.48 305.47 MinPts 31.71 25.87=En1 5.84 12.30 MAS=7.88(m) 345.45 345.41 MINPT-O-EOU 37.21 25.87 31.96 11. jj1 MAS=7.88(m) 454.42 454.19 MnPt-0SF 49.09 25.87 43.27 23.22 10.42 MAO=7.88(m) 541.78 540.99 CtCt<=15m415.00 Exit Alert 1702.73 54.68 1685.92 1648..'1 J OSF 1.50 1668.75 1528.94 MnPPOSF 1054.82 124.54 971.46 930.2.E OSF 1.50 6503.80 2947.41 MnPI-0SF 832.93 97.89 767.34 735.. OSF 1.50 7117.27 9051.99 MAPt-0SF 804.15 94.55 740.79 709.8.MEE OSF 1.50 7255.48 3075.56 MnP1.0SF 578.55 173.78 480.37 402.77 5.00 OSF 1.50 8728.17 3326.83 OSF<5.00 Enter Alert 183.23 453.12 392.37 4.73 OSF 1.50 8788.29 3338.88 MinPt-0tCt 589.11 232.74=MII 356.35 3.81 OSF 1.50 9139.52 3396.76 MINPT-0E0U 597.59 242.95 435.306 3.70 OSF 1.50 9224.71 3411.29 M.Pt-0-ADP 651.50 276.84 466.61 374.68 OSF 1.50 9534.00 3464.01 MnP1-0SF 879.13 444.87®�"1''MEIEE OSF 1.50 10352.03 3603.48 MinPts SP23-N3P81(De/Survey) Warning Alert 32.06 25.67 30.83 6.19"� N/A MAS=7.88(m) 0.11 0.11 CtCt<=15m<15.00 Enter Alert 1- 175 25.87 29.60 5.881 33.00 MAS=7.88(m) 190.10 190.10 MinPts 31.47 25.87 28.31 560 15.57 MAS=7.88(m) 305.48 305.47 MinPts 31.71 25.871; 28.01 5.84 12.30 MAS=7.88(m) 345.45 345.41 MINPT-O-EOU 37.21 25.87 31.96 11.341 MAS=7.88(m) 454.42 454.19 MiarPt-0SF 49.09 25.87 43.27 2122 10.42 MAS=7.88(m) 541.78 540.99 CtCK=15m415.00 Exit Alert 1702.73 54.68 1665.92 1648.0 OSF 1.50 1668.75 1528.94 MRPt-OSF 118.1. j�j® OSF 1.50 6765.77 2992.07 MinPts SP24-SE1(P2)(Del Plan) Warning Alert 40.01 32.25 38.78 7.76 N/A MAS=9.83(m) 5.00 5.00 CtCt<=15m<15.00 Enter Alert MIMI 32.25 37.971 7.761 47.93 MAS=9.83(m) 200.00 200.00 MinPts 40.11 32.251 37.441 7.86 26.83 MAS=9.83(m) 320.96 320.94 MINPT-O-EOU 48.95 32.25 43.72 16.70 11.90 MAS=9.63(m) 529.03 528.37 =KM Sm>15.00 Exit Alert 54.49 32.25 48.52 22.2 i.1En. MAS=9.83(m) 605.73 604.14 MnPFO-SF 119.01 32.25 110.03 86.74 MAS=9.83(m) 1134.54 1100.62 MnP•O•SF 137.83 32.25 127.42 105. .MEESE MAS=9.83(m) 1245.81 1196.18 MnP•OSF 147.08 32.25 13625 114.8 MBE MAS=9.83(m) 1298.84 1240.53 M.P8.3SF 261.39 80.95 207.07 180.44 4.89 OSF 1.50 3427.26 2422.90 OSF<5.00 Enter Alert 142.50 106.39 59.24 2.13 OSF 1.50 3570.33 2447.29 MinPFCICt 203.21 148.1 r muff 55.02 2.06 OSF 1.50 3587.88 2450.28 MINPT-O-EOU 204.39 149.64 104.21 2.05 OSF 1.50 3593.60 2451.25 MnP1.0-ADP 205.12 150.27 104.58 54.84 2.05 OSF 1.50 3596.43 2451.74 M.Pt-O-SF 41545 125.57 331.38 28988 499 OSF 1.50 3749.61 2477.85 OSF>5.00 East Alert 737.16 105.77 666.29 631.38 1055 OSF 1.50 360027 2486.49 TD L 105.6.,E 639.441 10.6311 OSF 1.50 3800.26 2486.49 MinPts S114-N6(P2)(Def Plan) Warning Alert 47.94 32.81 46.71 15.13 N/A MAS=10.00(m) 5.00 5.00 CtCt<=15m05.00 Enter Alert 32.81 45.90 15.131 57.66 MAS=10.00(m) 200.00 200.00 MinPts 47.97 32.8111 45.88 15.18 54.41 MAS=10.00(m) 214.88 214.88 MINP7-0-EOU 49.15 92.81 48.77 16.34 41.78 MAS=10.00(m) 294.05 294.04 CICte=15rrr>15.00 Exit Alert 67.21 32.81 62.77 34.4.1 . MAS=10.00(m) 507.66 507.18 MnPt-OSF 011M 76.51 3076.47 3051.33 62.17 OSF 1.50 2673.65 2212.11 MinPt-CtCt 3128.50 78.51 IIIIMIlal 3049.99 60.58 0561.50 2702.36 2225.80 MINPT-O-EOU 3129.36 79.54 3075.x:E 59.80 OSF 1.50 2716.89 2232.55 MnP1-0-ADP 3317•j MIME OSF 1.50 11319.94 3716.44 MinPts 51134-N4 Pet Survey'. Wamring Alert MUM 32.81 51.00 31.89 MAS=10.00(w) 274.28 274.28 MinPts MBE 32.81 4983®" 19.28 MAS=10.00(m) 988.07 388.00 MinPts MEM 32.81 49.321 16.17 MAS=10.00(m) 422.64 422.51 MinPts 56.08 32.81 23.28 6.88 MAS=10.00(m) 804.83 60326 MINPT-O-EOU 56.84 32.81 47.10 24.0 MAS=10.00(m) 834.82 632.73 MnPt-O-SF 71.32 32.81 57.85 38.51® MAS=10.00(m) 1055.71 1030.59 MnPt-O-SF 74.51 32.81 80.46 41.7.® MAS=10.00(m) 1090.31 1061.54 MaRt-OSF 97.16 32.81 78.56 64.3 ® MAS=10.00(m) 1300.79 1242.14 MaiPt-0.OF 106.38 32.81 86.11 73.5 ® MAS=10.00(m) 1402.70 1324.26 MnPtO-SF 116.84 32.88 94.51 83.9.1M1111113 OSF 1.50 1562.97 1448.02 MnPt-O-SF 144.85 44.33 114.89 100.52 5.00 OSF 1.50 1934.76 1730.24 00645.00 Enter Alert 164.63 54.33 128.01 110.31'. OSF 1.50 2167.47 1903.01 MEPt-O-SF 165.85 54.72 128.96 111.1 MIKE OSF 1.50 2176.98 1909.83 MRPSOSF 231.14 70.25 183.90 160.90 5.00 OSF 1.50 2492.21 2114.96 OSF>5.00 Exit Alert 291.08 8824 231.85 202.85 5.00 OSF 1.50 2758.36 2251.14 OSF<5.00 Enter Alert 376.15 124.93 292.45 251.21=In OSF 1.50 3252.70 2393.14 MnPt-O-OF 572.50 172.71 457.00 399.78 4.99 OSF 1.50 3918.19 2506.59 OSF>5.00 Exit Alert 2375.77 353.59 2139.69 2022.1811 10.10i1 OSF 1.50 10841.58 3675.99 MnPt-0SF 2962.14 348.15 2129 69 'xE 10.20 OSF 1.50 11044.45 3696.41 MnPt-O-ADP Drilling Office 2.6.1166.0 2360.78 3466 2129 .301 261422 Ni kaitchuq\Sprsifand\gi't = N2\gtTh67FN2\SI19-FN2(P5) 3/11/20MT:,irAM Page 4 of 12 Offset Trajectory Separation A.. Sep. Controlling Reference Trajectory Rim. Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dee.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor 1 Major 2411.09 368.16 2165.32 2042.9 9.8 OSF 1.50 11914.17 3757.89 M9nPt-O-SF 2430.37 376.3 I)))ffy 2054.03 9.71 OSF 1.50 12438.07 3763.95 MINPT-O-EOU 2433.18 379.54 2179.8.UK= 9.64 OSF 1.50 12537.98 3764.94 M'Pt-O-ADP 2440.40 400.28 2173.21 2040.12 9.16 OSF 1.50 13232.55 3784.57 MINPT-O-EOU 2442.12 402.34 217366 2039.7811 9.12 OSF 1.50 13286.11 3787.50 MnPt-O-ADP Ijjjjjj E 460.13 2075.15 192210 7.78 OSF 1.50 14748.44 3788.20 MinPt-CtCt ® 500.51 1994.72 1828.22 6.99 OSF 1.50 15556.43 3771.50 MinPtCtCt MEMil 518.90 1983.95 1811.51 6.75 OSF 1.50 16086.66 3765.74 MinPtCtCt 2331 65 522.4.1 . .1 1809.25 6.70 OSF 1.50 16204.51 3768.52 MINPT-0-EOU 1 2332611 526.35 1981.38 1806.26 6.66 OSF 1.50 16314.49 3771.15 MinPICtCI 1 2289.261 576.09 1904.88 1713.18 5.97 OSF 1.50 17578.47 3763.91 MinPtCtCt 2290.53 580.29I1111jjj11 ''! 1710.23 5.93 OSF 1.50 17708.19 3760.62 MINPT-0-EOU 229142 581.38 1903.50111BM 5.92 OSF 1.50 17738.18 3759.70 MnPt-0-ADP 1 2286.401 612.15 1877.98 1874.26 5.61 OSF 1.50 18567.42 3753.39 MinPt-C1Ct 1 2281.121 634.46 1857.82 1646.66 5.40 OSF 1.50 19161.71 3758.01 MInPtCICt 2281.91 636.75'M 1645.16 5.38 OSF 1.50 19200.56 3758.65 MINPT-0-EOU 2282.61 837.62 1857.2.IIIIMEO 5.38 OSF 1.50 19216.14 3758.98 MhPt-O-ADP 2300.45 851.3.MIME1 1649.13 5.30 OSF 1.50 19569.64 3767.82 MINPT-O-EOU 2302.06 653.24 1666.2.Ma= 629 OSF 1.50 19619.58 3769.07 MnP8-0-ADP 2312.82 658.26 1873.65 1654.5.jlllllllllll-illg:i OSF 1.50 19728.54 3771.70 MnPt-O-SF 2359.09 674.48 1909.11 1684.61'.® OSF 1.50 20118.00 3779.43 MMP-0-SF 2441.50 696.98 1976.51 1744.51 MIMEO OSF 1.50 20753.43 3781.69 MnPI-0-SF 2468.03 700.30 2000.84 1767.74 629 OSF 1.50 20886.52 3778.79 TD 5125-N2(Def Survey) Warning Alert ® 32.811 61.891 30.3111 319161.40 MAS=10.00(m) 5.00 5.00 MinPts 6364 32.811 61.61 3074 87.63 MAS=10.00(m) 200.00 200.00 MINPT-0-EOU 11 636511 32.81 61.13 30.841 48.47 MAS=10.00(18) 308.22 308.21 MnPls 63.74 32.81 61 02 30.93 42.00 MAS=10.00(m) 341.47 341.44 MINPT-0-EOU 85.13 32.81 8022 52.3 22.77 MAO=10.00(18) 610.30 608.64 MinPWSF 2101.52 32.81 208724 2068.71 158.97 MAS=10.00(88) 1550.02 1438.09 MnPt-0-SF 2664.14 82.56 2608.74 2581.58 4902 OSF 1.50 2784.27 2262.24 MINPT-0-EOU 2678.39 99.15 2611 931 2579241 40.94 OSF 1.50 2985.04 2334.56 MinPt-0-ADP 1013.65 305.20 809.86 708.45 469 OSF 1.50 9278.90 3425.18 OSFs5.00 Enter Alen Iljjjjjjjjj'l 407.27 16).70 25.271 1.591 OSF 1.50 10675.36 3654.83 MinPts SP27-N1(Def Survey) Pes I�1 32.81 lull) ir/ MM N/A MAS=10.00(m) 0.29 0.23 MinPts 32.81 65.67® 22.34 MAS=10.00(m) 588.49 587.18 MinPts 70.00 32.81 MUM 37.20 21.70 MAS=10.00(m) 598.23 596.76 MINPT-0-EOU 81.06 32.81 75.41 48.2.11.11a0 MAS=10.00(18) 711.54 707.60 MnP1-0SF f1 2256.3811 294.05 2080.02 196233 11.54 OSF 1.50 9001.91 3379.30 MinPtCSCt 225662 291.77r 2059 77 1961.84 11.52 OSF 1.50 9021.85 3376.87 MINPT-0-EOU 2256.94 295.13 2059661 1951 811 1 t 50 OSF 1.50 9031.51 3378.95 MnPIC-ADP 11 1731.55i1 356.65r 1493 461 1374.9. 0 OSF 1.50 10784.82 3669.20 MinPts SP12-9E3(P2)(Def Plan) Poe MIME 32.81 77.05 46.2 95 06 MAS=10.00(m) 200.00 200.00 MnPIs 79.29 32.81 78.82 46.48 62.59 MAO=10.00(m) 283.69 283.68 MINPT-0-EOU 32.81 72.88 45.1 1682 MAS=10.00(m) 498.59 498.15 MinPts 79.09 32.811 71.58 46.28 12.40 MAS=10.00(m) 590.75 589.38 MINPT-0-EOU 145.12 32.81 126.94 112.3211 8.4811 MAS=10.00(m) 1302.48 1243.53 MnPF0.SF 443.19 94.82 379.62 348.37 7.07 OSF 1.50 2823.57 2278.32 MnPt-0-SF 996.50 78.78 94363 917.72 19.21 OSF 1.50 3121.04 2389.32 TD 11 1000 94i1 78.600 948 181 922.3411 19.34.4 OSF 1.50 3121.03 2369.31 MinPts 6108-9N6(P3))Def Plan) PM ® 32.81 85.08 54.301 106.03 MAO=10.00(88) 200.00 200.00 MinPts 87.20 32.811 85.00 54.39 87.91 MAO=10.00(m) 229.49 229.49 MINPT-0-EOU 227.94 32.81 210.77 195.131 14.221 MAO=10.00(m) 1399.05 1321.38 MitP84DSF 163.28 59.71 423.06 403.56.1 11.851 OSF 1.50 2284.29 1984.31 MMP1-0-SP 178.51 61.65 437.01 416.871 11.851 OSF 1.50 2318.15 2006.88 MinPFO SF 5474.69 368.62 5228.62 5106.071 22.331 OSF 1.50 11041.19 3696.13 MinP1.0-SF 4832.35 848.2 llllll 2 4184.10 11.20 OSF 1.50 18668.60 3754.54 MINPT•0-EOU 1832.38 64829 4399.;•MIMEO 11.20 OSF 1.50 18671.78 3754.59 M.rPt-0-ADP WIEM 887.28 4379.58 4157.48 10.86 OSF 1.50 19118.76 3757.84 MnPtCtCt 1825.40 669.2. 415614 10.83 OSF 1.50 19180.76 3758.30 MINPT-0C0U 4826.14 670.15 4379.04 ME1111 10.82 OSF 1.50 19195.97 3758.57 MIrPS-0•ADP 484528 688.06 4385.5:BUM 10.56 OSF 1.50 19661.71 3770.13 MnPt-0-ADP 4901.22 709.78 4427.71 4191.4.'®' OSF 1.50 20162.04 3779.67 M,Pt-0-SF 4974.06 721.31 4492.86 4252.75 Mina OSF 1.50 20478.29 3781.21 MnP1-0-SF SP30-W 1 PB1(Def Survey) Pam M:1K1 32.81 84.51 58691 1566 MAS=10.00(m) 640.35 638.15 MinPts 91.64 32.811 84.38 58.83 14.99 MAS=10.00(18) 654.82 652.32 M1NPT-0-E0U 100.32 32.81 9149 67.51 14 MAS=10.00(18) 738.51 733.73 M1Pt-0SF 449668 163.93 4387.06 43327 43.01381 OSF 1.50 3899.53 2503.11 M,P10SF 11 3151.701 384.3.'. 2908.50 woo man OSF 1.50 10230.56 3582.77 MinPts SP3O-W t(Def Survey) Pas IIMIED 32.81 84.511 58.690 15.66 MAS=10.00(m) 640.35 638.15 MinPts 91.64 32.811 84.38 58.83 14.99 MAS=10.00(m) 654.82 852.32 MINPT-0-E0U 100.32 32.81 91.49 87.511=11M MAS=10.00(m) 738.51 733.73 1.4nP1-0SF 4496.68 163.93 4387.06 4332.7 IMILIIE OSF 1.50 3899.53 2503.41 MnPt-0-SF 2587.57 346.72 2338.10 2220.8.=NM OSF 1.50 11103.88 3701.22 96,88-0-SF 2491.14 387.31 2245.94 2123.8" I ,i OSF 1.50 12030.93 3762.82 MnPt-0-SF WOK 121.5•Man MIME Ijjjjjjjjjjjjjj'AM OSF 1.50 12907.41 3769.63 MinPts S129-S2(Def Survey) Pass Min 32.81 93.18 62.081 193.22 MAS=10.00(m) 145.08 145.08 MinPts 9537 32.811 92.89 62.56 75.51 MAS=10.00(m) 281.57 281.57 MINPT-0-EOU 203.98 32.81 188.00 171.1'® MAS=10.00(18) 1538.39 1429.15 M.P5CSF 217.82 32.81 200.76 184.8•ME= MAS=10.00(m) 1607.01 1481.79 MnPI-0-SF 586.82 122.91 484.47 443.91 Min OSF 1.50 3368.04 2412.46 MnPt-0SF 3005.81 200.65 2871.71 2805.15 22.57 OSF 1.50 5962.24 2855.08 TD 486670 212.22 4724.89 4654.4 34.551 OSF 1.50 2550.61 2148.13 MinPI-0SF 4385.18 215.74 4241.03 4169.4 1 30.621 OSF 1.50 3900.15 2503.52 MnPt-OSF 1 3010.5911 200.651 2876.50_ 2809.9'MIMI OSF 1.50 5962.24 2855.08 MnPls SPI O-FN5(Def Survey) Pen MEM 32.81 93.89 62.381 1228.79 MAS 10.00(m) 66.18 66.18 MinPts 95.39 32.811 93.77 62.58 233.78 MAS=10.00(m) 145.18 145.18 MINPT-0•EOU 213.82 32.81 195.68 181.011 12561 MAS=10.00(m) 1380.58 1308.75 MnPt-0-SF 846.96 133.24 757.73 713.74 9.611 OSF 1.50 3359.61 2411.36 MnPt-0SF 863.11 135.77 772.19 727.341 9.611 OSF 1.50 3394.62 2417.33 MnPt-0-SF 1079.28 170.48 965.30 908.801 9.541 OSF 1.50 3872.90 2498.87 MnPt-0SF 3442.47 347.28 3210.62 3095.191 14.911 OSF 1.50 10889.99 3681.42 MoPtCSF 3423.42 342.40 3194.8. 3081.0. 1604 OSF 1.50 11050.80 3696.95 MnPt-0-ADP 3422.89 341.7.1 3194.70 3081.10 15.06 OSF 1.50 11065.53 3698.18 MINPT-0-EOU 3422.32 340.04 3195.30 3082.28 15.14 OSF 1.50 11104.81 370129 MinPbCtCt Drilling Office 2.6.1166. 3420.26 342.67 3191.49 3077.59 Niklaitchuq\Spgfits land\SISgi2N2\9f18#N2\SI19-FN2(P5) 3/11/2013fAn1nIkAM Page 5 of 12 Offset Trajectory Separation Allow Sep. Controlling Referents Trajectory Risk Level Alert Status Ct-Ct(et)1 MAS(ft)I EOU(1 Day.(ft) Fact. Rule MD(ft) I TVD(ft) I Alert I Minor I Major 342078 344.61 3190.72 3076.18 14.93 OSF 1.50 11353.48 3718.78 MINPT-O-EOU 3421.30 34528 3190.80_?2,12623 14.90 OSF 1.50 11373.39 3720.17 MnP1-0-ADP 449.07 3240.84 3091.28 11.85 OSF 1.50 14607.37 3793.98 MinPtCtCt MIMEO 453.83 3237.47 3086.52 11.72 OSF 1.50 14740.25 3788.53 MinPICtCt 3542.16 459.0 IIIIII M 3083.13 11.80 OSF 1.50 14895.18 3782.18 MINPT-O-EOU oirogo 549.10 3096.50 2913.79 9.47 OSF 1.50 17048.78 3769.66 MinPt.C1Ct 3483.16 550.1 1 3096.08 2913.03 9.46 OSF 1.50 17067.24 3769.39 MINP1-0-EOU 3463.74 550.81 3096.20111111 'L', 9.45 OSF 1,50 17077.31 3769.26 MinPt.O-ADP 3479.69 577.7 Mx= 2901.96 9.05 OSF 1.50 17812.37 3757.42 MINP1-0•EOU 3480.41 578.62 3094.3.MIRE 9.04 OSF 1.50 17837.34 3756.65 MInPF0,4DP Ems'• 600.28 3141.16 2941.39 8.86 OSF 1.50 18437.00 3751.85 MnPICtCt 638.31 3081.08 2868.63 8.25 OSF 1.50 19396.93 3763.48 Mn1=1C5Ct 3509.98 648.3.1 3077.43 2861.66 8.13 OSF 1.50 19661.84 3770.13 MINPT•O•EOU 3510.38 648.81 3077.52 2861.5. 8.13 OSF 1.50 19670.71 3770.36 MinPt-0-ADP 3548.07 669.28 3101.55 2878.7• lla OSF 1.50 20180.99 3779.97 M8Pt-O-SF 3630.24 690.49 3169.58 2939.7-1,11111M OSF 1.50 20755.07 3781.70 M.3Pt-OSF 3637.47 707.4' OSF 1.50 20793.35 3781.49 MinPt8 SP11-N7(P4b)(Def Plan) Pam ® 32.81 109.10 78.311 138.70 MAS 0 10.00 941) 200.00 200.00 MinPts 111.13 32.811 109.09 78.33 133.45 MAS.10.00(m) 209.78 209.78 MINPT•0•EOU 171.87 32.81 187.49 139.061 53.961 MAS.10.00(m) 643.00 640.75 MnPt•0-SF 187.39 32.81 182.71 154.581 53.981 MAS•10.00(m) 680.51 877.42 MnPt-O-SF 613.71 32.81 604.65 580.901_ 78.101 MAS•10.00(m) 1099.96 1070.11 MnPtC•SF 2869.84 46.22 2838.87 2823.61 95 29 OSF 1.50 1890.83 1697.22 MnPt-O.SF 3457.37 52.38 3422.10 3404.99 101.04 OSF 1.50 2100.80 1854.12 MnPt-OSF MUM 91.33 4095.57 4065.48 69.06 OSF 1.50 2618.64 2183.52 MinPt•CtCt 4157.44 93.4.1 4094750= 6746 OSF 1.50 2645.91 2198.42 MnPts 4459.48 193.01 433048 4256.4 Mall OSF 1.50 3904.06 2504.18 MnP1-OSF 4603.48 198.12 4471.07 4405.3 I®i OSF 1.50 4523.79 2809.04 MnPt.O4F ®' O 332.11 MIMIC MarKIJIMEll OSF 1.50 11479.30 3727.56 MinPts SI32-W2 current(Non-Def Survey) Pass NEW 32.81 125.8 113M N/A MAS=10.00(m) 41.00 41.00 MinPts 127.30 32.81=ME 94.49 336.03 MAS=10.00(m) 13923 139.23 MINPT-O-EOU 32.81 114.03 M.113EE 40.25 MAS=10.00(In) 609.53 607.88 MinPts 118.18 32.81 113.97 85.38 39.08 MAS=10.00(m) 818.99 617.19 MINPT-O-EOU 152.19 32.81 145.64 119.381E1E0E MAS=10.00(m) 814.15 806.37 MoP1-0-SF 1727.27 73.93 1677.57 1653.3'''MEM OSF 1.50 1722.01 1569.50 MnnPt-O-SF S037•DSP1(Def Survey) Pass 11111101326 32.81 110.84 85.711 18.18 MAO=10.00(m) 942.65 927.30 MinPts 118.60 32.811 110.781 85.79 17.80 MAS=10.00(m) 951.95 935.91 MINPT-O-EOU 128.75 32.81 119.41 95.94® MAS=10.00(m) 1055.94 1030.80 MnnPt-OSF 4827.46 32.81 4813.62 4794.85 377.96 MAS=10.00(m) 3004.90 2340.36 TD SI07SE4(P2)(Del Plan) Pass 32.81 117.05 86.271 145.49 MAS=10.00(m) 200.00 200.00 MinPts 119.20 32.81 116.91 86.39 111.40 MAS=10.00(m) 243.96 243.96 MINPT-O-EOU 121.75 32.81 116.91 88.94 33.39 MAS=10.00(m) 447.71 447.51 MINPT-0-E0U 128.11 32.81 120.33 95.3.Ma:E5 MAS=10.00(m) 585.49 584.21 MnPI-0SF 273.67 32.81 255.55 240.••MOM MAS=10.00(m) 1300.43 1241.85 MWP1-0-6F 713.81 89.78 888.90 644.06 IIIIIIW2 OSF 1.50 2414.99 2068.68 M6P1-0-6F 824.68 79.42 771.33 7452-OWE OSF 1.50 2599.21 2174.41 MnPFOSF 844.83 81.23 790.32 763.61 MEE OSF 1.50 2631.00 2190.89 M.111-0-SF 1647.80 96.10 1583.37 1551.70 25.99 OSF 1.50 3029.81 234729 TD IMMO 96.04 I.EUME®1i OSF 1,50 3029.80 2347.28 MinPts 5132-W2(P6c)(Def Plan) Pam 32.81 113.62 87.041 23.70 MAS=10.00(m) 579.30 578.09 MinPts 120.25 32.811 113.33 87.45 20.89 MAS 5 10.00(m) 813.89 612.17 MINPT-O-EOU 131.19 32.81 12225 98.3:M111111 MAS=10.00(m) 732.79 728.20 MinPt-0•SF 4886.10 171.30 4771.58 4714.8.Mag331 OSF 1.50 3899.77 2503.45 MinPt-0SF 3728.12 354.00 3491.79 3374.1.IIIIIIII[E1111 OSF 1.50 11005.45 3700.57 MePt-O-SF 3726.38 353.64 3490.2 MIME 15.85 OSF 1.50 11133.00 3703.38 M9t17.1-0-DP 3726.34 353.•• 3490.2 3372.73 15.85 OSF 1.50 11134.57 3703.50 MINPT-O•EOU MEME 353.56 3490.29 3372.76 1565 OSF 1.50 11139.26 3703.83 McP•CtC1 3738.38 377.2,I 3359.09 14.88 OSF 1.50 11850.88 3753.48 MINPT•O•EOU 3737.65 378.89 348477 MIME, 14.83 OSF 1.50 11895.77 3756.61 MnPt-O-ADP 3738.52 379.56 3485.15 3350.' 14.81 OSF 1.50 11918.43 3758.19 MnPt-OSF 3788.48 390.94 3527.53r 3397.5. 14.57 OSF 1.50 12375.98 3763.34 MnP[C-ADP 3820.39 40401 355073 3416.39 14221 OSF 1.50 12741.82 3766.95 MnPt-0.SF SP33-W3(Def Survey) Pees 1•I 32.81 133.931 N/A MAO=10.00(m) 40.82 40.82 MinPts l=iEBE 32.81 133.60 IMIEKE1 300.34 MAS=10.00(m) 165.00 185.00 MinPts ® 32.81 132.32 MIMES 85.39 MAS=10.00(m) 958.03 357.99 MinPts 135.62 32.81 Mg111 102.81 55.91 MAS=10.00(m) 460.12 459.87 MINPT-O-EOU 159.45 32.81 153.54 126.6 ME y MAS=10.00(m) 750.41 745.22 MinPtQSF 164.79 32.81 158.73 131.9>11.111= MAS=10.00(m) 767.87 76205 M.Pt-0-SF 2100.81 92.81 2085.39 2068.0, MAS=10.00(m) 1532.24 1424.42 MnPt-OSF 586627 168.29 5755.08 5699.97'.® OSF 1.50 3897.98 2503.15 MirPt-OSF _ 360.03 4643.74 4524.05 20.40 OSF 1.50 10917.77 3684.38 MnPFCICt 4884.09 360..7 1111=KIE 4524.03 20.40 OSF 1.50 10919.85 3684.59 MINPT-O-EOU 4884.10 360.06 464373 MEM 20.40 OSF 1.50 10920.35 3684.65 M.P[-0-ADP 4887.43 360.55 4646.74 4526.891 20.381 OSF 1.50 10969.46 3689.58 MnPt-OSF 4888.42 360.68 4647.64 4527.741 20.381 OSF 1.50 11013.05 3693.65 M.tPt-O-SF 4888.42 360.68 4647.64 6 20.38 OSF 1.50 11015.63 3693.89 MnPI-0-ADP 4888.42 360.6• 4647.64 4527.74 20.38 OSF 1.50 11016.92 3694.00 MINPT-O-EOU 1 360.68 4647.64 4527.74 20.38 OSF 1.50 11018.21 3694.12 MnPtCtCt 4887.41 360.63 4646.66 4526.71,1111.11EX1 OSF 1.50 11043.88 3696.36 MinPt-OSF 4884.17 360.2• •'11101HLE 20.39 OSF 1.50 11080.08 3699.36 MinPts ICI 360,27 4643.65 4523.89 20.39 OSF 1.50 11081.97 3699.47 MinPt-CtCt 4982.71 385.18 4725.59 4597.5' '�' OSF 1.50 11917.78 3758.14 MnP1-0-SF 5115.46 395.82 48512 19.43 OSF 1.50 12375.02 3783.33 M.tP[C-ADP 5128.93 436.5 =MEC MEMO 17.66 OSF 1.50 12468.02 376425 MinP1s SP05-FN7(Def Survey) Pam .11 1931 32.81 140.13®" ' 122.20 MAS=10.00(m) 223.15 223.15 MinPts 142.66 32.81 MEM 109.85 92.69 8165=10.00(m) 273.41 273.41 MINPT-O-EOU 144.65 32.81 mom 111.84 4941 1665=10.00(m) 38520 385.12 MINPT-O-EOU 168.81 92.81 154.31 136.00 1262 MAS=10.00(m) 669.75 666.91 M'Pt-OSF 315.52 92.81 295.89 282.71 17.071 ?465=10.00(m) 1275.84 1221.48 MFP1-0SF 878.38 56.27 640.44 622.0 18.45 OSF 1.50 2180.66 1912.46 MnnPt-OSF 707.31 58.63 687.82 848.6 18.45 OSF 1.50 2229.17 1946.63 143.171-0SF 728.37 60.31 687.75 668.0 18.461 OSF 1.50 2263.40 1970.19 MnP1-0SF 767.50 63.47 724.78 704.0 18.471 OSF 1.50 2323.73 2010.55 MnP1-0SF 1055.07 85.09 997.93 969.9 18.851 OSF 1.50 2884.19 2217.19 MinPt-OSF 1887.78 169.13 1774.68 1718.6 16 84 OSF 1.50 3870.52 2498.47 MnPt-OSF Drilling Office 2.6.1166.0 5823.91 323.69 5607.80 5500.2 ?vl huq\Spg6lsland\SH9.feN2\8 1113 FN2\SI19-FN2(P5) 3/11/20134104FAM Page 6 of 12 Offset Trajectory II Separation . Sep. Controlling 1212r111=Til Ris Alert I Status Ct-Ct(ft). MAS(ft)1 EOU(ft) Den.(ft)I Fact. Rule MD(ft) TVD(ft) Alert Minor Ma)or 5947.381 363.10 5704.99 5584.29 24.63 OSF 1.50 12790.58 3767.43 MinPFCICt 5881851 429.88 5596.93 5453.97 20.57 OSF 1.50 14818.13 3793.54 MinPt-CtCt L 5884.77 439.46 5591.46 5445.30 20.13 OSF 1.50 14907.87 3781.66 MinPt-CtCt 588318 440.76 MEW 5444.42 2007 OSF 1.50 14926.09 3780.93 MINPT-O-EOU 588540 441.13 5591.071." 1I 20.05 OSF 1.50 14930.56 3780.76 MnPt-0-ADP I1 5883.4211 510.56 5542.72 5372.86 17.32 OSF 1.50 16576.72 3776.38 MinPt-CtCt 5883.68 511.41 I1 5372.27 17.29 OSF 1.50 16591.89 3776.27 MINPT-O-EOU MAM31 532.91 5516.86 5339.55 16.56 OSF 1.50 17128.67 3768.87 MinPt-CtCt MOM 580.16 5491.69 5305.30 15.73 OSF 1.50 17900.41 3754.71 MinPt-CICt 5866.70 566.621 5488.63 5300.08 15.56 OSF 1.50 18079.90 3749.23 MINPT-O-EOU 5867.38 567.44 5488.76 5299.94 15.53 OSF 1.55 18101.46 3748.79 MnPt-O-ADP 5876.99 575.91 5492.7 5301.08 15.33 OSF 1.50 18332.87 3750.63 M6Pt-0-ADP 1] 587.98 5493.17 5297.51 15.04 OSF 1.50 18888.71 3754.71 MInPt-CtCt 11 608.87 5458.78 5256.16 14.47 OSF 1.50 19186.72 3758.40 MinPt-CtCt 5865.53 811.01 1 525452 14.42 OSF 1.50 19222.13 3759.11 MINPT-O-EOU 5865.94 611.52 5457.94.1 14.41 OSF 1.50 19230,98 3759.32 M8P8-O-ADP 5866.66 612.2`1. 5254.41 14.39 OSF 1.50 19247,43 3759.72 MINPT-O-EOU 5875.36 625.8 5249.51 14.10 OSF 1.50 19611.46 3768.87 MINPT-O-EOU 5876.79 627.73 5457.971-•r•r., 14.06 OSF 1.50 19661.37 3770.12 MinPt-O-A5P 5951.85 664.581==MEM 1 OSF 1.50 20204.51 3780.28 MinPts SP05-FN7PB1(Def Survey) Pass 32.81 140.13 109.70 122.20 MAS=10.00(m) 223.15 223.15 MinPts 142.66 32.81 sliEn 109.85 92.69 MAS=10.00(m) 273.41 273.41 MINPT-O-EOU 144.65 32.81 1 111.84 49.41 MAS=10.00(m) 385.20 385.12 MINPT-O-EOU 168.81 32.81 154.31 136.00 12.82 MAS=10.00(m) 669.75 668.91 MnP1-0SF 315.52 32.81 295.89 282.71=WI MAS=10.00(m) 1275.84 1221.48 MnP1•0SF 678.36 56.27 640.44 622.095 OSF 1.50 2180.66 1912.46 MnPt-OSF 707.31 58.63 667.82 648.68 1845 OSF 1.50 2229.17 1948.83 MinP1-0 SF 728.37 60.31 887.75 668.05 18.46 OSF 1.50 2263.40 1970.19 MiPtO-SF 767.50 63.47 724.78 704.03 1947 OSF 1.50 2323.73 2010.55 MnPBO-SF 1055.07 85.09 997.93 969.9:1 18.851 OSF 1,50 2684.19 2217.19 MnPtO-SF 1887.78 169.13 1774.68 1718.661 16.841 OSF 1.50 3870.52 2498.47 MnPtOSF 5823.91 323.69 5607.80 5500.231 27.071 OSF 1.55 11046.49 3696.59 MnPt-0SF 1 363.10 5704.99 5584.29 24.63 OSF 1.50 12790.58 3767.43 MinPt-CtCt 1.' 429.88 5596.93 5453.97 20.57 OSF 1.50 14618.13 3799.54 MinPtCICt MEM 439.46 559145 5445.30 20.13 OSF 1.50 14907.87 3781.66 MinPt•C1Ct 5885.18 440.76[ 5591.011 544442 20.07 OSF 1.50 14926.09 3780.93 MINPT-O-EOU 5885.49 441.13 5591.07 5444.35 20.05 OSF 1.50 14930.56 3780.76 MiiPtO-ADP 1 529.06 11 ElEll OSF 1.50 16539.55 3776.27 MinPts SI35-W4(P3)(Del PMn) Peas 151.15 32.81 149.92 118.34 N/A MAS=10.00(m) 0.00 0.00 Sur ace 32.81 141.82 114.681 32.91 MAS=10.00(m) 519.73 519.14 MinPts 147.61 32.811 141.61 114.80 30.63 MAS=10.00(m) 544.95 544.13 MINP1'-O-EOU 149.90 32.81 149.18 117.0•'1 MAS=10.00(m) 608.99 607.35 MnPt-OSF 689.62 32.81 677.73 858.81 1 MAS=10.00(m) 1176.53 1137.19 MnPtO-SF 2214.21 32.81 219624 2181.41® MAS=10.00(m) 1586.76 1466.27 MnPt-03F 5558.83 172.19 5443.71 5388.8 1. OSF 1.50 3897.82 2503.12 MnPtOSF 5986.3 354.80 5749.44 5631.50 25.38 OSF 1.50 10892.08 3681.84 MinPt-CtCt 5986.36 354.9 1 5631.39 25.36 OSF 1.50 10898.65 3682.35 MINPT-0-EOU 5986.44 355.06 5749.4.1 25.36 OSF 1.50 15901.94 3682.70 MnPl-0-ADP 5998.33 357.02 5759.99 5641.31 MEM, OSF 1.50 10985.81 3691.14 MinP1.0-SF 6190.92 386.04 5933.23 5804.8.® OSF 1.50 11917.06 3758.09 MnPI-0+SF 6313.39 393.82 6050.52 5919.5 ®' OSF 1.50 12212.55 3763.12 MnPI-0SF SPO4-4E5(P2)(041 Plat) Pass MEM 32.81 149.05 118.271 185.00 MAS=10.00(m) 200.00 200.00 MnPIc 151.17 32.811 148.97 118.36 153.45 MAS=10.00(m) 229.13 229.13 MINPTO-EOU 399.75 32.81 383.29 366.9y •1 MAO=10.00(m) 1957.18 1288.04 MnPIOSF 813.15 53.60 777.00 759.54® OSF 1.50 2183.52 1914.50 MhPtO-OF 2350.52 90.49 2289.84 2260.03 39.41 OSF 1.50 2911.54 2910.94 TD IMMO 90.4 1 OSF 1.50 2911.54 2310.94 MinPts SP36-W5(P3)(Def Plan) Pam 32.81 152.97 123401 76.86 MAS=10.00(m) 532.52 531.83 MinPls 156.28 32.811 152.89 123.47 71.62 MAS=10.00(m) 553.12 552.22 MINP1'O•EOU 221.05 32.81 213.83 188.2 MAS=10.00(m) 882.75 871.35 M8iPI•OSF 2372.80 41.00 2345.06 2331..1 OSF 1.50 1788.74 1820.13 M1P8-0 SF 2421.48 41.81 2393.18 2379.6 89.4 OSF 1.50 1802.30 1630.39 MnPtOSF 3075.46 53.45 3039.42 3022.01 i 88.351 OSF 1.50 1970.92 1757.36 MnP1-0SF 3825.58 78.81 3774.02 3748.7' 75 661 OSF 1.50 2551.13 2148.42 MiPtOSF 6720.42 188.76 6607.59 6551.6•' 60.071 OSF 1.50 3873.79 2499.02 MnP8O-SF 1 351.80 6698.70 6581.76 29.64 OSF 1.50 10913.96 3683.98 MinPt-CtCt 6933.64 352.0'1 8581.59 29.62 OSF 1.50 10919.81 3684.59 MINPT-O-EOU 6933.78 352.21 6698.• : 29.61 OSF 1.50 10923.72 3685.00 MnPIOADP 6988.55 360-22 6748.07 6628.3 1' OSF 1.50 11106.24 3701.40 MinPSO SF 7156.47 390.75 6895.65 6765.7' OSF 1.50 11977.30 3761.39 MnPtO-SF 7220.16 394.57 6956.78 6825.5= 27.51 OSF 1.50 12089.91 3763.03 MnPtOSF S102SE6(P2)(Def Plan) Pass 167.06 32.81 165.03 134.251 204.73 MAS=10.00(m) 200.00 200.00 MinPts 167.14 32.811 164.96 134.33 173.59 MAS=10.00(89) 224.20 224.20 MINPT-0-EOU 195.45 32.81 188.21 162.64® MAS=10.00(m) 578.18 576.96 MnPF0-SF 320.66 32.81 310.93 287.8>1 MAS=10.00(m) 959.15 942.56 MnPtOSF 537.83 32.81 52121 504.8.1 MAO=10.00(m) 1298.73 1240.44 MnPtO-SF 1179.43 50.09 1145.63 1129. 1 OSF 1.50 2101.05 1854.45 MvPt-0SF 3543.65 93.13 348121 3450.52 57.72 OSF 1.50 2866.97 2295.01 TD 665398 129.17 6572.55 6529.8.MffiElj1 OSF 1.50 1353.80 1285.33 Mil=t-0SF 5901.90 114.24 5825.41 5787./v 1 OSF 1.50 2100.73 1854.22 MnPt-O-SF 11 93.1.'' 3486.06 11 OSF 1.50 2866.97 2295.00 MinPts SP01SE7(P2)(Def Plan) Pas ® 32.81 173.14 142.361 214.74 MAS=10.00(m) 200.00 200.00 MinPts 175.26 32.811 173.06 142.45 178.15 MAS=10.00(m) 228.99 228.99 MINPT-O-EOU 589.59 32.81 574.63 556.78 42.821 MAS=10.00(m) 1300.66 1242.04 MnPtOSF 1371.96 46.95 1340.30 1325.01 44.8 OSF 1.50 2099.60 1853.38 MinPt-O-SF 4657.25 86.90 4598.97 4570.36 81.38 OSF 1.50 2761.55 2252.53 TD r 8396.07 161.78 8287.89 8234.2.1 OSF 1.50 1173.09 1134.21 MnPtOSF 11 M.,.=Zan 1 OSF 1.50 2761.55 2252.53 MinPls OP09S1(Def Survey) Pala 016411E1E1 32.81 17843.54 17812 741 22549 75 MAS=10.00(m) 205.86 205.86 MinPls 17845.66 32.811 17843.41 17812.86 1739539 MAS 6--10.00(m) 220.69 220.69 MINPT-O-EOU 358.15 2943.62 2826.381 13.551 OSF 1.50 4414.56 2591.22 MinPls Kigun 1 PBt(Def Survey) Pass 1 32.81 5042,24 '®' 8982.55 MAS=10.00(m) 168.07 169.07 MinPts 4357.53 161.39 4249.35 4196.14 40.93 OSF 1.50 4867.32 2668.41 TD I 4913.711 42.551 4884.701 4871.161 181.301 OSF 1.50 2100.17 1853.80 MinPls Drilling Office 2.6.1166.0 Nikaltchuq\Spy Island\S119-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 11:14 AM Page 7 of 12 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major I uvaaq Si 1(Uef Survey) Pass I 32.81 5042 24r 5011 9111 8982 55 MAS=10.00(0) 169.07 169.07 Minf is 175.18 4243.99 4186.18 37.71 OSF 1.5D 6064.77 2872.56 MinPt-CtCt 4361.44 175.451 4243.89 4185.99 37.65 OSF 1.50 8083.77 2875.80 MINPT-O-EOU 4361.55 175.58 4243.91 4185.971 37.62 OSF 1.50 8093.28 2877.42 MInPSOADP 208.81 4257.86 4188.84 31.85 OSF 1.50 7753.68 3160.49 MinPtCICt 4398.37 211.2.MErlICE. 4187.17 31.49 OSF 1.50 7852.20 3177.29 MINP1-0-E00 4399.15 212.15 4257.1 . ..'� 31.35 OSF 1.50 7891.55 3184.00 MinPt 4-ADP 4579.89 289.74 4386.15 4290.15=MI OSF 1.50 10573.61 3639.98 MinPt-4F 6340.07 291.83 6145.11 8048.44 MEIN13 OSF 1.50 12409.42 3763.67 MinPt 4-SF 6629.58 304.69 6425.92 8324.9.®.. OSF 1.50 12924.59 3770.38 M16Pt-SF 7418.25 330.01 7197.71 7088.2-man OSF 1.50 13973.72 3795.10 MnPSO-SF 7997.62 391.00 7736.41 7806.61 man OSF 1.50 16006.59 3765.55 MinPFOSF 8203.17 404.28 7933.12 7798.9111111111111M 00F 1.50 16501.57 3775.61 M.PFP4F 8480.66 424.08 8197.40 8056.5:1 OSF 1.50 17247.97 3767.41 Min%-0SF Kigun 1(Del Survey) y t ' ^k= Pap 1M1=11E 32.81 5042.2 5011.911 8982.55 MAS=10.00(m) 169.07 169.07 MinPts 160.941 4273.62 4220.56 41.27 OSF 1.50 4804.22 2657.65 MinPts 4381.51 180.95 4273.62 4220.58 41.27 OSF 1.50 4805.77 2657.91 M.rt-O PADP 4384.44 181.22 4276.37 4223.21` 41.231 OSF 1.50 4838.42 2663.48 M11P10.SF 7625.86 103.18 7556.49 7522.69 112.76 OSF 1.50 5965.99 2855.72 TD INEIMIW 42.551 4884 701 4871.161 181.301 OSF 1.50 2100.17 1853.80 MinPts OP14-S3(Def Survey) pap 1A1 . .1I 32.81 17854.3 17823.69 1967007 MAO=10.00(m) 204.77 204.77 MinPts 17856.54 32.81 17854 17823.73 16292.14 MAS=10.00(m) 213.91 213.91 MINPT-O-EOU 15562.94 32.81 15544.13 15530.1 934.68 MAS=10.00(m) 654.14 651.65 MnPt.O4F 1 5586.571 393.07® i' 'MEI3E1 OSF 1.50 4745.91 2647.71 MinPts 0115-S4(Def Survey) Pap 17858.30 3281 17857.08 17825.491 Ni AS=10.00 On) 0.90 0.90 MnPt-OSF 6666 64 423.691 6382.591 6242.94 21.85 OSF 1.50 5025.23 2695.33 MinPts Nikanc hug 4(Del Survey) Pap I 8164.04 32.81 8162.10 MIME.307428.99 MAS=10.00(m) 52.90 52.90 MinPts 8164.07 32.81' 8162.0 8131.26 101351.39 MAS=10.00(m) 67.84 67.84 MINPT-O-EOU 8212.43 32.81 8208.64 8179.6 ME= MAS=10.00(m) 448.47 448.27 Min Pt4SF 8221.57 32.81 8217.77 8188.7. MAS=10.00(m) 468.83 468.55 Min Pt-O-SF 8337.41 32.81 8332.22 8304.6.1111EIME MAS=10.00(m) 646.20 643.88 Min PtOSF 8497.82 32.81 8491.91 8465.01 M1M11 MAS=10.00(m) 796.47 789.48 MinPFOSF 05=1 76.19 7863.67 7838.91 159.81 OSF 1.50 1493.75 1394.81 MinPt-CtCt ®'•' 78.52 7861.62 7836.08 154.93 OSF 1.50 1551.90 1438.53 MinPt-CtCt 7914.89 79.45 mmo 7835.44 153.08 OSF 1.50 1575.92 1457.96 MINPT4-E0U 7916.77 81.70 7861.67 ligE01 148.81 OSF 1.50 1632.64 1501.37 MnPt-0-ADP 7920.05 84.83M M. 7835.21 143.24 OSF 1.50 1708.53 1559.24 MINPT-O-EOU 7820,41 85.26 7862.9 142.51 OSF 1.50 1718.49 1566.62 MnPF0-ADP 7833.14 93 64'M"1 7839.50 129.70 OSF 1.50 1914.35 1714.91 MINPTO-EOU 7933.97 94.81 7870.1.mgige=En 088 1.50 1939,68 1733.93 MinPts Nlkaitchuq 3PB2(Del Survey) Pap mum 32.81 7914.12 7883.261 298088.97 MAS=10.00(m) 52.90 52.90 MinPts 7816.33 32.811 7813.471 7883.52 8428.54 MAS=10.00(m) 206.74 206.74 1.11NPT-0C00 7918.56 32.81 7815.22 7885.7•NEMO MAO=10.00(m) 278.89 278.89 MisPFO-SF 7989.02 32.81 7983.91 7956.2.MIME MAS=10.00(m) 553.13 552.23 MnPFOSF 8050.85 32.81 8045.29 8018.0 Num MAS=10.00(m) 654.68 652.18 MnPt-OSF 8131.59 32.81 8126.05 8098.7• 2239.81 MAS=10.00(m) 753.96 748.64 M11Pk0 4F 9332.13 32.81 9319.97 9299.321 911.00 MAS=10.00(m) 1356.35 1287.38 MnPt-OSF 9491.01 32.81 9478.58 9458.20 L 900.68 MAS=10.00(m) 1400.26 1322.34 M.rP1O8F 10536.85 32.81 10517,48 10504.041 603.84 MAS=10.00(m) 2123.17 1870.80 MnPt-0SF 10808.91 32.81 10789.07 10776.10 603.18 MAS=10.00(m) 2140.12 1883.21 MnPt-O 4F 10971.79 32.81 10951.73 10938.98 604.53 MAS=10.00(m) 2145.34 1887.01 WAN-0-SF 11035.59 32.81 11015.42 11002.78 L 604.711 MAS=10.00(m) 2146.54 1887.88 WIN-0-6F 1112408 32.81 11103.78 11091.27 604.97 MAS=10.00(m) 2147.16 1888.33 TD 1 .1)80I 32.811 11888.54 1 1096.001 604.9911 MAO=10.00(m) 2147.16 1888.33 MinPts Nikatchuq 3PB3 pet Survey) Pass ®' 32.81 7914.12 7883.261 298088.97 MAO=10.00(m) 52.90 52.90 MlnPts 7916.33 32.811 7913.471 7883.52 8428.54 MAS=10.00(m) 206.74 206.74 MINPT-O-EOU 7918.58 32.81 7915.22 7885.7•�- .n, MAS=10.00(m) 278.89 278.69 Mi1P1-0SF 7989.02 32.81 7983.91 7956.2.MIME MAS=10.00(m) 553.13 552.23 Min11-0SF 8050.85 32.81 8045.29 8018.0',MEM MAS=10.00(m) 654.68 652.18 MnPt-04F 8131.59 32.81 8126.05 0098.7•=MI MAS=10.00(m) 753.96 748.64 MitPFOSF 9332.13 32.81 9319.97 9299.3.iMIMM MAS•10.00(m) 135635 1287.38 MnPt44F 9491.01 32.81 9478.56 9458.2.1 900 68 MAS•10.00(m) 1400.26 1322.34 69rPt-0SF 10502.29 32.81 10482.83 10469.481 598.56 MAS=10.00(m) 2101.49 1854.78 MnPt-O4F 10581.26 32.81 10561.87 10548.451 MAS=10.00(m) 2106.94 1858.83 MnPtOSF 10661.02 32.81 10841.29 10828.21'MIMI MAS=10.00(m) 2111.87 1862.55 MnPtOSF 10704.78 32.81 10684.96 10671.95 MAS=10.00(m) 2114.52 1864.43 MnPt-0.SF 11419.96 32.81 11399.30 11387.16 608.94 MAS=10.00(m) 2138.67 1882.15 TD 1142490 32.81-MEM wpm 609 08 MAO=10.00(m) 2138.66 1882.15 MinPts Nikantchuq 3P01 Del Survey) Pap 7916.07 32.81 7914.12 7883. 298088.97 MAS=10.00(m) 52.90 52.90 MinPts 7916.33 32.81 7913.47 7883.52 8428.54 MAS=10.00(m) 206.74 206.74 MINPT-0-EOU 7818.56 32.81 791522 7885.7'.=Ma MAO=10.00(m) 278.89 278.89 MnPFO SF 7989.02 32.81 7983.91 7956.2.1 MEM MAS=10.00(m) 553.13 552.23 MnPI-0SF 8050.85 32.81 8045.29 8018.0': 2208.95' VAS=10.00(m) 854.68 652.18 M.P6-04F 8131.59 32.81 8126.05 8098.7•!® MAS=10.00(m) 753.96 748.64 MnPFOSF 9332.13 32.81 9319.98 9299.3.'. 911.00 MAO=10.00(m) 1356.35 1287.38 MilPFOSF 9491.01 32.81 9478.58 9458.2.1 900.68 MAS=10.00(m) 1400.26 1322.34 MirPFOSF 10536.85 32.81 10517.48 10504..'1 603 84, MAS=10.00(m) 2123.17 1870.80 MnPtOSF 10769.40 32.81 10749.64 10736.59 ME1M1 MAS=10.00(m) 2138.34 1881.91 MnP9-0SF 11155.42 32.81 11135.23 11122.81 IMMIEE MAS=10.00(m) 2152.69 1892.35 MnPF0 4F 11317.25 32.81 11296.86 11284.44 612.46 MAS=10.00(m) 2154.57 1893.71 TD 1• 32.81' MAS=10.00(m) 2154.57 1893.71 MinPts • Nika0chuq 3 Del Survey) Pap. ®'' 32.81 7914.12 7883.261 298088.97 MAS=10.00(110) 52.90 52.90 MinPts 7916.33 32.811 7913.47 7883.52 8428.54 MAS=10.00(m) 206.74 206.74 MINPT-0-EOU 7918.56 32.81 7915.22 7885.75 5561,04 MAS=10.00(m) 278.89 278.89 MnPF0.0F 7989.02 32.81 7983.91 7956.22 24.7 54 MAO=10.00(m) 553.13 552.23 1MPt-0SF 8050.85 32.81 804529 8018.04 2208.971 MAS=10.00(m) 654.68 652.18 MinP1OSF 8131.59 32.81 8126.05 8098.79 2239.811 MAS=10.00(m) 753.96 748.64 M.PS0-SF 9332.13 32.81 9319.97 9299.32 911.001 MAO=10.00(m) 1356.35 1287.38 MnP1-0-0F 9491.01 32.81 9478.56 9458.20 900.68 MAO=10.00(m) 1400.26 1322.34 M.nPt-0-OF 10502.29 32.81 10482.83 10489.45_ 598.56 MAS=10.00(m) 2101.49 1854.78 M W Pt-0-SF 10581.26 32.81 10581.67 10548.45_ 508.521 MAS=10.00(m) 2106.94 1858.83 M.rP1-0-5F 10661.02 32.81 10641.29 10628.21 598.61 MAS=10.00(m) 2111.97 1862.55 MinPtASF 10704.76 32.81 10884.98 10671.95 598.431 MAS=10.00(m) 2114.52 1864.43 MinPtOSF Drilling Office 2.6.1166.0 11419.96 32.81 11399.30 11387.16 Nika9chughrypy.IsYsnd\SHINON2\SPIS1FN2\SI19-FN2(P5) 3/11/2013 11:14DAM Page 8 of 12 Offset Trajectory Separation A. Sep. Controlling Reference Trajectory Ris,. Alert I Status CI-Ct(ft)I MAS(ft).1 EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) I Alert [nor -1 Major 1306362 3281 13044 77 13033721 775.561 MAO=10.00(m) 1837.82 1505.33 MinP409F II 11424.9011 32.811® 11392.091 609.081 MAS=10.00(m) 2138.66 1882.15 MinPts OP10-09(Der Survey) Pees `®' �' 32.81 17846 02 1111/11* N/A MAS=10.00(m) 0.97 0.97 MinPts 17847.67 32.81 17845.80 17814.86 27387.98 MAS=10.00(m) 169.35 169.35 MINPT-0-EOU 17847.17 32.81 17845.11 17814.371 21140.331 MAS=10.00(m) 213.88 213.88 M rP40-SF _17846.60 32.81 17844.55 17813.801 21597.811 MAS=10.00(m) 220.75 220.75 MnPt-O-SF 342.81 7820.50 7707.55 35.62 OSF 1.50 3062.55 2355.80 M61Pt-CICt 8052.33 348.4511== 7703.68 35.04 OSF 1.50 3135.12 237224 MINPT-0-EOU 1 8053 051 367.70 7806.62 7685.35 33.19 OSF 1.50 3495.43 2434.52 MinPtCICt 1 8053.531 392.31 7790.69 7661.22 31.09 OSF 1.50 4024.29 2524.68 MInPt-CCICt 8054.46 395.3 Ma1.121 7659.10 30.85 OSF 1.50 4195.72 2543.68 MINPT-0-EOU 414.09 7763.98 7827.24 29.39 OSF 1.50 4810.60 2658.74 MinPtCtCt 8041.56 414.7.EIMER 7626.77 29.34 OSF 1.50 4835.07 2662.91 MINPT-0-E00 MIMI 422.67 7755.56 7615.97 28.78 OSF 1.50 5108.97 2708.61 MinPFCtCt 8039.50 424.971 7754.89, 7614.53 28.62 OSF 1.50 5187.22 2722.95 MINPT-0-EOU 8043.42 431.49 7754.46 7811.93 28.20 OSF 1.50 5406.57 2760.34 MINPT-0-EOU 8044.87 433.25 7754.75 7611.83 28.09 058 1.50 5465.07 2770.32 MinPI-0-ADP 8060.39 445.711=1=ElgEn® OSF 1.50 5879.54 2840.98 MinPts Nikanchuq 1(Def Survey) Pas WrInE 32.81 8045.62 8015.5.11 10292.68 MAS=10.00(m) 218.19 218.19 MnPM 8048.37 32.811 8045.58 8015.57 9147.52 MAS=10.00(01) 233.29 233.29 MINPT-OEOU 8049.59 32.81 8046.58 8016.78 7221.98 MAS=10.00(01) 288.55 288.55 M8F8-0-0F 8288.12 32.81 8253.30 8235.32 640.18 MAS=10.00(01) 698.72 695.15 MinPPOSF 8364.79 32.81 8346.85 8331.98 521.85 MAS=10.00(01) 788.91 780.33 MnPt-O-SF 8559.48 32.81 8540.48 8526.671 500.981 MAS=10.00(01) 913.19 899.88 M'PI-0SF 11308.83 67.90 11262.93 11240.931 257.031 OSF 1.50 2301.34 1995.75 MnPt-O-SF 11786.75 71.29 11738.58 11715.46 254.811 OSF 1.50 2371.53 2041.45 MnPt-03F 12794.14 74.37 12743.92 12719.77 264.83 OSF 1.50 2498.50 2118.61 TD Nikaitchuq 4PB1(Def Survey) Pass Mallal 32.81 8162.10 8131.231 307428.99 MAS=10.00(m) 52.90 52.90 MinPts 8164.07 32.811 8162.071 8131.26 101351.39 MAS=10.00(m) 67.84 67.84 MINPT-0-EOU 8212.43 32.81 8208.84 8179.6 jE MAS=10.00(In) 448.47 448.27 MnPt-0-SF 8221.57 32.81 8217.77 8188.7u Man MAS=10.00(m) 468.83 468.55 MnPt-O-SF 8337.41 32.81 8992.22 8304.6.mmiE MAO=10.00(m) 646.20 643.88 MnPt-0-SF 8497.82 32.81 8491.91 8465.01 EMU MAS=10.00(In) 798.47 789.48 MinPt-0SF 9017.89 32.81 9009.14 8985.08 IMMEil MAS=10.00(81) 1094.75 1065.49 Millet-0-6F 0113-03(Def Survey) i . Pass I 9539.251 335.70 9314.37 9203.55 43.02 OSF 1.50 3011.05 2342.10 MinPtC8Ct 952770 367.43 9281.68 9160.26 39.22 OSF 1.50 3580.94 2449.10 MinPtCtCt 9529,84 381.22 9274.64 9148.62 37.80 OSF 1.50 3840.02 2493.27 MinPFCtCt 9532.59 381.31 Iljljl 9141.28 36.82 OSF 1.50 4181.11 2551.42 MINPT-0-EOU 9533.86 392.85 9270.9'MaIME 36.68 OSF 1.50 4240.25 2581.50 M'P1-0-ADP Iffraleg 419.88 9242.17 9103.24 34.26 OSF 1.50 5224.25 2729.26 MnPICtCt 551.58 MMIZEii MERE IIIMEI OSF 1.50 8889.40 3354.12 MinPts OPO4-07(Def Survey) Pass MEMO 1 32.81'',Ijjji N/A MAS=10.00(m) 0.74 0.74 MinPM 1783664 32.81 MEM 17803.83 32637.80 MAS=10.00(01) 160.74 160.74 MINP7-0-E06 17837.20 32.81 1783318 17804.391 22475 851 MAO=10.00(m) 216.79 216.79 MnPM3 SF 9100.17 91.471 9037.591 900810 157.41 OSF 1.50 899.95 887.50 MinPts OP12-01(Def Survey) Pass MEM 210.381 9321.181 9252.411 68.771 OSF 1.50 1266.27 1213.50 MinPts OP08-04(Def Survey) Pass 17542.53 32.81 17531.69 17509,721 1839.521 MAO=10.03 m 445.78 445.58 MirP1-0SF 12257.16 41.40 1222831 12215,761 488.191 OSF 1.50 792.36 785.55 Mr P1-0-SF 69.21 10128681 10107.15 2236.24 OSF 1.50 924.82 910.73 MinPts OPO4-07P51(Def Survey) Pass 11 17835 35i1 32 811 17837'31 17803 5411 N/A MAS=10.00(m) 0.74 0.74 MinPts 17836.64 32.81 17834.86 17803.83 32637.80 MAS=10.00(m) 160.74 160.74 MINPT-0-EOU 17837.20 32.81 17835.18 17804.3'/EMU MAS=10.00(m) 216.79 216.79 MAPt-0-OF • .' 74.03®. MEM WEElil OSF 1.50 845.52 83620 MinPts 0107-04(Def Survey) Pass h In 17841.991 32.81 17838.88 +��' '�' 9422.03 MAS=10.00(m) 220.70 220.70 MinPts 17772.07 32.81 MEM 17739.26 1497.43 MAO=10.00(m) 506.65 506.15 MINPT-0-EOU 16236.41 48.72 16203.29 16187.6/Ijj MEI OSF 1.50 672.88 669.97 MnP1-0-SF 16076.20 48.51 1604320 16027.6•.1 OSF 1.50 676.76 673.76 M9nPt-0SF 14910.56 51.40 14875.48 14859.1•i.' OSF 1.50 700.99 697.35 MnPt-O-SF 14744.59 51.14 14709.65 14693.•.MEM OSF 1.50 705.30 701.54 M9tPt-0SF 14337.67 52.68 14301.65 14284.9•®" OSF 1.50 716.65 712.56 MnPt-OSF 10340.09 83.13 EMED n®.' ii2C1 OSF 1.50 831.73 823.11 MinPts Oliktok Point 1-2(Def Survey) POs 10529.89 258.691 10356,391 10271,201 61.71 OSF 1.50 1327.46 1263.99 MinPts 0111-01(Def Survey) Paw 11 17888.84i1 32.81 17847.621 17816.0311 N/A MAS=10.00(m) 0.85 0.85 MinPts 17849.07 32,81 17847.05 17816.26 22295.06 MAS=10.00(m) 205.90 205.90 MINP7-0-EOU 17849.58 32.81 17847.22 17816.77 15721.24 MAS=10.00(01) 225.97 225.97 MnPPOSF 17850.07 32.81 17847.95 17817.264 19874 87 HAS=10.00(m) 254.96 254.95 MnPt-0SF wpm 85.41.10497.901 10470.92 195.57 OSF 1.50 974.38 956.61 MinPts OP17-02(Def Survey) Paw 117737-181.401 32.81 17859.891 17828.5911 63890.12 MAO=10.00(m) 114.82 114.82 MinPts 17861.42 32.811 17859.881 17828.61 56353.38 MAS=10.00(01) 125.85 125.85 MINPT-0-EOU MIKEM 324.17 10877.13 10769.76 51.65 OSF 1.50 1859.36 1673.51 MnPt-CtCt 11094.32 325.3•MEM 10769.00 51.47 OSF 1.50 1871.26 168247 MINPT-0.EOU 8887 11095.04 326.14 10876.9 El= 51.31 OSF 1.50 1878.75 1688.87 MFPt-0-ADP 11114.85 342.111 10886.16 10772 74 48.99 OSF 1.50 2050.89 1817.12 MINPT-0-EOU 11116.06 343.57 10886.41 maim 48.78 OSF 1.50 2087.07 1829.18 MnP1-0-ADP 11116.24 343.86 10886.3: 'E1, 48.75 OSF 1.50 2132.90 1877.94 MnPt-0-ADP 11115.50 342.9:MEMEE, 10772.52 48.87 OSF 1.50 2143.69 1885.81 MINP1-O-EOU 11104.69 330.09 10883.9. 1 50.79 OSF 1.50 2316.35 2005.70 MnPt-0-ADP 11103.94 329.1:18 10774,76 50.93 OSF 1.50 2329.67 2014.45 MINP7-0•EOU NM& 327.35 10884.31 10775.94 51.22 OSF 1.50 2357.07 203220 MinPtCICt 355.72 10845.22 10727.41 47.03 OSF 1.50 3103.38 2365.46 MinPtCtCt 11084.31 358.8 i "r" 1 10725.48 46.62 OSF 1.50 3151.28 2375.45 MINPT-0-EOU 420.30 10748.12 10808.79 39.57 OSF 1.50 4751.04 2848.58 MinPtCICt 11029.57 421.891 10747.681 10607.88 39.44 OSF 1.50 4800.60 2657.03 MINPT-0-EOU 11030.18 422.40 10747.82 10607.781 39.38 OSF 1.50 4825.36 2661.25 MnPt-0-ADP 11092.75 438.28 10799.81 10654.47 38.151 OSF 1.50 5378.14 2755.49 50181-0SF DDrlli n oWP esr: )1166.0 Nikaitchuq\Spy Island\S119-FN2\S119-FN2\SI19-FN2(P5) 3/11/2013 11:14 Arr Page 9 of 12 Offset Trajectory Separation Allow Sep. I Controlling I Reference Trajectory Risk Level Alert Status `Ct-Ct(ftj MAS(ft)I EOU(N) Dee.(f_14 Fact. Rot. MD(ft) I ND(ft) I Alert I Minor I Major 1786140 32.81 17859.89/ 17828.59 63889.94 MAS•10.00(m) 114.82 114.82 MinPts 17861 42 32.81 17859.88 17828.61 56353.23 MAS=10.00(m) 125.85 125.85 MINPT-O-EOU I.I 336.15 10911.70 10800.30 49.97 OSF 1.50 1978.71 1761.70 MinPFCtCt 11136.77 337.14 MGM 10799.63 49.83 08F 1.50 1987.68 1769.91 MINP7-0-E0U 11137.16 337.63 10911.44 MIME 49.75 OSF 1.50 1993.18 1774.03 M9nPt-0-ADP 11139.38 338.86 10912 73 10800.4. 49.58 086 1.50 2203.98 1929.00 MInPt-O-ADP 11139.01 338.51, 10912.66] 10800.50 49.65 OSF 1.50 2210.04 1933.26 MINPT-0-EOU 337.75 10912.92 10801.01 49.76 OSF 1.50 2220.22 1940.39 MInPtCtCt !BMW MIER 353.28 10880.17 10763.19 47.50 OSF 1.50 3057.00 2354.40 MInPt-CtCt 11117.58 357.8 l 10759.74 46.90 OSF 1.50 3126.25 2370.42 MINP7-0.906 11118.60 359.08 10878.4 I & 46.74 OSF 1.50 3145.32 2374.29 MInPt•0.4DP MIDECCI 378.51 10876.58 10751.17 44.36 OSF 1.50 3527.34 2439.96 McPtCtCt 409.98 10820.17 10684.26 40.81 OSF 1.50 4354.83 2581.03 MinPt.CCtCt 11094.64 411.18 '®' 10683.46 40.69 OSF 1.50 4399.00 2588.57 MINP7-0-EO5 11095.08 411.72 10819.8 MEMMII 40.81 OSF 1.50 4418.67 2591.92 M.tPFOADP 11110.78 422.; 111002EM 10688.11 39.63 OSF 1.50 4813.55 265924 MINP7-O-EOU 11111.18 423.51 10828.40_ 10687.9: 39.56 OSF 1.50 4843.35 2664.32 MnP1-0ADP 11117.47 428.15 10831.29 10689.3 39.15 OSF 1.50 5007.62 2692.33 MnP4-0-ADP IIii 442.73 10837.55 10690.71 37.90 OSF 1.50 5506.80 2777.43 MnPFCICt 11134.15 444.8 ]III I 10889.30 37.73 OSF 1.50 5576.37 2789.63 MINP7-0-600 11135.12 445.99 10837.0 II= 37.63 OSF 1.50 5818.79 2796.18 MhP1-0-ADP II 11131.1011 441.11 MEDEIM Ma=MEE OSF 1.50 6119.41 2881.87 MinPts OP03-P05 pet Survey) Pas MEM1 32.81 17833.48,x. .1 127319.96 MAS=10.00(m) 90.90 90.90 MinPts 17835.08 32.81 IMEEIE1 1780228 28993.01 MAO=10.00(m) 200.20 200.20 MINPT-O-EOU It 17741.0311 32.81 17727.47' '.•�• 1439.37 MAS=10.00(m) 502.69 502.22 MInPts 17741.24 32.81 17727.1 17708.43 1379.96 MAS=10.00(m) 505.01 504.52 MINPT•OEOU 17118.58 55.35 17081.23 17063.2 MUM OSF 1.50 632.29 630.25 MEIN-OSF ®"= 91.05 11482.27 11453.03 197.32 OSF 1.50 780.31 774.00 MinPts 0106-05(Def Survey) Pare II 1783941 fl 32.811E 17838.181 17806.6011 N/41 665=15.00(m) 1.01 1.01 MinPts 17839.46 32.81 17837.8 17806.65 45254 13 MAS=10.00(m) 136.01 136.01 MINP7-0-EOU 17996.45 32.81 17981.64 17963.641 MAS=10.00(m) 394.78 394.69 MnP1-0-SF 17580.58 9820 17514.76 17482.3:MEM OSF 1.50 830.36 628.35 MinPt•0-6F 18733.09 98.03 18667.32 16635..:IIMEGE OSF 1.50 844.62 642.33 MErPI-0-6F 15542.63 97.42 15477.10 15445.21 mum OSF 1.50 868.49 665.69 MinPt-0-SF 15458.47 97.02 15391.19 15359.4'IIIIIII M OSF 1.50 869.93 687.09 64168-0SF 15372.73 96.53 15307.77 15276.2.Min OSF 1.50 871.51 666.64 MinPt-0SF 15307.25 96.35 15242.41 15210.91 MEE OSF 1.50 672.88 669.97 MinP1-0SF 14904.15 94.53 14840.47 14859.6.MUM OSF 1.50 681.71 678.58 MinPt-O-SF 14450.71 92.85 14388.08 14357.8 INEExp OSF 1.50 690.78 687.42 MnPtQSF 14362.13 92.41 14299.80 14269.7.MEM OSF 1.50 893.19 689.77 64rPt-0SF 13842.90 88.67 13783.00 13754.2 240.60 OSF 1.50 708.62 704.77 MnPt-0SF 13687.38 88.49 13627.58 13598.8•MEM ME' 056 1.50 712.76 708.79 MnPt-0-SF 12999.31 89.22 12939.00 12910.0•MBE OSF 1.50 728.92 724.45 M9rPt-0-SF 12585.52 87.69 12506.22 12477.8® OSF 1.50 743.13 738.20 MnPO-0$F EMU 85.81®®. OSF 1.50 772.67 766.66 MlnPls 0124-08(Del Survey) Pass MIME 32.81 l x; N/A MAO=10.00(m) 1.90 1.90 MinPts MEM 338.54 11983.99 11871.00 54.31 OSF 1.50 1927.77 1724.99 MinPICICt 12209.94 339.7'MilE 11870.19 54.12 OSF 1.50 1942.41 1735.98 MINPT•0-EOU 12210.46 340.36 11983.11 I ''. 54.02 OSF 1.50 1949.76 1741.50 MnPFOADP 12218.34 347.41 11986.21 lam 52.95 OSF 1.50 2163.45 1900.12 MnPt-0ADP 12213.72 342..,MEM 11871.66 53.78 OSF 1.50 2229.18 1946.69 MINP74•E05 MIME 341.25 11985.43 11872.16 53.91 OSF 1.50 2239.80 1953.86 MnPI-CtCt MEM 483.991 11455.641 11294.951 36.641 OSF 1.50 6232.04 2901.07 MinPts 0708-04781(De(Survey) Pars 17542.53 32.81 17531.69 1750972 1839.52 MAS=10.00(m) 445.78 445.58 MnPt-0-SF 12280.93 41.42 12252.06 12239.51 488.99 OSF 1.50 789.24 782.56 M8P1-0S5 39.92®' 11111a1131 MEM OSF 1.50 800.43 793.27 MinPts 0106-05P51(Del Survey) Pas MO=I 32.81 1�11� T� llllll E MAS=10.00(m) 1.01 1.01 MnPtc 17839.46 32.81 eeYl'Ll6'Y 17806.66 46254.13 MAS=10.00(m) 136.01 136.01 MINPT.0EOU 17996.45 32.81 17981.64 17963.•' E MAS=10.00(m) 394.78 394.69 MnPFOSF 17580.58 98.20 17514.76 17482.3.'.MEINE OSF 1.50 630.36 628.35 M.rP1-0SF 16733.09 98.09 16887.32 16635..e MIME OSF 1.50 644.62 642.33 MnP1-0SF 15542.83 97.42 15477.10 15445.21- OSF 1.50 868.49 665.69 M.rPt-0SF 15456.47 97.02 15391.19 15359. Imam OSF 1.50 669.93 667.09 MOPt•0-SF 15372.73 98.53 15307.77 152713. .MIES OSF 1.50 671.51 668.64 M9nPt-0SF 15907.25 96.35 15242.41 15210.91 MEM OSF 1.50 672.88 669.97 MnPt-0SF 14904.15 94.53 14840.47 14809.6.E OSF 1.50 681.71 678.58 MnP1-0SF 14450.71 92.85 14388.08 14357.8'MEM OSF 1.50 690.78 887.42 MnPF0SF 14382.13 92.41 14299.80 14269.7.=ME OSF 1.50 693.19 689.77 WIN-0,4F 13842.90 88.67 13783.00 13754.2.I 240 60 OSF 1.50 708.62 704.77 MnPt-0SF 13887.38 88.49 13627.58 13598.8.MME OSF 1.50 712.78 708.79 MnPl-0-SF 12886.07 88.98 12805.90 12777.0.1,MEM OSF1.50 73128 728.74 MnPt4SF 12606.56 87.31 12547.50 12519.2 I® OSF 1.50 737.99 73323 MnP1-0.4F 12479.71 86.76 12421.01 12392.9-I® OSF 1.50 742.74 737.62 64861-0-SF 111E113:12 89.07 MR=NOME IIIIECEED OSF 1.50 758.16 752.70 MinPts O0Mok Poln11-2602(Del Survey) Pas 182.081 12258.761 12199.08( 103.701 OSF 1.50 996 46 976.86 MinPts OP05-06(Def Survey) Pas _M 32.81:F N/A MAS=10 00,r-r) 0 84 0.84 MinPts 17838.04 32.81 NEM 17805.23 35783.56 MAS=10.00 Im) 155.84 155.84 MINP7-0-E06 17904.84 32.81 17887.83 17871.84 1148.50 MAS=10.00(m) 375.75 375.69 MnPM-0-8F 18001.62 32.81 17984.20 17968.81 MAO=10.00(m) 441.67 441.49 MnP1-0SF 18659.87 120.35 18579.28 18539.5.NI= OSF 1.50 608.43 606.80 MinP1-0SF 18078.81 116.67 18000.70 17962.1 MEE OSF 1.50 1325.85 623.92 MnP1-0SF 17020.65 108.76 18947.81 16911.8.1® OSF 1.50 640.25 638.05 MinP1•0-SF 18852.41 105.81 16581.52 16546.5•I® OSF 1.50 643.36 641.10 MTP10SF 18345.83 104.44 16275.65 16241.1•'® OSF 1.50 647.62 645.27 MnPt-0-SF 18220.29 104.13 16150.51 16116.1 lIMIE OSF 1.50 649.73 647.34 MnPt-0SF 16027.90 103.18 15958.73 15924.7.I/IIMU OSF 1.50 653.25 650.79 MnPt-0-SF 15348.72 96.79 15283.73 15251.9 II) OSF 1.50 668.15 665.36 MirPt-0-SF 14992.59 93.58 14929.71 14899...Man OSF 1.50 676.49 673.50 M.rP1-0-6F 14719.92 91.67 1465828 14628.2'x OSF 1.50 682.75 679.60 Mi1P60SF 14449.09 90.60 14388.16 14358.41 MEW OSF 1.50 68721 683.94 MIP1-0SF 14014.28 86.43 13956.11 13927.8'MIKE OSF 1.50 697.05 693.52 MnP1-0-4F 13544.94 82.10 13489.65 13162.6 I® OSF 1.50 711.35 707.42 MnP1-0SF 86.09 EM374 MEMO Man OSF 1.50 749.18 744.04 MinPts OP18-08(Def Survey) Pass Drilling Office 2.6.1166.0 13524.71 32290f1 13309.051 13201.81i1 Nikalt chug\SpA1sla0ld\Sllti-AN2\S)t FN2\S119-FN2(P5) 3/11/2013 11:M4PAM Page 10 of 12 Off set Trajectory 1111M171 t.. Sep. Controlling I Reference Trajectory �R is, Alert Status Ct-Ct(ft MAS(ft) EOU(ft) Dev.(ft)I Fact. Rule MD(ft) I 'ND(ft) Alert I minor 7 Major 13524,5- 323.85 13308.31 13200.74 62.86 OSF 1.50 1438.11 1350.34 MinPt-CtCt MEEDIEE 329.88 13305.37 13195.76 61.69 OSF 1.50 1502.74 1401.73 MinP6•C1Ct 13519.3, 342.23 13290.88 13177.15 59.43 OSF 1.50 1644.71 1510.59 MinPt-CtCt 13519.66 343.071= 13176.59 59.29 OSF 1,50 1654.58 1518.13 MINPT-O-EOU 13520.03 343,49 13290.69 13176.541 59.21 OSF 1.50 1659,53 1521.90 MnPt-0ADP 13627.99 376.1 13378.87 13251.82 54.49 OSF 1.50 2036.62 1808.48 MINPT-O-EOU 13628.67 377.2 13376.81 13251.39 54.33 OSF 1.50 2139.64 1882.86 MINPT-0EOU 13546.05 349.65 13312.58 13196.411 58.30 OSF 1.50 2457.87 2094.71 MinPt-O-ADP 13545.86 349.44 13312.54 13196.45 58.34 08F 1.50 2461.33 2096.78 MINPT-O-EOU MEMl 348.80 13312.75 13196.87 58.44 OSF 1.50 2470.04 2101.95 MnPtCtCI /ME 351.63 13309.38 13192.58 57.97 OSF 1.50 2673.57 2212.06 MnPFCtCt 13544.71 353.011.3308 9B'i 13191.70 57.75 OSF 1.50 2695.00 2222.34 MINPT-O-EOU 13551.89 364.311 13308.64! 13187.59 55.97 OSF 1.50 2875.63 2298.19 MINPT-0-EOU 13552.34 364.83 13308.7 MIME 55.89 088 1.50 2884.48 2301.41 M6PI-0-ADP 511.08 12245.55 12075.67 37.04 OSF 1.50 7221.77 3069.81 MinPts OP18-05PB2(Del Survey) Pep 13524.71 322.8 13309.10'111EMIX 53.07 OSF 1.50 1429.17 1344.96 MinPts 323.77 13308.36 13200.81 62.87 OSF 1.50 1436.11 1350.34 MinPt-CtCt llllERIEM 329.81 13305.42 13195.84 61.71 OSF 1.50 1502.74 1401.73 MnPt-CtC1 lull E 342.15 13290.94 13177.23 59.44 OSF 1.50 1644.71 1510.59 MnPI•CtCt 13519.66 342.9.1 13290.66 13176.67 59.30 OSF 1.50 1654.59 1518.13 MINPT-0•EOU 13520.03 343.41 13290.741111Mu 59.23 OSF 1.50 1859.53 1521.90 MnPI.0.ADP 13627.99 376.1 MEM 13251.91 54.50 OSF 1.50 2036.62 1806.48 MINPT-O-EOU 13628.67 377.1. 13376.86 13251.48 54.34 OSF 1.50 2139.64 1882.86 MINPT-O-EOU 1354605 349,57 13312.63 1111 1 58.31 OSF 1.50 2457.87 2094.71 MnPF0-60P 1354586 349.3 ARNE 13196.53 58.35 OSF 1.50 2461.33 2096.78 MINPT-O-EOU I 13545.671 348.72 13312.81 13196.95 58.45 OSF 1.50 2470.04 2101.95 MinPt-CtCt 1 13544 221 351.55 1330944 13192.66 57.89 OSF 1.50 2673.57 2212.06 MinPt-CtCt 13544.71 352.93 13309.02 13191.78 57.76 OSF 1.50 2695.00 2222.34 MINPT-0-EOU 13551.89 3642 13308.69 13187.67 55.98 OSF 1.50 2875.63 2298.19 MINPT-0-EOU 13552.34 364.75 13308.79. 13187.591 55.90 OSF 1.50 2884,48 2301,41 M'Pt-O-ADP I '®' 463.981 12721.69 12567.45 42.241 OSF 1.50 5643.24 2800.69 MinPts 0111-01 PB1(Del Survey) Ps hill 32.81 MUM MEM WA MAS=10.00 On) 0.85 0,85 MinPts 17849.07 32.81 MEIMIZE 17818.26 22295.06 MAO=10.00(m) 205.90 205.90 MINPT-0-EOU 17849.58 32.81 17847.22 17816.77 15721 24 MAS=10.00(m) 225.97 225.97 MInPI-0SF 17850.07 32.81 17847.95 17817. 19874.87 MAO=10.00(m) 254.96 254.95 Minn-0.6F I®" 32.811 13229.161 13217.69 740.79 MAS=10.00(m) 781.97 775.59 Minns OP05-06P82(Def Survey) Pap 11 17837.8811 32.81 NEM EIMEE N/A MAS=10.00(m) 0.84 0.84 MinPts 17838.04 32.81 EL= 17805.23 3578356 MAS=10.00(m) 155.84 155.84 MINPT-0-EOU 17904.64 32.81 17887.83 17871..•lllllll MAS=10.00(m) 375.75 375.69 McPR0.SF 18001.62 32.81 17984.20 17968.81 m' MAS=10.00(m) 441.67 441.49 MInPI0-SF 18659.87 120.40 18579.25 18539.4 Man OSF 1.50 608.43 606.80 M,lP1-0SF 18078.81 116.71 18000.66 17962.10 MIMI OSF 1.50 625.85 823.92 MnPFPSF 17020.65 108.81 16947.77 16911.8.E OSF 1.50 640.25 638.05 Mil P1-0-SF 16652.41 105.87 16581.49 16546. •!MIME OSF 1.50 643.36 841.10 Minn-06F 16345.83 104.49 18275.82 18241.1 'I�1 OSF 1.50 847.62 845.27 MnP9-0SF 18220.29 104.18 16150.48 16116.1.NEW OSF 1.50 649.73 647.34 MnPtO-SF 16027.90 103.23 15958.89 15924.,,MEM OSF 1.50 653.25 650.79 Minn-OSF 15348.72 96.85 15283.69 15251.8 mmEILE OSF 1.50 668.15 685.38 MnP1-0SF 14992.59 93.63 14929.87 14898.<,=3=0 OSF 1.50 676.49 673.50 Minn-0-6F 14719.92 91.73 14658.25 14828.1.- OSF 1.50 882.75 879.60 WIN-0-OF 14449.09 90.65 14388.12 14358.,,- OSF 1.50 687.21 683.94 Minn-0-SF 14014.28 86.48 13956.07 13927.81- OSF 1.50 697.05 693.52 MnPI-0SF 13719.49 83.02 13663.58 13636.4 LmEgm OSF 1.50 705.73 701.98 Minn-0.6F I.''1 80.28 MEOW MEIIIIIIMIME0 OSF 1.50 723.82 719.51 MinPls OP03-P05PB2(DO Survey; Pap MI= 32.81 17833 481 17802.03]127319.96 MAS=1000(m) 90.90 90.90 Minns 17835.08 32.81 17833.23 17802.28 26993.01 MAO=10.00(m) 200.20 200.20 MINPT-0-EOU MEM 32.81 17727.471 17708 24 1439.33 MAS=10.00(m) 502.69 502.22 Minns 17741.24 32.81 17727.15 17708.43 1379.93 MAO=10.00(m) 505.01 504.52 MINPT-O-EOU 17118.58 55.36 17081.23 17063.2] 475 25 OSF 1.50 832.29 830.25 MnPEOSF 72.071 13219.451 13196.401 287.71 OSF 1.50 727.27 722.86 MinPts OP76-03(Def Survey) Ps illlllM1 32.81 17857.581 17827 001 17723.02 MAS C 10.00(m) 203.66 203.66 MinPts 17859.81 32.811 17857.571 17827.01 17473.45 MAO=10.00(m) 207.09 207.09 MINPT-0-EOU 17859.83 32.81 17857.58 17827.021 MAS=10.00(8) 210.52 210.52 Minn-0-6F .111112t 308.55 13952.74 1385089 69.49 OSF 1.50 1367.87 1298.82 MnPFCtCt 14157.67 307.2 MIME 13850.44 69.34 OSF 1.50 1372.37 1300.22 MINPT-0-EOU 14157.89 307.50 13952.5.MEEIEN 69.28 OSF1.50 1374.18 1301.66 M.,PF0-ADP 14250.74 336.29 14026.2. 13914.4 63.75 OSF 1.50 1667.10 1527.68 MinPt-0-ADP 14275.43 350.05 14041.7 13925.38] 61.34 0081.50 2323.70 2010.59 MnP1-0-ADP 14274.81 349.261 14041.64 13925.55 61.48 OSF 1.50 2332.51 2016.30 MINPT-0-EOU EMILIE 343.64 14043.60 13929.38 62.48 OSF 1.50 2398.33 2058.34 MnPICICt 1111110.; 337.42 14048.22 13936.08 63.63 OSF 1.50 2477.59 2106.41 MnPtCICI 360.77 14019.27 13899.34 59.45 OSF 1.50 3020.85 2344.84 MinPt•C1C6 14280.63 382.'1 13898.33 59.20 OSF 1.50 3047.58 2351.99 MINPT-0-EOU 14261.38 383.21 14018.91 MIME 59.05 OSF 1.50 3063.61 2356.08 M11Pt-0-ADP 14336.63 404.52 14086.6. 13932.11 53.29 OSF 1.50 3869.42 2498.28 M41P8-.0-ADP 483.441 13260.96 13100.14 42.231 OSF 1.50 6713.45 2983.15 MinPts OP23-W W 02(Def Survey) Ps MEM 32.81 1787024 mum 23117.22 MAS=10.00(m) 215.10 215.10 MnPls 17872.24 32.81•MIERE1 17839.43 23007.44 MAS=10.00(m) 216.24 216.24 MINPT-0-EOU 17872.43 32.81 17870.39 17839.6.NM= MAS=10.00(8) 231.72 231.72 MinPFOSF 17882.87 32.81 17880.38 17850.1,IIIIME MAS=10.00(m) 352.97 352.93 MinPF0.SF 17851.77 32.81 17848.12 17818.•11.5g= MAS=10.00(m) 442.72 442.53 M91P1-0SF Ma= 54.27 13927.96 13911.02 412.04 OSF 1.50 1149.48 1113.67 MnPtCIC1 13965.30 54.291 13927.961 13911.471 411.87 OSF 1.50 1149.96 1114.11 MinPts 14768.22 57.36 14729.65 14710.8 392.921 OSF 1.50 1372.58 1300.38 MnPt-0-SF 14799.88 57.45 14761.25 14742.43 393.14 OSF 1.50 1378.67 1305.24 TD Oliktok Point 1-2P81(Def Survey) Ps 123.621 14561.861 14521.491 181.351 OSF 1.50 833.16 824.47 MinPts OP26-DSPO2(Def Survey) Ps II 18064.1911 32.81 18063.0:mum WA MAO=10.00(m) 0.89 0.89 MinPts 18064.37 32.81 acc3NE 18031.56 26727.28 MAS=10.00(m) 200.20 200.20 MINPT-0-EOU 17805.14 32.81 17798.65 17772.3•=ME MAS=10.00(m) 444.77 444.58 MnP1-OSF 14663.69 32.81 14640.88 14830.88 741.92 MAS=10.00(m) 947.73 932.00 MinPts 14663.70 32.811 14640.88 14630.89 741.41 MAS=10.00(m) 948.32 932.55 MINPT-O-EOU 14871.67 35.93 14846.94 14835.74111111111 OSF 1.50 1068.77 1042.31 MnP1-0SF 14930.94 35.74 14906.41 14895.21 866.57 OSF 1.50 1085.79 1057.52 TD Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\5119-FN2\5119-FN2(P5) 3/11/2013 11:14 AM Page 11 of 12 Offset Trajectory Separation Avow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAO(ft)I EOU(ft) Des.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major 0120.01 pet Survey) Vass 15458.90 268.54 15279.48 15190.35 86.72 OSF 1.50 919.59 905.85 MinPt-CtCt 272.24 15277.59 15187.20 85.52 OSF 1.50 948.42 932.64 MinPt-CtCt 1545951 272.7 EggrglEM 15186.84 85.36 OSF 1.50 952.43 936.35 MINPT-O-EOU 15459.71 272.91 1527741 ERIMEE 85.30 OSF 1.50 953.92 937.73 MiPt-0-ADP I 15468 431 346.52 15237.09 15121.91 67.15 OSF 1.50 1905.54 1708.28 MinPtLYCt • 14690.60 489.341 14364.041 14201.251 45.121 OSF 1.50 7118.55 3052.21 MnNs 0120-07P02(Del Survey) Pass 1 15458.901 268.03 15279.82 15190.87 86.89 OSF 1.50 919.51 905.78 MivPt-C1Ct 1 15459.451 271.71 15277.94 1518774 85.68 OSF 1.50 948.33 932.56 MinPt-CtCt 15459.56 272.19 15277 74 15187.37 85.53 OSF 1.50 952.34 936.27 MINPT-O-EOU 15459.70 272.38 15277 761 15187.331 85.47 OSF 1.50 953.83 837.65 MinPt-O-ADP namm 440.501 14941 47 14794 961 51.991 OSF 1.50 4799.12 2656.78 MinPts 0120-07PB1(Def Survey) Pass 305.401 15214.801 15113.421 76.041 OSF 1.50 881.39 870.07 MinPts OP22-W W 03(P4)(Def Plan) Pass UM% 32.81 17868.75 '®'. r 14670.75 MAS=10.00(m) 196.90 196.90 MinPts 17871.43 32.81®. 2 17838.62 8528.33 MAS=10.00(m) 223.34 223.34 MINPT-O-EOU 17872.95 32.81 17669.80 17840.141 8448.311 MAS=10.00(m) 246.23 246.23 MilPtO-SF 15982.12 57.49 15942.95 15924.62 435.981 OSF 1.50 1026.98 1004.65 M.PtOSF 15930.39 56.9'MR= 15873.44 438.56 OSF 1.50 1072.93 1046.04 MinPts 15930.21 56.83 15891.53 15873.38 438.83 OSF 1.50 1075.21 1048.07 MnPF0-ADP MEM 56.821 15891.53 15873.38 438.90 OSF 1.50 1075.78 1048.58 MnPls 16755.20 70.95 16707.57 16684.25=BM OSF 1.50 1399.54 1321.77. MilPtOSF Nlkeitchuq 2(Def Survey) Pass 15956.16 32.81"'MOMe MIEMI N/A MAS=10.00(m) 14.15 14.15 MinPts 15956.33 32.81 NEM 15923.52 18974.64 MAO=10.00(m) 212.34 212.34 MINPTOEOU 15961.51 32.81 15958.17 15928.7 EIEBEE MAS=10.00(m) 290.22 290.21 MnPtO-SF 16203.29 32.81 16183.07 16170.4 =ME MAS=10.00(m) 632.32 630.27 MitP1OSF 16316.92 36.63 16291.85 16280.2.Mali OSF 1.50 709.13 705.26 Mirpt-0SF 16391.35 38.88 16386.14 16354.4.NEM OSF 1.50 753.08 747.78 M.P1-0-SF 16468.13 37.33 16442.60 16430.7•IE OSF 1.50 788.09 781.46 MW[-0-AF 18710.12 38.89 16883.69 16671.4 1MIME OSF 1.50 875.04 864.10 MnFFOSF 16839.13 40.09 16811.76 16799.. Main OSF 1.50 910.11 897.00 MnPt-OSF 17801.27 50.18 17767.17 17751,0 ® OSF 1.50 1162.65 1125.34 MiPPOSF 18479.48 54.50 18442.51 18424.98 MEM OSF 1.50 1304.80 1245.28 MnPtOSF 18610.58 54.77 18573.42 18555.80 528.09 OSF 1.50 1330.29 1286.30 TD OP03-P05PB1(Def Survey) Pass IMEXIM 32.81 1783148 17802.031 127319.96 MAS=10.00(m) 90.90 90.90 MinPts 17835.08 32.811 1783120 17802.28 26993.01 MAS=10.00(m) 200.20 200.20 MINPT-0-E08 ®'11 32.81 17727.47 1439.62 MAS=10.00(m) 502.69 502.22 MinPts 17741.24 32.81 IMBETKI 17708.43 1380.21 MAO=10.00(m) 505.01 504.52 MINPT-O-EOU 17071.80 55.59 17034.25 17016.21=au OSF 1.50 635.14 633.04 M6oP6-O-SF 57.50 1658183 16570.24 447.36 OSF 1.50 665.09 662.36 MinPts OP21-WW01(Def Survey) PO MEM' 32.81 N/A MAS=10.00(m) 0.48 0.48 MinPts 17869.71 32.81 Man 17836.90 32873.54 MAO=10.00(m) 160.48 160.48 MINPT-O-EOU 18017.54 32.81 18011.78 17984.7 MiriElEfi MAS=10.00(m) 374.66 374.60 M9tPI-0SF 17978.56 32.81 17965.73 17945.7.Mg= MAS=10.00(m) 608.25 606.62 MitPt-OSF 17856.77 32.81 17842.35 17823.: MAS=10.00(m) 637.89 635.74 M1rF[OSF 17734.20 32.81 17718.92 17701.4 M MAS=10.00(m) 666.89 664.12 MnP[-0SF 17511.84 32.81 17495.66 17479. MIMI MAS=10.00(m) 723.90 719.59 MinPtOSF 17381.49 32.81 17345.15 17328.6.ME= MAS=10.00(m) 766.82 761.03 Mnp[OSF 17225.69 32.81 17207.80 17192.8•MilM13 MAS=10.00(m) 809.15 801.80 MinPt-O-SF 17081.68 32.81 17062.47 17048.8. 965 49 MAS=10.00(m) 858.15 848.16 MnFt-OSF 36.50 16829.80 16817.99 71312 OSF 1.50 1006.38 985.91 MnPt-C1Ct 1685462 36.581 16829.78 18817.94 711.83 OSF 1.50 1007.50 986.93 MINPTO-E00 16854.54 36.61 16829.78 18817.93 711.23 OSF 1.50 1007.88 987.28 MnPE4ADP 17301.86 46.49 17270,54 17255.37 OEM OSF 1.50 1184.81 1144.17 M,PIOSF 17340.18 51.71 17305.38 17288.47 512.69 OAF 1.50 1194.20 1152.42 MnPtOSF OP18-08P81(Del Survey) Pail 32.811 17581.241 17560,691 1623.681 MAS=10.00(m) 423.59 423.45 MinPts Oliktok Point 1-1(Def Survey) Pam 17830.96 32.81 17828.68 EjlEMI 15337.72 MAO=10.00(m) 219.57 219.57 MinPts 17831.06 32.81 17798.25 12887.87 MAS=10.00(m) 232.04 232.04 MINPT-O-EOU 32.81 17883.,'MI= 853,16 MAS=10.00(m) 486.46 486.09 MinPts 17906.77 35.1•Et= 17871.66 789.93 OSF 1.50 490.67 490.28 MINPT-O-EOU 17907.28 35.79 17883.0'WOKE 774.50 OSF 1.50 491.72 491.32 1101-0-ADP 18262.21 130.20 18175.08 18132.*r MEM OSF 1.50 822.17 620.31 MIPF0-6F ISMIZE 129.5 'r. a rte. i 212.30 OSF 1.50 628.34 624.40 MinPts OP05-06F81(Dot Survey) Pan • 32.81 'R..'IMRE N/A MAS=10.00(m) 0.84 0.84 MinPts 17838.04 32.81 11=111 17805.23 35783.56 MAS=10.00(m) 155.84 155.84 MINPT-O-EOU 17904.64 32.81 17887.83 17871. MK= MAS=10.00(m) 375.75 375.69 MnFIQSF 18001.62 32.81 1798420 17988.81 MEM MAS=10.00(m) 441.67 441.49 MnFROSF 19205.82 119.13 19126.00 19086.68=ma OSF 1.50 581.47 58024 MitP1O-SF Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S119-FN2\S119-FN2\S119-FN2(P5) 3/11/2013 11:14 AM Page 12 of 12 Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum on: Oriented EOU Well: SI19-FN2 Dimension Field: Nikaitchuq Structure: Spy Island NoGo Region Anti- ��'►� Date: February 04, 2013 Collision rule used: Minor Risk- Separation Factor ( L North 345 350 355 0 5 10 15 0 - 800 'and 340 20 335 1 25 330 \ 30 yr '� 30 325 4 `` 35 320 `,`.11'7 4( I1;►0 315 �, 1 1 ` 1��,, I''/�� 45 310 , ` . / I, � ,'16-FN3 �►,/,,�, I (►/ /1/ 50 305 L\.�� 5�, /� 55 __�\ �/,•�/ .�� MIL:III `�300 :►— \ \I ' ,,��•//4j. / f1:elk 60 295 65 *OW&290 �� i \kailti ," 4 �';;;;I',I.�1,�� 70 285 ` \`\\ ,,,'r�l I ` `1117580 275 �_ ItSitAV\It� � r/ tor, .: .,\`"' �'4'r 85 270 ®. ' � ` ;`\ , ��:0 90 265 �d .sa f� I��' ,l:'I�� \I �` ,\�\� ♦• `, 95 260 I�l�/ '��dI 1' �.\ r ` -,\ !`�`I� 100 255 1 I . � �, �,*�� 1�� 105 250Z1e � I 1 �k `1\��y�'`��i��•110 245 ��.�:. //��k,.,1V \ \A��115 �I Irk . .��1'.i1A ��j��i*� 240 �� / %i� 4, , ` ��`�,�`< 17120• ir 235 . .•/� /T � .,� ��•�`� 125 230 3'� ' , lea �,, 1 �®®® >p�18-N5PB1 225 �'• ,4 • ' 135 220 /� � ilip, 140 215 �e g 145 210 150 205 ,V 155 200 195 `� �'� 160 SI 4f1 190 185 1 A 175 �� Well Ticks Type: MD on SI19-FN2(P5) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 5.00 deg Scale: 1 INCH= 10.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum on: Oriented EOU N Well: SI19-FN2 Dimension -" Field: Nikaitchuq I : Structure: Spy Island NoGo Region Anti- Date: February 04, 2013 Collision rule used: Minor Risk - Separation Factor North 350 0 10 0 - 8 0 0 'and Sao �� 2 330 30 140 320 40 310 50 100 jw 4111114,300 VS.illk /� 60 ♦ 80 `I ,w 290 $♦. .-:"' 4 " _ ;';1;;Rt-FN7PB1 4 *IL , Ai,(,f;1;;/...■.%011- 4 / -"..--0140 =��•I �,,.A O ,! c; ik j , � ,,,. , 4oPD4-SEi '' t kV �t f< � *Z� -:'.674:07.4;;.- "� ;ii� _=i 90 260 ``i ;i I'll` i 1 ', i..wr,4 . ♦�r�i `- Il `,/ . .10b1-N 7(P4b) '1!7" e'.1's ' ., '-. - . :' -,.,:,, f.‘*:.•." ..,;, . ,,,'• _.■ -, faki,,,lia.,,,,, r.:•,.a.**,,, , •••••., .:: -...,''/.:Iip.,40.... '',.;.---44.;0,`,le L,',' ,.........., -A, lopti ItW 250 ` _ - :Irii ti w7. 7 �7�� p 110 411 .., .,---,a. • ._ _...... , ;.„.,,,. , _,,,, ,,. i I" ,,,,40/iporroo, e,,,,,,,ir, 240 �∎7 ::•._ _411 .;. 1• lik,V,'..g*r(.fr'' %‘,AM'O'Velg1114 "UV/P.111 IP-230 � ':r►� it, �/� �:�11� <�"�h vo ,►� ;t.,�=�tI .-.X11F 4F-. 220 1'`..A �` i N' /��51 140 211 -"" i `;; � �� 0-N4PB1 200 �%... 160 190 180 1242 Well Ticks Type: MD on SI19-FN2(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft • 1 Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based on: Oriented EOU Client: Eni Petroleum .7( Dimension Well: SI 19-FN2 --■ Field: Nikaitchuq NoGo Region Anti- F Structure: Spy Island Collision rule used: Minor Risk - Separation Factor North Date: February 04, 2013 0 350 <8. 10 20 340 44,,.. 1111111-1Mrsm......1 ,•...- si:s4;,:•341.2■AN-... 800 'md - 3700 'md ir r jablrille :.11,4 111,•Ninp-liT.I t'ZII N',,_. - AT2) 330 /if Aw:44,11711,111z,-,.■s. ,1..7 si, ,4-15:1111... ..1.as,,,„,, , VA4lpirekt‘ ts..•-■4itt.114s,. •.- Itiele V 2 1116 ASO i`..*:•- — ■• 40 32044 , i 4 ir xso -. 4■41,,,t,1.1 .7--:,...,,,-...-1'w • a III* ‘ . q 0■4■PaL "Iit.r4 <kIV, °' f.----_•,, N„. "...„........„4.,.- .0.,411o.. -,01'. 4, 7 Nv.'1111-PO- 1 k l■il,•• ,..,. .e-ii1-:-.4!:'110-.S.:',, 4\t',j' 4 300 •" ,._•..4,,,. -... ,I ,://,',167-r-.,_-.l-:.-:--Z,;,44i:_-7w,--1_7,‘-1_-Z--■1'-:.---74;1:4-.0.-.-;--:7,40-..:..,r:f-41l;f"l;',■,,o",•.■%,■4,,,.);.o•'.1.l:i.r6.-■ei/g 4/A4At Ny-I2V.i‘.so:Is:.8,.--4,-,1.,.. v1,1-7..•o.C.-t*.-E4-w2 F t N (06P5,0 2 ) ,..1.40:1 . •■i m., ----___ 111,`,4,,0; 4, 4 ri-,*,,,ait, ‘1V4"---41iOnu. 1■4.t?"-4". .';',• Nkiii.......---- .....„,0-... Ass% isr4.2.111.,''s/;:i, '*t --- ..- ,,„A-77:::::.l'■''.k. 4 litallrAW f•In-F N6(P3) t '4+• 290 'll.r... 4"117 Pi° ..."01111a1V' . 74.'1' ''-• e?Si' /4011prOP,.4,40, ,..Z ■111111;41111.114r4IPP:' 'AI ‘-■---s:'.11-;;•.:.•;9•1•114;''Itt. ...-"b'--... WiNkot, At 1004,7 280 * V 11-f&-411*■,',41°,01144.--- -Ir.!:...41 i., -.40....";:',.;;;144,‘''.?... 14,./ ,'0 44,12q4,e, 1:1116ATP(;;-fit47%,441iti% \&44.114‘4■Ititir4;14°'14XlvW 4 ) 80 ;._____ ,...:.....4. . ,....,,,,,...:: :..s._ s 270 -ilf''‘-4*/4 11-14114#0 ;k% 4::#0)) r ' i A -_____,-mia mollh. 90 -AY'Tr, , - A c' ' ';. '■ :.h 1 v.v..41,, ,iimv..A.4•4 •• '- "'-'-'`t' j# 111)111 ;As-°%,9 4.■,, -,% 11, 4.4%! \k•Y'''''4.' 'j' A I illi:ifis•"'i;',.!": ;5#'V.•:.:117.71.:,,Zi.i.---'. ,..:•-• .„,-(004.:10•V - . ' A 114, ........:. — • 260 , ,k • 4"--' ,,isl....,■:-,alff.1 . 4, , . . r.,,,,..,,,, lath. Akksivh ks,...-,-....savey,h NI i / ‘1,111-::::;';411•0fr-..„„„;'w, IR .0,* ,/, fl Ilk 110 ,„.,_,...,......,....-.00 laix■e" AV AV th44114 ,.... ',AN,.■-ilk ,,,,,,„.- ,golm!I 4, 1k A\ "41 AIIIIIIII■L‘` '4,4AVSYSIO.,A,, AiiP^ NAk V:41 It/ .14* Ill. \ 1141'..—"AA AIIP kV_.„,111AV,4*,/bA kf0A4V A ,i 9/ . - ifiri2o 24o ■■■■1111\1- AlLicioN1100 IIP■\. AV WP il ' AO ill:- -iii.—,■0-44-..-ilLvi- -4■ 4 /fi . -.4.....-4.1t..... •41,.....■w.,1,....---t.---.. .. - -,tvvi -9.7130 \'''"NiromaLlele■ ,4816711R.....44 Illr&tilb\4" Ii 230 N.,Z1/411,wire,_-sgri1/4440,... ---swim"is..s,, ilw •ip:-.Ng _.„0/ r S P 2 2-F N 1P E311 111 IP'44;411/41&V.,,..411.1,1,P4111rb-anZIAw--ajor-o.--A4*N11114,4 111■4irre *Mt.'---'-'-'=-----z-4 44, liopir A 444460.-siskii-/I, 0-•■■■rillb■ .00.■ 4 1111:. .„P 140 22NNATmli■viz■veitleo•-_,.. ,......,4■...-- ■ No \s‘r 210 wsslie:47,---4"bigrdir20911111*ft& •PB1 fab - WirAvalt4, 4 ' " I *AdeltW 0 Sf51:8-N 20s --•••=.--- __,‘,4,444 V. SP271-6D1 190 185 P 1*?"381?' Well Ticks Type: MD on SI19-FN2(P5) _ 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 Client: Eni Petroleum on: Oriented EOU 3v Well: SI19-FN2 Dimension , i ►' Field: Nikaitchuq Structure: Spy Island NoGo Region Anti- Date: February 04, 2013 Collision rule used: Minor Risk - Separation Factor North • 350 0 10 3700 'md 11800 'md 340 320 20 330 300 `�1 kv, 3, 0 280 l 320 ri 260 .,I N40' 240 ' \ 310 220 *411111V∎ 50 ,All�0 200 � \ �,� 180 fljart4h`300 , 0 IVO',.om .! 60 �t� 160 4* 290 / , . 11240,0 �' Vti„, \sue M■ 70 III �i ♦ • so ♦ ilittaii 280 nd jl,,,., t•♦.♦,'1 60 • A011' ♦ 80 il �• rill* 40 ..•,•'y � --X020 �'��' ■rr�/ 270 � 90 0 0 ■ 0 a 0 o a i ,,,l 0 •1 ��• 260 --�` .��►A`-' o ' - �r _ 100:'' c, a ' �.f1 v 250// o \ \ l.�C / 110 't,�w 7 o240 �.' _ � ��; � o o�w 120 230 • .. ,-��//�/IH�;�\�,'4.� �,�,I 130• 220 �_�� ! 7�.4;�:�\�� 84,e `�i�1\��\\ ',�\�� 140 '11111111111r-.."0'..rigiali Vii- �,\\`�••• 210 ../0/_Iltl�i��. ∎..AV �� 150 200 MM. ` ``� FN1PBS 190 SPSE1 (P2) 1Rn Well Ticks Type: MD on SI19-FN2(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum on: Oriented EOU .74- Well: SI19-FN2 Dimension Field: Nikaitchuq --w'NoGo Region Anti- Structure: Spy Island Collision rule used: Minor Date: February 04, 2013•Risk - Separation Factor North 350 0 10 340 320 20 11800 'md - TD 330 300 1130 280 1 320 � 260 **111044° �a 240 310 e,*P: 220 _ .„ '�, 50 �, ,,,�0•_ 200 �4 , � ,,ii,■44,4*,� 180 �� ,`300 , � � ,, 60 160 ��. , , 140, '290 �. 120 ,"•. k ,, 70 •$* 1 100 ♦ • ��, ,Ali,►arre4A4� :' ♦ Ed 80 ,♦■♦ • *To� �� , 280 tali* k 60 ,•.♦.♦ a',11 80 WIWI* 1 '‘T 270 Iiinli111kik 0 20 1.:■..�/A� 1� 11 90 1111M111111 •'�d�r0 °� ,gam, /u �� p 1 260 II . w�•4�.,i,,i” o- �.1 ,',' 0 250 - ' + aterrir + o �A, 1. 110 "' `A ®■,+. � a/rr�A•�,� o`er w 240 ,'�•�� , , o° �w 120 230 s%1Ii*t4 13220 ' 140 ` •'`in s• 210 Ma00 150 10 200 160 190 1Rn 170 Well Ticks Type: MD on SI19-FN2(P5) Calculation Method: Normal Plane _ Ring Interval: 20.00 ft _ Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger - 5119-FN2 (P5) I FIELD Nikaitchuq 1 51RUCNRE Spy Island Magnetic PaamNen I Surtaca LocaBOn NPD27 Alaska State Rare.Zone 04.US Feet I MiaeeTMneeus Model'. BGGM2012 Dip: 8107E. Date. Rpn120.2013 LN: N■ 20 JJ 27818 NoMirg: 8063832.52 RUS Grid DOm:0089' Sbt'. 6P19 TVD Ret. 60 5Tebk(51.1R above MSL) Map Dec: 19.980' FSt. 57613017 Lon: W1495416./59 Eadkq: 51156711:1S Scale Fad:0.8998(1015 Plan: S119FM(P5) Srvk F,boary042013 SI08-FN6 (P3) SP05-FN7 SP1O-FN5 -16500 -15000 -13500 -12000 -10500 -9000 1 SI13 " 4 13500 – 04' • 4°.' 13500 �°• •c• SPO5 FN7PB1 .., d°^ SP16 ' c • 4 ,4• > 44®. .P05-FN7„,,,, AirAtk, A • tip• 12000 – , ; Q'1 �'•� 12000 e> SPO.-FN7PB1 AI. 4, • ,N • .e E) er '• • Q SP22-FN 1 B4 �^" °• �Q'� �'° �4,�QQ� • 10500 - �� .C'° �° �e ' >�+� ° 10500 > ,41., ,e• >4 el 8108 FN6 (P3)•Z SP22-FN 1 ., Re-• c�°';' "?”'1..i('9.-1°°�°�° 9000 – — i °C •��• 4P>C S°C,�• ff'• taO• 9000 n SP22-FN1PB3 . . >�, ,s b• >e4,q •• SP 0-FN5,,49 113 ''' .44 .<'1°• ,,,, ,b., ,_. ,,,, cn 7500 – S>5c�°�yo• ��oe'� �1 7500• P22-FN 1 PB2 �R \` SI1 -FN4 _ R • 6000 – ^�. __ ��a.._• 6000 * • SP22-FN1 PB1 °^�b� SP16-FN3 4500 – >, SP30-W1 iN4' s-FN2 (P5) Tuvaaq ST 1 6 \ SI32=W2 (P6c) >�b�^ct0 Asa SI25-N2 •Tuvs,aq ST 1 S P30-W1 3000 – T-- �� 3000 ° ,o-- ' SP2 -FN1 1 ^ °• s ,<' -16500 -15000 -13500 .,4'`e� -12000 -10500 -9000 C '^•'> <<< W Scale= :1500(ft) E >>> SP22-FN1PB1 SP22-FN1PB2 SI32-W2 (P6c) SP22-FN1PB3 SP22-FN1PB4 Schlumberger • SI19-FN2(P5)Anti-Collision Detailed Report (P I'fl 11 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: March 11,2013-12:01 North Reference: True Analysis Machine: AKA-DEC-9010 Client Eni Petroleum Database\Project: lovalhoalydrilling-Nikaitchuq Version/Patch: 2.6.1166.0 NOTE:Measured Depth is referenced to individual borehole elevation. ND,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. Results filtered:Depth 11700.00 ft ue MD en 21284.00 ft,Ct-Ct separation 0=3000.00 ft Anti-Collision Rules Used Rule Set Name D&M AntiCollision Standard S00205.1/5.2 Exemption Risk Level: Minor Rule Name EjI Lawl Rula Tvoe Bmalabil NaO.Rule SLB Alert Zone Threshold OSF=5.0 S002 05.115.2 Alert Ratio OSF=6.00 SLB Minor Risk Threshold OSF=1.5 S002 05.115.2 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 5002 v5.1/5.2 Alert CT_CT MAS=49.21(0) Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 1 of 58 Reference Trajectory Summary Field: Nikadohuq Well: Si/O-FN2 Structure: Spy Island Borehole: Si/0-FN2 Slot: SP10 Trajectory: SI10-FN2(P5) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.0894628e° Grid Scale Factor: 0.999900152 Magnetic Declination: 10.9801 Magnetic Declination Date: April 20.2013 Magnetic Model: BGGM 2012 Reference Point: Northing Easdng Elevation Structure Unc. Slot Unc. 6053637 520(ftUS) 511587.110(WS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(0)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 05.000%Confidence 2.7955 sigma Surviving Pros: Description MD From(ft) MD To(ft) EOU Frog(ft) Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.000 1/100.000 SLB_MWD-STD-Depth Only-No Global 18.000 SI19-FN2/SI19-FN2(P5) 41.000 1050.000 1/100.000 SLB_MWD-STD-No Global 18.000 SI19-FN2/SI10-FN2(P5) 1050.000 3872.890 1/100.000 SLB_MWD+SAG-No Global 18.000 SI19-FN2/5119-FN2(P5) 3872.890 11338.978 1/100.000 SLB_MWD+GMAG-No Global 12.250 SI19-FN2/5119-FN2(P5) 11338.978 21283.504 1/100.000 SLB_MWD+GMAG-No Global 8.750 SI19•FN2/S119-FN2(P5) Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\5119-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 2 of 58 Offset Trajectory Summary Offset Selection Criteria; Wellhead distance scan:Not performed! Offset Selection Criteria: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 Selection Summary Wells Selected:32 Boreholes Selected:47 Definitive Surveys Selected:34 Non-Def Surveys Selected:2 Definitive Plans Selected:13 Non-Def Plans Selected:0 Total Trajectories:49 None OSF filter in detailed report Trajectory Borehole Well Type SI17-SE2(P2) S117-SE2 SI17-SE2 Def Plan SP22-FN1PB2 SP22-FNIPB2 SP22-FN1 Def Survey SP22-FN1 SP22-FN1 SP22-FN1 Def Survey SP22-FN1PB4 SP22-FN1PB4 SP22-FN1 Def Survey SP22-FN1PB1 SP22-FN1PB1 SP22-FN1 Def Survey SP22-FN1PB3 SP22-FNIPB3 SP22-FN1 Def Survey 5120-N4PB1 S120-N4PH 5120-N4 Def Survey 5120-N4 S120-N4 S120-N4 Def Survey SP18-N5 SP1e-N5 SP18-N5 Def Survey SP18-N5PB1 SP1S-N5PB1 SP18-N5 Def Survey SP18-FN3 SP18-FN3 SP18-FN3 Def Survey SP23-N3 SP23-N3 SP23-N3 Def Survey SP23-N3PB1 SP23-N3PB1 SP23-N3 Def Survey SP24-SE7(P2) SP24-SE1 SP24-SE1 Def Plan 0114-Ne(P2) SI14-N8 S114-N8 Def Plan SN3-FN4 SI13-FN4 S113-FN4 Def Survey SI25-N2 SI25-N2 SI25-N2 Def Survey SP27-N1 SP27-N1 SP27-N1 Def Survey SP12SE3(P2) SP12-5E3 SP12-SE3 Def Plan 5108-FN8(P3) 5108-FN8 SI08-FN8 Def Plan SP30-W 1 SP30-W 1 SP30-W 1 Def Survey SP30-W IPB1 SP30-W1 P81 SP30-W 1 Def Survey S128-S2 SI26S2 SI29-S2 Def Survey SP10-FN5 SP10-FN5 SP16FN5 Def Survey SP11-N7(P4b) SP11-N7 SP11-N7 Def Plan SI32-W2 current SI32-W2 SI32-W2 Non-Def Survey SI32-W2 MWD-Standard SI32-W2 SI32-W2 Non-Def Survey SI07-SE4(P2) S107-SE4 5107-SE4 Def Plan SD37-DSP7 SD37-DSP7 5D37-DSP1 Def Survey 5132-W2(Pen) SI32-W2 SI32-W2 Def Plan SP33-W3 SP33-W3 SP33-W3 Def Survey SP05-FN7 SP05-FN7 SP05-FN7 Def Survey SP05-FN7PB1 SP05-FN7PB1 SP05-FN7 Def Survey St35-W4(P3) SI35-W4 S135-W4 Def Plan SP04SE5(P2) SP04-SE5 SP04-SE5 Del Plan SP38-W5(P3) SP38-W5 SP38-W5 Def Plan 5102-SE8(P2) 5102-SE8 5102-SE8 Def Plan SP01SE7(P2) SP01-SE7 SP01-SE7 Def Plan Kigun 1 PB1 Kigun 1 PB1 Tuvaaq ST 1 Def Survey Tuvaaq ST 1 Tuvaaq ST 1 Tuvaaq ST 1 Def Survey Kigun 1 Kigun 1 Tuvaaq ST 1 Def Survey Nikaitchuq 4 Nikaitchuq 4 Nikaitchuq 4 Def Survey Nikaitchuq 3PB1 Nikaitchuq 3PB1 Nikaitchuq 3 Def Survey Nikaitchuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Def Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Def Survey Nikaitchuq 1 Nikaitchuq 1 Nikaitchuq 1 Del Survey Nikaitchuq 4PB7 Nikaitchuq 4PB7 Nikaitchuq 4 Def Survey Nikaitchuq 2 Nikaitchuq 2 Nikaitchuq 2 Def Survey Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\5119-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 3 of 58 Field: N/kedchuq Well: SP22-FN1 Structure: Spy Island Borehole: SP22-FNIPB2 Slot: SP22 Trajectory: SP22-FNIPB2 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08928045° Grid Seal.Factor: 0.988900151 Magnetic Declination: 20.104° Magnetic Declination Date: January 31,2013 Magnetic Model: BGGM 2012 Reference Point: Northing Eluding Elevation Structure Unc, Slot Una. 6053633.080(ftUS) 511543.560(ftUS) 53820(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Sury ng Pro Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 40.720 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 SP22-FNIPB1/SP22-FNIPB1 40.720 665.420 Act-Sloe SLB_GYRO-MWD-No Globe 18.000 SP22-FN1PB1/SP22-FNIPB1 665.420 3014.860 Act-Stns SLB_MWD*GMAG-NO Globe 16.000 SP22-FN1 PB1/SP22-FNIPB1 3014.860 12095.310 Act-Stns SLB_MWD*GMAG-No Globe 12.250 SP22-FN1PB1/SP22-FNIPB1 12095.310 13272.400 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP22-FNIPB1/5P22-FN1P81 13272.400 16293.110 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP22-FNIPB2/SP22-FNIPB2 16293.110 18380.000 Act-Stns SLB_BLIND+TREND-No Globa 8.750 SP22-FNIPB2/SP22-FN1PB2 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North A n, Ct-Ct Distance Separation Clearance OSF Rule Statue (ft) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Cl-Cl separation<=2640.00 ft 11700.00 374295 4672.01 -8809.71 1243349 3721.29 3904.08 -8902.88 230.22 1255.62 354.77 1018.77 5.32 OSF 1.50 Pass 1180300 3749.83 4747.30 -8875.16 12548.13 372835 390136 -9971.19 230.28 124130 356.25 1011.58 5.27 OSF 1.50 Pass 1190300 3756.80 4822.59 -9040.60 1284811 3734.69 4074.62 -10032.83 230.30 124177 359.15 1003.00 5.20 OSF 1.50 Pass 12000.00 376217 4898.90 -9104.98 12750.28 373939 4156.08 -1009197 232.15 1237.10 362.02 99542 5.14 OSF 1.50 Pass 12100.00 3763.03 4977.73 -9166.50 1284785 3742.48 4233.69 -10152.89 233.38 1235.58 365.51 991.55 5.08 OSF 1.50 Pass 12200.00 3763.11 5056.98 -9227.48 12946.15 3746.55 4312.29 -1021111 233.19 1 34. 368.97 988.17 5.03 OSF 1.50 Pass 12300.00 3763.18 5138.24 -9288.48 13032.64 3751.82 4380.86 -1028437 232.9 374.17 984.38 4.96 OSF 1.50 Warning 12400.00 3763.58 5215.40 -9349.56 13115.28 3755.84 4445.76 -10915.36 232.55 37175 081.49 4.89 OSF 1.50 Warning 12500.00 3764.56 529441 -9410.85 13202.45 3755.85 4513.52 -1037018 232.59 123100 384.70 980.20 4.83 OSF 1.50 Warning 12600.00 3765.55 5373.41 -9472.15 13307.05 3751.42 4595.50 -10436.44 23234 1239.04 387.16 88030 4.81 OSF 1.50 Warning 12700.00 376353 5452.42 -953344 13403.69 3750.43 4888.96 -10486.60 232.83 1241.03 390.92 880.08 4.77 OSF 1.50 Warning 12800.00 3767.52 5531.43 -9594.74 13520.09 3750.29 478340 -1058389 232.98 1243.28 39200 981.60 4.77 OSF 1.50 Warning 12900.00 376335 5610.53 -9655.88 13672.82 3751.42 4882.21 -10681.98 233.41 124218 38785 983.42 4.82 OSF 1.50 Warning • 13000.00 3773.85 5889.96 -9716.48 1380315 3752.31 4986.33 -10735.28 233.81 1238.38 386.38 980.45 482 OSF 1.50 Warning • 13100.00 3778.46 5769.41 -9777.02 13882.74 3752.88 505416 -10782.39 233.97 1234.11 392.19 97232 4.73 OSF 1.50 Warning 13200.00 378307 584826 -9837.57 13959.88 375232 5116.50 -10827.82 234.15 1232.02 398.76 985.85 484 OSF 1.50 Warning 13300.00 3787.68 5928.31 -9898.12 14056.66 3751.31 5194.11 -10885.62 234.41 1231.08 402.41 962.46 460 OSF 1.50 Warning 13400.00 3792.11 800776 -9958.89 14171.38 375320 5286.60 -10953.49 234.66 122341 403.39 960.16 458 OSF 1.50 Warning 13500.00 3793.48 808723 -1001336 14280.75 3748.88 537346 -11017.24 23472 122253 405.16 956.10 4.55 OSF 130 Warning • • 13600.00 379182 818670 -1008305 1438534 3747.88 548375 -11077.77 234.79 122108 40736 95307 4.51 OSF 130 Warning 13700.00 3794.18 6246.18 -10140.75 1448829 3747.50 554320 -11136.02 234.83 1219.40 410.74 945.25 446 OSF 1.50 Warning 13800.00 3794.50 6325.65 -1020144 14576.62 3746.85 5816.78 -11188.40 234.88 1216.09 415.48 93277 4.40 OSF 1.50 Warning • 13900.00 3704.85 6405.13 -10282.13 14689.69 3746.11 570305 -11253.76 234.94 1212.52 416.71 93439 437 OSF 1.50 Warning 14000.00 3795.18 6484.43 -10323.06 14787.91 3745.68 578336 -11310.30 23429 1208.39 420.17 927.85 432 OSF 1.50 Warning 14100.00 3795.51 8563.58 -10384.17 14891.42 3744.90 587418 -1138382 23475 1203.73 42283 921.51 4.28 OSF 130 Warning 1420300 3795.84 6642.73 -10445.28 14988.08 3744.85 5853.27 -1142319 23478 1199.24 426.80 914.52 4.22 OSF 1.50 Warning 1430300 3798.17 6721.88 -10506.39 15088.99 3744.00 603385 -11483.18 23484 119478 429.71 90738 418 OSF 130 Warning 14400.00 3796.49 8801.04 -1056720 15172.07 3742.17 8104.23 -11531.38 23495 1190.61 43352 898.83 411 OSF 1.50 Warning 14500.00 379356 8880.00 -10628.86 15240.06 3740.23 6158.31 -11571.53 234.22 1188.55 44339 892.43 402 OSF 1.50 Warning 14600.00 379426 6957.21 -10692.36 15312.51 3738.20 821336 -11616.14 232.20 1186.11 450.93 885.17 3.95 OSF 1.50 Warning 14700.00 3790.19 7033.05 -10757.40 1538455 3737.05 6277.02 •77881.88 237.91 458.06 878.17 3.88 OSF 1.50 Warning 14800.00 3786.09 7108.88 -10822.47 15452.37 3737.55 832233 -11706.21 23176 1184. 485.50 873.40 3.82 OSF 130 Warning 14900.00 3781.99 7184.70 -10887.54 15520.59 373852 837152 -1175138 231.57 1187.21 47219 871.82 3.77 OSF 1.50 Warning 15000.00 3778.51 7259.52 -10953.79 15839.89 373683 848159 -1183211 229.34 1188.58 473.85 872.35 3.77 OSF 1.50 Waming 15100.00 3776.03 7331.84 -11023.02 15728.78 3735.66 6525.98 -11893.02 227.00 118345 478.28 887.28 3.73 OSF 1.50 Warning • 15200.00 3775.52 7402.41 -11093.87 15828.36 3734.62 659167 -11059.21 227.01 1182.56 482.03 880.87 3.88 OSF 130 Warning 15300.00 3774.42 7473.17 -11164.32 15913.80 373281 8661.38 -1201107 227.06 1179.56 486.86 854.68 3.84 OSF 1.50 Warning 15400.00 3773.32 7543.94 -11234.96 1599174 3730.15 8720.62 -1207362 227.1.f1til6, 492.18 849.02 3.59 OSF 1.50 Warning 15500.00 3772.20 7614.80 -11305.71 18051.12 372862 6759.47 -12115.06 226.55 11 499.89 844.77 3.54 OSF 1.50 Warning 15600.00 3770.92 7883.31 -11378.38 16139.22 3728.12 8819.34 -12179.63 225.17 1179.' 50406 842.81 3.51 OSF 1.50 Warning 15700.00 3769.80 7751.48 -11451.50 16251.22 3723.21 8895.95 -12281.27 225.24 1178.9 50633 840.82 3.49 OSF 1.50 Warning 15800.00 3788.28 7819.66 -11524.64 16380.00 372214 6971.83 -1233340 225.18■181L111 532.73 821.39 3.32 OSF 1.50 Warning 15900.00 3786.96 7887.84 -11597.79 18380.00 3722.94 8971.63 -1233340 225.18 11 r.5-- 542.33 81738 3.27 OSF 1.50 Warning 16000.00 3785.64 7956.02 -11870.93 1836010 3722.94 6971.63 -12339.40 225.18 1190.6 548.04 824.98 3.26 OSF 1.50 Warning 16100.00 3766.03 8024.53 -11743.77 1636030 3722.94 6971.63 -1233340 225.29 1210.4i 549.81 843.73 3.31 OSF 1.50 Warning 16200.00 3768.42 8093.37 -11816.25 1836010 3722.94 8971.83 -12339.40 225.29 1238.57 547.96 872.93 3.39 OSF 1.50 Warning 16300.00 3770.80 8162.22 -1188174 1636300 3722.94 8071.63 -12339.40 225.29 1273.93 543.33 911.38 3.52 OSF 1.50 Warning 16400.00 3773.19 823137 -1196112 16360.00 3722.94 8971.83 -1233340 225.29 1315.95 536.26 958.12 3.88 OSF 1.50 Warning 16500.00 3775.57 8299.92 -1203171 1636030 3722.94 8071.83 -1233340 225.29 1384.03 527.31 1012.16 3.88 OSF 1.50 Warning 16600.00 3776.18 8368.09 -12106.88 18380.00 3722.94 6971.63 -1233140 225.43 1418.88 517.01 107168 4.12 OSF 1.50 Warning 16700.00 3774.72 8435.42 -12180.78 16360.00 3722.94 6971.63 -1233340 225.43 1473.27 505.74 113538 4.38 OSF 1.50 Warning 16800.00 3773.27 8502.78 -12254.70 1636300 3722.94 6971.63 -1233340 225.43 1534.29 493.89 1204.70 4.67 OSF 1.50 Warning 16900.00 3771.82 8570.09 -12328.62 1636100 3722.94 8971.63 -1233140 225.43 1599.24 481.79 127172 4.99 OSF 1.50 Warning 17000.00 3770.36 8837.42 -12402.54 18380.00 372234 697133 -12339.40 225.43 1687.88 469.68 1354.21 333 OSF 1.50 Pass 1710300 3768.98 8704.45 -12476.74 1836030 3722.94 8971.63 -12339.40 224.09 173838 457.65 1433.43 5.71 OSF 1.50 Pass 17200.00 3767.92 8770.11 -12552.15 16360.00 3722.94 8971.83 -12339.40 223.82 1811.57 445.65 1514.15 6.11 OSF 1.50 Pass 17300.00 3766.88 8835.78 -12827.58 16360.00 3722.94 8971.83 -1233340 223.82 1886.78 434.07 1597.07 6.53 OSF 1.50 Pass 17400.00 3765.80 890141 -12703.00 18360.00 3722.94 8971.83 -1233340 223.82 1964.20 422.93 1681.92 8.98 OSF 1.50 Pass 17500.00 3764.74 896737 -12778.42 1636300 3722.94 8971.83 -1233340 223.82 2043.58 412.26 1768.42 7.45 OSF 1.50 Pass 17600.00 376165 9032.73 -12853.84 1636030 3722.94 6971.83 -12339.40 224.30 2124.71 402.07 1858.34 7.94 OSF 1.50 Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\5119-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 5 of 58 Trajectory:S119-FN2(P5)Vs.SP22-FN1PB2 • • Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North/aim Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (6) (ft) (ft) 17700.00 3760.87 9098.81 -12928.84 16360.00 3722.94 6971.63 -12339.40 225.94 2207.66 392.46 1945.60 8.46 OSF 1.50 Pass 17800.00 3757.60 9164.97 -13003.76 18380.00 3722.94 8971.83 -12339.40 225.94 2292.01 383.38 2036.10 8.99 OSF 1.50 Pass 17900.00 3754.72 9231.12 -13078.69 16380.00 3722.94 6971133 -12339.40 225.94 2377.57 374.76 2127.41 9.54 OSF 1.50 Pass 18000.00 3751.65 9207.28 -13153.82 16360.00 3722.94 8971.83 -12339.40 225.94 2464.22 366.59 2219.50 10.11 OSF 1.50 Pass 18100.00 3748.81 9383.40 -13228.58 18380.00 3722.94 6971.63 -12339.40 224.25 2551.84 358.81 2312.30 10.89 OSF 1.50 Pass 18200.00 3749.08 9429.11 -13303.95 18360.00 3722.94 6971.63 -12339.40 220.92 2640.12 351.21 2405.65 11.30 OSF 1.50 Pass 18300.00 3750.24 9494.69 -13379.44 18360.00 3722.94 6971.63 -12339.40 220.92 2729.15 344.12 2499.40 11.93 OSF 1.50 Pass 18400.00 3751.42 9580.27 -13454.92 16360.00 3722.94 6971.83 -12339.40 220.92 2818.91 337.40 2593.65 12.58 OSF 1.50 Pass 18500.00 3752.59 9625.88 -13530.40 16360.00 3722.94 6971.63 -12339.40 220.92 2909.34 331.03 2888.32 13.22 OSF 1.50 Pass End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\S119-FN2(P5) 3/11/2013 12:01 PM Page 6 of 58 Field: Nikadchuq Well: SP22-FN7 Structure: Spy Island Borehole: SP22-FN7 Slot: SP22 Trajectory: SP22-FN1 Client: Eni Petroleum Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08928045° Grid Scale Factor: 0.999900151 Magnetic Declination: 20.104° Magnetic Declination Date: January 31,2013 Magnetic Model: BGGM 2012 Reference Point: 119IShjn9 J ii.tio9 elevation jitructure Une. Slot Uno. 8053833.080(WS) 511543.580(ftUS) 53.820(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) • Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(in) Borehole/Survey 0000 40.720 Act-Sine SLB_GVRO-MWD-Depth Only-No Global 16.000 SP22-FN1PB1/SP22-FNIPB1 40.720 685.420 Act-Sloe SLB_GVRO-MWD-No Globe 18.000 SP22-FNIPB1/SP22-FN1PB1 865.420 9014.880 Act-Stns SLB_MWD+GMAG-No Globe 18.000 SP22-FNIPB1/SP22-FN1PB1 3014.860 12005.310 ActSme SLB_MWD*GMAG-No Globe 12.250 SP22-FN1PB1/SP22-FN1PB1 12095.310 13272.400 Act-Sloe SLB_MWD+GMAG-No Globe 8.750 SP22-FN1PB1/SP22-FNIPB1 • 13272.400 14859.310 Act-Sloe SLB MWD+GMAG-No Globe 8.750 SP22-FN1PB2/SP22-FN1PB2 14859110 17940.580 Act-Sloe SLB MWD+GMAG-No Globe 8.750 SP22-FNIPB3/SP22-FNIPB3 17940.580 20181.550 Act-Sms SLB_MWD+GMAG-No Globe 8.750 SP22-FN1PB4/SP22-FNIPB4 20181.550 22858.110 Act-Sine SLB_MWD+GMAG-No Globe 8.750 SP22-FN1/SP22-FN1 • 22858.110 22923.000 Act-Stns SLB_BLIND*TREND-No Globe 8.750 SP22-FN1/SP22-FNI • Minimum ' Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Rule Status (0) (ft) (ft) (ft) _ (ft) (ft) (ft) (ft) (°) (ft) (ft) (8) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 8 Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Ct-Ct separation<=2640.00 ft 11700.00 3742.95 4672.01 -8909.71 12433.49 3721.29 3904.08 -9002.88 230.22 1255.82 354.77 1018.77 5.32 OSF 1.50 Pass 11800.00 3749.93 4747,30 -8975.18 12546.13 3728.35 399136 -5971.19 230.26 1249.39 358.25 1011.56 5.27 OSF 1.50 Pass 11900.00 3756.90 4822.59 -9040.80 12848.31 3734.69 4074.62 -10032.83 230.30 1242.77 359.15 1003.00 5.20 OSF 1.50 Pass 12000.00 3762.17 4898.90 -9104.98 12750.28 3739.39 4156.08 -10093.97 232.15 1237.10 382.02 995.42 5.14 OSF 1.50 Pass 12100.00 3763.03 4977.73 -0188.50 12847.85 3742.48 4233.69 -1015289 23138 1235.56 365.51 991.55 5.08 OSF 1.50 Pass 12200.00 378111 5050.98 -9227.48 12948.15 3746.55 4312.29 -10211.91 233.15 1234.48 368.97 988.17 5.03 OSF 1.50 Pass 12300.00 3763.18 5136.24 -9288.48 13032.64 3751.82 4380.86 -10264.37 232.9 374.17 984.38 4.98 OSF 150 Warning 12400.00 3763.58 5215.40 -9349.56 13115.28 3755.84 4445.78 -10315.36 232.55 379.75 981.49 4.89 OSF 1.50 Warning 12500.00 3764.58 5294.41 -9410.85 13202.45 3755.85 4513.52 -10370.18 232.59 1237.00 384.70 980.20 4.83 057 1.50 Warning 12800.00 3765.55 5373.41 -9472.15 13307.95 3751.42 4595.50 -10436.44 23284 1230.04 387.16 980.80 4,81 OSF 1,50 Warning 12700.00 3786.53 5452.42 -9533.44 13403.69 375043 4689.96 -10496.60 232.93 1241.03 390.92 980.09 4.77 OSF 1.50 Warning 12800.00 3787.52 5531.43 -0594.74 13520.09 3750.29 476040 -10589.89 232.98 1243.28 39200 981.80 4.77 OSF 1.50 Warning 1290000 3769.35 5810.53 -9655.88 1387282 3751,42 4882.21 -10661.98 233.41 1242.18 387.65 983.42 4.82 OSF 1.50 Warning 13000.00 3773.85 568918 -9716.46 13800.15 375231 4986.33 -10735.28 233.81 1238.36 38618 980.45 452 OSF 1.50 Warning 13100.00 3778.48 5789.41 -977302 13882.74 3752.68 5054.16 -10782.39 233.97 1234.11 302.19 972.32 4.73 OSF 1.50 Warning 13200.00 3783.07 5848.88 -9837.57 13959.88 3752.32 511550 -10827.82 234.15 1232.02 39816 965.85 4.64 OSF 1.50 Warning 13300.00 3787.68 5928.31 .9898.12 14056.66 3751.31 5194.11 -10885.62 234.41 1231.06 402.41 962.46 4.60 OSF 1.50 Warning 13400.00 3792.11 6007.78 0058.69 14171.38 3750.20 5286.60 -10953.49 234.66 1229.41 40139 980.16 4.58 OSF 1.50 Warning 13500.00 3793.48 6087.23 -1001136 14280.75 3748.88 5375.48 -11017.24 234.72 1226.53 405.16 956.10 4.55 OSF 150 Warning 13600.00 3793.82 6168.70 -10080.05 1438514 374718 5460.75 -11077.77 234.79 1223.08 40786 95097 4.51 OSF 150 Warning 13700.00 3794.16 6246.18 -10140.75 1448829 374750 5543.20 -11138.02 234.83 121140 41074 945.25 4.48 OSF 150 Warning ' 13800.00 3794.50 6325.85 -10201.44 1457682 3748.85 5616.78 -11188.40 234.88 1216.00 415.48 938.77 4.40 OSF 1,50 Warning 13900.00 3794.85 6405.13 .10282.13 14689.69 3746.11 5709.05 -11253.76 234.94 1212.52 416.71 934.39 4.37 OSF 150 Warning 14000.00 3795.18 6484.43 .10323.08 14787.91 3745.68 5789.36 -11310.30 234.69 1208.39 420.17 927.95 4.32 OSF 1.50 Warning 14100.00 3795.51 856158 -10384.17 14912.21 374529 5851.47 -11381.16 234.74 1203.43 41950 923.44 4.31 OSF 1.50 Warning 14200.00 3795.84 6642.73 -10445.28 15011.13 3748.51 597189 -11436.06 234.61 1106.45 422.99 914.13 4.25 OSF 1.50 Warning 14300.00 3798.17 6721.88 -10506.39 15097.84 3751,77 6045.17 -11485.22 234.48 1190.81 428.49 904.82 4.17 OSF 1.50 Warning ' 14400.00 3796.49 680104 -10567.50 15195.82 3752.07 6125.41 -1154013 234.49 1185.75 432.17 897.31 4.12 OSF 1.50 Warning 1450000 3796.56 688000 -10628.86 15308.43 3750.74 8218.87 -11603.76 233.71 118006 433.65 890.63 4.09 OSF 1.50 Warning 14800.00 3794.26 8957.21 -10692.36 15416.20 3749.28 8307.73 -11665.02 231.58 1170.43 435.24 87194 4.04 OSF 1.50 Warning 1470000 3790.19 7033.05 -10757.40 15515.52 3747.75 6390.37 -1172011 231.19 1158.29 438.58 865.58 3.97 OSF 1.50 Warning 14800.00 3786.09 7108.88 -10822.47 15813.12 3745.81 8471.58 -11774.23 231.11 1146.14 442.17 851.04 3.89 OSF 150 Warning 14900.00 3781.99 7184.70 -10887.54 1589335 3743.73 6538.20 -11819.57 231.06 1134.04 448.73 835.48 3.80 OSF 1.50 Warning 15000.00 3778.51 725152 -10953.70 15753.97 3741.77 6587.13 -11854.62 229.06 1124.70 458.42 818.76 168 OSF 1.50 Warning 15100.00 3778.63 7331.84 -11023.02 15807.42 3740.17 8629.41 -11887.28 226.87 1114.19 488.47 80155 3.57 OSF 1,50 Warning 15200.00 3775.52 7402.41 -11093.67 15850.68 3739.23 666228 -11915.37 226.90 1106.48 479.41 788.55 3.47 OSF 1.50 Warning 15300.00 3774.42 747117 -11184.32 15897.86 3738.65 6698.49 -11947.88 228.9 488.82 77763 3.39 OSF 1.50 Warning 15400.00 3773.32 7543.94 -11234.96 15961.72 373822 8741.11 -11993.54 228.89 1 495.77 774.24 3.35 OSF 1.50 Warning 1550000 3772.20 7614.60 -11305.71 16049.06 3737.83 880052 -12057.56 226.22 1108.69 500.41 774.75 3.33 OSF 1.50 Warning 15800.00 3770.92 7683.31 -11378.38 1816604 3737.24 6880.39 -12143.02 224.72 1109.29 50249 773.97 3.31 OSF 1.50 Warning 15700.00 3769.60 7751.48 -11451.50 16253.38 3737.09 694028 -12206.61 224.67 1108.75 50318 770.30 3.28 OSF 1.50 Warning 15800.00 3768.28 7819.66 -11524.64 16358.36 3738.97 7011,95 -12283.29 224.6 510.38 787.98 3.28 OSF 1.50 Warning 15900.00 3768.96 7887.84 -11597.79 16448.05 3736.18 7071.65 -12347.52 224.58 1 515.02 785.03 3.23 OSF 1.50 Warning 16000.00 3785.64 7958.02 -1187093 1054186 3734.33 7142.08 -1242176 224.81 1109.15 518.32 763.28 3.21 OSF 1,50 Warning 1610000 3788.03 8024.53 -11743.77 18639.24 3732.35 7202.50 -12489.60 225.23 1110.47 522.36 761.90 3.19 OSF 1.50 Warning 16200.00 3788.42 8093.37 -1181825 1872418 3731.23 7259.72 -12553.44 225.39 1113,46 526.91 78156 3.17 OSF 1.50 Warning 18300.00 3770.80 816222 -11888.74 16797.59 3730.79 7307.17 -12608.39 225.50 1118.31 532.19 783.19 3.18 OSF 1.50 Warning 1640000 3773.19 8231.07 -11961.22 16882.56 3730.48 7361.32 -12673.88 225.61 1125.23 53656 787.20 3.15 OSF 1.50 Warning 18500.00 3775.57 8299.92 -12033.71 16978.58 3731.86 7421.93 -12748.30 225.64 1132.88 540.36 77231 315 OSF 1.50 Warning ' 16600.00 3776.18 8368.09 -12108.88 17091.91 3733.88 7493.80 -12835.93 224.54 1139.18 543.40 778.58 3.15 OSF 1.50 Warning 16700.00 3774.72 8435.42 -12180.78 17219.68 3735.11 7576.80 -12932.98 224.33 1142.13 545.52 778,12 114 OSF 150 Warning 18800.00 3773.27 8502.76 -12254.70 17324.82 3734.86 7846.47 -13011.80 224.27 1143.64 548.86 777.40 3.13 OSF 1.50 Warning 16900.00 3771.82 8570.09 -12328.82 17416.10 3795.17 7706.78 -19080.33 224.18 1145.32 553.13 778.23 111 057 1.50 Warning 17000.00 3770.36 8637.42 -12402.54 17506.36 3735.25 7765.61 -13148.77 224.11 1148.11 557.44 776.16 109 057 1.50 Warning 17100.00 37118.98 8704.45 -12476.74 17814.80 3734.11 783821 -13230.81 222.99 1150.51 560.57 776,47 3.08 OSF 1.50 Warning 17200.00 3787.92 8770.11 -12552.15 17721.76 3732.75 7906.88 -13311.38 22279 115(115 563.85 774.05 106 OSF 1.50 Warning 17300.00 3766.86 8835.78 -12627.58 1782199 3728.76 7974.48 -13387.93 22293 114152 56706 771.15 304 OSF 1.50 Warning Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S119-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 7 of 58 • Trajectory:S119-FN2(P6)Vs.SP22-FN1 • • Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset NO Offset NS Offset EW North API)) Ct-Ct Distance Separation Clearance OSF Rule Status (6) (8) (8) (8) (8) (8) (8) (8) C) (8) (9) (8) 17400.00 376580 8901.41 -1270350 1701174 3728.34 803171 -1345531 223.01 1149.1t. 571.31 787.90 3.02 OSF 1.50 Warning 17500.00 3784.74 8987.07 -12778.42 18014.13 3727.23 8099.31 -13531.29 222.91 114$.44 57502 76517 3.00 OSF 1.50 Warning 17600.00 3783.65 9032.73 -12853.84 18120.58 3729.72 8169.21 -13611.51 222.82 114930 578.42 763.35 2.98 OSF 1.50 Warning 17700.00 3760.87 9098.81 -12928.84 18244.81 3730.71 8252.07 -13704.08 222.92 114543 58051 761.09 2.97 OSF 1.50 Warning 17800.00 3757.80 916497 -13003.78 18362.02 3730.82 8332.02 -13789.80 222.73 1145.59 582.91 75566 2.95 OSF 1.50 Warning 17000.00 375472 9231.12 -13078.69 18475.96 3730.81 8410.83 -13872.27 222.56 1141.73 585.45 751.10 2.93 OSF 1.50 Warning • 18000.00 3751.65 9297.28 -13153.62 18588.26 3731.13 8489.18 -13052.53 222.38 1138.53 588.05 744.17 2.90 OSF 1.50 Warning 18100.00 3748.81 9383.40 -13228.58 18737.43 3731.33 8597.13 -1405545 222.08 1127.48 586.37 736.24 2.89 OSF 1.50 Warning 18200.00 3749.06 9429.11 -13303.95 18861.22 3731.11 8688.44 -14139.03 22250 1118.37 58851 725.03 2.86 OSF 1.50 Warning 18300.00 3750.24 9494.69 -13379.44 18924.98 3732.63 8735.64 -14181.85 221.97 1104.69 59460 707.98 2.79 OSF 1.50 Warning 18400.00 3751.42 9560.27 -1345492 1898559 373487 8778.97 -1422460 221.89 1096.87 60248 69488 2.73 OSF 1.50 Warning 1850500 375259 9625.88 -1353540 19062.74 3737.96 883225 -14279.89 221.78 1091.68 60819 68576 269 OSF 1.50 Warning 1860.00 3753.77 969144 -13805.89 1913655 374058 888243 -14334.36 221.68 1088.73 61427 678.89 2136 OSF 1.50 Warning 18662.59 3754.50 9732.50 -13853.12 18187.11 3742.79 8915.77 -14371.91 221.8 617.52 676.04 2.84 OSF 1.50 Warning 0 187 .00 375480 9757.34 -13681.09 10218.55 3744.01 893645 -14395.58 22243 1 819.27 875.15 2.64 OSF 1.50 Warning 1880500 375545 9824.08 -13755.55 19299.91 3746.57 898912 -14457.34 222.32 109050 62420 674.13 2.62 OSF 1.50 Warning 1890500 3756.10 9890.82 -13830.02 19400.07 3746.00 9053.41 -14534.30 222.38 109424 627.91 675.30 2.62 OSF 1.50 Warning 1900500 3756.75 9957.56 -13904.49 19478.90 3743.81 9103.99 -14594.72 22252 1097.80 63252 675.72 2.60 OSF 1.50 Warning 19100.00 3757.40 10024.30 -13978.96 19545.73 3742.48 9145.09 -14847.40 222.61 1104.56 837.44 879.27 2.80 OSF 1.50 Warning 19200.00 3758.64 10089.72 -1405457 19631.10 3741.29 9196.40 -14715.82 22552 1111.44 64129 683.59 2.60 OSF 1.50 Warning • 19300.00 3761.05 1015257 -1413231 19700.47 3740.85 9236.90 -14771.93 219.72 1117.12 645.08 688.74 2.60 OSF 1.50 Warning • 19400.00 3763.58 10215.18 -14210.25 1977506 3740.84 927598 -14829.51 219.80 1125.21 64852 692.47 2.60 OSF 1.50 Warning 1950500 3766.07 10277.79 -14288.18 19839.42 3740.84 9313.39 -14887.92 219.89 1135.96 651.68 701.17 2.62 OSF 1.50 Warning 19600.00 3768.58 10340.40 -14386.11 19908.49 374551 9349.09 -1494754 219.98 1149.33 65428 71282 2.64 OSF 1.50 Warning 19700.00 3771.06 10402.78 -14444.23 19978.80 3740.02 9383.90 -15008.12 219.20 1164,93 656.48 726.95 2.86 OSF 1.50 Warning 19800.00 377107 1046256 -14524.38 20058.85 3739.84 9421.02 -1507578 217.57 117945 658.78 739.93 269 OSF 1.50 Warning 1990.00 377440 10521.48 -14605.15 20129.41 3740.48 9454.40 -15141.21 217.59 1194.84 680.61 753.91 2.71 OSF 1.50 Warning 20000.00 3778.72 1058536 -14685.94 20205.43 3741.31 9487.81 -15209.58 217.60 121225 682.49 770.27 2.75 OSF 1.50 Warning 20100.00 3778.55 10639.27 -1476634 20348.59 3745.14 9550.83 -15337.94 217.51 1229.66 689.91 782.73 2.76 OSF 1.50 Warning 2020500 3780.23 10697.71 -14847.88 20473.87 3744.35 9610.70 -15447.99 21643 1242.19 675.28 791.87 2.76 OSF 1.50 Warning 20300.00 3780.90 10753.13 -14931.09 20554.95 3743.74 9649.37 -15519.25 214.44 1251.23 677.84 799.01 2.77 OSF 1.50 Warning 20400.00 3781.07 10807.22 -15015.20 20605.36 3744.12 9872.19 -1556418 21442 1261.36 877.98 809.05 2.75 OSF 1.50 Warning 20500.00 3781.25 10861.30 -15099.31 20660.50 3745.33 9695.14 -15614.31 214.36 1275.32 677.68 823.21 2.82 OSF 1.60 Warning 2060500 3781.42 10915.39 -15183.42 20746.88 374852 9729.67 -1569147 21429 1291.24 88025 837.41 2.85 OSF 1.50 Warning 20700.00 3781.60 10969.48 -15267.53 20813.68 374582 9755.31 -15755.15 21427 1308.89 880.47 854.92 2.89 OSF 1.50 Warning 20800.00 3781.39 1102138 -15351.77 20923.57 374668 979622 -15857.14 21179 1327.58 68583 87518 2.91 OSF 150 Warning 2090050 3778.24 11075.59 -15436.98 21020.62 3747.74 9833.15 -15946.88 212.85 1343.35 689.40 883.42 2.92 OSF 1.50 Warning 21000.00 377422 11127.31 -1552247 21128.19 3750.96 987431 -16046.21 21251 1358.26 69442 894.98 294 OSF 1.50 Warning 21100.00 3770.19 11179.04 -15607.96 21215.29 3754.57 9907.56 -1612653 212.20 1373.28 697.15 908.19 2.96 OSF 1.50 Warning 21200.00 3786.18 1123576 -1569145 21276.24 375760 9929.76 -1618131 211.96 1390.19 696.65 925.43 3.0 OSF 1.50 Warning 21283.50 3782.80 11273.95 -15764.83 21317.08 3759.86 9943.70 -16221.63 211.80 1408.50 69450 943.17 104 OSF 1.50 Warning End of results • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 8 of 58 • Raid: Nikaitchuq Well: SP22-FN7 Structure: Spy Island Borehole: SP22-FN1PB4 Slot: SP22 Trajectory: SP22-FN1PB4 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08928045° Grid Scale Factor: 0.999900151 Magnetic Declination: 20.104° Magnetic Declination Date: January 31,2013 Magnetic Model: BGGM 2012 Reference Point: H91Shln9 E9!iID9 Elevation Structure Unc. slot Unc, 6053633.080(ftUS) 511541560(ftUS) 51820(ft)MSL 0.000(Ii)(1 sig me) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Survevino Prop: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(In) Borehole/Sunray 0.000 40.720 Act-Sloe SLB GYRO-MWD-Depth Only-No Globs 18.000 SP22•FN1PB1/SP22-FNIPB1 40.720 665.420 Act-Stns SLB_OYRO•MWD-No Globe 18.000 SP22-FNIPB1/SP22-FN1PB1 865.420 3014.860 ActStns SLB_MWD+GMAG-No Globe 18.000 SP22-FNIPB1/SP22-FN1PB1 3014.800 12095.310 Act-Stns SLB_MWD+GMAG-No Globe 12.250 SP22-FN1 PB1/SP22-FNIPBI 12095.310 13272.400 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP22-FNIPBI I SP22-FNIPB1 13272.400 14859.310 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP22-FNIPB2/SP22-FNIPB2 14859.310 17940.580 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP22-FNIPB3/5P22-FNIPB3 17940.580 21734.350 Act-Stns SLB_MWD+GMAG•No Globe 8.750 SP22-FNIP84/SP22-FN1PB4 21734.350 21800.000 Act-Stns SLB_BLIND+TREND-No Globe 8.750 SP22•FNIPB4/SP22-FNIPB4 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference ND Reference NS Reference EW Offset MD OffsetTVD Offset NS Offset EW North Atm Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (8) (8) (8) (8) (f) (8) (°) (f) (0) (ft) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Ct-Ct separation•=2840.00 ft 11700.00 3742.95 467211 -8900.71 12433.49 3721.29 390408 -9902.88 230.22 1255.62 35477 1018.77 5.32 OSF 1.50 Pass 11800.00 3749.93 4747.30 -8975.16 12548.13 3728.35 3993.36 -9971.19 230.28 1249.39 356,25 1011.56 5.27 OSF 1.50 Pass 11900.00 3756.90 4822.59 -9040.60 12848.31 3734.69 407462 -10032.83 230.30 1242.77 359.15 1003.00 5.20 OSF 1.50 Pass 12000.00 3762,17 4888.90 -9104.98 12750.28 3739.39 4156.08 -10093.97 232.15 1237.10 302.02 995.42 5.14 OSF 1.50 Pass 12100.00 378103 4877.73 -9166.50 12847.85 374248 4233.69 -10152.69 233.38 1235.56 385.51 991.55 5.08 OSF 1.50 Pass 12200.00 3763.11 5056.98 -9227.48 12946.15 3746.55 431229 -10211.91 233.19 388.97 988.17 5.03 OSF 1.50 Pass 12300.00 3763.18 5136.24 -9288.46 13032.64 3751.82 4380.86 -10264.37 232.95 374.17 984.38 4.96 OSF 1.50 Warning 12400.00 3763.58 5215.40 -9349.56 13115.28 3755.84 4445.76 -10315.36 232.55 1 379.75 98149 4.89 OSF 1.50 Warning 12500.00 3764.56 5294.41 -9410.85 13202.45 3755.85 451152 -10370.18 232.59 1237.00 384,70 980.20 4.83 OSF 1.50 Warning 12600.00 3785.55 5373.41 -9472.15 13307.05 3751.42 4595.50 -10436.44 232.84 1239.04 387.16 980.80 4.81 OSF 1.50 Warning 12700.00 3766.53 545242 -9533.44 13403.69 3750.43 466196 -10496.60 23293 1241.03 390.92 980.09 4.77 OSF 1.50 Warning 12800.00 3767.52 5531.43 -9594.74 13520.09 3750.29 476140 -10589.89 232.98 1243.26 392.00 981,60 4.77 OSF 1.50 Warning 12900.00 3789.35 5610.53 -9655.88 13672.82 3751.42 488221 -10661.98 23141 1242.18 387.85 98142 4.82 OSF 1.50 Warning 13000.00 3773.85 588196 -9716.48 1380815 3752.31 4986.33 -1073828 233.81 1238.38 388.38 980.45 4.82 OSF 1.50 Warning 13100.00 3778.48 576141 -9777.02 13882.74 3752.68 505416 -10782.39 233.97 123411 392.19 972.32 473 OSF 1.50 Warning 13200.00 3783.07 584186 -9837.57 13959.88 3752.32 5116.50 -10827.82 234.15 1232.02 398.76 965.85 4.64 OSF 1.50 Warning 13300.00 3787.68 5928.31 -9898.12 1405616 3751,31 5194.11 -10885.82 234.41 1231.06 40241 96246 4.60 OSF 1.50 Warning 13400.00 379211 8007.76 -9958.69 14171.38 3750.20 528160 -10953.49 234.66 1229.41 403.39 96116 4.58 OSF 1.50 Warning 1350100 379148 8087.23 -1001136 1428175 3748.88 5375.48 -11017.24 234.72 122813 40116 958.10 4.55 OSF 1.50 Warning 13800.00 3793.82 6186.70 -10080.05 1438134 3747.98 546175 -11077.77 234.79 122108 40766 050.97 4.51 OSF 1.50 Warning 13700.00 379416 6246.18 -10140.75 1448829 3747.50 5543.20 -11136.02 234.83 121140 410.74 945.25 446 OSF 110 Warning 1380000 379450 6325.65 -10201.44 1457882 374815 5618.78 -11188.40 234.88 121109 41548 938.77 440 OSF 1.50 Warning 1300100 3794.85 6405.13 -10282.13 14689.69 3748.11 5709.05 -11253.76 234.94 121252 416.71 93439 4.37 OSF 1.50 Warning 14000.00 3795.18 6484.43 -1032106 14787.91 3745.68 578136 -11310.30 234.69 1208.39 420.17 927.95 4.32 OSF 1.50 Warning 14100.00 379511 6563.58 -10384.17 14912.21 3745.29 5891.47 -11381.16 234.74 120143 419.50 923.44 4.31 OSF 1.50 Warning 14200.00 379514 6642.73 -10445.28 15011.13 3748.51 5973.89 -11436.06 234.61 1196.45 422.99 91413 4.25 OSF 1.50 Warning 14300.00 3796.17 6721.88 -10506.39 15097.94 3751.77 8045.17 -11485.22 23448 1190.81 428.40 90482 4.17 OSF 1.50 Warning 14400.00 3796.49 680114 -10567.50 15195.82 375217 6125.41 -11540.93 234.49 1185.75 432.17 897.31 4.12 OSF 1.50 Warning 14500.00 3796.56 6880.00 -10828.86 15306.43 3750.74 8216.67 -11603.78 233.71 1180.06 43165 890.83 4.09 OSF 1.50 Warning 14600.00 3794.26 6957.21 -10692.36 15418.20 3749.28 6307.73 -11665.02 231.58 1170.43 43524 87194 4.04 OSF 1.50 Warning 14700.00 3790.19 7033.05 -10757.40 15515,52 3747.75 6390.37 -11720.11 231.19 1158.29 43818 885.58 3.97 OSF 1.50 Warning 14800.00 3786.09 7108.88 -1082247 15613.12 3745.81 6471.58 -11774.23 231.11 1148.14 442.17 851.04 3.89 OSF 1.50 Warning 14900.00 3781.99 7184.70 -10887.54 15693.75 3743.73 6538.20 -11819.57 231.06 113494 448.73 835.48 3.80 OSF 1.50 Warning 15000.00 3778.51 7259.52 -10953.79 15753.97 3741.77 6587.13 -11854.82 229.08 1124.70 458.42 81176 3.68 OSF 1.50 Warning 15100.00 3778.83 7331.64 -11023.02 1580742 3740.17 6629.41 -11887.28 226.87 111419 488.47 801.55 3.57 OSF 1.50 Warning 15200.00 3775.52 7402.41 -11093.67 15850.68 3739.23 6882.28 -11915.37 226.90 1106.48 470.41 788,55 147 OSF 1.50 Warning 15300.00 3774.42 7473.17 -11164.32 15897.86 3738.85 6698.49 -11947.86 226.90 488.82 777.63 3.39 OSF 1.50 Warning 15400.00 3773.32 7543.94 -11234.96 15961.72 3738.22 6741.11 -11093.54 226.89 1 495.77 77424 3.35 OSF 1.50 Warning 15500.00 3772.20 7614.60 -11305.71 1604916 3737.83 6800.52 -12057.56 226.22 1108.69 500.41 774.75 3.33 OSF 1.50 Warning 15800.00 3770.92 7683.31 -11378.38 16166.04 3737.24 688139 -12143.02 224.72 1109,29 502.49 773.07 3.31 OSF 1.50 Warning 15700.00 3769.60 7751.48 -11451.50 16253.38 3737,09 6940.28 -12206.61 224.67 .1108,75 507.18 770.30 3.28 OSF 1.50 Warning 15800.00 3768.28 7819.66 -11524,64 16358.36 3738.07 7011.95 -12283.29 22480 0870 510.38 767.98 3.26 OSF 1.50 Warning 15900.00 3768.96 7887.84 -11597.79 16448.05 3736.18 7071.65 -12347.52 224.5811 1515.02 765.03 3.23 OSF 1.50 Warning 18000.00 3785.84 795612 -11670.93 16549.86 3734.33 714218 -12423.76 22481 110115 518.32 763.28 3.21 OSF 110 Weming 1610800 3786.03 802453 -11743.77 16630.24 3732.35 720250 -12489.60 225.23 1110.47 52236 761.90 3.19 OSF 1.50 Warning 16200.00 376142 8093.37 -11816.25 1672498 3731.23 725172 -12553.44 225.39 111348 52611 761.86 3.17 OSF 110 Warning 16300.00 377180 8162.22 -11888.74 18797.59 373179 7307.17 -12608.39 225.50 1118.31 532.19 763.19 3.16 OSF 110 Warning 16400.00 3773.19 823117 -11961.22 16882.56 3730.48 7361.32 -12873.86 225.61 1125.23 536.56 787.20 3.15 OSF 1.50 Warning 1650100 3775.57 8299.92 -1203171 16078.56 3731.88 7421.93 -12748.30 22584 1132.88 54016 77231 3.15 OSF 1.50 Warning 1660100 3776.18 8368.09 -12106.88 17091.01 3733.88 749180 -12835.93 224.54 113118 54140 778.58 3.15 OSF 110 Warning 16700.00 3774.72 8435.42 -12180.78 17210.88 3735.11 757619 -12932.98 224.33 1142.13 545.52 778.12 3.14 OSF 1.50 Warning 16800.00 377127 8502.76 -1225470 1732482 3734.86 7646.47 -13011.80 224.27 114164 548.86 777.40 3.13 OSF 150 Warning 16900.00 3771.82 8570.09 -1232162 1741110 3735.17 7708.76 -13080.33 224.18 1145.32 55113 778.23 3.11 OSF 1.50 Warning 17000.00 377018 8637.42 -12402.54 17506.36 3735.25 7765.61 -13148.77 22411 1148.11 557.44 778.16 3.09 OSF 1.50 Warning 17100.00 376198 870445 -12476.74 17614.60 3734.11 7838.21 -13230.81 222.99 1150.51 580.57 778.47 3.08 OSF 1.50 Warning 17200.00 3767112 8770.11 -12552.15 17721.78 3732.75 7906.86 -13311.36 222.79 115115 563.85 77405 106 OSF 1.50 Warning 17300.00 3768.86 8835.78 -12627.58 17823.90 3728.76 797448 -13387.93 22213 114152 587.06 771.15 104 OSF 1.50 Warning 17400.00 3765.80 8901.41 -12703.00 17013.74 3728.34 8033.71 -13455.31 223.01 If inlit 571.31 767.90 312 OSF 1.50 Warning Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\S119-FN2(P5) 3/11/2013 12:01 PM Page 9 of 58 • • Trajectory S119-FN2(P5)Vs.SP22-FN1PB4 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Aam Ct-Ct Distance Separation Clearance OSF Rule Status • (ft) (fl) (ft) (ff) (ft) (ft) (ft) (n) (°) (ft) (0) - (0) 17500.00 3784.74 8987.07 -12778.42 1801413 372723 8099.31 -13531.20 222.91 1149.44 575.02 765.77 3.00 OSF 1.50 Warning 17600.00 376185 9032.73 -12853.84 18120.56 3729.72 8189.21 -13611.51 222.82 114130 578.42 78315 298 OSF 1.50 Warning 17700.00 376087 909851 -12928.84 1824451 3730.71 8252.07 -1370408 22292 1148.43 580.51 761.09 297 OSF 1.50 Warning 17800.00 3757.80 9184.97 -13003.78 1836202 373052 8332.02 -1378180 222.73 114559 582.91 758.66 295 OSF 1.50 Warning 17900.00 375472 9231.12 -1307818 1847516 373051 8410.83 -1387227 222.56 1141.73 58545 751.10 293 OSF 150 Warning 18000.00 3751.65 8297.28 -1315312 18588.26 3731.13 8480.18 -1395253 22238 1138.53 58815 744.17 2.90 OSF 1.50 Warning 18100.00 3748.81 9383.40 -1322838 18737.43 3731.33 8597.13 -14055.45 222.08 1127.48 588.37 738.24 2.89 OSF 150 Warning 1820100 3749.06 9429.11 -13303.85 18861.22 3731.11 888144 -1413103 22200 1116.37 58651 72513 286 OSF 150 Warning 18300.00 375024 9494.69 -13379.44 18924.98 3732.63 873564 -14181.85 221.97 1104.89 59460 707.96 2.79 OSF 150 Warning 18400.00 3751.42 958027 -1345492 18985.89 3734.87 8778.97 -1422480 221.89 1098.87 60248 69488 2.73 OSF 150 Warning 18500.00 375259 9625.88 -1353040 19062.74 373716 883225 -1427189 221.78 109158 608 39 685.76 2.69 OSF 1.50 Warning 18600.00 375177 9691.44 -1380589 1913655 374058 888243 -1433436 221.68 .7 61427 678.89 266 OSF 1.50 Warning 18662.59 3754.50 973250 -13853.12 18187.11 3742.79 8815.77 -14371.91 221.8 617.52 676.04 264 OSF 1.50 Warning 18700.00 3754.80 9757.34 -13881.09 1921855 3744.01 8936.45 -1439556 22243 1 8.2 61127 67515 264 OSF 150 Warning 18800.00 3755.45 982408 -13755.55 1929911 374657 898132 -14457.34 22232 109060 62420 87413 262 OSF 1.50 Warning 18900.00 3756.10 9890.82 -13830.02 19400.07 3748.00 0053.41 -14534.30 222.38 1094.24 827.91 875.30 2.62 OSF 1.50 Warning 18000.00 3756.75 0957.56 -13904.48 19478.90 3743.81 9103.99 -1459472 222.52 1097.80 63262 67512 2.60 OSF 150 Warning 18100.00 3757.40 10024.30 -13878.98 19545.73 3742.48 9145.00 -14647.40 222.61 1104.56 637.44 679.27 2.60 OSF 1.50 Warning 18200.00 3758.64 10089.72 -14054.57 19831.10 3741.29 9196.40 -14715.62 22052 1111.44 841.29 68159 260 OSF 1.50 Warning 18300.00 3761.05 10152.57 -14132.31 19700.47 3740.85 9236.90 -14771.93 219.72 1117.12 845.08 686.74 260 OSF 1.50 Warning 19400.00 3763.56 10215.18 -1421125 19770.06 3740.84 927598 -1482151 219.80 1125.21 84812 69247 260 OSF 1.50 Warning 1950100 3766.07 10277.79 -14288.18 19839.42 3740.84 931139 -1488712 219.89 1135.96 65118 701.17 2.62 OSF 1.50 Warning 19600.00 3768.58 10340.40 -14386.11 19908.49 3740.51 934109 -14947.04 219.98 1149.33 654.28 71282 264 OSF 1.50 Warning 19700.00 3771.06 10402.78 -1444423 19978.80 374012 938190 -15008.12 219.20 1164.03 858.48 728.95 268 OSF 1.50 Warning 19800.00 3773.07 10462.56 -1452436 20058.85 373184 9421.02 -15076.78 217.57 1179.45 65818 73193 2.69 OSF 150 Warning 19800.00 3774.90 10521.46 -1480515 20129.41 3740.48 945440 -15141.21 21759 1194.64 680.81 753.81 271 OSF 1.50 Warning 20000.00 3776.72 10580.36 -1468514 20200.62 3741.14 9485.51 -15205.28 217.81 121230 682.05 77011 275 OSF 1.50 Warning 20100.00 3778.55 10839.27 -1476174 20288.20 3741.06 9521.78 -15282.77 217.66 1231.47 66460 78107 2.78 OSF 1.50 Warning I 20200.00 3780.23 10687.71 -14847.88 20374.72 3739.03 9558.68 -1536121 21613 125087 667.30 80568 2.81 'OSF 150 Warning 20300.00 3780.90 10753.13 -14931.09 20444.14 3736.57 958612 -1542170 21476 128521 86753 82286 285 OSF 1.50 Warning 20400.00 3781.07 10807.22 -1501520 2051489 373197 961163 -1549204 214.86 1286.18 668.31 840.31 289 OSF 1.50 Warning 20500.00 378125 10861.30 -1509131 2059298 3731.46 9841.98 -1556476 21495 1308.11 689.50 85145 293 OSF 150 Warning 20800.00 3781.42 10915.39 -15183.42 20687.27 3731.45 9875.32 -1565295 21493 1326.03 672.83 878.05 2.96 OSF 1.50 Warning 2070100 3781.60 10969.48 -15287.53 20780.06 3732.91 9708.19 -1573171 214.84 1347.65 678.04 896.63 299 OSF 150 Warning 20800.00 3781.39 1102136 -15351.77 20887.95 3734.95 9738.41 -1582222 214.29 138115 678.65 91539 3.03 OSF 150 Warning 20900.00 3778.24 1107559 -15436.98 20999.61 3736.21 9784.75 -1594543 213.33 138810 686.76 92183 103 OSF 1.50 Warning 21000.00 3774.22 11127.31 -15522.47 21124.49 3738.11 9831.48 -18061.22 21101 140185 683.72 941.04 104 OSF 1.50 Warning 21100.00 3770.19 11178.04 -15807.88 21589.45 3755.75 10053.40 -1844506 211.55 1402.85 714.08 92147 295 OSF 1.50 Warning 21200.00 3768.16 11250.76 -15893.45 21731.13 3759.38 10153.88 -16571.81 211.13 716.31 911.98 291 OSF 1,50 Warning 21283.50 3762.80 11273.95 -1576483 21800.00 3781.08 10197.18 -18825.17 210.95 735.90 887.34 2.81 OSF 1.50 Warning End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 10 of 58 Field: Nikaltchuq Well: SP22-FN1 Structure: Spy Island Bonhole: SP22-FNIPB1 Slot: SP22 Trajectory: SP22-FNIPB1 Client: Eni Petroleum Type: De(Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08928045° Grid Scale Factor: 0.999900151 Magnetic Declination: 20.104° Magnetic Declination Date: January 31,2013 Magnetic Model: BGGM 2012 Reference Point: Nortlrjpg ailing Elevation Structure Unc. Slot Unc. 8053633.080(BUS) 511543.560(fIUS) 53.820(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Treiootory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma St/re Surveying Pro Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 40.720 Act-Stns SLBGYRO-MWD-Depth Only-No Global 16.000 SP22-FNIPB1/SP22-FNIPB1 40.720 665.420 Act-Stns SLB_GYRO-MWD-No Global 18.000 SP22-FNIPBI/SP22•FN1PB1 665.420 3014.860 Act-She SLB MWD+GMAG-No Global 18.000 SP22-FNIP81/SP22•FN1PB1 3014.860 12085.310 Act-Stns SLB MWD+GMAG-No Global 12.250 SP22-FNIPB1/SP22-FNIPB1 12095.310 14484.260 Act-Stns SLB_MWD+GMAG-No Global 8.750 SP22-FNIPB1/SP22-FNIPB1 14484.260 14550.000 Act-Stns SLB BLIND+TREND-No Global 8.750 SP22-FNIPB1/SP22-FNIPB1 Minimum Reference Traveling Cylinder Allowable EOU-EOU Contrdling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aam Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (8) (8) (ff) (B) 1.) (8) (ft) (8) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 B Results filtered:Ct-Ct separation r_3000.00 B Results highlighted:Ct-Ct separation c 2640.00 ft 11700.00 374285 467281 -8909.71 12433.49 3721.29 3904.08 -9902.88 230.22 1255.82 354.77 1018.77 532 OSF 150 Peas 11800.00 374893 4747.30 5975.16 12548.13 3728.35 3993.36 -9971.19 230.28 1249.39 356.25 1011.58 5.27 OSF 150 Pass 11900.00 3756.90 4822.59 -9040.60 12648.31 3734.69 4074.82 -10032.83 230.30 1242.77 359.15 1003.00 5.20 OSF 150 Pass 1200200 3762.17 4898.90 -910498 12750.28 3739.39 4158.08 -10093.97 232.15 1237.10 362.02 995.42 5.14 OSF 150 Peas 12100.00 3763.03 4977.73 -9166.50 12847.85 3742.48 4233.69 -10152.89 23358 1235.56 365.51 991.55 5.08 OSF 1.50 Pass 12200.00 3783.11 5058.98 -9227.48 12946.15 3748.55 4312.29 -10211.91 233.19 1234.48 368.87 988.17 5.03 OSF 1.50 Pass 12300.00 3763.18 513824 -9288.46 13032.84 3751.82 438286 -10264.37 2328 374.17 984.38 896 OSF 1.50 Warning 12400.00 3783.58 5215.40 -9349.58 13115.28 3755.84 444576 -10315.36 232.55 7 379.75 881.49 4.89 OSF 1.50 Warning 12500.00 376856 529841 -9410.85 1320285 3755.85 451152 -10370.18 232.59 1237.00 384.70 980.20 4.83 OSF 1.50 Warning 12600.00 3765.55 5373.41 -947215 13301.16 3751.43 4590.16 -10432.23 232.83 1230.13 388.08 980.10 480 OSF 180 Warning 12700.00 3766.53 5452.42 -9533.44 13379.96 3747.39 4850.78 -10482.43 233.05 1242.41 393.93 979.46 4.74 OSF 1.50 Warning 1280000 3767.52 5531.43 -9594.74 13452.66 3743.78 4705.77 -1052884 233.25 1247.67 400.40 980.41 4.68 OSF 1.50 Warning 1290800 3769.35 5610.53 -965588 13573.24 373886 4798.63 -10608.92 23183 1253.65 400.94 986.03 4.70 OSF 1.50 Waming 13000.00 3773.85 5689.96 -971846 13722.74 3734.58 4912.10 -10703.79 234.43 1257.55 397.45 992.25 4.75 OSF 1.50 Warning 13100.00 3778.48 5769.41 -9777.02 13917.12 3734.50 507012 -1081859 234.85 1253.55 386.83 99513 4.87 OSF 1.50 Warning 1320000 3783.07 5848.86 -9837.57 14023.66 3735.61 5158.84 -1087586 235.04 1247.57 388.89 987.98 4.82 OSF 1.50 Warning 1330000 3787.68 5928.31 -9898.12 14150.12 3733.46 526585 -1094182 235.43 123827 387.52 980.80 4.81 OSF 1.50 Warning 1340080 3792.11 6007.76 -9958.69 1422788 373280 5330.52 -1098581 235.60 1231.76 394.22 968.62 4.69 OSF 1.50 Warning 1350000 3793.48 6087.23 -10019.36 14304.35 3731.74 5394.24 -11028.62 235.53 1225.83 401.08 95812 4.59 OSF 1.50 Warning 13600.00 379182 6166.70 -10080.05 1438235 373187 5447.29 -11086.18 235.54 1222.23 409.68 948.78 4.48 OSF 1.50 Warning 13700.00 3794.18 6248.18 -1014875 14436.11 3731.48 550888 -11106.26 235.57 417.76 942.61 4.39 OSF 1.50 Warning 13800.00 3794.50 8325.85 -10201.44 14513.08 372988 5561.03 -11154,00 235.67 1223.2 435.54 93251 4.22 OSF 1.50 Warning 13900.00 3794.85 8405.13 -10262.13 14550.00 372864 558284 -11177.06 235.72 1227.28 481.33 919.37 4.00 OSF 1.50 Warning 14000.00 3795.18 648443 -1032106 14550.00 3728.64 5589.84 -11177.06 235.42 1238.56 473.39 922.64 3.93 OSF 1.50 Warning 14100.00 379581 6563.58 -10384.17 1455000 372884 5589.84 -11177.06 235.42 1257.50 482.34 935.62 3.82 OSF 1.50 Warning 1420800 3795.84 6642.73 -1044828 1455080 372884 5589.84 -11177.06 235.42 1283.98 488.22 95817 3.95 OSF 1.50 Warning 1430800 3796.17 6721.88 -10506.39 14550.00 3728.64 558984 -11177.06 235.42 1317.53 491.29 989.67 4.03 OSF 1.50 Warning 14400.00 379849 6801.04 -1056780 1455800 3728.64 5589.84 -11177.06 235.42 1357.63 491.89 102837 4.15 OSF 1.50 Waming 1450000 3796.56 6880.00 -10628.86 14550.00 3728.64 5589.84 -11177.06 234.94 1403.44 490.42 1076.17 4.30 OSF 1.50 Waming 14600.00 3794.26 6957.21 -10892.36 14550.00 372884 558884 -11177.06 233.84 1452.22 487.29 1127.03 4.48 OSF 1.50 Warning 14700.00 3790.19 703105 -1075780 1455800 372884 5589.84 •11177.06 233.88 1504.25 482.73 1182.10 4.68 OSF 1.50 Warning 14800.00 3786.09 7108.88 -1082247 14550.00 372854 558284 -11177.08 233.89 1560.93 477.08 1242.55 4.91 OSF 1.50 Waming 14900.00 3781.99 7184.70 -1088784 14550.00 372884 5589.84 -11177.06 23389 1621.80 470.63 1307.72 5.18 OSF 1.50 Pass 1500200 3778.51 725252 -10953.79 14550.00 372884 5589.84 -11177.06 230.81 168528 483.47 1375.97 546 OSF 1.50 Pass 15100.00 3776.83 7331.84 -11023.02 14550.00 3728.64 558284 -11177.08 227.83 174828 455.58 1445.21 5.77 OSF 1.50 Pass 15200.00 377552 7402.41 -1109567 1455200 372854 558284 -11177.06 227.83 1815.00 44749 1516.43 1509 OSF 1.50 Pass 15300.00 3774.42 7473.17 -11184.32 14550.00 372884 558884 -11177.06 227.63 1883.93 439.30 159274 6.44 OSF 1.50 Pass 15400.00 3773.32 7543.94 -11234,96 14550.00 372884 5589.84 -11177.08 227.63 185547 431.11 1887.73 8.82 OSF 1.50 Pass 15500.00 3772.20 7614.80 -1130571 14550.00 372854 558284 -11177.06 227.01 202232 423.01 1748.88 7.21 OSF 1.50 Pass 15800.00 3770.92 7683.31 -11378.36 1455200 372854 558884 •1117786 225.58 210355 414.77 1828.70 7.82 OSF 1.50 Pass 15700.00 3769.60 7751.48 -11451.50 14550.00 3728.84 558284 -11177.08 225.58 2179.38 406.72 1907.91 8.05 OSF 1.50 Pass 15800.00 3768.28 781958 -11524.64 1455200 372854 5589.84 -11177.06 225.58 2257.10 39820 1990.84 8.50 OSF 1.50 Pass 15900.00 3766.96 7887.84 -11597.79 1455020 3728.84 558984 -11177.08 225.58 2338.51 391.33 2075.30 8.97 OSF 1.50 Pass 16000.00 3765.64 7956.02 -11870.93 14550.00 372884 558884 -11177.08 225.58 2417.45 384.03 2181.10 9.46 OSF 1.50 Pass 18100.00 3766.03 8024.53 -1174327 14550.00 3728.64 5589.84 -11177.08 223.01 2500.05 37680 2248.45 9.57 OSF 1.50 Pass 16200.00 3788.42 809337 -1181625 14550.00 372854 5589.84 -11177.06 22381 258415 370.24 2338.99 10.49 OSF 1.50 Pass 18300.00 3770.80 8182.22 -11888.74 14550.00 3728.64 5589.84 -11177.08 223.01 2889.35 363.87 2426.44 11.03 OSF 1.50 Pass 18400.00 3773.19 8231.07 -11981.22 14550.00 3728.64 5589.84 -11177.06 223.01 2755.54 357.77 2518.70 11.58 OSF 1.50 Pass 16500.00 3775.57 8299.92 -12033.71 14550.00 3728.64 5589.84 -11177.08 223.01 2842.64 351.94 2807.68 12.15 OSF 1.50 Paw 16600.00 3776.18 8368.09 -12108.86 14550.00 3728.64 5589.84 -11177.06 225.83 2930.10 346.31 2698.90 12.72 OSF 1.50 Paw End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\S)19-FN2(P5) 3/11/2013 12:01 PM Page 11 of 58 Field: Nikaitchuq Well: SP22-FN7 Structure: Spy Island Borehole: SP22-FNIPB3 Slot: SP22 Trajectory: SP22-FN1P83 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08928045° Grid Scale Factor: 0.999900151 Magnetic Declination: 26104° Magnet°Declination Dale: January 31,2013 Magnetic Model: BGGM 2012 Reference Point: &W O= lath/ft Eh3utl911 ;Structure Unc. Slot Unn, 6053833.080(WS) 511543.560(ftUS) 53.820(ft)MSL 0.000(ft)(1 sigma) 3000(9)(1 sigma) Traieetory Error Model.ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prow Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Monder(fn) Borehole/Survey 0.000 46720 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 SP22-FN1PB1/SP22-FNIPB1 40.720 885.420 Act-Stns SLB_GYRO-MWD-Nn Globe 18.000 SP22-FN1PB1/SP22-FNIPB1 6885.420 3014.880 Act-Stns SLB_MWD+GMAG-No Globe 18.000 SP22-FN1PB1/SP22-FN1PB1 3014.800 12095.310 Act-Sins SLB_MWD0GMAG-No Globe 12.250 SP22-FN1PB7/SP22-FN1PB1 12095.310 13272.400 Act-Sins SLB_MWD0GMAG-No Globe 8.750 SP22-FN1PB1/SP22-FNIPB1 13272.400 14856310 Act-Sins SLB_MWD♦GMAG-No Globe 8.750 SP22-FN1PB2/SP22-FNIPB2 14859.310 19239.940 Act-Stns SLB_MWD*GMAG-No Globe 8.750 SP22-FN1PB3/SP22•FNIPB3 8.600 19239.940 19308.000 Act-Stns SLB BLIND+TREND-No Globe 8.750 SP22-FN1PB3/SP22-FN1PB3 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North ANm Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 N Results highlighted:Cl-Cl separation<=2840.00 ft 11700.00 3742.95 467231 -8909.71 12433.49 3721.28 3904.08 -9902.88 230.22 1255.82 354.77 1018.77 332 OSF 1.50 Pass 11800.00 3749.93 4747.30 -8975.18 12548.13 3728.35 399336 -9871.19 230.26 124939 358.25 1011.58 5.27 OSF 1.50 Pass 1190030 375830 482259 -9040.80 12648.31 3734.89 4074.82 -10032.83 230.30 1242.77 359.15 1003.00 5.20 OSF 1.50 Pass 12000.00 376217 4898.90 -910458 12750.28 3739.39 4158.08 -10093.97 232.15 1237.10 362.02 895.42 314 OSF 1.50 Pass 12100.00 3763.03 4977.73 -9188.50 12847.65 3742.48 423369 -10152.89 233.38 1235.58 365.51 991.55 5.08 OSF 1.50 Pass 1220500 3763.11 5056.98 -922748 12948.15 374355 4312.29 -10211.91 233.10 1 .4 388.97 988.17 5.03 OSF 1.50 Pass 12300.00 3763.18 5138.24 -928848 1303284 375152 438386 -10211437 232.9 374.17 984.38 496 OSF 1.50 Warning 12400.00 3763.58 521540 -9349.56 13115.28 3755.84 4445.76 -10315.36 232.55 379.75 981.49 4.89 OSF 1.50 Warning 12500.00 3764.56 5294.41 -9410.85 13202.45 3755.65 451152 -10370.18 232.59 1237.00 38470 880.20 4.83 OSF 1.50 Warning 12800.00 376555 5373.41 -9472.15 13307.95 3751.42 4595.50 -1043344 232.84 1239.04 387.16 980.60 4.81 OSF 1.50 Warning 1270500 3766.53 545242 -9533.44 13403.69 3750.43 4669.96 -10498.60 232.93 124153 39592 98039 4.77 OSF 1.50 Warning 12800.00 3767.52 5531.43 -9594.74 13520.09 3750.29 4760.40 -10589.88 232.98 1243.26 39230 981.80 4.77 OSF 1.50 Warning 12900.00 378535 5810.53 -9655.88 1387252 3751.42 488221 -10681.98 233.41 1242.18 387.65 98342 4.82 OSF 1.50 Warning 13000.00 377385 5689.96 -971848 13800.15 3752.31 4986.33 -10735.28 23331 1238.36 388.38 98345 4.82 OSF 1.50 Warning 13100.00 377846 576941 -9777.02 1388274 3752.68 5054.16 -1078239 233.97 123411 392.19 97232 4.73 OSF 1.50 Warning 1320500 378107 584836 -983737 1395938 3752.32 5116.50 -10827.82 234.15 123202 39876 98585 4.64 OSF 1.50 Warning 13300.00 3787.68 5928.31 -989312 1405366 3751.31 5194.11 -1088562 234.41 1231.06 402.41 962.46 4.60 OSF 150 Warning 13400.00 379211 6007.76 -995839 14171.38 3750.20 5288.60 -10953.49 234.86 122541 403.30 980.78 4.58 OSF 1.50 Warning 13500.00 3793.48 8087.23 -10019.36 14280.75 3748.88 5375.48 -11017.24 234.72 1228.53 405.16 956.10 455 OSF 1.50 Warning 1360600 379182 6188.70 -10080.05 14385.34 3747.98 546035 -11077.77 234.79 1223.08 407.66 95697 451 OSF 1.50 Warning 1370500 3794.16 6248.18 -10140.75 14486.28 3747.50 554520 -11136.02 23483 1219.40 410.74 945.25 4.46 OSF 1.50 Warning 1380050 3794.50 6325.65 -10201.44 14576.82 3746.85 5616.78 -1118840 23488 121839 415.48 938.77 4.40 OSF 1.50 Warning 13900.00 3794.85 8405.13 -10262.13 14889.69 3746.11 5709.05 -11253.76 23494 1212.52 416.71 934.39 4.37 OSF 1.50 Warning 14000.00 3795.18 8484.43 -1032338 14787.91 374538 578536 -1131530 23489 120839 420.17 927.95 432 OSF 1.50 Warning 14100.00 379551 6583.58 -10384.17 14912.21 3745.29 5891.47 -11381.16 234.74 1203.43 41930 923.44 4.31 OSF 1.50 Warning 14200.00 379584 664273 -10445.28 15011.13 3748.51 597369 -11436.06 234.61 1196.45 422.99 914.13 4.25 OSF 1.50 Warning 14300.00 3796.17 6721.88 -10506.39 15097.94 3751.77 6045.17 -11485.22 234.48 1190.81 428.49 904.82 4.17 OSF 1.50 Warning 14400.00 379849 6801.04 -10587.50 15195.82 3752.07 6125.41 -11540.93 23449 1185.75 432.17 897.31 4.12 OSF 1.50 Warning 14500.00 3798.56 8880.00 -10628.88 15306.43 375574 6216.67 -11603.76 233.71 1180.06 433.85 890.83 4.09 OSF 1.50 Warning 14600.00 3794.28 6957.21 -10692.38 15418.20 374528 6307.73 -11665.02 231.58 1170.43 435.24 879.94 4.04 OSF 1.50 Warning 14700.00 379519 7033.05 -10757.40 15515.52 3747.75 6390.37 -11720.11 231.19 1158.29 43838 865.58 3.97 OSF 1.50 Warning 14800.00 378509 710858 -10822.47 15613.12 3745.81 6471.56 -1177423 231.11 1148.14 44217 851.04 3.89 OSF 1.50 Warning 14900.00 3781.99 7184.70 -10887.54 15693.75 3743.73 6538.20 -11819.57 231.08 1134.94 448.73 835.48 3.80 OSF 1.50 Warning 15000.00 3778.51 7250.52 -10953.79 15753.97 3741.77 6587.13 -11854.82 229.06 1124.70 458.42 818.76 3.68 OSF 1.50 Warning 15100.00 3778.63 7331.84 -11023.02 15807.42 3740.17 6629.41 -11887.28 226.87 1114.19 46547 801.55 3.57 OSF 1.50 Warning 15200.00 3775.52 7402.41 -11093.67 15850.88 3739.23 6882.28 -1191337 226.90 1106.48 479.41 786.55 3.47 OSF 1.50 Warning 15300.00 3774.42 7473.17 -11184.32 15897.88 3738.85 8696.49 -11947.86 226.90 488.82 777.63 3.39 OSF 1.50 Warning 15400.00 3773.32 7543.04 -11234.96 15081.72 3738.22 6741.11 -11993.54 226.89 495.77 774.24 3.35 OSF 1.50 Warning 15500.00 3772.20 7814.80 -11305.71 16049.06 3737.83 6800.52 -12057.56 226.22 1108.69 50041 77475 3.33 OSF 1.50 Warning 1560300 3770.92 7883.31 -11378.36 16186.04 3737.24 6880.39 -12143.02 224.72 1109.29 502.49 773.97 3.31 OSF 1.50 Warning 15700.00 3769.80 7751.48 -11451.50 18253.38 3737.09 694526 -1220631 224.67 11 .75 507.18 770.30 3.28 OSF 1.50 Warning 15800.00 3788.28 7819.66 -11524.64 16358.36 3736.97 7011.95 -12283.29 224.6 510.38 787.98 3.26 OSF 1.50 Warning 15900.00 3766.98 7887.84 -11597.79 1844655 3736.18 707155 -12347.52 224.58 515.02 785.03 523 OSF 1.50 Warning 18000.00 376534 7958.02 -11670.93 16540.86 3734.33 7142.08 -12423.76 224.81 1109.15 518.32 783.28 3.21 OSF 1.50 Warning 18100.00 3788.03 8024.53 -1174377 18639.24 3732.35 7202.50 -12489.80 225.23 1110.47 522.38 761.90 3.79 OSF 1.50 Warning 16200.00 3788.42 8093.37 -11818.25 1672458 3731.23 7259.72 -12553.44 225.39 1113.46 528.91 781.86 3.17 OSF 150 Warning 16300.00 377580 8182.22 -11888.74 16797.59 3730.79 7307.17 -12608.39 22530 1118.31 532.19 763.19 3.16 OSF 1.50 Warning 16400.00 377319 8231.07 -1196112 1688258 3730.48 7361.32 -12673.88 225.81 1125.23 538.56 767.20 315 OSF 1,50 Warning 16500.00 377357 8299.92 -12033.71 16978.58 3731.86 7421.93 -12748.30 225.84 1132,88 54336 77231 3.15 OSF 1.50 Warning 16600.00 3776.18 838839 -12108.86 1709151 3733.88 7493.80 -12835.93 224.54 1139.18 543.40 776.58 115 OSF 1.50 Warning 16700.00 377472 843542 -12180.78 1721938 3735.11 7578.89 -12932.98 224.33 114213 545.52 778.12 3.14 OSF 1.50 Warning 16800.00 3773.27 8502.78 -12254.70 17324.82 373436 7646.47 -13011.80 224.27 114304 548.86 777.40 3.13 OSF 1.50 Warning 16900.00 3771.82 8570.09 -12328.62 17416.10 3735.17 7706.78 -13080.33 224.18 1145.32 553.13 778.23 3.11 OSF 1.50 Warning . 17000.00 377538 8837.42 -12402.54 17508.36 3735.25 7765.61 -1314377 22411 1148.11 55744 778.16 339 OSF 1.50 Warning 17100.00 376838 8704.45 -1247374 1761460 3734.11 783611 -13230.81 222.99 1150.51 58357 77647 108 OSF 1.50 Warning 17200.00 3767.92 877511 -1255215 17721.76 373215 790836 -13311.36 222.79 1150.15 563.65 774.05 3.06 OSF 1.50 Warning 17300.00 3766.86 883576 -12627.58 17823.99 3728.76 7974.48 -13387.93 222.93 114.2 567.06 771.15 3.04 OSF 1.50 Warning 17400.00 3765.80 8901.41 -12703.00 17813.74 3726.34 803371 -1345531 223.01 571.31 767.90 3.02 OSF 1.50 Warning 17500 00 3764.74 898737 -1277342 18008.16 3725.39 8095.32 -13526.85 22350 57511 785.75 300 OSF 1.50 Warning • • • • • • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\8119-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 12 of 58 • • • Trajectory:5119-FN2(P5)Vs.SP22-FNIPB3 Minimum Reference Traveling Cylinder Allowable EOU-EOU Contrdling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aam Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (6) (ft) (ft) (ft) (ft) (`) (ft) (ft) _ (ft) 17600.00 3783.85 032.73 -12853.84 18080.01 3722.46 8141.72 -13581.62 223.21 1151.20 58041 763.93 2.98 OSF 1.50 Warning 17700.00 3780.87 098.81 -12928.84 18151.87 3719.52 8186.17 -13637.75 223.61 1156.36 585.18 78521 2.97 OSF 1.50 Warning 17800.00 3757.80 16497 -13003.76 1825489 371454 824062 -1371202 223.88 1162.46 58868 76268 298 OSF 1.50 Warning 17900.00 3754.72 231.12 -13078.69 18359.98 3712.76 8314.62 -1380156 223.60 1168.02 592.22 772.88 2.98 OSF 1.50 Warning 18000.00 3751135 297.28 -13153.62 18465.27 3713.88 8379.91 -1388416 223.38 1173.32 595.85 775.78 2.96 OSF 1.50 Warning 18100.00 3748.81 383.40 -13228.58 1859628 3717.32 846253 -13985.74 222.84 1177.23 598.31 77823 295 OSF 1.50 Warning 18200.00 374208 429.11 -13303.95 18718.19 3717.62 8541.82 -14078.34 222.52 1178.11 800.42 777.51 295 OSF 1.50 Warning 18300.00 3750.24 494.89 -13379.44 18857.55 3717.13 8634.94 -14182.03 222.82 1178.62 801.33 775.40 2.94 OSF 1.50 Warning 18400.00 3751.42 580.27 -13454.92 18980.45 3717.39 8705.42 -14256.99 222.67 1172.71 804.77 769.20 2.91 OSF 1.50 Warning 18500.00 3752.59 0825.86 -13530.40 19082.82 3719.81 8775.33 -14331.45 222.63 1168.83 608.34 782.94 2.88 OSF 1.50 Warning 18600.00 3753.77 969144 -1380589 1914282 3725.14 882958 -1439226 222.41 116570 813.74 758.21 2.85 OSF 1.50 Warning 18700.00 3754.80 9757.34 -13881.09 19244.72 3732.50 8897.80 -1446555 222.97 1163.91 618.81 751.04 2.82 OSF 1.50 Warning 1880020 3755.45 9824.08 -1375555 19308.00 3735.03 8939.04 -14510.81 222.8r�:E31 642.27 735.18 272 OSF 1.50 Warning 18900.00 3756.10 9890.82 -13830.02 19308.00 3735.03 8939.04 -14510.81 222.86 11 0.9 648.81 737.52 211 OSF 1.50 Warning 19000.00 3756.75 9957.56 -1390449 19301500 3735.03 8939.04 -14510.81 222.88 1185.53 850.87 751.42 2.73 OSF 1.50 Warning 1910200 375740 10024.30 -1397828 1030620 3735.03 893204 -14510.81 222.86 1208.78 648.14 778.38 280 OSF 1.50 Warners 1920200 375854 1008272 -1405457 19306.00 3735.03 8939.04 -14510.81 220.48 1238.05 641.57 810.01 2.90 OSF 1.50 Warning 1930200 3761.05 1015257 -1413231 19306.00 3735.03 893204 -14510.81 219.47 127145 63154 85209 3.02 OSF 1.50 Warning 19400.00 378356 10215.18 -14210.25 19306.00 3735.03 8939.04 -14510.81 219.47 1311.36 618.98 888.38 3.18 OSF 1.50 Warning 19500.00 3766.07 10277.79 -14288.18 19306.00 3735.03 8939.04 -14510.81 219.47 1357.49 604.43 954.21 3.37 OSF 1.50 Warning 19600.00 3788.58 10340.40 -14366.11 1930620 373523 8939.04 -14510.81 219.47 140221 588.51 1016.54 260 OSF 1.50 Warning • 19700.00 3771.06 1040278 -14444.23 19306.00 373523 8939.04 -14510.81 218.65 1465.69 571.74 1084.21 3.85 OSF 1.50 Warning 19800.00 377207 1048256 -14524.36 19306.00 3735.03 8939.04 -1451281 217.10 1524.06 554.10 1154.33 413 OSF 1.50 Warning 19900.00 3774.90 1052148 -1460515 19306.00 3735.03 893204 -14510.81 217.10 158573 536.31 1227.88 4.44 OSF 1.50 Warning 2000200 3776.72 10580.38 -1468594 19306.00 3735.03 893924 -1451021 217.10 1651.16 518.70 1305.04 478 OSF 1.50 Warning 20100.00 3778.55 10639.27 -14766.74 19306.00 3735.03 893924 -14510.81 217.10 1719.93 501.48 1385.28 5.15 OSF 1.50 Pass 20200.00 3780.23 10697.71 -14847.86 19306.00 3735.03 893924 -14510.81 216.18 1791.24 48470 1487.78 5.55 OSF 1.50 Pass 2030200 3780.90 10753.13 -14931.09 19308.00 3735.03 8939.04 -14510.81 214.88 1862.70 487.89 1550.44 5.98 OSF 150 Pass 20400.00 3781.07 10807.22 -15015.20 19306.00 3735.03 8939.04 -1451281 214.88 1935.61 451.53 1634.27 6.44 OSF 1.50 Pass 20500.00 3781.25 10881.30 -15099.31 19306.00 3735.03 8939.04 -14510.81 21456 2010.86 435.87 1719.05 6.93 OSF 1.50 Pass 20600.00 3781.42 10915.39 -15183.42 19306.00 3735.03 893204 -14510.81 214.66 2088.18 420.95 180722 7.45 OSF 1.50 Pass 20700.00 3781.60 1096948 -15267.53 19306.00 3735.03 8939.04 -14510.81 214.66 2167.36 406.76 1895.88 8.01 OSF 1.50 Pass • 20800.00 3781.39 11023.36 •15351.77 19306.00 3735.03 893204 -14510.81 215.32 2248.05 39327 1985.54 8.59 OSF 1.50 Pass 20900.00 3778.24 11075.59 -15436.08 19306.00 3735.03 893204 -14510.81 218.25 2329.05 380.19 2075.26 9.21 OSF 1.50 Pass 21000.00 377422 11127.31 •15522.47 1030820 3735.03 8939.04 -14510.81 216.25 2411.12 367.70 2165.68 9.86 OSF 1.50 Pass 21100.00 3770.19 11179.04 -15607.98 10306.00 3735.03 8939.04 -14510.81 216.25 249450 355.88 2256.93 1254 OSF 1.50 Pass 21200.00 3766.16 11230.76 -15693.45 19308.00 3735.03 893204 -1451081 216.25 2579.06 344.85 2348.97 11.25 OSF 1.50 Pass 21283.60 3762.80 11273.95 •15784.83 19308.00 3735.03 8939.04 -14510.81 218.25 2850.50 335.78 2428.33 11.87 OSF 1.50 Pass End of results • • . Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 13 of 58 Field: NikaBchup Well: S120-N4 Structure: Spy Island Borehole: S120-N4 Slot: SP20 Trajectory: 5120-1,14 Client: Eni Petroleum Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08940154° Grid Scale Factor: 0.999900152 Magnetic Declination: 20.612° Magnetic Declination Date: April 01,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Loam Favatlon $aucture Unc, U Ung, 6053636.060(ftUS) 511559.210(ftUS) 53.990(ft)MSL 0.000(8)(1 sigma) 0.000(ft)(1 sigma) Traiectory Error Mode(;ISCWSAO 3-D 95.000%Confidence 2.7955 shuns Surveying Pro9; Description MO From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole/Survey 0.000 40.890 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 18.000 5120-N4PH/5120-N4P131 40.890 748.900 Act-Stns SLB_NSG+SSHOT-No Global 18.000 S120-N4PH/S120-N4PB1 748.900 2578.600 Act-Stns SLB_MWD+GMAG-No Global 18.000 S120-N4PH/S120-N4PB1 2578.600 2673.890 Act-Stns SLBMWD-STD-No Global 12.250 S120-N4PH/S120-N4P81 2873.890 12719.280 Act-Stns SLB_MWD_ «GMAG-No Global 12.250 S120-N4/S120-N4 12719.280 12788.000 Act-Stns SLB_BLIND•TREND-No Global 8.750 5120-N4/5120-N4 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Ct-Ct separation<=2840.00 ft 11700.00 3742.95 4672.01 -890171 1278010 388814 5580.47 -8604.08 53.97 248247 330.45 2261.84 11.30 OSF 1.50 Pass 11800.00 374193 4747.30 -8975.16 1276610 388814 558147 .6604.06 53.97 2517.06 323.53 2301.05 11.70 OSF 1.50 Pass 11900.00 3758.90 4822.59 -9040.60 1278610 388814 5580.47 .6604.06 53.97 2555.11 316.38 2343.88 12.15 OSF 1.50 Pass 12000.00 378217 4898.90 -9104.98 12786.00 3888.94 558147 .6604 06 54.82 2595.23 308.93 238815 12.84 OSF 1.50 Pass 12100.00 378103 4977 73 -9166.50 12788.00 3888.94 5580.47 -6604 06 5145 2635.38 301.09 2434.33 1117 OSF 1.50 Pass 12200.00 3783.11 5058.98 -9227.48 12788.00 3888.94 5580.47 -8804.06 55.45 2678.10 293.22 2482.29 13.74 OSF 1.50 Pass 12300.00 3783.18 5138.24 -5288.46 12788.00 3888.94 5580.47 -8804.06 55.45 2723.82 285.31 2633.29 14.38 OSF 1.50 Pass 12400.00 3783.58 5215.40 -9349.56 12788.00 3888.94 5580.47 -0804.06 55.52 2772.50 277.33 2587.29 15.04 OSF 1.50 Pass 12500.00 3764.58 5294.41 -0410.85 12786.00 3888.94 5580.47 -6604.06 55.52 2824.07 269.49 2844.09 15.77 OSF 1.50 Pass 12800.00 3785.55 5373.41 -0472.15 12786.00 3888.94 5580.47 -8604.06 55.52 2878.20 261.73 2703.39 18.55 OSF 1.50 Pass 12700.00 3788.53 5452.42 -9533.44 12788.00 3888.94 5580.47 -8804.06 55.62 2934.74 254.07 2785.03 17.39 OSF 1.60 Pass 12800.00 3787.52 5531.43 -9594.74 12788.00 3888.94 5580.47 -8804.08 56.62 2993.55 248.53 2828.86 18.28 OSF 1.60 Pass End of results • • • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 15 of 58 Field: Nikakchup Well: SP10-FN3 Structure: Spy Island Borehole: SP10-FN3 Slot: SP10 Trajectory: SP10-FN3 Client: Eni Petroleum Type: Del Survey Coordinate System: NA027 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08970521° Grid Scala Factor: 0.999900153 Magnetic Declination: 20.516° Magnetic Declination Date: June 01,2012 Magnetic Model: BGGM 2011 Reference Point J4orthinp Luting Elevation Structure Unc. Slot Una, 8053643.710(WS) 511598160(ftUS) 53.920(ft)MSL 0.000(6)(1 sigma) 0.000(R)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Survevino Prop: Description MD From(ft) MD To(ft) EOU Fret; Survey Tool Type Hole Diameter(In) Borehole/Survey 0.000 40.820 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 SP18-FN3/SP16-FN3 40.820 464.000 Act-Stns SLB_NSG+SSHOT-No Global 18.000 SP78-FN3/SP78-FN3 484.000 3218.620 Act-Stns SLB_MWD+GMAG-No Global 16.000 SP16-FN3 I SP7&FNS 3218.620 11579.610 Act-Stns SLB_MWD+GMAG-No Global 12.250 SP16-FN3/SP78-FN3 11579.610 21100.000 Act-Stns SLB_MWD+GMAG-No Global 8.760 SP16-FN3 I SP16-FN3 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aim Ct-Cl Distance Separation Clearance OSF Rule Status (0) (ft) (8) (8) (ft) (ft) (8) (ft) (°) (ft) (8) (8) ' All local minima indicated. Results filtered:Depth 11700.00 ft c=MD 0=21284.00 ft • Results filtered:Ct-Ct separation c=3000.00 ft Results highlighted:Ct-Ct separation 0=2840.00 ft 11700.00 374205 4672.01 -890571 11239.03 3801.46 5468.65 -7965.35 51.76 1236.88 385.57 992.84 5,08 OSF 1.50 Pass • 11800.00 3749.93 4747.30 -8975.16 11354.85 3810.29 5556.34 -8040.48 51.80 1237.87 370.73 990.18 502 OSF 1.50 Pass • 11900.00 3756.90 4822.59 -9040.60 11465.69 3819.86 5639.22 -811344 51.88 1237.13 375.21 986.68 4.95 OSF 1.50 Warning 1200500 376217 4898.90 -9104.08 11583.15 3831.21 5726.06 -8191.71 54.16 1234.11 380.24 980.29 4.88 OSF 1.50 Warning 12100.00 3783.03 4977.73 .9166.50 11676.68 3840.61 5794.58 -8254.68 56.06 1226.85 382.40 971.39 4.82 OSF 1.50 Warning 1220500 3783.11 505658 -9227.48 11752.41 3845.19 585127 -8304.67 56.28 1220.32 382.68 964.89 4.79 OSF 1.50 Warning 12300.00 378118 5136.24 -9288.48 11864.27 3847.18 5935.41 -8378.34 56.40 1214.11 387.30 955.58 4.71 OSF 1.50 Warning 12400,00 3783.58 5215.40 -9349.56 11957.94 3843.82 8006.22 -843554 5558 1208.29 389.81 948.09 4.66 OSF 1.50 Warning 12500.00 3764.58 5294.41 -941585 1206485 3841.21 6086.44 -8510.16 55.82 1201.84 393.92 93190 4.58 OSF 1.50 Warning 12600.00 3785.55 5373.41 -9472.15 1214120 3841.21 6144.24 -8560.03 55.8011�1 9983'.8491 394.27 933.43 4.56 OSF 1.50 Warning 12700.00 3768.53 5452.42 -9533.44 12214.34 3841.18 6200.84 -8606.61 55.77 1194 43 304.04 930.47 4.55 OSF 1.50 Warning 12800.00 3787.52 5531.43 -959474 12284.56 3840.68 6255.83 -8650.01 55.71 393.23 930.25 4.56 OSF 1.50 Warning 12900.00 3769.35 5610.53 -9655.88 12388.27 3839.96 6321.23 -8698.99 55.95 303.74 931.21 4.56 OSF 1.50 Warning 13000.00 3773.85 568596 -9716.48 12493.54 383538 6422.98 -8775.43 5580 1194.63 400.66 827.20 4.48 OSF 1.50 Warning 1310500 3778.48 5789.41 -9777.02 12809.82 3836.40 6514.13 -884758 55.41 119241 406.37 921.17 4.41 OSF 1.50 Warning 13200.00 3783.07 5848.86 49837.57 12899.81 3831.44 6584.47 -890114 54.97 119522 • 408.52 917.54 4.38 OSF 1.50 Warning 13300.00 3787.68 5928.31 -9898.12 12838.58 3828.86 6692.19 -899078 5414 1186.72 417.10 908.33 4.27 OSF 1.50 Warning 13400.00 3792.11 0007.76 -9958.69 12942.23 3822.96 6771.15 -9057.81 5106 1181.23 42155 900.20 4.21 OSF 1.50 Warning 13500.00 379148 008723 -10019.36 13027.33 382042 6836.40 -9112.39 53.94 1176.68 42251 894.68 4.18 OSF 1.50 Warning 1360500 379182 6166.70 -1008505 1310134 3818.19 689525 -9163.44 53.82 117163 423.28 891.11 4.17 OSF 1.50 Warning 1370500 379416 6248.18 -1014575 1318592 381580 698532 -9211 23 531 42547 88573 4.18 OSF 1.50 Warning 13800.00 3794.50 8325.05 -10201.44 13274.06 3814.87 703548 -926155 53.6 425.03 888.90 4.14 OSF 1.50 Warning 13900.00 3794.85 6405.13 -10282.13 13374.86 3817.21 7110.99 -9325.18 53.72 1173.31 428.34 887.42 4.11 OSF 1.50 Warning 14000.00 3785.18 6484.43 .10323.06 13488.58 3818.63 7201.26 -9394.29 554 433.58 884.09 4.07 OSF 1.50 Warning 14100.00 3795.51 6563.58 -10384.17 1357213 3817.88 7267.78 -9444.85 53.42 1' 434.57 884.15 4.06 OSF 1.50 Warning 14200.00 379584 6642.73 -10445.28 1367752 381656 7351.98 -9508.22 53.34 1175.3 438.71 882.59 4.02 OSF 1.50 Warning 14300.00 3798.17 6721.88 .10508.39 13785.59 3816.32 7437.87 -9573.79 5131 1175.91 443.19 88513 199 OSF 1.50 Warning 14400.00 3796.49 6801.04 -10587.50 13888.93 3815.69 7519.83 -9636.74 53.28 1176.1E 447.05 877.79 3.95 OSF 1.50 Warning 1450050 3796.56 8880.00 -10628.86 14017.14 3811.81 7620.57 -9715.94 5228 117563 45137 87238 3.89 OSF 1.50 Warning 14600.00 3794.28 8957.21 -10692.38 1415951 3808.08 7757.07 -9838.70 50.39 1171.38 48759 859.32 3.76 OSF 1.50 Warning 14700.00 3790.19 7033.05 -10757.40 14321.55 3812.33 7845.70 -9920.46 50.80 1168.78 473.09 851.05 170 OSF 1.50 Warning 14800.00 3786.09 7108.88 -10822.47 14406.50 3817.38 7906.61 -9979.46 51.02 1161.05 474.83 844.17 3.67 OSF 1.50 Warning 14900.00 3781.99 7184.70 -1088754 14496.48 3821.34 797224 -10040.89 51.41 1158.98 477,02 838.63 3.64 OSF 1.50 Warning 15000.00 3778.51 7259.52 -1095179 1465816 3830.52 8087.84 -10154.22 50.02 115214 485.95 828.15 3.56 OSF 1.50 Warning 15100.00 3778.83 733114 -11023.02 14806.91 382461 8188.99 -10262.30 47.49 1147.19 49352 818.18 3.49 OSF 150 Warning 15200.00 3775.52 7402.41 -11093.67 14896.77 3816.28 824871 -10328.92 47.13 1141.37 495,99 81037 3.46 OSF 1.50 Warning 15300.00 3774.42 7473.17 -11104.32 15000.69 380952 8318.43 -10405.88 48.85 1138.32 499,88 802.74 3.41 OSF 1.50 Warning 15400.00 3773.32 7543.94 -11234.96 15110.70 3806.56 8391.57 -10487.79 48.78 1130.42 504.12 794.01 3.37 OSF 1.50 Warning 15500.00 3772.20 7814.00 -11305.71 15204.50 380658 845179 -10557.98 48.18 1124.49 50720 788,03 3.33 OSF 1.50 Warning 15600.00 3770.92 7683.31 -1137836 15311.71 3806.11 8524.81 -10638.29 44.81 1121.19 511.12 780.11 3.29 OSF 1.50 Warning 15700.00 376560 7751.48' -11451.50 15406.80 3806.36 8587.73 -10709.59 44,89 1118.52 514.32 775.31 3.27 OSF 1.50 Warning • 15800.00 3768.28 781566 .11524.64 15494.32 3806.76 8646.16 -10774.74 44.87 1116.68 516.94 771.71 3.24 OSF 1.50 Warning 15900.00 3768.96 788784 .11597.79 15575.43 3807.07 8701.16 -10834.36 45.04 519.00 769.88 3.23 OSF 1,50 Warning 16000.00 3785.84 7956,02 .11670.93 15677.83 3806.04 8771.30 -10908.95 45,06 522.76 767.83 3.21 OSF 150 Warning 16100.00 3788.03 8024.53 -11743.77 15777.26 3802.45 8839.24 -10981.46 45.39 1116,34 526.12 765.26 3.19 OSF 1.50 Warning 16200.00 378142 8093.37 -11818.25 15870.93 3798.90 8903.46 -11049.55 45.09 111579 529.37 762.55 3.16 OSF 1.50 Warning 16300.00 3770.80 8162.22 .11888.74 15972.32 3795.75 8973.15 -11123.13 44.80 111552 533.22 759.71 3.14 OSF 1.50 Warning 18400.00 3773.19 8231,07 .11961.22 16065.98 3795.92 9037.63 -11191.04 44.70 536.36 757.54 3.12 OSF 1.50 Warning 16500.00 3775.57 8299.92 .12033.71 16168.91 3799.80 9108.51 -11265.58 44.77 540.21 755.06 3.10 OSF 1.50 Warning 16503.67 3775.88 8302.45 .12038.37 16172.12 3799.92 9110.72 -11267.91 44.77 54531 75550 110 OSF 1.50 Warning 18600.00 3778.18 8388.09 .1210186 16256.39 380113 916502 -11328.67 4174 54272 754.01 3,09 OSF 1.50 Warning 16700.00 3774.72 8435.42 .12180.78 16347.14 380196 9232.48 -11393.50 43.84 1120.73 545.42 758.79 3.09 OSF 1.50 Warning 18800.00 3773.27 8502.76 -12254.70 16565.76 3804.61 9377.26 -11557.14 4199 1119.07 557.01 747.40 3.02 OSF 1.50 Warning 18900.00 3771.82 8570.09 -12328.62 16697.99 3804.19 9457.68 -11662.10 44.09 111548 56177 735.61 297 OSF 1.50 Warning 17000.00 3770.36 8637.42 -12402.54 1679503 3802.27 9515.99 -11739.84 44.07 1101.06 56538 723.82 292 OSF 1.50 Warning 17100.00 376198 870145 -12476.74 16891.35 3801.69 957119 -11816.39 4101 1092.51 56813 712.96 2.88 OSF 1.50 Warning 17200.00 3787.92 8770.11 -12552.15 16989.38 3801.53 9633.51 -11894.43 42.85 1085.90 57229 704.05 2.85 OSF 1.50 Warning 17300.00 3766.88 883576 -12627.58 1708529 380011 9694.12 -11973.85 4287 1079.48 57557 695.17 2.81 OSF 1.50 Warning 17400.00 3785.80 8901.41 -1270350 1718151 3802.44 9750.28 -12047.47 43.03 1073.14 579.31 686.61 2.78 OSF 1.50 Warning 17500.00 3784.74 8967.07 -12778.42 17255.84 3806.20 9795.78 -12105.61 43.28 106125 581.76 680.08 2.76 OSF 1.50 Warning 17600.00 3763.65 9032.73 -12853.84 17317.50 3809.27 9835.35 -12152.80 43.58 583.13 877.57 2.75 OSF 1.50 Warning 17700.00 3780.87 9098.81 -12928.84 17394.31 3812.72 9886.37 -12210.12 44.20 10 584.83 677.28 2.74 OSF 1.50 Warning • • • • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 18 of 58 Trajectory:S119-FN2(P5)Vs.SP16-FN3 Minimum ' Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aam Ct-Ct Distance Separation Clearance OSF Rule Status (6) (6) (ft) (6) (6) (8) (6) (6) (°) (6) (6) (6) 17800.00 3757.80 9164.97 -13003.76 17497.03 3816.86 9955.55 -12285.92 4458 1089.49 588.37 67391 2.73 OSF 1.50 Warning 17900.00 3754.72 9231.12 -13078.89 17885.65 3810.86 10074.39 -12432.22 45.08 106455 596.47 866.57 2.88 OSF 1.50 Warning 18000.00 3751.65 9297.28 •13153.62 17769.34 3816.04 10125.80 -12498.15 45.03 1058.41 599.60 658.34 265 OSF 1.50 Warning 18100.00 3748.81 936340 -13228.58 17844.93 3812.51 10173.44 -125513.73 44.77 105432 802.10 65260 2.63 OSF 1.50 Warning 18200.00 3749.08 9429.11 -13303.95 1793739 380328 10233.53 -12827.31 4425 105288 805.17 649.10 2.61 OSF 1.50 Warning 18300.00 375324 940469 -13379.44 18053.47 3807.17 10307.05 -12716.73 44.07 1049.93 60384 843.04 258 OSF 1.50 Warning 18400.00 3751.42 9560.27 -13454.92 18142.95 3805.88 1036390 -1278381 43.94 1047.13 613.15 838.03 2.56 OSF 1.50 Warning 18500.00 375259 962536 •13530.40 18226.52 3804.69 1041739 -12849.58 43.84 1045.73 616.02 634.72 2.55 OSF 1.50 Warning 18600.00 3753.77 9691.44 -13805.89 18334.70 3805.01 1048372 -12931.36 43.78 1045.80 62025 831.77 2.53 OSF 1.50 Warning 18700.00 375480 9757.34 -13881.09 18442.45 3805.39 1055743 •1301435 4464 4 62434 828.15 251 OSF 1.50 Warning 18800.00 375345 982408 -13755.55 18517.81 3805.89 10608.18 -13071.83 44.8 62359 62200 249 OSF 1.50 Warning 18900.00 3756.10 989382 -1383302 1859458 380825 1065736 -13128.85 44.63 1040. 628.60 62382 248 OSF 1.50 Warning 19000.00 3758.75 9957.58 -13904.49 18701.74 3807.47 1072938 -13208.22 44.68 1040.84 832.83 618.62 2.47 OSF 1.50 Warning 19100.00 3757.40 10024.30 •13978.96 18797.14 3806.13 1079341 -1327308 4455 1041.02 636.29 616.50 2.46 OSF 1.50 Warning 19188.77 375340 10081.25 -14044.42 18887.28 3804.39 10841.10 -1333347 42.59 1043.66 638.18 617.89 245 OSF 1.50 Warning 19200.00 375364 10089.72 -14054.57 18880.08 3804.06 1084388 -1333379 42.25 1044.42 83880 818.38 2.45 OSF 1.50 Warning 19300.00 3761.05 10152.57 -1413231 1897359 3801.52 10915.47 -13409.17 41.11 1051.94 64137 82384 2.48 OSF 1.50 Warning 19400.00 378158 10215.18 -14210.25 19068.99 3797.74 10980.04 -13478.55 40.76 1060.41 645.38 829.83 2.47 OSF 1.50 Warning 19500.00 3788.07 10277.79 -14288.18 1916335 379530 11049.34 -13549.10 40.50 1008.84 649.33 835.82 2.47 OSF 1.50 Warning 19800.00 3768.58 10340.40 -14366.11 19252.04 379382 11107.07 •13608.29 40.37 1078.34 65130 643.87 2.48 OSF 1.50 Warning 19700.00 3771.08 10402.78 -14444.23 19359.84 3798.14 11182.18 •13085.63 39.34 1087.90 65638 650.19 2.49 OSF 1.50 Warning 19800.00 3773.07 10482.56 -14524.38 19425.86 3796.82 11228.77 -13732.11 37.53 1102.40 656.24 664.58 2.52 OSF 1.50 Warning 19900.00 377490 10521.46 -14605.15 19531.49 379835 11304.78 -1380371 37.50 1119.49 680.71 678.69 2.54 OSF 1.50 Warning 2000300 377372 10580.36 -14685.94 19620.75 380038 11388.75 -13887.95 37.47 1138.32 86339 693.73 2.57 OSF 1.50 Warning 2010300 3778.55 10639.27 -14788.74 19768.71 3803.93 11472.50 -13973.33 37.51 1150.84 67130 702.57 2.57 OSF 1.50 Warning 20200.00 3780.23 10697.71 -14847.86 19917.02 3806.77 11573.18 -14082.18 36.24 1183.37 879.22 710.23 2.57 OSF 130 Warning 20300.00 3780.90 1075113 -14931.09 1997733 380731 1161158 -14126.97 3405 1177.98 680.14 72422 2.60 OSF 130 Warning 20400.00 378137 10807.22 -1501520 20045.46 3805.61 11600.92 -1417532 3338 1197.41 681.27 742.91 2.64 OSF 130 Warning 20500.00 3781.25 10861.30 -1509331 20147.58 3805.22 11732.70 -14248.54 33.91 1218.07 885.31 760.87 2.67 OSF 1.50 Warning 20600.00 3781.42 10915.39 -15183.42 20302.70 3810.88 11838.40 -14381.91 34.14 123830 69320 773.54 2.68 OSF 1.50 Warning 2070300 3781.60 10969.48 -15267.53 2043281 3817.05 11923.36 -1448321 34.42 1250.18 69352 784.17 2.69 OSF 1.50 Warning 20800.00 3781.39 11023.36 •15351.77 20556.92 3821.79 12002.49 -14555.73 3186 1282.54 70327 793.36 2.69 OSF 1.50 Warning 20900.00 3778.24 11075.59 -15436.98 2067211 3819.52 12074.51 -14845.55 32.75 1275.12 707.57 803.07 2.70 OSF 1.50 Warning 21000.00 3774.22 11127.31 •15522.47 20767.32 3812.13 12133.69 -14719.77 32.58 1287.85 711.28 813.34 2.72 OSF 1.50 Warning 21100.00 377319 11179.04 -15807.98 20856.76 3804.54 12189.67 -14789.10 32.38 1301.19 714.74 824.37 2.73 OSF 1.50 Warning 21200.00 3766.16 11230.76 -15693.45 20943.92 3798.60 12244.83 -1485332 32.26 1315.38 717.99 838.37 2.75 OSF 1.50 Warning 21283.50 376280 11273.05 -15784.83 21030.81 379844 12300.22 -14923.23 32.31 1327.85 721.20 846.62 2.76 OSF 1.50 Warning End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 19 of 58 Field: Nikaitchuq Well: SP23-N9 Structure: Spy Island Borehole: SP23-N3 Slot: SP23 Trajectory: SP23-N3 Client: Eel Petroleum Type: Del Survey Coordinate System: NAD27 Alaska Stele Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08921902° Grid Scale Factor: 0.999900151 Magnetic Declination: 20.734° Magnetic Declination Date: January 15,2012 Magnetic Model: BGGM 2011 Reference Point Northing Entire flevatlon Structure Une. Slot Una, 6053631.530(ftUS) 511535.620(ftUS) 53.990(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory 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/Survey 0.000 40.890 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 SP23-N3PB1/SP23-N3PB1 40.890 824.000 Act-Stns SLB_GYRO-MWD-No Globe 18.000 SP23-N3PB7/SP23-N3PB1 824.000 2892.400 Act-Stns SLB_MWD+GMAG-No Globe 16.000 SP23-N3PB1/SP23-N3PB1 2892.400 2719.040 Act-Stns SLB_INC+TREND-No Globe 12.250 SP23-N3PB1/SP23-N3PB1 2719.040 8326.380 Act-Stns SLB_MWD+GMAG-No Globe 12.250 SP23-N3PB1/SP23-N3P81 8328.380 9752.270 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP23-N3PB1/SP23-N3PB7 9752.270 13950.110 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP23-N3/SP29-N3 13950.110 14021.000 Act-Stns SLB_BLIND+TREND-No Globe 8.750 SP23-N3/SP23-N3 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference ND Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North ASm CtCt Distance Separation Clearance OSF Rule Status (0) (5) (ft) (ft) (ft) (ft) (8) (8) (°) (8) (fl) (fl) All local minima indicated. Results filtered:Depth 11700.00 6<=MD<=21284.00 ft Results filtered Ct-Ct separation<=3000.008 Results highlighted:Ct-Ct separation<=2640.00 ft 11700.00 374195 4872.01 -8009.71 14021.00 3806.15 452723 -7543.71 57.10 1375.11 267.37 1198.53 7.74 OSF 1.50 Pass 11800.00 3749.93 4747.30 -8975.16 14021.00 3806.15 4527.23 -7543.71 57.10 1449.36 251.18 1281.57 8.88 OSF 1.50 Pass • 11900.00 3756.90 4822.59 -9040.60 14021.00 3808.15 4527.23 -7543.71 57.10 1526,55 238.49 1388.56 9.72 OSF 1.50 Pass • 12000.00 3702.17 4898.90 -9104.98 14021.00 3806.15 4527.23 -7543.71 55.73 1605.51 22103 1456.56 10.84 OSF 1.50 Pass 12100.00 3783.03 4977.73 -9166.50 14021.00 3806.15 4527.23 -7543.71 54.92 1884.71 210.05 1544.35 12.08 OSF 1.50 Pass 12200.00 3783.11 5058.98 -9227.48 14021.00 3808.15 4527.23 -7543.71 54.92 1785.87 198.42 1633.06 13.41 OSF 1.50 Pass 12300.00 3763.18 5136.24 -9288.46 14021.00 3806.15 4527.23 -7543.71 5492 1848.49 188.04 1722.80 1412 OSF 1.50 Pass 12400.00 3783.58 5215.40 -9349.56 14021.00 3806.15 4527.23 -7543.71 55.55 1933.00 178.80 1813.47 16.30 OSF 1.50 Pass 12500.00 3784.56 5294.41 -9410.85 14021.00 3808.15 4527.23 -7543.71 55.55 2019.04 17087 1904.93 17.84 OSF 1.50 Pass 12800.00 3765.55 5373.41 -9472.15 14021.00 3808.15 4527.23 -7543.71 55.55 2108.31 16349 1996.99 19.43 OSF 1.50 Pass 12700.00 3766.53 5452.42 -953144 14021.00 3806.15 4527.23 -754171 55.55 2104.87 157.17 2089.57 21.07 OSF 1.50 Pass 12800.00 3767.52 5531.43 -959474 14021.00 3806.15 4527.23 -7543.71 55.55 228199 151.62 2182.59 22.73 OSF 1.50 Pass 12900.00 3789.35 5810.53 -985518 14021.00 3806.15 4527.23 -7543.71 59.00 237406 148.72 2275.92 2443 OSF 1.50 Pass 13000.00 377185 5689.96 -9716.46 14021.00 3808.15 4527.23 -754171 60.24 2484.52 14218 236928 28.14 OSF 1.50 Pass 13100.00 3778.46 5769.41 -9777.02 14021.00 3806.15 4527.23 -754171 80.24 2555.67 138.64 2482.92 27.84 OSF 1.50 Pass 13200.00 3783.07 5848.86 -9837.57 14021.00 3806.15 4527.23 -7543.71 60.24 2647.48 135.42 2558.85 29.53 OSF 1.50 Pass 13300.00 3787.88 5928.31 -9898.12 14021.00 3806.15 4527.23 -7543.71 80.24 2739.82 132.88 21151.18 31.20 OSF 1.50 Pees 13400.00 3792.11 6007.78 -9958.69 14021.00 3806.15 4527.23 -7543.71 58.38 2832.72 130.30 2745.52 32.85 OSF 1.50 Pass 13500.00 3793.48 8087.23 -10019.38 14021.00 3806.15 4527.23 -7543.71 53.87 2928.19 128.31 2840.32 34.48 OSF 1.60 Pass End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 20 of 58 Field: Nikaitchuq Well: S113-FN4 Structure: Spy Island Borehole: SI13-FN4 Slot: SP13 Trajectory: SI13-FN4 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08988733° Grid Scale Factor: 0.999900153 Magnetic Declination: 20.238° Magnetic Declination Data: November 06,2012 Magnetic Model: BOOM 2012 Reference Point: Nonhina Emilia lliyjttgs $tractor.Unc, Slot Unc, 8053848.260(WS) 511622.000(ftUS) 54.010(ft)MSL 0.000(8)(1 sigma) 0.000(6)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Sury no Pro Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.910 Act-Stns SLB_GVRO-MWD-Depth Only-No Global 18.000 SI13-FN4/S113-FN4 40.910 611.040 Act-Stns SLB_GVRO-MWD-No Global 16.000 SI13-FN4/SI13-FN4 611.040 20908.810 Act-Stop SLB_MWD•GMAG-No Global 18.000 5113-FN4/SI13-FN4 20908.810 20974.000 Act-Stns SLB UNKNOWN-No Global 18.000 5113-FN4/5113-FN4 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aam Ct-Ct Distance Separation Clearance OSF Rule Status (f) (6) (0) (ft) (8) (8) (6) (8) • (°) (6) (ft) (ft) All local minima indicated. Results filtered:Depth 11700.00 8 c=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Ct-Ct separation<=2840.00 R 11700.00 3742.95 4672.01 -8909.71 10890.48 3810.08 6123.42 -7020.75 50.85 238312 355.74 2145.64 10.07 OSF 1.50 Pass 11800.00 3749.93 4747.30 -8975.18 10957.21 3814.76 617644 -708103 50.85 2389.67 35630 2151.54 1007 OSF 1.50 Pass 11900.00 3756.90 4822.59 -904080 11031.11 3819.91 623506 -710492 50.85 2397.42 358.08 2158.37 1007 OSF 1.50 Pass 12000.00 3782.17 4898.90 -910408 11093.08 3824.27 6285.81 -7141.09 5263 2405.05 358.44 216576 10.09 OSF 1.50 Pass • 12100.00 3783.03 4977.73 -9166.50 11169.54 3829.42 834806 -7184.74 54.01 2410.47 359.85 2170.37 1008 OSF 1.50 Pass • 12200.00 3763.11 5056.98 -0227.48 11253.62 3833.64 6417.43 -723251 54.10 2415.72 38156 2174,35 1005 OSF 1.50 Pass 12300.00 3763.18 5136.24 -9288.48 11324.20 3838.61 6475.77 -7271.90 54.21 2422.10 362.39 2180.17 10.05 OSF 1.50 Pass 12400.00 376158 521540 -9340.58 1142032 3845.10 8583.08 -7330.07 54.16 2429.23 365.78 2185.05 9.98 OSF 1.50 Pass 1250000 3784.56 529441 -9410.85 11646.58 3854.12 6738.82 -7457.35 5432 2431.15 377.55 2179.12 9.68 OSF 1.50 Pass 12600.00 376505 537341 -9472.15 11726.95 385250 8803.71 -7504.74 54.26 2433.93 379.35 2180.70 905 OSF 1.50 Pass 12700.00 3786.53 5452.42 -9533.44 11888.17 3851.29 693209 -7601,17 54.19 2435.70 386.68 2177.59 9.47 OSF 1,50 Pass 12800.00 3787.52 5531,43 -9594.74 1199042 3851.57 7014.11 -766329 54.17 2438.37 390.04 2176.01 9.39 OSF 1.50 Pass 12900.00 3789.35 5610.53 -9655.88 12078.18 3852.02 7083.67 -7716.76 54.48 2436.62 392.32 2174.75 9.34 OSF 1.50 Pass 13000.00 3773.85 5689.98 -8716.48 12156.81 3851.25 7148.83 -7783.88 54.53 2437.30 393.91 2174.37 9.30 OSF 1.50 Pass 13100.00 377848 5769.41 -9777.02 12258.61 3850.51 7228.04 -7825.01 54.40 2437.86 397.35 2172.63 9.22 OSF 1.50 Pass 13200.00 3783.07 5848.86 -9837.57 12333.30 3849.40 7288.15 -7889.33 54.30 243925 39800 2172.99 019 OSF 1.50 Pass 13300.00 3787.68 592831 -9898.12 12421.61 3848.25 7359.54 -7921.30 5417 2441.30 401.33 2173.41 014 OSF 1.50 Pass 13400.00 3792.11 8007.78 -9958.69 12492.41 3847.53 7417.14 -7982.46 5403 244425 402.48 2175.80 9.13 OSF 1.50 Pass 13500.00 3793.48 6087.23 -10019.36 12580.79 3846.95 748049 -801320 5309 2448.24 404.81 2178.04 9.09 OSF 1.50 Pass 1380000 3793.82 816830 -10080.05 12796.32 3850.64 7684.17 -813035 53.96 2451.93 416.00 217427 8.86 OSF 1.50 Pass 13700.00 379416 8248.18 -10140.75 13029.65 3852.22 7845.21 -8288.47 53.98 2449.20 427.54 2103.85 8.61 OSF 1.50 Pass 13800.00 3794.50 6325.65 -10201.44 13155.26 3850.60 7930.68 -8369.23 5094 244239 432.37 2153.82 8.49 OSF 1.50 Pass 13900.00 3794.85 640013 -10262.13 13218.66 384702 7987.54 -8410.71 53.87 2438.11 433.66 2148.68 8.44 OSF 1.50 Pass 14000.00 3795.18 6484.43 •10323.06 13298.04 3843.57 804020 -8481.74 5348 2431.50 435.74 2140.68 8.30 OSF 1.50 Pass 14100.00 3795.51 658308 -10384.17 1345042 383901 8170.78 -856605 5308 2428.68 442.55 2131.32 8.24 OSF 100 Pass 14200.00 3795.84 664273 -10445.28 13642.58 3849.82 8305.40 -869029 53.59 2418.12 450.24 211704 8.07 OSF 1.50 Pass 1430000 3798.17 8721.88 -10506.39 13740.13 385407 8376.10 -8757.38 53.69 2408.07 453.54 2105.39 7.98 OSF 100 Pass 1440000 3798.40 8801.04 -1058700 1382623 385725 8438.63 -881648 53.77 2398.22 456.22 209075 7.00 OSF 100 Pass 14500.00 3796.56 6880.00 -10828.86 13885.80 385804 8482.30 -885608 5303 2389.94 45751 2084.80 7.85 OSF 1.50 Pass 14600.00 3794.28 6957.21 -10892.36 1400932 3859.16 8573.67 -8640.09 51.26 2384.87 462.19 207641 7.75 OSF 1.50 Pass 14700.00 3790.19 7033.05 -10757.40 14054.20 3858.87 8807.01 -8970.13 51.05 238202 482.61 207339 7.74 OSF 1.50 Pass 14800.00 3788.09 7108.88 -10822.47 14129.44 385607 8664.09 -9019.10 51.07 2382.41 464.58 2072.36 7,71 OSF 1,50 Pass 14900.00 3781.99 7184.70 -10887.54 1425345 3852.37 8757.28 -8100.79 51.09 2381.26 469.34 2068.04 7.02 OSF 1.50 Pass 15000.00 3778.51 7259.52 -10953.79 14729.05 3834.33 908201 -9445.59 48.91 2306.97 488.13 2041.22 7.29 OSF 1.50 Pass 15100.00 377803 7331.64 -11023.02 14810.73 3835.29 9135.18 -9508.35 48.53 2355.93 490.80 2028.34 7.21 OSF 1.50 Pass 15200.00 3775.52 7402.41 .11093.67 14888.27 3834.59 9185.32 -958750 48.54 2347.85 493.81 2018.11 7.14 OSF 1.50 Pass 15300.00 377442 747117 .1116432 1498241 383073 9233.83 -9623.55 4804 2340.38 49808 2009.01 7.08 OSF 1.50 Pass 15400.00 3773.32 7543.94 -11234.08 15034.22 3832.72 9281.45 -967729 46.54 2334.28 49920 2001.15 7.02 OSF 100 Pass 15500.00 3772.20 7614.60 -11305.71 1510322 3831.83 9327.87 -972034 45.91 329.57 501.62 1994.83 6.98 OSF 1.50 Pass 15557.53 3771.48 7654.35 -11347.29 15144.87 3831.37 9356.06 -9758.72 44.48 50297 1993.08 6.96 OSF 1.50 Pass 1560000 3770.92 7683.31 -11378.38 15176.08 383096 9377.54 -9781.81 44.46 504.02 1992.53 8.94 OSF 1.50 Pass 15700.00 3789.60 7751.48 -11451.50 15252.95 3829.69 943000 -983725 44.45 232098 506.65 1991.89 801 OSF 1.50 Pass 15800.00 376028 7819.66 -11524.84 1537702 382805 9517.00 .9927.10 44.45 2331.88 511.19 1900.55 8.85 OSF 1.50 Pass 15900.00 3766.96 788704 -11597.79 1548211 382942 9588.34 -10003.43 4452 2331.86 514.88 198828 080 OSF 1.50 Pass • • 16000.00 376504 795602 -11870.93 1561642 383465 9678.40 -10102.91 4469 3 0 5 510.62 1983.51 6.74 OSF 1.50 Pass 16097.45 3765.97 8022.77 -11741.92 15858.94 3835.94 9707.38 -10134.02 4525. 520.75 1982.32 6.72 OSF 1.50 Pass 18100.00 3786.03 802453 -11743.77 15880.06 3835.96 9708.13 .10134.83 4525 2329.8 520.78 1982.31 6.72 OSF 1.50 Pass 18200.00 376042 8093.37 -11818.25 15722.82 3837.00 9751.95 -1017935 4024 2331.03 522.86 1982.13 070 OSF 1.50 Pass 18300.00 3770.80 8162.22 -11888.74 1587105 3841.97 9855.92 -10286.30 45.27 2332.03 52842 1980.02 6.63 OSF 1.50 Pass 18400.00 3773.19 8231.07 -11961.22 15933.99 3845.33 9898.86 -10331.19 45.32 2333.17 53049 1979.19 6.61 OSF 1.50 Pass 18500.00 3775.57 8299.92 -12033.71 16022.10 3851.51 9960.47 -10393.87 45.42 2335.01 533.53 1978.99 6.57 OSF 1.50 Pass 18800.00 3778.18 8368.09 -12106.86 16214.60 3862.13 10092.85 -10533.40 4449 2336.02 540.60 197523 6.49 OSF 050 Pass 16700.00 3774.72 8435.42 -12180.78 16334.05 3859.53 1017264 -10821.95 44.42 2335.81 545.00 197105 6.44 OSF 1.50 Pass 18800.00 3773.27 8502.76 •12254,70 16578.82 3844.78 10330.47 -10808.34 44.15 2331.88 55248 1963.22 8.34 OSF 1.50 Pass 18900.00 3771.82 8570.09 -12328.02 16726.01 3843.19 10420.08 -10925.08 44.17 2323.25 556.90 1951138 8.27 OSF 1.50 Pass 17000.00 3770.38 883742 -12402.54 16790.99 3842.85 10459.75 -10976.55 44.19 2315.08 559.99 1941 42 021 OSF 1.50 Pass 17100.00 378088 870445 -12478.74 1690907 384250 10532.54 -11070.18 43.12 2307.77 563.89 193351 8.15 OSF 1.50 Pass 17200.00 3767.92 877011 -12552.15 17008.89 3843.54 1059292 -11149.00 42.96 2301.56 587.41 192207 6.08 OSF 1.50 Pass 17300.00 3766.86 8835.76 -12627.58 17080.14 3842.76 10638.75 -11205.17 42.96 2296.21 570.61 191547 6.04 OSF 1.50 Pass 17400.00 3785.80 8901.41 -12703.00 17145.38 3840.52 1067701 -11255.99 42.93 2292.22 573.61 1909.40 6.00 OSF 1.50 Pass 17500.00 3784.74 8967.07 -12778.42 1720020 3837.81 1071518 -11301.96 42.88 578.34 1905.27 5.97 OSF 1.50 Pass 17588.74 3783.80 9025.33 -12845.35 17254.89 3835.87 10748.18 -11330.58 42.84 578.49 1903.29 5.94 OSF 1.50 Pass 17600.00 3763.65 8032.73 -12853.84 17261.20 3835.88 1075234 -1134432 42 93 1 57815 1903.15 5.94 OSF 1.50 Pass • • • • • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 24 of 58 Trajectory:SI1 9-FN2(P5)Ve.S113-FN4 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aam CICI Distance Separation Clearance OSF Rule Status (5) (6) (ft) (ft) (ft) (ft) (ft) (ft) C) (ft) (ft) (ft) 17700.00 376587 9098.81 -1292584 17325.25 3833.44 1079501 -1139203 43.24 2290 01 581.13 1902.26 5.92 OSF 1.50 Pass 17800.00 3757.80 81644.97 -13003.76 17384.73 3831.19 1083532 -11435.72 43.22 2282.21 583.24 1903.05 5.90 OSF 1.50 Pass 17900.00 375412 9231.12 -13078.69 1743531 3828.97 10872.40 -1147433 4521 2296.36 58492 190659 5.90 OSF 150 Pass 18000.00 3751.65 9297.28 -13153.62 17711.92 3823.95 11056.91 -11676.08 4329 2298.84 59456 1902.14 581 OSF 1.50 Pass 18100.00 3748.81 9383.40 -13228.58 1785274 3822.81 1114562 -1178462 43.17 2295.72 59507 189651 5.76 OSF 1.50 Pass 18200 00 3749.06 9429.11 -1330595 1795502 3822.26 11209.30 -11862.91 42.79 2291.51 602.42 1889.57 5.71 OSF 1.50 Pass 18300.00 3750.24 9494.69 -1337544 18009.95 3821.85 1124554 -11906.80 4278 2288.94 605.19 1885.15 5.68 OSF 1.50 Pass 18400.00 3751.42 9560.27 -13454.92 1809594 3820.39 11299.87 -11970.83 4271 2287.68 608.53 1881.66 5.65 OSF 1.50 Pass 18500.00 3752.59 9825.88 -13530.40 18195.87 3818.64 1136594 -12048.18 4263 2::.75 612.34 1878.20 5.61 OSF 1.50 Pass 18600.00 375577 969144 -13805.89 18259.65 3817.77 11407.80 -12096.55 42.5'i00L!40. 61553 1876.15 5.58 OSF 1.50 Pass 1870500 375480 975754 -13881.09 18337.35 3817.25 11459.53 -12154.52 43.43 2287.30 81755 1875.01 5.58 OSF 1.50 Pass 1880500 3755.45 9824.08 -13755.55 1843333 3816.82 1152356 -12226.20 4141 2287.42 82154 1872.73 553 OSF 1.50 Pass 18900.00 3756.10 989052 -1383502 18520.86 381855 1158230 -1229590 43.42 2287.76 62419 187590 5.50 OSF 1.50 Pass 1900500 3756.75 9957.56 -1390449 18778.81 3828.68 11750.31 -1248588 43.65 2287.26 63247 1865.28 5.43 OSF 1.50 Pass 19100.00 375740 10024.30 -13978.96 1882247 383031 1177756 -12519.94 43.70 8. 635.08 1858.63 5.40 OSF 150 Pass 19186.77 375540 10081.25 -1404442 18869.95 383220 1180560 -12556.10 41.8 637.21 1856.15 5.38 OSF 1.50 Pass 19200.00 3758.64 1008572 -1405457 18882.43 3832.51 11816.74 -12565.56 41.57 81.9 637.65 1856.08 5.37 OSF 1.50 Pass 19300.00 3781.05 1015257 -1413251 18969.93 3833.86 1187594 -12631.76 40.66 2284.75 640.91 1857.15 5.35 OSF 1.50 Pass 19400.00 3763.58 10215,18 -1421525 1904570 3833.78 11922.74 -12687.09 40.61 2289.26 643.02 1859.85 5.34 OSF 1.50 Pass 19500.00 3786.07 10277.79 -14288.18 18123.82 3833.44 11976.34 -12746.64 40.55 2294,76 647.03 186359 5.33 OSF 1.50 Pass 19600.00 3788.58 1034540 -14366.11 19268.22 3833.36 12072.86 -1285402 40.45 2300.44 652.22 1865.30 550 OSF 1.50 Pass 19700.00 3771.06 10402.78 -1444423 18374.34 3832.83 12141.89 -12934.62 39.47 230315 656.19 1865.95 5.27 OSF 1.50 Pass 1980050 3773.07 10482.58 -1452456 19443.66 3830.96 12187.77 -12986.54 37.64 2311.83 658.94 1872.21 5.27 OSF 1.50 Pass 19900.00 3774.90 10521.48 -14805.15 18536.81 3829.73 12249.87 -13055.70 37.56 2321,89 662.49 1879.91 526 OSF 1.50 Pass 2000050 3776.72 10580.36 -14685.84 19861.81 3831.35 12332.87 -1314541 37.54 2331,35 667.04 1886.33 5.25 OSF 1.50 Pass 20100.00 3778.55 10639.27 -14786.74 19750.02 3833.39 12390.99 -1321533 37.54 2340.34 670.46 1893.03 524 OSF 1.50 Paas 20200.00 3780.23 10897.71 -14847.86 19821.92 3834.08 12438.93 -13269.33 36.26 235585 673,30 1901.66 5.24 OSF 1.50 Pass 20300.00 3780.90 10753.13 -14931.09 19897.40 3833.64 12480.01 -13324.88 34.08 2388.31 878.12 1015.23 5.26 OSF 1.50 Pass 20400.00 3781.07 10807.22 -15015.20 20020.47 3832.79 12579.09 -13422.38 34.02 2383.12 881.05 1928.76 5.25 OSF 1.50 Pass 20500.00 3781.25 10861.30 -15099.31 20158.56 382533 12883.44 -13517.38 33.92 2398.43 885.71 1940.96 5.25 OSF 1.50 Pass 20800.00 3781.42 10915.39 -15183.42 20305.84 382408 12761.27 -13630.01 33.78 2412.91 890.91 1951.98 524 OSF 1.50 Pass 20700.00 3781.80 10969.48 -15287.53 2049524 3822.49 12878.83 -13775.90 33.72 2423.27 686.46 1958.64 522 OSF 1.50 Pass 20800.00 3781.39 11023.36 -15351.77 2059257 3824.69 12939.63 -1385416 33.08 2432.45 70022 1965.31 5.22 OSF 1.50 Pass • 20900.00 3778.24 11075.59 -15438.98 2085592 382552 1298584 -13906.41 31.99 2444.36 703.36 1975.12 5.22 OSF 1.50 Pass 21000.00 3774.22 11127.31 -15522.47 20714.19 3826.25 13015.82 -1394519 32.05 2458.54 706.10 1987.48 5.23 OSF 1.50' Pass 21100.00 377519 11179.04 -1560758 20827.73 3827.49 13088.28 -1403559 32.18 '2473.40 710.07 1999.69 5.23 OSF 1.50 Pass 21200.00 3786.16 11230.78 -15893.45 20937.82 3829.27 13157.84 -14121.85 32.32 2487.60 713.88 2011.48 5.23 OSF 1.50 Pass 21283.50 378250 11273.95 -15764.83 20974.00 3829.83 13180.82 -14149.85 32.36 249576 71533 2022.54 5.25 OSF 1.50 Pass End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 25 of 58 Field: Nikaitchuq Well: 5126-N2 Structure: Spy Island Borehole: 5125-N2 Slot: SP25 TreJectory: S125-N2 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08898328° Grid Scale Factor: 0.09900015 Magnetic Declination: 20.397° Magnetic Declination Date: July 25,2012 Magnetic Model: BGGM 2012 Reference Point: lit hIDa gating Emilio Atrueture Une, 1119.1 2119, 6053625.540(ftUS) 511505.150(ftUS) 54.100(ft)MSL 0.000(8)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Modell ISCWSAO 3-D 96.000%Congdonce 2.7955 sigma Sury e Proc: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.000 Act-Stns SLS_NSG+SSHOT-Depth Only-No Global 16.000 S125-N2/S125-N2 41.000 741.000 Act-Stns SLB_NSG+SSHOT-No Global 16.000 5125-N2/S125-N2 741.000 2864.450 ActSins SLB_MWD+GMAG-No Global 16.000 5125-N2/5125-N2 2884.450 7884.910 Act-Stns SLB_MWD+GMAG-No Global 12.250 S125-N2/0125-82 7884.910 13819.210 Act-Stns SLB_MWD+GMAG-No Global 8.750 5125-N2/SI25-N2 13819.210 13882.000 Act-Stns SLB_BLIND+TREND-No Global 8.750 5125-N2/5125-N2 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aam Ct-Ct Diatence Separation Clearance OSF Rule Status (ft) (0) (ft) (8) (8) (0) (ft) (ft) (°) (9) (ft) (ft) All local minima indicated. Results filtered:Depth 11700.00 8<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted Ct-Ct separation<=2640.00 ft 11700.00 3742.95 4672.01 -8909.71 1388100 374187 358718 -841105 214.74 119170 233.40 1036.76 7.89 OSF 1.50 Pass 11800.00 3749.93 4747.30 -8975.18 1388100 374167 358716 -841105 214.74 128819 22657 1137.32 156 OSF 1.50 Pass 11900.00 3756.90 4822.59 -9040.60 13882.00 3748.67 358716 -8413.05 214.74 138526 220.66 1237.82 9.45 OSF 150 Pass 12000.00 3762.17 4898.90 -9104.98 13882.00 374167 358756 -841105 22541 1482.67 21550 1338.47 1535 OSF 150 Pass 12100.00 3763.03 4977.73 -9166.50 13882.00 3748.67 3587.86 -8413.05 235.44 1581.20 21211 1439.33 11.22 OSF 1.50 Pass 12200.00 376111 5056.98 -9227.48 1388250 374167 358718 -841105 235.44 1680.00 209.38 1540.09 12.09 OSF 1.50 Pass 12300.00 3763.18 5136.24 -9288.48 13882.00 3748.67 358756 -841105 235.44 1778.95 20637 1640.77 1196 OSF 1.50 Pass 12400.00 3783.58 5215.40 -9349.56 13882.00 3748.67 3587.66 -8413.05 231.43 1877.98• 204.40 1741.38 1184 OSF 1.50 Pass 12500.00 3764.56 529441 -9410.85 13882.00 3748.87 3587.66 -8413.05 231.43 1977.08 20215 1841.92 14.73 OSF 150 Pass 12000.00 3765.55 5373.41 -9472.15 13882.00 3748.87 3587.66 -8413.05 231.43 2076.27 200.29 1942.41 15.82 OSF 1.50 Pass 12700.00 3766.53 5452.42 -9533.44 13882.00 3748.67 3587.66 -8413.05 231.43 2175.53 198.52 2042.85 18.51 OSF 1.50 Pass 12800.00 3767.52 5531.43 -9594.74 1388250 3748.67 3587.66 -8413.05 231.43 2274.85 196.91 2143.25 17.41 OSF 1.50 Pass 12900.00 3769.35 5610.53 -965588 13882.00 3748.67 ' 358756 -8413.05 217.44 2374.25 195.44 2243.63 18.31 OSF 150 Pass 13000.00 3773.85 5689.96 -9716.46 13882.00 3748.67 3587.88 -8413.05 212.30 2473.70 194.15 2343.94 19.20 OSF 1.50 Pass 13100.00 3778.48 5769.41 -9777.02 13882.00 374167 358716 -841105 212.30 257119 192.98 2444.21 20.10 OSF 1.50 - Pass 13200.00 3783.07 5848.86 -9837.57 13882.00 3748.67 3587.68 -8413.05 212.30 2672.72 191.90 2544.46 20.99 OSF 1.50 Pass 1330500 3787.68 5928.31 -9898.12 13882.00 3748.67 3587.86 -8413.05 212.30 2772.29 19090 2644.70 21.89 OSF 1.50 Pass 13400.00 3702.11 6007.76 -9958.69 13882.00 3748.67 3587.68 -8413.05 220.35 2871.89 189.97 2744.91 22.79 OSF 1.50 Pass 13500.00 3793.48 6087.23 -10019.36 13882.00 3748.67 3587.66 -8413.05 240.83 2971.55 180.11 2845.14 23.69 OSF 1.50 Pass End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 26 of 58 • Field: Nikeitcheq Well: SP27-N7 Structure: Spy Island Borehole: SP27-N7 Slot: SP27 Trajectory: SP27-N7 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Pierre,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08886174° Odd Scale Factor: 0.99990015 Magnetic Declination: 20.802° Magnetic Declination Date: December 01.2011 Magnetic Model: BGGM 2011 Reference Point: ti9Lthitg Lading Elevation Structure Unc, SlatU11e- 6053622 430(ftUS) 511489.440(ftUS) 53.870(8)MSL 0.000(h)(1 sigma) 0.000(fl)(1 sigma) Traieetorn Error Modgjy ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Suv 'g r Prop: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Nob Diameter(In) Borehole/Survey 0.000 40.770 Act-Stns SLB_NSG*SSHOT-Depth Only-No Global 18.000 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 8215.980 Act-Stns SLB_MWD*GMAG-No Global 12.250 SP27-N1/SP27-N1 8215.980 14094410 Act-Stns SLB_MWD*GMAG-No Global 8.750 SP27-N1/SP27-N1 14094.410 14155.000 Act-Stns SLB BLIND 2-NO Global 8.750 SP27-N1/SP27-N1 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Arim Cl-Ct Distance Separation Clearance OSF Rule Status (h) (q) (ft) (ft) (ft) (ft) (ft) (ft) (°) (5) (ft) (ft) All local minima indicated. Results filtered:Depth 11700.00 8<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Cl-Ct separation<=2640.00 8 11700.00 3742.95 4672.01 -8909.71 14155.00 3742.81 2817.89 -9309.40 225.89 2092.84 388.44 1846.88 8.54 OSF 1.50 Pass 1180100 374193 4747.30 -8975.16 14155.00 3742.81 2817.69 -9308.40 225.89 2155.69 366.03 1911.34 8.85 OSF 1.50 Pass 11900.00 3756.90 4822.59 -9040.60 14155.00 3742.81 281719 -9309.40 225.89 2221.26 36312 1978.72 9.19 OSF 1.50 Pass 12000.00 3762.17 489810 -9104.98 14155.00 3742.81 2617.69 -9309.40 230.04 2280.43 380.38 2049.85 156 OSF 1.50 Pass 12100.00 378103 4977.73 -9166.50 14156.00 3742.81 2617.69 -930140 233.12 2364.45 357.37 2125.87 9.95 OSF 1.50 Pass 12200.00 3783.11 505618 -9227.48 14155.00 3742.81 2617.69 -930140 233.12 2440.75 354.39 2204.16 10.36 OSF 1.50 Pass 12300.00 376118 5136.24 -9288.48 14155.00 3742.81 261719 -930140 233.12 2518.72 351.38 228114 10.78 OSF 1.50 Pass 12400.00 3763.58 5215.40 -934156 1415510 3742.81 2617.69 -930940 232.21 2598.10 348.29 2365.58 11.22 OSF 1.50 Pass 12500.00 3764.58 5294.41 -9410.85 14155.00 3742.81 2617.69 -9309.40 232.21 2678.73 345.26 2448.23 11.67 OSF 1.50 Pass 12600.00 3765.55 5373.41 -9472.15 14155.00 3742.81 2617.69 -9309.40 232.21 2760.62 342.26 2532.12 12.13 OSF 1.50 Pass 12700.00 3766.53 5452.42 -9533.44 14155.00 3742.81 2817.69 -9309.40 232.21 2843.67 339.30 2617.14 12.80 OSF 1.50 Pass 12800.00 3767.52 5531.43 -9594.74 14155.00 3742.81 2617.69 -9309.40 232.21 2927.78 338.39 2703.19 13.09 OSF 1.50 Pass End of results • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S)19-FN2\SI19-FN2\S)19-FN2(P5) 3/11/2013 12:01 PM Page 27 of 58 Field: Nikeifchuq Well: SP3O-W7 Structure: Spy Island Borehole: SP3O-W8 Slot: SP30 Trajectory: SP30-W7 Client: Eni Petroleum Type: Oaf Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08867938° Grid Scale Factor: 0.999900149 Magnetic Declination: 20.271° Magnetic Declination Date: October 15.2012 Magnetic Model: BGGM 2012 Reference Point: JYgillllDg flan Elevation Structure Unc. Slot Unc, 6053617.960(ftUS) 511465.870(NUS) 53.920(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model;ISCWSAO 3-15 95.000%Confidence 2.7955 sigma Surveying Prog; Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 40.820 Act-Stns SLB_GVRO-MWD-Depth Only-No Globe 16.000 SP30-WIPB1/SP3O-W1PB1 40.820 956.580 Act-Stns SLB_GYRO-MWD-No Globe 16.000 SP30-WIPB1/SP30-W1PB1 956.580 2599.700 Act-Stns SLBMWD*GMAG-No Globs 16.000 SP3O-WIPBI/SP3O-WIPBI 2599.700 9465.920 Act-Stns SLB_MWD*GMAG-No Globs 12.250 5P30-W1PBI/SP3O-WIPBI 9485.920 12948.130 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP30-WIPB1/SP3O-WIPB1 12948.130 17879.520 Act-Sine SLB_MWD+GMAG-No Globe 8.750 SP3O-W1/SP30-W1 17879.520 17945.000 Act-Sloe SLB BLIND+TREND-No Globe 8.750 SP3O-W1 ISP3O-W1 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Add Ct-Ct Distance Separation Clearance OSF Rule Status (ft) l8) (ft) (N) (8) (ft) (5) (8) (°) (N) (N) (ft) All local minima indicated. Results filtered:Depth 11700.00 ft<=MD<=21284.00 ft Results filtered:Ct-Ct separation<=3000.00 6 Results highlighted:Ct-Ct separation<=2640.00 ft 11700.00 3742.95 467211 -8909.71 16772.00 3643.84 317448 -10933.43 231.57 2519.51 356.74 2281.36 10.62 OSF 1.50 Pass 11800.00 3749.93 4747.30 -8975.16 17004.30 3630.83 336469 -11066.03 232.26 250945 351.98 227451 10.72 OSF 1.50 Pass 11900.00 3758.90 4822.59 -9040.80 17062.95 3627.80 341139 -11098.56 232.44 2497.53 357.41 225813 10.51 OSF 1.50 Pass 12000.00 378117 489810 -910498 17103.01 362574 3446.19 -11121.46 234.28 2489.01 363.83 2246.13 10.29 OSF 1.50 Pass 12100.00 3763.03 4977.73 -9168.50 17143.43 3623.73 3478.72 -11145.36 235.64 2486.43 370.04 2239.41 10.10 OSF 1.50 Pass 12200.00 3783.11 5056.98 -9227.48 17283.63 3618.78 3591.10 -11229.04 235.75 2485.14 370.89 2237.55 10.07 OSF 1.50 Pass 12300.00 3763.18 5138.24 -9288.46 17390.83 3618.82 3877.88 -11291.93 235.81 248216 373.60 223217 0.99 OSF 1.50 Pass 12400.00 3783.58 5215.40 -9349.58 17492.22 3617.67 375926 -11351.73 235.59 247170 376.59 2228.31 9.90 OSF 1.50 Pass 12500.00 3764.58 5294.41 -9410.85 17588.87 3819.84 3837.85 -11408.82 235.56 2476.61 379.98 2222.96 080 OSF 1.50 Pass 12600.00 3765.55 5373.41 -9472.15 17702.53 3620.06 3929.78 -11475.47 235.59 2473.57 382.41 2218.30 9.72 OSF 1.50 Pass 12700.00 3780.53 5452.42 -9533.44 17785.58 382120 3998.98 -1152425 235.58 2470.38 38618 2212.33 8161 OSF 1.50 Pass 12800.00 3787.52 5531.43 -9594.74 17903.13 3624.58 4091.92 -11593.48 235.54 2487.30 39195 220111 9.30 OSF 1.50 Pass 12900.00 3769.35 5610.53 -0655.88 1794100 3625.08 412185 -11617.99 235 8 423.87 2181.93 8.74 OSF 1.50 Pass 13000.00 3773.85 5689.96 -971646 17945.00 3625.88 4125.85 -11617.99 236.03 43113 2178.94 8.60 OSF 1.50 Pass 13100.00 3778.48 576141 -977712 1794510 3625.88 412585 -11817.99 236.03 247212 437.95 2180.32 8.48 OSF 1.50 Pass 13200.00 3783.07 5848.86 -9837.57 17945.00 3625.68 4125.85 -11617.99 236.03 2482.63 444.17 2186.19 8.40 OSF 1.50 Pass 13300.00 3787.68 5928.31 -9898.12 17945.00 3625.68 4125.85 -11617.99 234103 2496.61 449.68 2196.49 8.34 OSF 1.50 Pass 13400.00 3792.11 6007.76 -995819 17945.00 3825.68 4125.85 -11617.99 236.15 251447 454.47 2211.17 8.31 OSF 1.50 Pass 13468.69 3793.37 608135 -10000.35 17945.00 3625.88 4125.85 -111117.99 236.49 2528.82 457.37 2223.57 131 OSF 1.50 Pass 13500.00 3793.48 608723 -10019.36 1794510 362168 4125.85 -11817.99 236 49 253511 458.59 2229.85 8.31 OSF 1.50 Pass 13600.00 379182 6166.70 -10080.05 17545.00 3625.88 4125.85 -11617.99 236.49 2560.98 482.01 2252.65 8.33 OSF 1.50 Pass 13700.00 379416 6246.18 -10140.75 17945.00 3825.68 4125.85 -11617.99 236.49 2589.68 464.76 2279.51 8.37 OSF 1.50 Pass 13800.00 379450 6325.65 -10201.44 17945.00 3625.68 4125.85 -11617.99 236.49 2621.88 46617 2310.31 8.44 OSF 1.50 Pass 13900.00 3794.85 6405.13 -10262.13 17945.00 3625.68 4125.85 -11817.99 236.49 2657.48 408.30 2344.89 8.53 OSF 1.50 Pass 14000.00 3795.18 8484.43 -10323.06 17945.00 3825.88 4125.85 -11617.99 236.18 2698.01 489.24 2382.86 8.63 OSF 1.50 Pass 14100.00 3795.51 6583.58 -10384.17 17945.00 3825.88 4125.85 -11617.99 236.18 2737.48 469.64 2424.04 8.76 OSF 1.50 Pass 14200.00 3795.84 6642.73 -10445.28 17945.00 362568 4125.85 -11617.99 236.18 2781.89 469.55 2468.53 8.90 OSF 1.50 Pass 14300.00 3796.17 6721.88 -10506.39 17945.00 3625.88 4125.85 -11817.99 238.18 282618 469.02 2516.15 9.06 OSF 1.50 Pass 14400.00 3796.49 6801.04 -10567.50 17945.00 3625.68 4125.85 -11617.99 238.18 2879.12 488.10 2586.73 9.24 OSF 1.50 Pass 14500.00 3796.58 6880.00 -10628.86 17945.00 3625.68 4125.85 -11617.99 235.75 2931.38 488.84 2819.82 9.44 OSF 1.50 Pass 14800.00 3794.28 8957.21 -10892.38 17845.00 3825.88 4125.85 -11817.99 234.71 2983.60 485.28 2673.08 9.64 OSF 1.50 Pass End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI19-FN2\SI19-FN2\SI19-FN2(P5) 3/11/2013 12:01 PM Page 30 of 58 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 | /g IIz — . { ./ > (C e ID e } : ? } (§� , \ e ( � ( \ \ � (°; =oj .off =o! z} J )\| \ [ 2 ) / to ` t°' Z°` Zn' 2 22 ®\w r // 2 CD \< q { 7 e \' 4 | r . f| cc § | cc & [ ® | to \ o : _ 2g° _§ ■# � i.•''- 6 g y _6-. • ( . . ;k / '�'- )rz \ _ ` % !} eE ■ li _° jh-ID_ii §$ �. EC 2 § • I\* _ § ; ; , § ; | f Si §! q & &0 ( § K 2|g ; 2 ■ 2 § .m m e ! E{ | ! i \ , |ƒ \ )ƒ R ® ! £ � !® $ »!° ? 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Schlumberger CemCAD E*well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : S119-FN2 Country : USA State : Alaska Prepared for : Mr.Luca Borri Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 3/15/2013 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (907)273-1765 E-Mail Address : slauper©slb.com 41, 4VATE Disclaimer Notice: Schlumberger submits this document with the benefit of as judgment experience,and good oilfield practices This information is provided in accordance wnh generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculatons are estimates based on provided inlormation.All proposals.recommendations.or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS DA SUPPI IFS.RECOMMENDATIONS MATE.OR RFSUI TS OF TEF SERVICES RFNOFSFT Freedom frwn infringement of any intellectual property rights of Schlumberger or others is not to be Interred and no intellectual property rights are granted hereby Mark of Schlumberger Page 1 SI1S&FN2.ctw;0315-2013; LoanCase 13 3/Bin Surface Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : S119-FN2 Schlumburgcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 3610.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000)psi - - . Fr 2 X - -Pore SV--1 s • SV-3 • SV-2 6 Permafrost 1 C ▪ SV-1 N Ugnu Top (UG-t: TD � _ 4"Nell Lithology Formation Press. Page 2 5119-FN2.cfw;03-152013: LoadCase 13 3/8in Surface Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : S119-FN2 SchlMnberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 3530.0 ft Casing/liner Shoe MD : 3610.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 3610.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 117.7 % Mean OH Equivalent Diameter: 18.621 in Total OH Volume : 1162.0 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 2000.0 16.000 190.0 20.063 3610.0 16.000 35.0 16.822 Max. Deviation Angle : 80 deg Max. DLS : 3.768 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 775.0 11.70 8.40 SV-4 Siltstone 1159.0 11.50 8.40 SV-3 Sandstone 1471.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2206.0 12.00 8.40 SV-1 Sandstone 2747.0 12.50 8.40 Ugnu Top(UG4) Shale 3610.0 12.50 8.40 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1779.1 32 0.7 3610.0 2454.1 50 1.2 Page 3 SI19-FN2.cfw:03-15-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : S119-FN2 Schlumbcrgcr String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 2: fluid sequence Job Objectives: Cement Surface Casing with Returns Seen at Surface Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty : 0.48 Ibf/100ft2 Displacement Volume 528.5 bbl Total Volume 1227.5 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 lbf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Surface Lead Slurry 536.0 3105.4 10.70 k:2.08E-1 lbf.s^n/ft2 n:0.187 Ty:16.36 Ibf/100ft2 12.5ppg DeepCRETE 63.0 504.6 3105.4 12.50 k:1.68E-1 Ibf.s^n/ft2 n:0.301 Ty:0.44 lbf/100ft2 Surface Tail Mud 528.5 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 8 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2024 psi at 3530.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 60 ton Check Valve Diff Press 159 psi ft (x 1000)psi < > 0 2 1tat1, —Frac —Pore o + ZS Fluid Sequence Static Well Security Page 4 SI19-FN2.cfw:03-15-2013; LoadCase 13 3/Bin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI19-FN2 SChillikliger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/Bin Surface Casing Section 3: pumping schedule Start Job: Circulate BU, Ramp up Rates 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 Spacer Ahead with Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 2.0 0.0 80 Line up Cement Unit Surface Lead Slurry 5.0 536.0 107.2 536.0 80 Mix/Pump Lead SLurry(3-7 BPM) 12.5ppg DeepCRETE 4.0 63.0 15.8 63.0 80 Mix/Pump Tail Slurry(2-6 BPM) Surface Tail Pause 0.0 0.0 1.0 0.0 80 Shut Down Pumping Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.5 401.4 47.2 401.4 80 Kick Out Plug with Cement Unit Pause 0.0 0.0 5.0 0.0 80 Line Up Rig Pump Shut-In 0.0 0.0 5.0 0.0 80 Bleed Off&Check Floats Total 03:26 1100.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats ' Dynamic Security Checks: Frac 16 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2078 psi at 2681.0 ft Burst 4738 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 68 degF ' Simulated BHCT 68 degF Max HCT Depth 3610.0 ft CT at TOC 58 degF Max HCT Time 03:21:10 hr:mn:sc Static temperatures: At Time I (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 52 degF 1 24 degF Bottom Hole (degF) 68 degF 50 degF Page 5 S119-1N2.cfw;03-15-2013; Loadcase133/8in Surface Casing;Version wcsicem472_05 Client : Eni Petroleum Well : S119-FN2 Schlumherger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Casing Shoe o Depth= 3610 ft ; 1 ri Frac Willi — Fore i i W . 1. . 1 l i 1 1 i f l 1 ? t -1 I t 1 i 1 1_ 1 ___ Lc) ■ Hydrostatic I_ Dynamic ._ ... ._ N- i I . _. _ - ...C. = .. Cuuu uuuu ... _.r__ .r•_w.w..w .e an orluuu. u� u....ws g . .u.. ......rw .. ..1.Ili MN .111111•11111111111 mai umm u=.==...IC no..w.w . .s. . w.wwi ..w.. ._.w. w....w.wwww.=.u. Tu cr)o ww.wwi�rlINII ruuu.wwwiirrii=uilrii�_' . _ ...w � wwwwwwwwww wwww.www . — 2 uuirwiiwo.wuuururiiiuriuuu uu_iii� ` muuu. o ■1111 , Q r ._._ __. rwiriwwwi in rim= - — rrrrarw�www w - -_ rn '_ iwi iiii uiw� iu� iuwu MI`M I i i uiiw. � uo ......i.. ui .. . .. i NI iii RIB cs .wwwwwww.uu .www www. 11.www.wwwwww .. w .. . . u . . •. iwwwww . . —_ . i 11 Lo ____ - . co 0 cd 1 I I r 1 1 --1 — , 1 I 1 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 6 SI19-FN2.cfw;03-15-2013: roadCase 13 3/8in Surface Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : S119-FN2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Conductor Shoe o_ Depth= 160 ft cV Frac a—i 1 i — Fore Hydrostatic � Dynamic 111 -1 ■ ■■■■■m■ ■■ ■■ ■■ ■ 1111 ■ _ ■ ■ ■■ ■■Ii■ ■ ■Ii I M ■ saus ■■■ ■.i■ ■ Emma as ■ ■ ■S■1■ -_ '�'i.'l�i1°1'ii 1" i 'i'ii I co : Client : Eni Petroleum Well : S119-FN2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Load case : 13 3/8in Surface Casing Simulated Surface Pressures 0 O — Calc.CemHP ■ Calc.Pump Press. O 11 ___ f t i I I 1 O- , ^ 'Q� ui VJ O f 1 I I cn 1 _-_ 11 11 11 I O 1 r r r r r r r r 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page B S119-FN2.cfw;03-15-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatuers during Placement 0 00 — Last Sack Temp. ' ■ First S. k Temp. ■■l■■■■■11 11111 111111111111111111111111.111 API B ■u■■■■■■•■■■ ■■■ ■�■■■■ –o�– 11111111111111111111111111111 NMI — ■ 11l ■■ _ ■■■ lull l■ lull ■■. ■iI :1q■ ■ o isle- 1111111 ::n ■■ ■■■ ■■-l■ ■ ■■■■11 ■ ul u■ ■ ■ ■Null , l■llu■■■■■■■■■■■■ ■■u■u■■ ■ , ■■■■■■■■■■■■■■■■■■■■►n■■■■■■ :UIi: 320, Ell 1 11 II In 1 11111111111111 ■■ _■ ■ lull lull■■■■■■■■ 11;ai 011101111MM -, ,c2 ■ 11■l l _ ■l ■ ll■l ■lp l■■■ll _ ±� ' 1111■■ UN ■ ■ ■■l■ ■■l■■■■■lullll■■l - U ' .■...■■■lll _._. .■u■.■■...■.0■.■■u■■..■.. —P L1 Emus .■>... N. ,� U ■■ aNu ■ ■ ■ ■ ■ °o TIMM■■I11= a III■■_k _ ■=■l■■N:■:■:■11■:11 II■ ■■ -N ._ ■l■■■■■l I ll■■l '.. '. . ................• ■ _N ■■■......11■■■■l .■■■ ■ l■■ll ■■ lull. N ,_ .......••■••■ ■u■■ ._ ••■lll■l • ._.� N F ■ 11 1111■■ ::iip "' r- MEOWS ■ ■■■ ■ _ ■llIll ■■lull/ ■1111■■ ►.11111,//i_ o iiii , Lf7— i r i r r r r M 0 25 50 75 100 125 150 175 200 225 Time (min) Page 9 SI19-FN2.cfw:03 15 31313; LoadCase 13 3/13in Surface Casing;Version wcs-cem47Z_05 Client : Eni Petroleum Well : S119-FN2 Schluminger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatures up to 24 hours after Placement Lo- o - — Last Sack Temp. • - - O_ — First Sack Terre• ,-... �M N AR BHCT — ��. M� _ �� _I^ _o is- ��loam r�mo�ommou ��i� -o 0_ NM•MMM UMMIMMOMMOMMMIMMNMMIimMM_ � �- -o/�� N1��NINNI tr��•�� NO� O O ��r��111111111111111111111111111111111111111111111111110111111111 _o _ a I Imii� �■u■■ie■��mi�, o � o co- - --- l----� -iii-,�lr�wUM! Al- MINIM V �MM_-� ■I■---i---=iii ?' a '- a) al _� an i0iffibmo��1�■mw 1 0 0 0_in Al AM MMUMAMMUM AM MIS o ummullummummiuma�i�irl �r��MINN�NI ��1�NI�Z��r��r■�r�� -L '= i iiiiii '-ii�IN 1.: -i i -- lI - :- -- i - ---- Lo NIMMIIIMINAMIM MI - N . _ __.__. O O -1 i r I r I ■ ---M 0 250 500 750 1000 1250 1500 1750 Time(min) Page 10 SI19-FN2.cfw;03-15-2013; loadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : 3119-FN2 ScIimberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.262 Ty :0.48 lbf/100ft2 Gel Strength :6.40 I bf/100ft2 MUD Mud Type :WBM Job volume : 528.5 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n : 0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Surface Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo.Model : HERSCHEL_B. k :2.08E-1 lbf.s^n/ft2 At temp. :75 degF n :0.187 Ty : 16.36 lbf/100ft2 Gel Strength : 14.25 lbf/100ft2 DESIGN BLEND SLURRY Name :ASL(0.79) Mix Fluid : 11.075 gal/sk Job volume :536.0 bbl Dry Density : 108.69 Ib/ft3 Yield :2.40 ft3/sk Quantity : 1253.64 sk Sack Weight : 100 lb Solid Fraction :38.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 11.075 gal/sk Thickening Time Schedule () 30 Bc at 01:45 hr:mn Compressive Strength Schedule () (psi) at (hr:mn) Page 11 S119-FN2.cfw;03-15-2013; LoadCase 13 3/Bin Surface Casing;Version wcs-cen472_05 Client : Eni Petroleum Well : SI19-FN2 SIE18rg r String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing 12.5ppg DeepCRETE Surface Tail DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo.Model : HERSCHEL_B. k : 1.68E-1 Ibf.s^n/ft2 At temp. :74 degF n :0.301 Ty :0.44 lbf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid :5.471 gal/sk Job volume :63.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity :226.05 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 D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Thickening Time Schedule () 100 Bc at 06:58 hr:mn Compressive Strength Schedule () (psi) at (hr:mn) Page 12 S119-FN2.cfw;03-15-2013; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 S hlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 133/8in Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3590.0 ft Casing Shoe :3610.0 ft NB of Cent. Used :36 NB of Floating Cent. :15 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2090.0 17 1/3 NW-ST-13 3/8-8-ST A3B W131 0.0 2047.6 3610.0 19 1/2 NW-ST-13 3/8-8-ST A3B W131 5.9 3470.0 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-13 3/8-8-ST W131 13 3/8 18.386 14.685 No Hannover 16.000 1225.21 2996.70 A3B 0. ft _ 0 20 60 80 100 ° ; I ° _ ! Pipe Standoff _ Page 13 5119-fN2.cfw;03-15-2013; LoadCase 13 3/9in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI19-FN2 SciIimberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 6: operator summary MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer Surface Lead Slurry Volume:536.0 bbl Density : 10.70 lb/gal Yield :2.40 ft3/sk Dry Phase Liquid Phase Blend: 105249 lb Design Mix Water 277.5 bbl 10.0 bbl LAS Design 12.5ppg DeepCRETE Surface Tail Volume :63.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 22786 lb Design Mix Water 29.4 bbl 10.0 bbl LAS Design 12.5-0.82-53 22604.963 lb Fresh water 29.445 bbl 10.001 bbl D046 45.210 lb 0.200%BWOB D065 56.512 lb 0.250%BWOB D167 56.512 lb 0.250%BWOB D153 22.605 lb 0.100%BWOB Page 14 SI19-FN2.cfw:03-15-2013: LoadCase 13 3/8in Surface Casing:Version wns-cem472_05 Schlumberger C emCAD E* well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : S119-FN2 Country : USA State : Alaska Prepared for : Mr.Luca Borri Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 3/14/2013 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (907(273-1765 E-Mail Address : slauper©slb.com Cr URTE Disclaimer Notice: Schlumberger submits this document with the benefit of its lodgment,experience.and good sift eld 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 GMEN CONCERNING ACCURACY DR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTNENESS OF MATERIAL,PRODUCTS OR SUPPI IFS.RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be interred and no nrelNUUal property rights are granted hereby. *Mark of Schlumberger Page 1 S119-FNZ.ctw;03-15-2013; LoadCase 9 5/Bin Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI19-FN2 Schlumburgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 11795.0 ft BHST : 90 degF Bit Size : 12 1/4 in ft (x 1000)psi . ■ 0 2.5 Frx _ a==I MI \ , it- \ ':7.-,-.----— - Shale o i 0 o' - Shale S ' 1 '. o Shale II o- o ••••••Sandstone••••••• III 1 - * '�"dell Litholog.; Formation Press. Page 2 age S119-RJ2.ctw;03-15-2013: LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 S hlumtirgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 3610.0 13 3/8 68.0 12.415 Landing Collar MD : 11715.0 ft Casing/liner Shoe MD : 11795.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 11795.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1421.5 bbl (including excess) Max. Deviation Angle : 86 deg Max. DLS : 3.768 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 775.0 11.50 8.40 SV-4 Siltstone 1159.0 11.50 8.40 SV-3 Sandstone 1471.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2206.0 12.00 8.40 SV-1 Sandstone 2747.0 12.50 8.40 Ugnu Top(UG4) Shale 5217.0 12.50 8.40 UG-2 Coal Bed Shale Marke 8700.0 12.50 8.40 Lower Ugnu Shale 10143.0 12.50 8.40 Schrader Bluff Top Shale 10297.0 12.50 8.40 N Sequence Top Sandstone 10489.0 12.50 8.40 N Top Sandstone 10733.0 12.50 8.40 N Bottom Sandstone 11081.0 12.50 8.40 N Sequence Base Sandstone 11795.0 12.50 8.40 TD Sandstone , Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1779.1 32 0.7 3610.0 2454.1 50 1.2 11795.0 3750.0 90 1.9 Page 3 SI19-FN2.cfw;0115-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : Sl19-FN2 Schlumbergs' String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 9489'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty : 8.86 lbf/100ft2 Displacement Volume 888.3 bbl Total Volume 1187.3 bbl TOC 9489.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 8293.9 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 12.5ppg DeepCRETE 199.0 2306.0 9489.0 12.50 k:4.89E-3 lbf.s^n/ft2 n:0.960 Ty:15.95 Ibf/100ft2 Mud 888.3 0.0 9.50 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 Ibf/100ft2 Static Security Checks: Frac 382 psi at 3610.0 ft Pore 140 psi at 3610.0 ft Collapse 2883 psi at 11715.0 ft Burst 5750 psi at 0.0 ft Csg.Pump out 62 ton Check Valve Diff Press 55 psi ft (x 1000) psi 0 25 —Hy:' eetatc —Frac —Pore c� r O O Q " Fluid Sequence Static "Nell Security Page 4 SI79-FN2.crw;03-15-2013; LoadCase 9 5/Bin Intermediate Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schliolirger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Line-up Cement Unit 12.5ppg DeepCRETE 6.0 199.0 33.2 199.0 80 Mix/Pump Cement Slurry(3-7 BPM) Pause 0.0 0.0 2.0 0.0 80 Shut Down Pumping Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Mud 8.0 888.3 111.0 888.3 80 Kick Out Plug w/Cement Unit Pause 0.0 0.0 5.0 0.0 80 Line up Rig Pumps Shut-In 0.0 0.0 5.0 0.0 80 Bleed Off/Check Floats Total 03:00 1187.3 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 200 psi at 11795.0 ft Pore 140 psi at 3610.0 ft Collapse 2765 psi at 65.8 ft Burst 5301 psi at 0.0 ft Temperature Results BHCT 85 degF Simulated Max HCT 90 degF Simulated BHCT 74 degF Max HCT Depth 11795.0 ft CT at TOC 74 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time 1 (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 74 degF 181 degF Bottom Hole (degF) 74 degF 90 degF Page 5 5119-FNicfw;03-15-2013; loadCase95/Bin Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schhaberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Shoe o Depth= 11795 ft I i 1 1 ' I I , I 1 i 11 I- of Frac { !! in ■ Hydrostatic N- Dynamic i �� o + w Iwwww�M r 1111111111111111111111111111111• wwwwwwlw Iw ww I�w ...im w■r t �� = r rwrwww■Tiirrrr MINI ww Mammon ` • wwww wwwwwwwww w�ll�wwww wwrw rrrr rrrrrrrrrr:rrr�r wwwwwwl.■Iwwwwlwww www ;- NIw■Mw� wwwlwwww MOM !- ° wwwrrww :�i' } la ww■��■w�iiwwww�F__ __ _ME_ _._-_w _ . I- r LC' 1.111111 92 o r N _ w rn. Mww VIIIIIIIIIIIIIIIIIIIMMINIMI w= 1i o r•I�iwwiw _MEI= rr rr r=iwNlw� r� _ ■ wl.....uwrwlw www+mm. i r m Imir m. ci wwwwwwww w Q ww ..w u, .. mos , cri � _��— WI M w �i_wwrr� ww�ww1 rwlwwww 1rrrr � rO w rw wwwI•wwlIs■ ww III 1111111111111111111111111 _m rrrr � wlw r rw r�rr _. wwwwwww r - wwwwiui w IM 1111•111111 w -NM In - _ -4 O Co I I I I I I I I I 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 6 5119-FN? 03-15-2013: LoadCase 9 5/tin Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Surface Shoe °_ Depth= 3610ft vi Frac - 1 j -T_. ■ Fbre ■ Hydrostatic ....... Dynamic u --- a .' 4__ - MI-rill --1_- — .1 O - - - - _� - _ _ ._ -.-- _s ��. �s :. � � � - - - �E __. W_=i_ _.._WWW _: -IW. NIZE_- -Z= 121-_m�:-:....M.SMSS... ----��- �� ._ �r--i-i -�--------r-r- -- i --rW------- --------■1iIWIWIr--r-r•-i---- 2 LO } 1.1.11.1 - -tai=1■ -��---m -mm��mormomom � mw --r --- rr-1--------1i�-�1-r--1----- N • --r --------11�-1r-----I------1�i1 a 11111111111111111111•1._ 1� -i---i_ i --wsili l 11 i-_ii= o- c— No N 1 ----------- ------------ -- ---- J ■■■■iuiii iiiiaiisiiiiui•1111uuuuuuu: ------------i11-------'----i i1i--1- ---iono-- °' s Lo -::_:mmm:-;:__s:__:::1:::: Co ---------- ------ -- - - ---- - =' . ----- IINII---111-1N -----r---- ---�--,� _ - . oc; r r r I 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 7 8119-FN2.cfw;03-15-2013; LoadCase 95/8in Intermediate Casing;Version wcs-cem472_t5 Client : Eni Petroleum Well : Sl19-FN2 S hlumbergcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Surface Pressures 0 N — Calc.CemHP ■ Calc.Pump Press. 1 W_ Ml ■■■■■■■■■,■■■■■■■■■■■■ ■ MI� s. Ms I I I f ■■■■ sss ■ M■ s■■■ s ■ �■ ■■■ ■■■ ■■■ ■■ CO i • ■■■■■■N■■■■=■■■■ ■■■■ � u � ; �- s- ri - : s o ?-- r ss ■■■■■■ ■■■■■1.- ■ _ f- ■■ ■■■■■■■ ■■■■■ ■ ■ (N_ ■■■ ■■ . ■__■■■■■■■•_■■■ ■ - um ■■ ■ ■■■■■■■ ■■■ ■__ ■ ■■■ ■■ ■■■1.r -ilrr--�■-- i.■■ ■ . ■■■ i ■■ s■PI� ■■■■■■■•■ ■■■ s Qom_ ■.I■.s■ ■__■ III _ III ■ /' ■■■■ ■ ■ ■ -6 • _ 1. s■ . ■.■■s■. ■■ s ■ s ■■■■■s ■ ss ■ co _s ass■■■■■ ■•■ s■ o ■ ■■■■■ ■■ ■ ■ v, ■■■■■■■■■ ■■■■■ ■ • (0 co .-+- 9 • esm o U- ■■ ■=■■ ..... . ............. 1.,s mum a ■ .- pn - - N ` ■s■■ O- ■■■■ . iliiiiii ' ' 11111111111111 o r r r r r r r r r r r 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 8 SI19-R42.ctw;03-15-2013: LoadCase 9 5/8in Intermediate Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schiumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures during Placement cc _o Last Sack Temp. — First Sack Temp. Lo API BHC T co— -1" iliplaill pialmil Nip _Lcc?,). 1 ' t I ■ U_ ■I ■■ ■■■ ■■■ ■ ■ ■■■■ O ■ NI ■ ■■ i ■ ■ ■■ ■ ■- — CD ■■ . ; ■■ ■■■■■ ■■■■■■■■■■■■■ ° _ ■■■ f ■ ■u■_� ■■ ■■■■■ ■■■ i ■ ■ ■■ ■.n=_ m■ �_ I ■ 1 ■ ■ ■■ ■ri�A ■=eo 1 11 ■■ 1 ■■■ ■■■■ ■■■ m co_ 1 ■■ ■■■■■111`■■ ■■■■■■■■ _I y _ co ■■■1 ■ ■■ o 0 4-_ ■ ■ ■■■►1 ■ i ■■■ ■ U � co ■ ■ ■■■ ■■■■ c.i _ a ■■ ■to ■■■■■u 1 ■ ■■■■\■_ ■■ ■■■■■ _N c ■■■ ■■■■ ■. ■ ■■ ■■■ c.i _ _ ■■ ■ ■■■■■■\ �■■■■■ ■■ ■■ ■■_ ■■ ■■■■p - - ■■ C■■ _■■ ■■ 111111111111111/1411111111 ■■. ■■■ N CO ' ■ IN 111111111N111111111111N11111111 ■■ ■ ■■ N ■■ 1 111 ■ _. _N N i- ■ ■ I i _i o Lot r 1M 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 5119-FN2.cfw:03-15-2013: LoadCase 9 5/8in Intermediate Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schlumbcrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures up to 24 hours after Placement co -o co Last Sack Temp First Sack Temp ._ .._� ._T_ �___ ._ _-_ -. __, u0 c�p� API I ...I 1. iim in. . O !__w Co- ..imummiiiiiiiii is co _amiiiiiim,- _ _ . 4-- _ ._ 1___t,._ ___ ,., , ,÷, 1 T al . .... __.4iis_ re , LI_ 1 _ _,),,,c2 Wo _.__. ....__�_ N co- rn L U as _._ ...' — 1111 _ O o CO- 1 4 III Ire - q O ME � N • a® r_ 1 0 NI �i _ ll: _ . CV CD 1.1111 IA NI . O O (• LC) i r--_ I . I t . . . I —M 0 250 500 750 1000 1250 1500 1750 Time(min) Page 10 5119-FN2.cfw:03-15-2013; LoadCase 9 5/ein Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI19-FN2 SGhlimbeger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 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 lbf/100ft2 MUD Mud Type :WBM Job volume : 888.3 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0% Oil :0.0% Water : 96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 lbf.s^n/ft2 At temp. :80 degF n : 0.324 Ty : 12.92Ibf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 100.0 bbl 12.5ppg DeepCRETE DESIGN Fluid No: 3 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :4.89E-3 Ibf.s^n/ft2 At temp. : 74 degF n :0.960 Ty : 15.95 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN • BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid : 5.471 gal/sk Job volume : 199.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity : 714.08 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 D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss , D153 0.100%BWOB Antisettling Page 11 5119-FN2.ctw;03-15-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 Schlumburgur String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :11775.0 ft Casing Shoe :11795.0 ft NB of Cent. Used :57 NB of Floating Cent. :57 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 9515.0 0 0/0 0.0 9533.1 11795.0 57 1/1 HYDROFORM HFD 50.0 11795.0 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) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford'') N.A. N.A. N.A. ft % o— 0 70 0 60 80 100 --BCert 1_.__._-__-.+ I 1 4- a At Cent. ___1 1._ c.— . III i� ■ii kr, 1N_ �� ,.. .. _.__a T • •.... t _, ii c. . , „ I 1111111 o - _ �� u., Pipe Standoff Page 12 S119-FN2.crw:03-15-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S119-FN2 SciliIllierger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/bin Intermediate Casing Section 6: WELLCLEAN II Simulator % % ft o_ 0 20 40 60 80 100 0 20 40 60 80 100 8 `—Std Betw.Cent. —Mud Contamination rn —Cement Coverage —Uncontaminated Slurry - 7 pO O pp .1.--S......-....."-----... O— S Cement Coverage Uncontaminated Slurry rw.ce.* a.Hw a lnrwr 3 z 3 3 z 9000 9000 9000 9000 9500- - - 9500 9500 9500 10000- 10000 1 0000 10000 a 10500- 10500 a a 10500 10500 Q m m m m 0 0 0 0 11000- 11000 11000 1 1000 11500- 11500 11500 11500 m ; m m 3 m 0 3 3 0 0 0 z z '!mpDe =All■Ze. D SH II, '' NI Page 13 5119-FN2.cfw;03.15.2013• LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI19-FN2 Salome' String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loedcase : 9 5/8in Intermediate Casing Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume: 100.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.200 gal/bbl of spacer D182 543.750 lb 6.000 lb/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer 12.5ppg DeepCRETE Volume: 199.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (lb) Design Mix Water 93.0 bbl 10.0 bbl LAS Design 12.5-0.82-53 71407.680 lb Fresh water 93.013 bbl 10.001 bbl 0046 142.815 lb 0.200%BWOB 0065 178.519 lb 0.250%BWOB D167 178.519 lb 0.250%BWOB D153 71.408 lb 0.100%BWOB Page 14 8119-FN2.cfw;03-15-2013; I.oadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 REV DATE BY CR t•REV DATE BY CK APP DEScRIP110N .; 10/.:410 D-1S CC CC tntt#01 [)rowirsg VICINITY MAP SCALE: 1' _ L. in 16 14 ii 48 'I' ,, N ._. ____ ,. _ 1_- 1 �:,•3 21 I :?s 14 19 20 21 7" THIS __ _ SURVEY 7: 30 29 P8- tI W a.5.a. nnpa3, xn 55 }B ct 39 31 s3 54 1.5 `1n & 31 3«' 35 at+ I 113N �rrf* pa .r PAD*, t? OO " ; a_ ors -i__ . 9 1G t't \5 i` 7 a z\"^'S-3R „ * ± '� I _ i; I 15 i d ='1' 3 DS-r`3G�+'N•irtis-il.r 1 oT iPA01, '�l�a 4.-. 'i ,'s 4 tin , �rlj„'.0 t- 1 . DS 3D- r` $ , ((r' \ Slit _ 21 22 2: k ++`_{ ' I .Ian MiM v� zo P'%it 0 2B 27 n r. (9 11, 1 DS 3N, �� i. `"I:, �! Ii j P�iO TL1 �, Up.1 G P " DRAWING NOTES: I 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS SOi_UTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH. RANGE 9 EAST, UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.i'.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. it s+a♦�+�tttti SURVEYOR'S CERTIFICATE f 9 t h =.i� `I r HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 qy- /i 't 0 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF Y..'!bt :3;-' .:fdo. ....0 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY � .... FRANCIS JIII� CORNING t DONE BY ME OR UNDER MY DIRECT SUPERVISION AND •1 s ` LS-10665 THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT ♦ a� •. C 1O f,(-17,e719•'•y AS OF OCTOBER OI, 2010 X14 0• •..............a 40 4i gr+, t,•i�p�++ iiiik a�Se�a &ar,i, SPY ISLAND DRILL SITE s WELL CONDUCTORS . AS—BUILT LOCATIONS 2111111 ./��,;1. CAD FILE:EN13b43D9 US O(p er �` rag DATE DRAWING NO PART: REV: If J ,oho:/zolo Eni-3543—d9 ( 1 of 3 0 REV DATE BY P' '. GRIPIION R V DATE BY K "P DESCRIPTION ®® ') 1S®ms" Iri: c DraYw'"S IIIIIIIIIIIIIII i r �r� _ \4c. — et. T8 I\ sec 17 ill G- O' Sec,�'9 ,r Scr,. %p cr L., A.S.P. NADB3. Zt : 4) .0 1J amc+ N cO r O W 000000 N -4 1J N C7 t„., to a W W rn LA cy, .P Ip i DETAIL A. SCALE: 1"=80' SAµ9BAG TOE L.AEl 940•45;1E -.-..�c a01:071 ("4 s b rh4:341"1171 o qI s c�\�QG Y *ot 1 DETAIL A \' L SPY ISLAND DRILL SITE ; 4 : (SID) r, i GRAS 51106-5: 1 i rrroBA G !1E LEGEND SCALE 2DC 10o zoo 0 - WELL CONDUCTOR AS—BUILT THIS SURVEY air 1 1'- = 200' i till* , ,� c SPY ISLAND DRILL SITE ` s� WELL CONDUCTORS fir' 1�',�'� AS—BUILT LOCATIONS @1111 n • �j '�4;, �� operating FILE:Fh13543C9 c l�nrnl� o~>i:CjD1j2010 DRAWING NO: Ent-3543—d9 !PAT: 3 ,RE: R V' DATE BY CK APP 6 P110N REY DATE B)' CK APP DESCRIPTION � E3�RI 0 1D C fr C ;;,...S CO ,�..0 1'.i,.C, C,cNir':� Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. - - 'Y' 'X' _atitude(N) Longitude (W) F N L F.E.L Elev. (US ft.) (USft.) , 1 6053423.20 1651769,82 70°33'27.209" 149'54'24.765" 797 1171 12.4 2 605342.1.65 1651761.87 70°33'27,194" 149•54'25.000" 798 1179 124 3 6053420.07 1651754.10 70'33127,179" 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 165173844 70°33'27.149" 149°54'25.692" 803 1202 12,4 6 6053415.54 1651730.54 70°33'27.134" 149°54'25.925" 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°33127.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70°33'27.074" 149°54'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70°33'27.060" 149°54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149°54'27,318" 813 1257 12.4 I 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 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 I 19 6053389.63 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 70 033'26.823" , 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°54'31.673" 842 1405 12.4 26 6053376.14 1651528.13 _ 70'33'26.750" 149°54'31,904" 843 1413 12.4 27 6053374.53 1651520.23 70°33'26.734" 149°54'32,137" 845 1421 12.4 1 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 70'33'26.690" 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 70°33'26.646" 149°54'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70'33'26.631" 149°54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70°33'26.616" 149°54'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'25.601" 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 i *0&ABC SPY ISLAND DRILL SITE P " \ WELL CONDUCTORS AS--BUILT LOCATIONS @II ll -,, CAS rILC:Eti13543C9 us oiler 1tting D"Ti0/00.,o DRAWING No. Eni-3543-d9 [PART:Cr: 3 (REV: a1 Cr 0o o 0 re• u O o m H y C row N N N N N N N N N N N N N N N N N N N N N N N N N N N N ev Q Z 0 m .-4 .-4r-o ,-1 .-I N . 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S P E O IDENTIFICATION CODE PAG 206 OF 338 Cli�ll E&P Division REVISION STAP-P-1-M-6140 0 1 I I I I 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW — Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. S P E O IDENTIFICATION CODE PAG 207 OF 338 End E&P Division REVISION STAP-P-1-M-6140 0 1 1 1 1 1 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. S P E O IDENTIFICATION CODE PAG 208 OF 338 Enti E&P Division REVISION STAP-P-1-M-6140 0 1 I I 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. S P E O IDENTIFICATION CODE PAG 209 OF 338 En11 E&P Division REVISION STAP-P-1-M-6140 0 1 I ilifit LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE: I CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rig twe: J.UPs Hole Dameter(in): 12114 Weight(KgA): 1.3 R.K.B.eleieUon(m): 26 Last Csg.Shoe(m): 797 Marsh'5Ascosity(sec/Qt): 44 Water Depth(in): 24 Csg.diameter¢n): 13'318 P.V(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.i b1100 R'): 5 Liners(in): 6.5" Weight(Obit): 61 Gels(b/100 t': 2/8 Flow Rate(bpi): 025 Max.Burst pres(psi): 3103 W.L(cc i30 min): 10.5 Laholog x Shale Expected EMW 1.68 Kg!cm2/10 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bti) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 060 100 95 2 480 3 075 200 10 2 470 4 100 300 10.5 2 463 5 125 400 11 2 455 6 150 500 11.5 2 450 7 176 670 12 2 445 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Nate: Pumped with a constant Into rate of(bbl)• Volume pumped(bbl): flume returned(bbl). (ps) 1000 900 - - . 800 - dap pump 700 r e 600 / S - shut in curve l•S 500 U 400 _ . t- 18 minutes I e 300 . . 200 100 0 . - . . • . . . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(UN) 41 • Time mins RESULTS: (Press.,,,,,,+Press.Lo.)x10rD epth=[(1.3 x 797 110)+(430 x 0.07)]x10/797=1.68(Kg/cm2M O m) Note: I Company Representable Figure 15-1 - Leak-Off Test Report � bz8 p8p88$4 p8R8 _ filkk98883 _.t____ FRB:" 8kR8k8888'sBA.. ..R... W c 9 V 9 Y 9 N'1 p i V! .!!!!! 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I II tr.- 1 6 m '�0.. z J N .e-, o 3 az IN u,2�ur,�I.Es.,l mu\ma m1�ab'Au String Summary String OD/Weight/Grade ..,,,nnection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Surface Casing 13 3/8",68.000 ppf,L-80 BTC,L-80 32.0-3610.0 12.259 2.35 2.13 3.42 Burst Design(13 3/8"Surface Casing) Collapse Design(13 3/8"Surface Casing) Axial Design(13 3/8"Surface Casing) 850 850 850 co co L 1700 L 1700 t 1700 a a a 0 0 0 8) 0 j 2550 j 2550 ! j 2550 Cl) Ca N a) u) 0) 3400 3400 3400 I , - Design Load Line --- Design Load Line - Design Load Line - Pi.e Ratin. y Pi.e Refit). - Pi.e Ratin. 2400 3200 4000 4800 0 700 1400 2100 350000 700000 1050000 1400000 Burst Rating (psi) Collapse Rating (psi) Axial Force(lbf) Minimum Safety Factors(13 3/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(13 3/8"Surface Casing) 32 13 3/8",68.000 ppf,L-80 BTC,L-80 2.46 B5 L +100.00 C1 5.29 B5 F 3.17 B5 41 2.46 B5 L +100.00 C1 5.30 B5 F 3.17 B5 Drilling Load: Pressure Test 160 2.46 B5 L 32.53 C1 5.45 B5 F 3.16 B5 Test Pressure: 2000.00 psi 160 2.46 B5 L 32.52 C1 5.45 B5 F 3.16 B5 Mud Weight: 9.40 ppg 200 2.46 135 L 26.03 C1 5.51 85 F 3.16 B5 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 200 2.46 B5 L 26.03 C1 4.23 85 F 3.08 135 600 2.44 B5 L 8.72 C1 3.42 B5 F 2.91 B5 Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 800 2.43 135 L 6.59 C1 3.52 B5 2.92 B5 Surface Pressure(1/3'BHP): 547.41 psi 900 2.42 B5 L 5.89 C1 3.57 B5 2.91 B5 Shoe Depth,MD: 3610.0 usft 982 2.42 B5 L 5.43 C1 3.61 B5 2.90 B5 Fracture Pressure at Shoe: 1598.41 psi 1000 2.42 135 L 5.34 C1 3.62 85 2.89 B5 Fracture Margin of Error: 0.00 ppg 1159 2.41 135 L 4.67 Cl 3.70 85 2.87 B5 1159 2.41 B5 L 4.67 C1 3.71 B5 2.87 B5 External Pressure: Fluid Gradients(w/Pore Pressure) 1300 2.40 135 L 4.22 C1 3.78 85 2.84 B5 TOC,MD: 3610.0 usft 1441 2.40 B5 L 3.87 C1 3.84 B5 2.82 135 Prior Shoe,MD: 160.0 usft 1441 2.40 B5 L 3.87 C1 3.96 A4 3.06 135 Mud Weight Above TOC: 8.60 ppg 1800 2.39 135 L 3.22 C1 4.07 A4 3.02 B5 Fluid Gradient Below TOC: 8.60 ppg 2101 2.37 135 L 2.83 C1 4.20 A4 2.87 B5 Pore Pressure In Open Hole: No 2101 2.37 B5 L 2.83 C1 4.04 135 2.69 135 2206 2.37 B5 L 2.71 C1 4.17 85 2.69 135 2206 2.37 135 L 2.71 C1 4.09 85 2.68 B5 2300 2.37 135 L 2.63 C1 4.14 85 2.67 B5 2400 2.36 85 L 2.54 C1 4.19 85 2.65 135 2400 2.36 135 L 2.54 C1 4.18 B5 2.65 B5 Collapse Load Data(13 3/8"Surface Casing) 2500 2.36 B5 L 2.47 C1 4.23 B5 2.64 85 2500 2.36 B5 L 2.47 C1 4.24 B5 2.64 B5 Drilling Load: Full/Partial Evacuation 2600 2.36 B5 L 2.41 C1 4.27 85 2.63 B5 Mud Weight: 9.40 ppg 2600 2.36 135 L 2.41 C1 4.28 135 2.63 B5 Mud Level,MD: 3610.0 usft 2700 2.36 135 L 2.35 C1 4.32 B5 2.62 B5 Assigned External Pressure:Fluid Gradients(w/Pore Pressure) 2700 2.36 135 L 2.35 Cl 4.31 B5 2.62 B5 2800 2.35 B5 L 2.31 Cl 4.36 135 2.61 B5 External Pressure:Fluid Gradients(w/Pore Pressure) 2800 2.35 B5 L 2.31 C1 4.35 135 2.61 B5 TOC,MD: 3610.0 usft 2900 2.35 B5 L 2.27 Cl 4.38 B5 2.61 B5 Prior Shoe,MD: 160.0 usft 3000 2.35 B5 L 2.24 C1 4.41 85 2.60 85 Fluid Gradient Above TOC: 8.30 ppg 3100 2.35 B5 L 2.21 C1 4.43 85 2.60 135 Fluid Gradient Below TOC: 8.30 ppg 3100 2.35 B5 L 2.21 C1 4.44 85 2.60 85 Pore Pressure In Open Hole Below TOC: No 3112 2.35 135 L 2.21 C1 4.79 A4 2.63 B5 3113 2.35 B5 L 2.21 C1 4.81 A4 2.64 135 3200 2.35 B5 L 2.20 C1 4.88 A4 2.94 B5 Axial Load Data(13 3/8"Surface Casing) 3608 2.35 B5 L 2.13 C1 5.22 A4 2.93 B5 3609 2.35 B5 L 2.13 C1 5.22 A4 2.94 B5 Running in Hole-Avg.Speed: 0.7 ft/s 3610 2.35B5L 2.13 C1 5.22 A4 2.94 B5 Overpull Force: 100000 lbf Green Cement Pressure Test: 1000.00 psi String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Production Casing 9 5/8",40.000 ppf,L-80 Series 500 Type 563(TC) 32.0-11795.0 8.750 A 3.74 1.69 3.13 Burst Design(9 5/8"Production Casing) Collapse Design(9 5/8"Production Casing) Axial Design(9 5/8"Production Casing) 2500---- - - 2500- 2500 - - - N - �� u) - N - - �.. - - _c 5000- t 5000- r 5000 - - a - a - a - II o 0 _ 1 1 7500- N 7500- - co 7500- f _ 10000--- -- 10000--- - - 10000- - Design LoadlLine _H- Design I,iLoad Lin: - Diesign Load Trine 12500-i- i i i Pipe Ratinp_ i__- 12500 fPlpe R t n i i i 12500-=j P�pe Rating i i i.'. 1500 3000 4500 6000 0 1000 2000 3000 250000 500000 750000 Burst Rating (psi) Collapse Rating (psi) Axial Force (lbf) Minimum Safety Factors(9 5/8"Production Casing) MD(m) ODANeight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(9 5/8"Production Casing) 32 9 5/8",40.000 prfe8(500 Type 563(TC) 3.82 B6 +100.00 C1 3.96 A4 3.96 A4 41 3.82 B6 +100.00 C1 3.96 A4 3.95 A4 Production Load: Tubing Leak 200 3.84 B6 30.64 C1 3.96 A4 3.95 A4 Packer Fluid Density: 8.60 ppg 200 3.84 B6 30.63 C1 3.52 A4 3.51 A4 Packer Depth,MD: 21283.0 usft 600 3.88 B6 10.29 C1 3.13 A4 3.10 A4 Perforation Depth,MD: 21283.5 usft 800 3.91 B6 7.79 C1 3.14 A4 3.09 A4 Gas Gravity: 0.70 900 3.92 B6 6.97 C1 3.14 A4 3.09 A4 Reservoir Pressure: 1648.01 psi 1000 3.93 B6 6.31 C1 3.14 A4 3.08 A4 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 1159 3.94 86 5.53 C1 3.15 A4 3.08 A4 1300 3.96 B6 5.00 C1 3.15 A4 3.08 A4 External Pressure: Fluid Gradients(w/Pore Pressure) 1441 3.97 B6 4.59 C1 3.15 A4 3.07 A4 TOC,MD: 9489.0 usft 1800 4.00 B6 3.83 C1 3.17 A4 3.07 A4 Prior Shoe,MD: 3610.0 usft 2101 4.03 B6 3.37 C1 3.19 A4 3.08 A4 Mud Weight Above TOC: 9.40 ppg 2206 4.04 B6 3.24 C1 3.20 A4 3.08 A4 Fluid Gradient Below TOC: 8.60 ppg 2300 4.05 136 3.14 C1 3.20 A4 3.08 A4 Pore Pressure In Open Hole: Yes 2400 4.05 B6 3.04 C1 3.21 A4 3.08 A4 2500 4.06 B6 2.96 C1 3.22 A4 3.09 A4 2600 4.07 66 2.89 C1 3.22 A4 3.09 A4 2700 4.07 66 2.82 C1 3.23 A4 3.09 A4 2800 4.08 B6 2.77 C1 3.24 A4 3.10 A4 2900 4.08 B6 2.72 C1 3.24 A4 3.10 A4 3000 4.09 B6 2.69 C1 3.25 A4 3.10 A4 3100 4.09 B6 2.66 C1 3.26 A4 3.11 A4 3200 4.09 B6 2.64 C1 3.26 A4 3.11 A4 3610 4.10 B6 2.56 C1 3.29 A4 3.13 A4 Collapse Load Data(9 5/8"Production Casing) 3832 4.11 B6 2.52 C1 3.31 A4 3.15 A4 9489 4.23 B6 1.82 C1 3.78 A4 3.49 A4 Drilling Load: Full/Partial Evacuation 9489 3.74 B6 1.82 C1 3.78 A4 3.49 A4 Mud Weight: 9.40 ppg 10521 3.74 66 1.74 C1 4.15 A4 3.20 C1 Mud Level,MD: 11795.0 usft 10733 3.74 66 1.73 C1 4.25 A4 3.18 C1 Assigned External Pressure:Fluid Gradients(w/Pore Pressure; 10900 3.74 66 1.72 C1 4.34 A4 3.17 C1 10900 3.74 B6 1.72 C1 4.34 A4 3.16 C1 External Pressure:Fluid Gradients(w/Pore Pressure) 11100 3.74 B6 1.71 C1 4.46 A4 3.16 C1 TOC,MD: 9489.0 usft 11100 3.74 B6 1.71 C1 4.46 A4 3.15 C1 Prior Shoe,MD: 3610.0 usft 11200 3.74 B6 1.71 C1 4.53 A4 3.66 C1 Fluid Gradient Above TOC: 9.40 ppg 11794 3.74 B6 1.69 C1 5.00 A4 3.62 C1 Fluid Gradient Below TOC: 8.30 ppg 11795 3.74 B6 1.69 C1 5.00 A4 3.62 C1 Pore Pressure In Open Hole Below TOC: No Axial Load Data(9 5/8"Production Casing) Running in Hole-Avg.Speed: 0.7 ft/s Overpull Force: 100000 lbf Green Cement Pressure Test: 1000.00 psi TRANSMITTAL LETTER CHECKLIST WELL NAME Ai S1 9 -Ft z PTD# 02/30y3 Development ✓ Service Exploratory Stratigraphic Test Non-Conventional Well n FIELD: Ali-i K POOL: Ii Kc,i 1cJ , SGh Ikc -]i - 2k ii- Qi I 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 To u) a a H N N N a) 0 1 O co _0 _m oo — C co a) C Q > a) C -0 ai O a` ca m o 0 (Lr (MO o 0 -6 T c — m 0 O M 0-O a N 3 0 N W a) C C C E 0 a) a U) c o m O)a m LC O y O 0 a N a E m C > N O V E O a N aL.- o) rn m � c U N N W O O O O a) m m W N p U r a) a) 0) a IlL(n oMo a a-C (o cco ti ? Well History File APPENDIX Infoinration of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infor nation. RECEIVED HALLIBURTON AUG 12 2013 2.3�g3 Sperry Drilling AOG0C Surface Data Logging End of Well Report SI19-FN2 Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: June 29, 2013 es. • fie? tc ? yrt ,, .i rb�ea ,}rut rkb`s E 1 »�S . t T M .. e 3 . .a5� 45. ' ^-'44-4-44-'t• HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops it 6. Show Reports 7. Mud Record 8. Bit Record 9. Morning Reports 10. Survey Report Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Doyon 15 Well: SI19-FN2 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-029-23487-00-00 Sperry Job Number: AK-AM-0900480746 Job Start Date: 26 May 2013 Spud Date: 29 May 2013 Total Depth: 21258' MD, 3745' TVD North Reference: True Declination: 19.923° Dip Angle: 81.076° Total Field Strength: 57611.833 nT Date Of Magnetic Data: 26 May 2013 Wellhead Coordinates N: North 70° 33' 27.918" Wellhead Coordinates W: West 149° 54' 18.458" Drill Floor Elevation 54.10' Ground Elevation: 13.10' Permanent Datum: Mean Sea Level SDL Engineers: Leigh Ann Rasher, Kori Jo Plowman, Clifton Posey, Alexander Kalenuik SDL Sample Catchers: Michael Johnston, Craig Pence, Chance Taylor Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 HALLIBURTON I Sperry Drilling DAILY SUMMARY 05/26/2013 SDL continues on location from previous well. Move rig. 05/27/2013 Ih SDL continues on location from previous well. Spot and set mudlogging shack. Wait on the unit to warm up before rigging up. Began rigging up gas trap and ran gas line to the unit. Rigged up network connection with MWD and WITS to Canrig and Petrolink. 05/28/2013 Continue rig up operations. Rig up suitcases and test. Pick up 5" drill pipe and perform 13-3/8" dummy hanger run. Fill conductor and check for leaks. Pick up first half of clean out BHA#1 and perform diverter test. 05/29/2013 Drill out conductor to 160' MD. Pull out of hole and pick up second half of BHA#1.Shallow hole test tools. Drill ahead to 310' MD and pull out of hole. Pick up BHA#2. Drill ahead from 310' MD to 1522' MD. Gas: The max gas was 84 units at 1485' MD. Geology: No samples collected during surface section. 05/30/2013 Drill ahead from 1522' MD to 3150' MD. Gas: The max gas was 553 units at 1896' MD. Geology: No samples collected during surface section. 05/31/2013 Drill ahead from 3150' MD to surface section TD of 3960' MD. Circulate bottoms up twice and back ream out of hole per K&M representative. Lay down BHA#2. Gas: The max gas while drilling was 221 units at 3763' MD. The max gas while back reaming was 615 units. Geology: No samples collected during surface section. 06/01/2013 Run in hole with 13-3/8" casing. Make up landing joint, break circulation and land hanger. Set the casing shoe at 3950' MD. Circulate bottoms up twice. Gas: The max gas was 142 units. 06/02/2013 Condition mud for the cement job and cement 13-3/8" casing. Lay down landing joint and rig down cement equipment. Nipple down diverter and nipple up BOP. Load 5" drill pipe in pipe shed. Gas: The max gas was 94 units. 06/03/2013 Change out saver sub and pick up 5" drill pipe. Set test plug and test BOP's. Pull test plug and install wear ring. Test 13-3/8" casing to 2500 psi for 30 minutes. Gas: N/A HALLI BU RTON I Sperry Drilling 06/04/2013 Cut and slip drill line. Pick up BHA#3 and run in hole to top of plug at 3865' MD. Circulate bottoms up and drill shoe track from 3868' MD to 3950' MD. Drill 20' rat hole to 3980' MD. Circulate hole clean and displace mud to LSND. Rig up and perform LOT to 12.74 ppg EMW. Pull out of hole and lay down BHA#3. Pick up BHA#4 and run in hole to 1183' MD. Perform shallow hole test. Gas: The max gas was 20 units. 06/05/2013 Continue to run in hole to 3897' MD. Wash down to 3980' MD. Drill ahead from 3980' MD to 6680' MD. Gas: The max gas was 204 units at 4349' MD. Geology: Samples consist mainly of sand with some silt and occasional coal cuttings. 06/06/2013 Drill ahead from 6680' MD to 9030' MD. Gas: The max gas was 54 units at 8845' MD. Geology: Samples consist of clean sands with occasional silt. 06/07/2013 Drill ahead from 9030' MD to intermediate section TD of 11746' MD. Circulate bottoms up. Gas: The max gas was 1080 units at 10712' MD. Geology: Samples consist mainly of clean sands and became more silty towards bottom of N- Sands. 06/08/2013 Shoot survey and down link per Schlumberger. Circulate bottoms up once while pulling out of hole from 11746' MD to 11647' MD. Back ream out of hole from 11647' MD to 4550' MD per K&M representative. Gas: The max gas was 90 units. 06/09/2013 Continue to back ream out of hole to 1188' MD. Circulate bottoms up four times. Pull out of hole from 1188' MD to 254' MD. Lay down BHA#4. Pull wear bushing and set test plug. Change out top rams to 9-5/8" and test. Pull test plug and set mod wear bushing. Rig up casing equipment and make up shoe track to 157' MD and test floats. Run in hole with 9-5/8" casing. Gas: The max gas was 57 units. 06/10/2013 Finish running in the hole with 9 5/8" casing. Proceed to fill pipe. Add water at 15 bbl per hour and circulate. 06/11/2013 Circulate and condition mud. Test lines. Nipple down BOPE. Set emergency slips. Install pack off and test. Nipple up BOP. Rig up to pump freeze protect. 06/12/2013 Close out top pipe rams. Pick up 102 stands of 4.5" drill pipe and rack back into derrick. Slip and cut the drill line. Set test plug. Rig up and test BOPE. HALLIBURTON Sperry Drilling 06/13/2013 Complete BOPE testing. Make up BHA#5. Run in the hole with logging cement bonding from 8900' MD to float collar. Test casing to 3000 psi for 30 minutes. Begin to displace LSND mud with OBM. 06/14/2013 Displace the mud. Break circulation to clean out the shoe track and rat hole from 11746' MD to 11766' MD. Drill 20' of new hole from 11746' MD to 11766' MD. Back ream out of hole from 11766' MD to 11736' MD. Perform a FIT test. Drill 8.75" hole from 11766' MD to 11988' MD. Gas: The max gas was 938 units. Geology: Samples consist mainly of clean sands. 06/15/2013 Drilled 8.75" hole from 12921' MD to 15338' MD. Gas: The max gas was 1191 units Geology: Samples consist mainly of clean sands. 06/16/2013 Continue to drill 8.75" hole from 15338' MD to 17024' MD. Losses of 845 bbl. Monitor well for breathing. Gas: The max gas was 1130 units Geology: Samples consist mainly of clean sands. 6/17/2013 Continue to drill 8.75" hole from 17024' MD to 18943' MD. Monitor well for breathing. Rig is experiencing issues with Can Rig data transfer. Gas: The max gas was 1052 units Geology: Samples consist mainly of clean sands. 6/18/2013 Continue to drill 8.75" hole from 18943' MD to 20377' MD. Monitor well for breathing. Continue to experience problems with Can Rig, including a total failure. Gas: The max gas was 940 units Geology: Samples consist mainly of clean sands. 6/19/2013 Continue to drill 8.75" hole from 20377' MD to TD at 21258' MD. Can Rig technician arrived after hole was TD. Begin to back ream out of hole. Gas: The max gas was 973 units Geology: Samples consist mainly of clean sands. 6/20/2013 Back ream out of hole to a depth of 8521'MD. Can Rig technician has been working on system but still experiencing problems. Gas: The max 9 as was 0 units Geology: Samples consist mainly of clean sands. HALLIBURTON I Sperry Drilling 6/21/2013 Continue to pull out of hole. Lay down BHA#5. Run in hole with hole opener to 11502' MD filling every 25 stands. Cut and slip drill line, service draw works brakes and top drive. Perform exhale test for one hour with 24 bbls returned. Run in hole to 15875' MD. 6/22/2013 { Continue to run in the hole with hole opener. Wash and ream the hole to 21244' MD. 6/23/2013 Spot the breaker throughout the open hole and begin pulling out of hole. Continue to pull out of the hole inside the casing and displace the 9.3 ppg Faze Pro mud with 9.0 ppg KCI Brine. 6/24/2013 Circulate while rigging up 4.5" liner equipment. Run in the hole with liner to 7350' MD. 6/25/2013 Run in the hole with 4.5" liner to 9730' MD. Make up liner hanger. Continue to run in the hole 4.5" liner with 5" drill pipe. Set liner at 21230' MD. Test packer. Pull out of hole to 11235' MD. Slip and cut drill line. Pull out of hole to 6150' MD. 6/26/2013 Pull out of hole from 6150' MD. Lay down packer running tool. Run 4.5" completion tubing to 11418' MD. Land hanger. Test hanger to 5000 psi for 10 minutes. Rig up to set and test packer. Pull landing joint and lay down. Lay down drill pipe. Ij HA:L.LIBUR'TC`Y' Sperry Qrining WELL NAME: SI19-FN2 Days vs. Depth LOCATION: North Slope OPERATOR: ENI Petroleum AREA: Spy Island MUD CO: MI Swaco STATE: Alaska RIG: Doyon 15 SPUD: 29 May 2013 SPERRY JOB: AK-AM-900480746 TD: 19 June 2013 0 ' Commenced 16"Surface 26 May 2013 1000 --- , Hole Section —__ --- Sperry SDL continues on location-- On Bot:04:00 29 May 2013 from previous well 2000 ---- , —' TD Surface Hole Section --- --- I 3960' MD,2445'TVD Prognosed Off Bot:08:45 31 May 2013 —Actual 3000 ---- : IIIIIIIIIIIIIII ', 4000 ---- ,2.��`� Commenced 12.25' Intermediate— Eprmak Hole Section Iteteg mill i- , On Bot 0300 05 Jun 2013 _ =� _' 5000 - --- Landed 13 3/8"Casing- 6000 — 3950'MD,2443'TVD -- -- I E --- . — ---- 01 Jun 2013 so 7000 --- 8000 ---- --- -- --- --- --- ---- t 9000 ---- --- ■ -- -- 10000 ---- --- — --- Commenced 8.75"Production— 0 - Hole Section — On Bot:07:15 14 Jun 2013 -- 11000 TD Intermediate Hole Section -- — — €__ 1 22 -°- 11746' MD,3747'TVD - � - Off Bot:23:45 07 Jun 2013 (A 12000 -- — --- , -- 13000 1 , - _ ---- Landed 9 5/8"Casing — ---- 11731'MD,3746'TVD 14000 ---- ---- 10 Jun 2013 _-- I 1 15000 ---- --- --- --- --- 16000 ---- --- --- --- 17000 ---- --- --- --- 18000 ---- --- --- --- i� - .. _.'... 19000 ---- --- --- _ s 20000 ---- --- --- --- — s TD Production Hole Section 21000 ---- — 21258' MD, 3745'TVD — --- Off Bot:09:15 19 Jun 2013 22000 - ---- _ -- --- --- --- 23000 - , . r , � � '- i i_ 0 5 10 15 20 25 30 35 Rig Days 11-4p. —Lillural-T Surface Data Lo • . „3 6 �sr gr r P.Elk"r �� After Action Review , w. WELL NAME: S119-FN2 LOCATION: North Slope OPERATOR: ENI Petroleum AREA: Spy Island SPERRY JOB: AK-AM-900480746 STATE: Alaska RIG: Doyon 15 HOLE SECTION: Surface EMPLOYEE NAME: Leigh Ann Rasher DATE: 1-Jun-2013 What went as, or better than, planned: Surface section was completed with no major issues. Difficulties experienced: The only issue with INSITE was the pit volume total, auxilary total, and pit volume change were not tracking after starting the new well. This was fixed by going into the INSITE program on the IRIS computer and resetting the pits. Also the gas trap had to be adjusted a few times while drilling due to mud levels in the flow line dropping. Recommendations: Make sure to check all INSITE configurations after creating a new well or run. Also frequently check the lower gas trap while in use to make sure it is adjusted accordingly with mud levels in the flow line. Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v3.0 FIALL1 BUR"rrh *= Surface Data Logging 3p ray CIrrit!grog. After Action Review WELL NAME: SI19-FN2 LOCATION: North Slope OPERATOR: ENI Petroleum AREA: Spy Island SPERRY JOB: AK-AM-900480746 STATE: Alaska RIG: Doyon 15 HOLE SECTION: Intermediate EMPLOYEE NAME: Leigh Ann Rasher DATE: 8-Jun-2013 What went as, or better than,planned: Gas equipment fucntioned well with no major problems or lost data. Difficulties experienced: The only major problem experienced in intermediate section was bit depth being thrown off during connections causing no new footage while drilling a new stand. Recommendations: Make sure to check bit depth during every connection. Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v 3.0 Surface Data Logging SpEsrry C)r.ill r q After Action Review WELL NAME: Sl19-FN2 LOCATION: North Slope OPERATOR: ENI Petroleum AREA: Spy Island SPERRY JOB: AK-AM-900480746 STATE: Alaska RIG: Doyon 15 HOLE SECTION: Production EMPLOYEE NAME: A.Paul Kalenuik DATE: 20-Jun-2013 What went as, or better than,planned: Logging unit equipment functioned as planned. There were no issues to report with the functioning of the Insite software. Difficulties experienced: Can Rig services were sporadic at best. They sent data in an interrupted format or not at all. By the end of the well they were not functioning at all. The service response was poor. Recommendations: Keep a close eye on bit depth when making connections. Innovations and/or cost savings: Add a monitor to the drill floor to enable the driller to see our data frist hand. Sperry Drilling Confidential Document v 3.0 f-IALLIBLIRTOIV _. ��,,,,, ...... Formation Tops WELL NAME: SI19-FN2 LOCATION: Spy Island OPERATOR: ENI Petroleum AREA: North Slope MUD CO: M I Swaco STATE:Alaska RIG: Doyon 15 SPUD: 29-May-2013 SPERRY JOB:AK-AM-0900480746 TD: 19-Jun-2013 Marker MD INC AZ TVD TVD55 16"Surface Borehole 20"Conductor Shoe 160 0.3 213.7 160 -106.4 SV-4 775 15.6 304 770.4 -716.7 SV-3 1,150.00 30.1 302.6 1,116.70 -1063 SV-2 1,454.00 39.1 306.4 1,369.60 -1315.9 Permafrost Base 1,948.00 43.5 308.2 1,747.00 -1693.3 SV-1 2,228.00 53.5 306 1,929.00 1,928.90 Ugnu Top(UG4) 2,911.00 72.9 293.5 2,251.10 2,250.80 13 3/8"Casing Shoe 3,950.00 79.4 297.8 2,443.60 -2390 TD 16"Borehole 3,960.00 79.3 298.2 2,445.50 -2391.9 12 1/4"Intermediate Borehole UG-2 Coal Bed Marker 5,406.00 79.5 291.8 2,706.20 -2,652.50 Lower Ugnu 8,960.00 79.7 293.3 3,299.50 -3,245.80 Schrader Bluff Top 10,062.00 79 296.2 3,541.40 -3,487.70 N Sequence Top 10,179.00 79.6 299.9 3,563.40 -3,509.70 N Sand Top 10,436.00 80.1 306.4 3,609.10 -3,555.40 N-2 Top 10,519.00 81.1 307.7 3,622.70 -3,569.00 N-3 Top 10,653.00 82.7 308.3 3,641.70 -3,588.00 N Sand Bottom 10,800.00 83.3 306.8 3,659.50 -3,605.80 N-Sequence Base 11,173.40 83.7 306.8 3,702.60 -3,648.90 9 5/8"Casing Shoe 11,731.00 85.8 318.8 3,745.60 -3,691.90 TD 12 1/4"Borehole 11,746.00 85.8 318.8 3,746.70 -3,693.00 8 3/4"Lateral Borehole OA Top 11,891.00 86.9 321.5 3,757.00 -3,703.30 OA-2 Top 12,747.00 90.1 322.5 3,767.20 -3,713.50 OA-3 Top 12,969.00 86.7 321.6 3,769.60 -3,715.90 OA-3 Top 13,777.00 92.3 324.3 3,766.20 -3,712.50 OA-2 Top 13,990.00 90.4 322.8 3,762.70 -3,709.00 OA-2 Top 14,683.00 90.5 317.8 3,754.10 -3,700.40 OA-2 Top 14,886.00 91.1 316.8 3,750.60 -3,696.90 OA-2 Top 15,612.00 86.5 315.6 3,754.10 -3,700.40 OA-3 Top 15,842.00 88 314.5 3,761.10 -3,707.40 OA-4 Top 16,055.00 87.8 310.4 3,771.00 -3,717.30 OA-4 Top 16,234.00 91.6 310.3 3,771.50 -3,717.80 OA-3 Top 16,566.00 90.6 312.7 3,764.60 -3,710.90 OA-3 Top 16,660.00 88.5 312.5 3,765.30 -3,711.60 OA-4 Top 16,782.00 87.9 311.9 3,769.90 -3,716.20 OA-4 Top 16,925.00 91.2 311.6 3,770.60 -3,716.90 OA-3 Top 17,714.00 91.8 313.3 3,765.30 -3,711.60 OA-3 Top 17,906.00 90.1 310.5 3,763.20 -3,709.50 OA-3 Top 18,400.00 91 311.1 3,758.00 -3,704.30 OA-2 Top 18,747.00 88.7 310.5 3,754.40 -3,700.70 OA-2 Top 19,494.00 90.5 308.8 3,757.20 -3,703.50 OA-2 Top 19,611.00 93 309 3,753.90 -3,700.20 OA-2 Top 19,999.00 87.7 307.2 3,753.80 -3,700.10 OA-3 Top 20,322.00 88.3 306.6 3,761.00 -3,707.30 Fault C 20,558.00 90.6 305.7 3,765.10 -3,711.40 OA-4 Top 20,573.00 91.1 305.7 3,764.70 -3,711.00 OA-4 Top 20,742.00 92.7 303.9 3,757.60 -3,703.90 OA-3 Top 20,879.00 92.8 301.1 3,751.20 -3,697.50 OA-2 Top 20,993.00 92.3 299.6 3,746.00 -3,692.30 TD 8 3/4"Borehole 21,258.00 89.6 298.2 3,745.30 -3,691.60 - HALLIBURT0IV , Show Report .R Report prry Drilling Se M{ Well Name: S119-FN2 Depth (MD) 10400 to 11100 ft Location: Spy Island _ (TVD) 3600 to 3686 ft Operator: ENI Petroluem Report Prepared By: Leigh Ann Rasher Formation: N-Sand Report Delivered To: Andrew Buchanan Date: 7-Jun-2013 Interpretation: No producible oil within zones 1 through 3. Producible gas within zone 4 based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 10433 ft Gas Units 304 Mud Chlorides(mg/L)= 1400 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 37744 - 3996 = 33748 C1/C2 = 104 1000 _ C2 345 - 20 = 325 C1/C3 = 536 — — C3 66 - 3 = 63 C1/C4 = 1250 - --Aill 1 C4 27 - 0 = 27 C1/C5 = 6750 NPH C5 5 - 0 = 5 Production 100 - _ Analysis f Gas f oil 71Water pi: Non-Producible Hydrocarbons - - -- - Depth 10633 ft Gas Units 544 Mud Chlorides(mg/L)= 1400 Gas Flowline Background Show I - - -- PPm PPm PPm Hydrocarbon Ratios 10 - C1 67185 - 4825 = 62360 C1/C2 = 87 = C2 781 - 65 = 716 C1/C3 = 264 C3 256 - 20 = 236 C1/C4 = 671 Oil C4_ 103 - 10 = 93 C1/C5 = 538 -_-- C5 116 - 0 = 116 NPH Production 1 Analysis f Gas f Oil f Water nNon-Producible Hydrocarbons • Hydrocarbon Ratios Depth 10712 ft Gas Units 1021 Mud Chlorides(mg/L)= 1400 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 PPm PPm PPm -- __ Hydrocarbon Ratios 1000 - C1 118327 - 5371 = 112956 C1/C2 = 82 C2 1442 - 70 = 1372 C1/C3 = 191 C3 618 27 = 591 C1/C4 = 377 NPH C4 322 - 22 = 300 C1/C5 = 323 C5 352 - 2 = 350 --'imAll0 - Production 100 - Analysis fGas f Oil f Water nNon-Producible Hydrocarbons • Depth 11003 ft Gas Units 403 Mud Chlorides(mg/L)= 1400 Gas Flowline Background Show - - -" PPm PPm PPm —_ -_ -__ Hydrocarbon Ratios 10 L—_ C1 33146 - 7389 = 25757 C1/C2 = 65 C2 510 - 114 = 396 C1/C3 = 69 Oil C3 486 - 115 = 371 C1/C4 = 104 C4 523 - 275 = 248 C1/C5 = 51 C5 691 - 189 = 502 NPH 1 Production Analysis NGas foil f Water fNon-Producible Hydrocarbons HALLIBUR I QNI pry r•ry Grilling Show Report Report# 2 p Well Name: S119-FN2 Depth (MD) 12031 to 14140 ft Location: Spy Island (TVD) 3766 to 3920 ft Operator: ENI Petroluem Report Prepared By: Paul Kalenuik/Kori Jo Plowman Formation: OA Sands Report Delivered To: Andrew Buchanan Date: 22-Jun-2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. ,.•111 .................�,....................................,.................,.......................•Hydrocarbon Ratios.•..,•................ Depth 12031 ft Gas Units 927 Mud Chlorides(mg/L)= 135000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 109485 - 3811 = 105674 C1/C2 = _ 130 1000 C2 870 - 58 = 812 C1/03 = 208 - - C3 559 - 51 = 508 C1/C4 = 222 - C4 535 - 58 = 477 C1/C5 = 700 NPH ' C5 164 - 13 = 151 .1. ''. -:..--- Production 100 - Analysis nGas nail Water nNon-Producible Hydrocarbons 121 - Depth 12637 ft Gas Units 674 Mud Chlorides(mg/L)= 145000 Gas Flowline Background Show - - ---- PPm PPm PPm - _ _ -_- - - - - -- Hydrocarbon Ratios 10 01 78035 - 2650 = 75385 C1/C2 = 103 C2 793 - 63 = 730 C1/C3 = 154 C3 573 - 85 = 488 C1/04 = 490 Oil C4 308 - 154 = 154 C1/C5 = 299 -- - C5 330 - 78 = 252 NPH Production 1 Analysis nGas nail nWater nNon-Producible Hydrocarbons • Hydrocarbon Ratios Depth 14697 ft Gas Units 743 Mud Chlorides(mg/L)= 132000 01 C1 C1 Cl Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 Cl 72587 - 4640 = 67947 C1/C2 = 102 =__C2 739 - _ 112 = 627 _ C1/C3 = 140 - - -- -- C3 553 142 = 411 C1/C4 = 140 NPH - C4 624 - 838 = -214 C1/C5 = 208 05 429 - 272 = 157 Production 100 _ --- Analysis nGas nOil nWater nNon-Producible Hydrocarbons Depth 14140 ft Gas Units 816 Mud Chlorides(mg/L)= 134000 Gas - Flowline Background Show ---- -------- --- r ppm ppm ppm - Hydrocarbon Ratios 10 C1 87030 - 72387 = 14643 01/02 = 115 C2 847 - 720 = 127 01/03 = 183 Oil C3 623 - 543 = 80 C1/C4 = 488 -. • - 04 373 - 343 = 30 C1/C5 = 159 - - --- -- - • _ - C5 417 - 325 = 92 NPH 1 Production Analysis nGas nOil nWater nNon-Producible Hydrocarbons FIALLIBUPITON Sperry Orillinc Show Report Report# 3 Well Name: S119-FN2 Depth (MD) 15400 to 18876 ft Location: Spy Island (TVD) 3746 to 4264 ft Operator: ENI Petroluem Report Prepared By: Paul Kalenuik/Kori Jo Plowman Formation: OA Sands Report Delivered To: Andrew Buchanan Date: 22-Jun-2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 15472 ft Gas Units 905 Mud Chlorides(mg/L)= 13500 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 94496 - 4633 = 89863 C1/C2 = 121 1000 C2 857 - 113 = 744 C1/C3 = 167 C3 658 - 121 = 537 C1/C4 = 122 6 C4 906 - 169 = 737 C1/C5 = 4279 NPH C5 157 - 136 = 21 — ._► Production 100 _ Analysis nGas Moil Water ANon-Producible Hydrocarbons _—_——" - -— �,� — - Depth 16530 ft Gas Units 1121 Mud Chlorides(mg/L)= 145000 Gas Flowline Background Show — PPm PPm PPm Hydrocarbon Ratios 10 _ C1 78035 - 2650 = 75385 C1/C2 = 103 . C2 793 - 63 = 730 C1/C3 = 154 C3 573 - 85 = 488 C1/C4 = 490 Oil C4 308 - 154 = 154 C1/C5 = 299 — C5 330 - 78 = 252 NPH Production 1 Analysis []Gas nOil nWater [Non-Producible Hydrocarbons III Hydrocarbon Ratios Depth 17280 ft Gas Units 987 Mud Chlorides(mg/L)= 142000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 _ Cl 50439 - 4640 = 45799 C1/C2 = 64 — - C2 830 - 112 = 718 C1/C3 = 132 C3 489 142 = 347 C1/C4 = 105 NPH C4 624 - 186 = 438 C1/C5 = 1696 C5 36 - 9 = 27 Production A 100 Analysis nGas []Oil []Water nNon-Producible Hydrocarbons Depth 18876 ft Gas Units 821 Mud Chlorides(mg/L)= 138000 Gas Flowline Background Show — —— ppm ppm ppm Hydrocarbon Ratios 10 --C1 62712 19986 42726 C1/C2 = 305 C2 283 143 = 140 C1/C3 = 668 Oil i C3 196 - 132 = 64 C1/C4 = 257 — -- - i C4 209 - 43 = 166 C1/C5 = 356 C5 132 - 12 = 120 NPH1 Production fAnalysis nGas nail MWater nNon-Producible Hydrocarbons HALLII13LiR1 0NI .pExrry Car-ining Show Report Report# 4 Well Name: Sl19-FN2 Depth (MD) 19000 to 21200 ft Location: Spy Island (TVD) 4273 to 4433 _ ft Operator: ENI Petroluem Report Prepared By: Paul Kalenuik/Kori Jo Plowman Formation: OA Sands Report Delivered To: Andrew Buchanan Date: 22-Jun-2013 Interpretation: No producible oil within zones 1 or 3. Producible gas within zones 2 and 4 based upon gas and chromatograph data collected. Ili............. ......................................... ....................... _ ...............•Hydrocarbon Ratios.....•.��-........... Depth 19039 ft Gas Units 585 Mud Chlorides(mg/L)= 13900 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 36568 - 7254 = 29314 C1/C2 = 56 1000 C2 522 - 0 = 522 C1/C3 = 104 C3 281 - 0 = 281 C1/C4 = 0 - C4 0 - 32 = -32 C1/C5 = 0 NPH C5 0 - 0 = 0 Production 100 _ Analysis []Gas nOil -17VVater nNon-Producible Hydrocarbons Depth 19836 ft Gas Units 767 Mud Chlorides(mg/L)= 145000 Gas Flowline Background Show _____ PPm PPm PPm Hydrocarbon Ratios 10 C1 35268 - 988.3 = 25385 C1/C2 = 40 C2 640 - 0 = 640 C1/C3 = 69 C3 370 - 0 = 370 C1/C4 = 0 Oil C4 0 - 0 = C1/C5 = 0 - — C5 0 - 0 = NPH Production 1 Analysis nGas []Oil []Water []Non-Producible Hydrocarbons • Hydrocarbon Ratios Depth 20796 ft Gas Units 949 Mud Chlorides(mg/L)= 128000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 36047 - 4640 = 31407 C1/C2 = 67 C2 579 - 112 = 467 C1/C3 = 212 re...._ C3 290 142 = 148 C1/C4 = 50 NPH C4 624 - 0 = 624 C1/C5.= 0 . C5 0 - 0 = 0 Production 100 __ - Analysis nGas []oil []Water []Non-Producible Hydrocarbons ►- 141 _ Depth 21074 ft Gas Units 726 Mud Chlorides(mg/L)= 133000 Gas . Flowline Background Show _ _ _ __--- --- PPm PPm PPm ___ _ - Hydrocarbon Ratios 10 Cl 62712 6326 = 56386 C1/C2 = 154 C2 509 143 = 366 C1/C3 = 641 Oil C3 220 - 132 = 88 C1/C4 = 340 C4 209 - 43 = 166 C1/C5 = 470 C5 132 - 12 = 120 NPH 1 - Production IAnalysis []Gas []oil []Water nNon-Producible Hydrocarbons I HALLIBURTON Spa,-, ,3 : : , Water and Oil Based Mud Record CO O W a cs8o ° - < < � Ow8 � L v -2 >_ 'C WC OS , ❑ xuOWO � °o 1'..' n_ = , _ E0IIOm iti ❑ (/l CT 0 O 7'I N N [D O a0 O 0 : C= 6 ,-- , , , , 0 ,3 O d a O E• - "° W cO � � � Um ° a S ,I-T❑ E o�mal mo g 0-• -1,7) 08 U ❑ O W coo — O a ❑ ❑ ❑ ❑ ❑ I O a U a pa_ m a a + V. 0 •- 0 o o (0 0 0 o V) y 0 2 U N v05' m m m m m C C (0 0 m . rn o N W m N N .ir. 6 O O O oo o o o o o o o 0 0 0 I a 0 M N ui O' N U E N N C m M ,- . . 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N 4. u:,6 ❑ 77777777777 N N [") N N N N N N N ■ HALLIBURTON Sperry Drilling ------ Bit Record Q F- ❑ F m N - o N co O • Ol N U U• r U d a < 0 F- m ~ F z p z O _ Z W X X Q U) m Q r H S m 2 a C7'' • E N o 0 0 o W h CO L0 LL M N N• w OO a ON o r CO M CL N• N !n E N N w• Z Q N Z Q W d d 2Z' O O m a s m ro m Q Q N CO U O 0 m 0 0 CD v E }d co 0 (0 0 <r re m — N � N Q 88 O u CO CO m ~ o o o m o' r o O° m O o N 0 (0 = N 0 � (LE 0 O O O t0(0 O N N h O M m 5.LL W co co o ❑ J M m ^ N co O V N C O L O OD O O V N O 0 m (N N N O O O O M M .- Z ❑ m as o Q _ Co Co �„ o f0 N N (n W n p Q m co W O_ o m U U <• O o U O U ❑ ❑ Za p >_ ❑t a a > o U U ❑ J W W 2>3 --`O W w W • o a In '- (D X n n O m Y Y Y co N N O I � = f0 l9 U S _ _ N CO V m 1 p Z O O O O • 0 N 0M °y = N ((l HQLLEBURTC3N Sp©rry D.-4fl nco Morning Report Report#1 Customer: ENI Petroleum Job No.: AK-AM- Yesterdays Depth: 0' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 0' Area: Spy Island Total Charges: $4,710.00 24 Hour Progress: 0' Location: North Slope Rig Activity: Pre Spud Rig Up Date: 27-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr) ---- Flow In ••m SPP(•si) ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary 0, D ipth o Tools ECD (ppg)=== .----- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) ••b Eq) cP (Ib/100ft2) m1/30min m./1 % -----m ------ -r Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Size Set At Type Weight Grade Comments Casing Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) -_---------_ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) Fr " __ 24 hr Recap: Continue to move rig to SI19-FN2.Spot rig over well.Spot pits.M/U diverter line.Mudlogging unit spotted and rigged up. I Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 Sp©rry Orit lines Morning Report Report#2 Customer: EM Petroleum Job No.: AK-AM- Yesterdays Depth: 160' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 160' Area: Spy Island Total Charges: $7,520.00 24 Hour Progress: 0' Location: North Slope Rig Activity: Diverter test Date: 28-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr ---- Flow In •im) SPP(•si ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 ww n> MWD Summary Depth Tools •ECD (ppg) • Min Max 0' to 0' Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) ppb Es) cP (Ib/100ft2) ml/30min mg/I % 62' Gel Mud 8.70 92 22.5 20 35 7.0 9.40 1200.00 2.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hushes MX-1 Milltooth 16" 1.117 - 160' ---- ' . . ...,...: ,::,' _. _ _� ._.. .te. ._ .w. .: Size Set At Type Weight Grade Comments Casing Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) __-_-------- Gas Summary Chromatograph (ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) : r 24 hr Recap: Cont.R/U ops.R/U suitcases&test.P/U 5"DP.Perform 13 3/8"dummy hanger run.Fill conductor&check for leaks.P/U BHA#1.Perform diverter test. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 1 HALL[Bl.1FiTON � Morning Re « Sporry E]rlllinco Customer: ENI Petroleum Job No.: AK-AM- Yesterdays Depth: 160' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 1522' Area: Spy Island Total Charges: $10,330.00 24 Hour Progress: 1362' Location: North Slope Rig Activity: Drill 16" Hole Date: 29-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 272.5 1683.1 281' Flow In(..m) 681 SPP(psi) 1149 ---- Flow In(spm) 161 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg>Mr. Min Max 160' to 1522' SP Motor 1.83,GyroPulse,TeleScope 825,ARC 825 9.70 8.73 10.68 l. Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) •.b Eq) cP (Ib/100ft2) ml/30min mg/I % 1343' Gel Mud 9.30 72 24.3 19 30 6.0 9.10 2400.00 3.5 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hu•hes MX-1 Milltooth 16" 1.117 - 160' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) --_--------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 84 1485' 10681 0 0 0 0 0 0 Minimum 2 555' 88 0 0 0 0 0 0 Average 19 2078 0 0 0 0 0 0 Background 28 Trip Connection * 10,000 Units = 100%Gas In Air (current) (max) max 24 hr Recap: Drill out conductor to 160'MD.POH.P/U BHA#1.Shallow hole test tools.Drill ahead to 310'MD&POH.P/U BHA#2. RIH&drill ahead to 1522'MD. Max gas observed in the past 24 hrs was 84 units @ 1485'MD.No samples are collected during surface section. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HA4E.LItBRJRTQN Morning Report Report#AV Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterdays Depth: 1522' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 3150' Area: Spy Island Total Charges: $13,140.00 24 Hour Progress: 1628' Location: North Slope Rig Activity: Drill 16" Hole Date: 30-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) 360.9 214.6 917.1 2569' Flow In *pm) 749 SPP(psi 1713 ---- Flow In(spm) 177 Gallons/stroke 4.23 @ 0.96 .- IT ,� .� �� __.. __ . .. w . v. I .__.-.7 ,_ ._..__ _ _ 7:77w ��. MWD S i Depth Tools �;' Min Max Summary 1522' to 3150' SP Motor 1.83,GyroPulse,TeleScope 825,ARC 825 ECD (ppg) 9.93 9.58 10.48 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) •.b Eq) cP (Ib/100ft2) ml/30min mg/I % 2920' Gel Mud 9.40 76 25.0 27 28 5.3 9.30 1000.00 5.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 - 160' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary I Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) __---------- Gas Summary it Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 553 1896' 77707 0 0 0 0 0 0 Minimum 8 1857' 317 0 0 0 0 0 0 Average 78 9619 0 0 0 0 0 0 Background 58 Trip Connection * 10,000 Units = 100% Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 1522'MD to 3150'MD.Max gas observed in the past 24 hrs was 553 units @ 1896'MD.No samples collected during surface section. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 L-114.11—LIBRJR"Ti OIV Sp+enrry drilling Morning Report - Report#5 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterdays Depth: 3150' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 3960' Area: Spy Island Total Charges: $15,950.00 24 Hour Progress: 810' Location: North Slope Rig Activity: Clean Rig Floor Date: 31-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 . . . ROP Current Avg 24 hr Max Max a@ ft Current Pump & Flow Data: P ROP(ft/hr) 266.2 1099.1 3412' Flow In ••m) SPP (psi) ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 r MWD Summary Depth Tools ECD (ppg)E'er Min Max 3150' to 3960' SP Motor 1.83,GyroPulse,TeleScope 825,ARC 825 10.20 9.74 10.85 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 3960' Gel Mud 9.40 61 25.0 18 25 5.9 9.30 900.00 5.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hushes MX-1 Milltooth 16" 1.117 - 160' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 0 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ . emu , Gas Summary Chromatograph (ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 221 3763' 26633 0 0 0 0 0 0 Minimum 41 3411' 5405 0 0 0 0 0 0 Average 109 16336 0 0 0 0 0 0 Background Trip 615 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) . 24 hr Recap: Drill ahead from 3150'MD to surface section TD of 3960'MD.CBU x2,BROOH per K&M rep.L/D BHA#2.Max gas observed while drilling was 221 units @ 3763'and 615 units while BROOH.No samples collected during surface section. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 H/ 1-LiIl3vRI-C3r4 -------- Sperry Elriliiny Morning Report Report#6 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 3960' Well: S119-FN2 Daily Charges: $3,810.00 Current Depth: 3960' Area: Spy Island Total Charges: $19,760.00 24 Hour Progress: 0' Location: North Slope Rig Activity: Circ&Cond Mud Date: 1-Jun-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 [7:7.... _ n w_. ...._ _ 77 T-.: ' ,_ . 7: ,_ . °, ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In •.m) 195 SPP (psi) 127 ---- Flow In(spm) 45 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max 3960' to 3960' --- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (p.b E. cP (Ib/100ft2) ml/30min ms/I % 3960' Gel Mud 9.40 102 32 32 7.80 -- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hushes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) --------_--- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 142 Connection * 10,000 Units = 100% Gas In Air (current) (max) (max) m.. 24 hr Recap: RIH w/13 3/8"csg.M/U landing jt,brk circ&land hanger,csg shoe set @ 3950'MD.CBU x2. Logging Engineers: Leigh Ann Rasher/Clifton Posey Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 ' 31°Z ry `HALLL L.JRTQF I r � „.. Epetrry Orlling 0■�■�� /. "d 1 ; - t , Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterdays Depth: 3960' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 3960' Area: Spy Island Total Charges: $22,570.00 24 Hour Progress: 0' Location: North Slope Rig Activity: N/U BOPs Date: 2-Jun-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In •.m) SPP(psi) ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max 3960' to 3960' --- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) •.b E•) cP (Ib/100ft2) ml/30min mg/I % 3960' Gel Mud 9.50 46 21 13 7.80 -- u .;' m - ti . Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hushes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Ilk Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 94 Connection * 10,000 Units = 100% Gas In Air (current) (max) (max) 24 hr Recap: Condition mud.Cmt 13 3/8"csg. L/D land jt&R/D cmt equip.N/D diverter.N/U BOP. Load 5"DP in pipe shed. Logging Engineers: Leigh Ann Rasher/Clifton Posey Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HQLL BUR"rON1 r SPQrrY ,,j;�. _..__.____ Morning Report Report#8 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterdays Depth: 3960' Well: S119-FN2 Daily Charges: $3,410.00 Current Depth: 3960' Area: Spy Island Total Charges: $25,980.00 24 Hour Progress: 0' Location: North Slope Rig Activity: Clean rig floor Date: 3-Jun-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In 'pm) SPP *Si ---- Flow In (spm) Gallons/stroke 4.23 @ 0 96 :. s MWD Summary Depth Tools ECD (ppg) Avg Min Max 3960' to 3960' --- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (p.b E. cP (Ib/100ft2) ml/30min mg/I 3960' Gel Mud 9.50 47 21 13 7.80 -- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ___--------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: C/O saver sub.P/U 5"DP.Set test plug.Test BOPs.Pull test plug&install wear ring.Test 13 3/8"csg to 2500 psi for 30 min. Logging Engineers: Leigh Ann Rasher/Clifton Posey Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALL,BtJR MINI sFA-ru Chilling Morning Report Report#9 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 3960' Well: SI19-FN2 Daily Charges: $3,410.00 Current Depth: 3980' Area: Spy Island Total Charges: $29,390.00 24 Hour Progress: 20' Location: North Slope Rig Activity: RIH BHA#4 Date: 4-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ft Current Pump& Flow Data: ROP(ft/hr) ---- Flow In(..m _ SPP(•si) ---- Flow In(spm) _ Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD Av. Min Max 3960' to 3980 .111 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (.pb Eq) cP (Ib/100ft2) ml/30min mg/I % 3980 LSND 9.30 50 10 19 6.4 9.70 600.00 4.0 Bit# Bit Type Size ' Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" ® 22.70 160' 3960' 3800' 40.0 40.0 1-1-VVT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E4C PDC 12.25" 0.969 3980' 1:::171:17.7-17712:::.:::,;71. ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) _----------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 20 Connection " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Cut&slip drill line.P/U BHA#3.RIH to top of plug @ 3865.CBU.Drill shoe track f/3868'MD to 3950'MD.Drill rat hole 20'to 3980'MD.Circ hole clean.Displace mud to LSND.R/U&perform FIT to 13.0 ppg EMW.POOH.L/D BHA#3.P/U BHA #4.RIH to 1183'MD.Perform shallow hole test. Logging Engineers: Leigh Ann Rasher/Clifton Posey Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 Hi4LL1BtJRTON •„®.-.-u Civilli., ■ Morning Report Report#10 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 3980' Well: SI19-FN2 Daily Charges: $3,410.00 Current Depth: 6680' Area: Spy Island Total Charges: $32,800.00 24 Hour Progress: 2700' Location: North Slope Rig Activity: Drill 12.25"Section Date: 5-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 . Y. 777777 a 77 X77 .... ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP(ft/hr) 125.1 331.4 617.3 6236' Flow In(•pm) 909 SPP(psi) 1821 ---- Flow In(spm) 215 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD X11 Min Max 3980' to 6680 PowerDrive900,TeleScope 825,ARC 825 ... 10.04 9.53 10.39 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (p•bE•) cP (Ib/100ft2) m1/30min mg/I 6523 LSND 9.30 55 12.5 15 29 5.5 9.50 1100.00 6.0 _ ..._z � ._�,. . . -w u _., YU te. r . .., Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" ® 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E4C PDC 12 25' 0.969 3980 ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 95 -- 5 -------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 204 4349' 27032 0 0 0 0 0 0 Minimum 2 6405' 64 0 0 0 0 0 0 Average 36 1318 0 0 0 0 0 0 Background 7 (current) Trip 25 Connection * 10,000 Units = 100%Gas In Air (max) (max) r L 24 hr Recap: Cont.RIH to 3897'MD.Wash down to 3980'MD.Drill ahead f/3980'MD to 6680'MD.Max gas observed in the past 24 hrs was 204 units @ 4349'MD.Samples consist mainly of sand w/some silt and occasional coal ctgs. I l Logging Engineers: Leigh Ann Rasher/Clifton Posey Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 -I LLIBtJRTOI\I �Elcry oc.,i_n _.___ Morning Report Report#11 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 6680' Well: SI19-FN2 Daily Charges: $3,410.00 Current Depth: 9030' Area: Spy Island Total Charges: $36,210.00 24 Hour Progress: 2350' Location: North Slope Rig Activity: Drill 12.25"Section _ Date: 6-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP(ft/hr) 84.2 274.0 598.3 8192' Flow In(gpm) 908 SPP(psi) 2113 Flow In(spm) 214 Gallons/stroke 4.23 @ 0 96 MWD Summary Depth Tools p ECD Avg Min Max 6680' to 9030' PowerDrive900,TeleScope 825,ARC 825 ... 10.26 10.04 10.51 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in I out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 8654' LSND 9.30 52 15.0 12 26 4 8 9.50 1500.00 5.5 Bit# I Bit Type Size TFA Hours Depth in/out Footage WO RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E4C PDC 12.25" 0.969 3980' Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 54 8845' 6653 0 0 0 0 0 0 Minimum 3 7141' 266 0 0 0 0 0 0 Average 13 1384 0 0 0 0 0 0 II Background 6 Trip 0 Connection 10,000 Units = 100%Gas In Air (current) (max) (max) \ 1 24 hr Recap: Drill ahead f/6680'MD to 9030'MD.Max gas observed the past 24 hrs was 54 units @ 8845'MD.Samples consist of clean sandstone with occassional silt. 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Logging Engineers: A.Paul Kalenuik/Clifton Posey Report By: A.Paul kalenuik Unit Phone 907-685-0772 ■ iiALLIBuFt-ro I Morning Report Report#21 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 15338' Well: Sl19-FN2 Daily Charges: Current Depth: 17024' Area: Spy Island Total Charges: 24 Hour Progress: 1686' Location: North Slope Rig Activity: Drilling Ahead Date: 16-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr) 341.0 75.0 397.0 16872' Flow In •.m) 470 SPP(psi) 2899 ---- Flow In(spm) _ Gallons/stroke 4.23 @ 0.96 r,. =. MWD Summary Depth Tools ECD Av. Min Max to 11.25 -- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (..b Eq) cP (Ib/100ft2) m1/30min mg/I 16850 Fazepro 9.40 9.40 53 19 15 n/a 131000 00 5 1 Bit# Bit Type Size En Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16' ® 22.70 160 3960 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA ME=Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980 11746 7766' 14 180 1-3-WT-A-X-In-BT-TD i' '616r- 1D 8/5 0.902 - 11746 ---- Size Set At Type Weight t -. Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 J # Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 ----------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n IMaximum 1130 16523' 96918 944 825 531 476 459 153 I Minimum 11 198 12 0 0 0 0 0 Average 347 27148 211 204 115 133 20 4 Background 76 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) • 24 hr Recap: Drilling ahead from 15338'MD to 17024'MD.Max gas 1130u at 16523'MD.Monitoring well volumes.Losses of 845 bbl.Continuing to drill 8.75"hole.Monitoring well for breathing. Logging Engineers: A.Paul Kalenuik/Clifton Posey Report By: A.Paul kalenuik Unit Phone: 907-685-0772 II 1 HALLIBLIRTON Sperry Grilling Morning Report Report#22 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 17024' Well: S119-FN2 Daily Charges: $3,410.00 Current Depth: 18831' Area: Spy Island Total Charges: $75,130.00 24 Hour Progress: 1807' Location: North Slope Rig Activity: Drilling Ahead Date: 17-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) NA NA NA NA Flow In(gpm) I 436 I SPP(psi) I 2623 Flow In (spm) Gallons/stroke 4 23 @ 0.96 MWD Summary Depth Tools ECD Avg Min Max to I I (ppg) I 11 25 Mud Data Density(ppg) Viscosity -MB- BT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in _ out _ (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I Vo 18747 Fazepro 9.40 9.40 53 20 16 n/a n/a 138000.00 4.7 ' d.c.._ a ua7 ?: ..:. h..,: T— ,.,,.N ;.*".-' x ;a,1," '",:.. * t',,; Bit# Bit Type _ Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-_BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD 4 SKH616M-E1D 8.75 0.902 1 11746' Size Set At Type Weight ra•e Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology (%) I Ss Cht I Silt I Siltst I Cly Clyst I Sh I Lst I Coal Gvl I Tuff I Cement (current) 100 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n ' Maximum 1052 18713' 68189 830 560 367 351 158 44 k Minimum _ 20 17372' 223 0 0 0 0 0 0 Average 391 27163 168 205 82 88 7 1 Background 111 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) ., 24 hr Recap: Drilling 8.75"hole and monitor well for breathing.Performed exhale test and got returns of 458 bbls for 60 minutes. Experiencing issues with Can Rig data transfer.Interupted data flow.Continuing to drill ahead to 18943'MD at time of report. Logging Engineers: A.Paul Kalenuik/Clifton Posey Report By: A.Paul kalenuik Unit Phone 907-685-0772 HALLIBIJRTON Sperry �rlliing Morning Report Report#23 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 18831' Well: S119-FN2 Daily Charges: $3,410.00 Current Depth: 20514' Area: Spy Island Total Charges: $78,540.00 24 Hour Progress: 1683' Location: North Slope Rig Activity: Drilling Ahead Date: 18-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP(ft/hr) NA NA NA NA Flow In(..m) 438 SPP('Si 2984 ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD MEM Min Max to 11.25 t� `,H,y'r�.' te»sxi: g, yTMsw fs ' 4 �: ¢' ;ii. kaN1iL'S'v46��`� t � ,�`.,..v r a,� ' r ro.�G,saau,:� TL - Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (••b E. cP (lb/100f2) m1/30min mg/I % 20377 Fazepro 9.40 9.40 58 21 16 n/a n/a 138000.00 4.7 Bit# Bit Type Size En Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" ® 22.70 160 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 1.11rM Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD i'M97 1tft!xilla 8.75 0.902 - 11746 ----� ,. 'C:'s^^+"�, T ','sue 5 °€".. h �1 a,Srk r w4°w. ; �� :�� ,,:�. Asti )�:��J :�;�. Size Set At Type Weight Mq02.1111 Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 77..,.. mgr Lithology (%) Ss Cht Silt Siltst CIy Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 --___------ . niE d'r Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 761 19839' 64902 641 385 149 177 35 404 Minimum 140 20277' 110 0 0 0 0 0 0 Average 36 18430 46 70 5 6 7 0 Background 11 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drilled 8.75"hole and monitored breathing from 18834'to 19675'at 448 GPM.Had toal losses of 767 bbls for last 24 hours.Continueing to experience Can Rig problems including total failure.Can Rig tech should be here in morning. Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 HALL1BlJRTON '�"pc-arrX Drilling Morning Report Report#24 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 18831' Well: Sl19-FN2 Daily Charges: $3,560.00 Current Depth: 20514' Area: Spy Island Total Charges: $82,100.00 24 Hour Progress: 1683' Location: North Slope Rig Activity: Drilling Ahead Date: 19-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 - ... — M- x41 wad"`-.:.: xa,,k srn +11,x e.n ,'':';» ''2':' #A, ,uc 3N...::.'-'':x.,... s'2-.',aazur''w, ''''' ROP Current Avg za hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) NA NA NA NA Flow In(gpm) 398 SPP(psi) 2271 Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD Avg Min Max to I (ppg) 11.25 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth I Mud Type in I out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 21258 Fazepro 9.35 l 9.30 56 20 18 n/a n/a 134000.00 4.7 7 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD 4 SKH616M-E1D 8.75 0.902 11746' 21258' Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology (%) I Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 �.,,: rte'.. Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 973 20803' 44828 700 380 142 207 0 0 Minimum 123 20611' 0 0 0 0 0 0 0 Average 36 21800 55 89 6 8 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drilled 8.75"hole and monitored breathing from 20514'to a TD of 21258'MD at 448. Had toal losses of 734 bbls for last 24 hours.Can Rig Tech arrived after the hole was TD.Currently BROOH. _ -I Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 HALLI9LJRTON Sperry Orliling Morning Report Report#25 Customer: ENI Petroleum _ Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: S119-FN2 Daily Charges: $3,410.00 Current Depth: 21258' Area: Spy Island Total Charges: $85,510.00 24 Hour Progress: 0' Location: North Slope Rig Activity: BROOH Date: 20-Jun-2013 Rig: Doyon 15 Report For: Ross/Wimmer/Buchanan Time: 24:00:00 I ... .Y �. �; .; � ��.� r; •�•., Wit.,..®. s� � � ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP(ft/hr) NA NA NA NA Flow In(gpm) 0 SPP(psi) 0 Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD Avg Min Max to � 11.25 a ;°ue ' ,,_. , �<. .1: , ,x : u,. 4-t$.: Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in I out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 21258 Fazepro 9.30 9.30 56 20 16 n/a n/a 148000.00 3.7 —_ t it.aL .a� aum� a�i u•� "' ' cs Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD 4 SKH616M-E1D 8.75 0.902 56.00 11746' 21258' 9512' 45 188 Size Set At Type Weight rase Comments ' Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology (%) I Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) - u7 24 hr Recap: BROOH at 400 GPM.Wellbore breathing.Losses for the previous 24 hours are 98 bbls. Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 I-1ALLIBURTON 'Sperry or„„.,g Morning Report Report#26 ICustomer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: S119-FN2 Daily Charges: $2,810.00 Current Depth: 21258' Area: Spy Island Total Charges: $88,320.00 24 Hour Progress: 0' Location: North Slope Rig Activity: BROOH Date: 21-Jun-2013 Rig: Doyon 15 Report For: Keener/Wimmer/Buchanan Time: 24:00:00 Y _� 1u,,.. �? ,;:,s .=,34,''.;.- ;pis 7 L;,= ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP ft/hr) NA NA NA NA Flow In(.pm 0 SPP(.si) 0 ---- Flow In(spm) _ Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD EMU Min Max to ... 11.25 -- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids I Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 21258 Fazepro 9.30 9.30 62 20 17 n/a n/a 14300.00 4.0 ,- Bit# Bit Type Size isni Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16” ® 22.70 160 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA =ME Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD i' ' 616T- 1D 8.75 0.902 56.00 11746 21258' 9512' 45 188 0-0-BT- - -1-NS-TD Size Set At Type Weight =ME= Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 , Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 1 �''` ""�xr a.;.xi'" ?r' ', r:�' M j. .a� - v ri ` . 3CaAaw;G�^ �.Fs '�+'9 '"".. ��`��` ,...�� ......a,.v�.. Y."; -�"w . -.�;kat 24 hr Recap: POH from 9965'and pumped dry job.Monitored and was okay.L/D BHA#5.RIH with hole opener to 11502'filling every 25 stds.Cut and Slip drill line,service draw works brakes and top drive.CBU at 400 gpm down to 350 gpm and 1170psi. 39 bbls lost while circulating.Exhale test for 1 hr with 24 bbls returned.RIH to 15875'at time of report. Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 1 HALL1BlJRTOIV Sperry Drilling Morning Report Report#27 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: SI19-FN2 Daily Charges: $2,810.00 Current Depth: 21258' Area: Spy Island Total Charges: $91,130.00 24 Hour Progress: 0' Location: North Slope Rig Activity: Spot Breaker Date: 22-Jun-2013 Rig: Doyon 15 Report For: Keener/Wimmer/Buchanan Time: 24:00:00 i ROP Current Avg 24 hr Max Max @ ft _ Current Pump& Flow Data: ROP(ft/hr) NA NA NA NA Flow In(gpm) 0 SPP(psi) 0 Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD Avg Min Max to 11.25 %:-1:7: Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in I out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 21258 Fazepro 9.30 9.30 68 20 17 n/a n/a 143000.00 4.5 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD 4 ,SKH616M-E1D 8.75 1 0.902 56.00 11746' 21258' g 9512' I 45 188 0-0-BT-S-X-1-NO-TD ' ,,,.<„: .': fR:�f'L2L-�.w� w. '''.. ` ',tikl Kea,1 Y u.. jlL tlia e,�,fx, Size Set At Type Weight rase Comments Casing 20" 160' EVAMAR 178.9 _ X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 , L-80 Q1-`' Lithology (%) I Ss I Cht Silt I Siltst I Cly Clyst Sh I Lst I Coal I Gvl 1 Tuff l Cement i I(current) 100 l Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: RIH hole opener from 15875'.Wash and ream hole to 21244'.Circulate and condition hole. Total losses wer 142 bbls. Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 HALLIBUFUTON sperry Drilling Morning Report Report#28 Customer: _ ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: SI19-FN2 Daily Charges: $2,810.00 Current Depth: 21258' Area: Spy Island Total Charges: $93,940.00 24 Hour Progress: 0' Location: North Slope Rig Activity: POOH to shoe Date: 23-Jun-2013 Rig: Doyon 15 Report For: Keener/Wimmer/Buchanan Time: 24:00:00 '_ .._ - _ .�:, .,;..2vr:--•,),;.:,.--VE".r: f ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP(ft/hr) NA NA NA NA Flow In(gpm) 0 SPP(psi) 0 Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD Avg Min Max to (p„ 11.25 `2i .. . +'-4 ' W, ray r .::: Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 21258 Fazepro 9.30 9.30 68 20 17 n/a n/a 14200 00 4.2 Bit# Bit Type Size TFA Hours Depth in/out Footage ' WOB RPM Condition 1 Hughes MX-1 Milltooth 16" 1.117 22.70 160' 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD 4 SKH616M-E1D 1 8.75 0.9021 56.00 11746' 21258' 9512' 1 45 188 1 0-0-BT-S-X-1-NO-TD E .. t ,2iaa & ,p i 2.,1;idiit s Size Set At Type Weight rase Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology (%) I Ss I Cht Silt I Siltst l Cly Clyst Sh I Lst I Coal ( Gvl Tuff I Cement (current) 100 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Finished spotting breaker throughout the open hole and began pulling out of hole.No problems of overpull throughout the lateral section.Overpull was noted at 11,731'.This was believed to be from swelling shale cuttings where the shoe is set.The string was worked to insure the area was mitigated.Continued to POOH inside the casing and displacing the 9.3 ppg Faze Pro with 9.0 KCI Brine. Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 HALLIBURTON Sperry Or;..;.,g Morning Report Report#29 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: SI19-FN2 Daily Charges: $2,810.00 Current Depth: 21258' Area: Spy Island Total Charges: $96,750.00 24 Hour Progress: 0' Location: North Slope Rig Activity: Run 4.5"liner Date: 24-Jun-2013 Rig: Doyon 15 Report For: Keener/Wimmer/Buchanan Time: 24:00:00 R qua ROP Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: ROP ft/hr NA NA NA NA Flow In(..m) 0 SPP(psi) 0 ----- Flow In(spm) _ Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD /WM Min Max to 11.25 -- Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 21258 KCI Brine 9.30 60 ----- 72000.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" ® 22.70 160 3960' 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA MIMI Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD IlIIIILMl♦ ' 616Y- 1D 8.75 0.902 56.00 11746' 21258' 9512 45 188 0-0-BT- -'-1-N•-TD fr Size Set At Type Weight =ME= Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 100 ----------- t Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) max) (max) 24 hr Recap: Circulate with trip tank while rig up 4 5"liner equipment.RIH with liner to 7350'. 163 bbl loss for last 24 hours. Logging Engineers: A.Paul Kalenuik/Kori Jo Plowman Report By: A.Paul kalenuik Unit Phone: 907-685-0772 HIA.LtIE1L1FrT01'1/ t � Morning Report .. ,.. ., Spry r-•-y OrFI IFnge � .yea Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: SI19-FN2 Daily Charges: $3,810.00 Current Depth: 21258' Area: Spy Island Total Charges: $101,900.00 24 Hour Progress: 0' Location: North Slope Rig Activity: POOH running tool Date: 25-Jun-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr) ---- Flow In(.•m SPP .si) -_ -_-- Flow In(spm) _ Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD(ppg) Av. Min Max tO Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (••b E• cP (Ib/100ft2) m1/30min mg/I % 21258 3%KCVNaCIBrine 9.00 9.00 27 -_--- 72000.00 .� Bit# Bit Type Size MEI Hours Depth in/out Footage WOB RPM Condition 1 Hughes MX-1 Milltooth 16" ® 22.70 160' 3960 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD i' KH616M-E1D 8.75 0.902 56.00 11746' LEEN=am 45 188 0-0-BT-S-X-1-Ns-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ _ Gas Summary ��.�.. ._..v.... �,.�... . Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: RIH w/4.5"liner f/7350'MD to 9730'MD.M/U liner hanger.Cont RIH 4.5"liner w/5"DP to 19575'MD.Rotate in hole. Tag bottom @ 21258'MD.Set liner @ 21230'MD.Drop&pump ball.PSI up to 3000 psi&4000 psi for 5 min each.Test packer. Unsting f/packer @ 11469'MD.POOH to 11235'MD.Slip&cut drill line.POOH to 6150'MD. k Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 I-Ii4LLIBIURTON pa(-cy avt,rr•s Morning Report Report#31 Customer: ENI Petroleum Job No.: AK-AM-900480746 Yesterday's Depth: 21258' Well: SI19-FN2 Daily Charges: $2,810.00 Current Depth: 21258' Area: Spy Island Total Charges: $104,710.00 24 Hour Progress: 0' Location: North Slope Rig Activity: L/D 5"DP Date: 26-Jun-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In(spm) SPP •si) ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD(ppg) Avg Min Max to FIT ,. _ Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) ••b Eq) cP (Ib/100ft2) ml/30min mg/I 21258 3%KCI/NaCI Brine 9.00 9.00 27 ----- 72000.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hushes MX-1 Milltooth 16" ® 22.70 160 3960 3800' 40.0 40.0 1-1-WT-A-E-1-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25' 0.969 0.10 3960' 3980' 20' 10.0 80.0 1-1-NO-A-X-1-NO-BHA 3 Hycalog SKHI716D-E8C PDC 12.25" 0.969 40.80 3980' 11746' 7766' 14 180 1-3-WT-A-X-In-BT-TD i' KH616M-E1D 8.75 0.902 56.00 11746' 21258' 9512' 45 188 0-0-BT- -X-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 133/8" 3950' BTC 68.0 L-80 9 5/8" 11731' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement ¢4" (current) ---_--_ ------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) • 24 hr Recap: POOH f/6150'MD.UD packer running tool.Run 4.5"comp tbg to 11418'MD.Land hanger RILDS.Test hanger to 5000 psi for 10 min.R/U to set&test packer.Pull landing jt&L/D.UD DP. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Sperry®rw:„g 1 1 ±ELL INFORMATION _ Customer : ENI Petroleum Survey Report Well Name : S119-FN2 Job Number : AK-XX-0900480746 Rig Name : Doyon 15 Field Name : Nikaitchuq Country : USA 1IRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 0.00 0.00 299.80 0.00 0.00 N 0.00 E 0.00 0.00 40.55 0.00 0.00 40.55 0.00 N 0.00 E 0.00 0.00 116.87 0.31 198.10 116.87 0.20 S 0.06 W -0.20 0.41 142.36 0.28 197.79 142.36 0.32 S 0.10 W -0.32 0.12 170.21 0.28 244.99 170.21 0.41 S 0.19 W -0.41 0.81 201.09 0.48 263.02 201.09 0.46 S 0.38 W -0.46 0.75 235.68 1.08 289.32 235.68 0.37 S 0.84 W -0.37 1.98 263.56 1.19 290.16 263.55 0.19 S 1.35 W -0.19 0.40 _ 298.48 1.37 297.78 298.46 0.13 N 2.06 W 0.13 0.71 325.81 1.95 301.32 325.78 0.53 N 2.75 W 0.53 2.15 357.01 2.39 300.15 356.96 1.13 N 3.77 W 1.13 1.42 387.86 3.23 301.39 387.77 1.91 N 5.07 W 1.91 2.73 418.77 3.80 300.32 418.62 2.88 N 6.69 W 2.88 1.86 449.87 4.63 301.43 449.64 4.05 N 8.65 W 4.05 2.68 483.03 5.77 303.30 482.66 5.67 N 11.19 W 5.67 3.48 514.10 6.29 303.24 513.56 7.46 N 13.92 W 7.46 1.67 542.76 6.80 303.30 542.03 9.25 N 16.65 W 9.25 1.78 575.78 6.95 302.38 574.81 11.39 N 19.97 W 11.39 0.56 606.92 7.64 300.04 605.70 13.44 N 23.35 W 13.44 2.41 635.67 8.85 300.48 634.15 15.51 N 26.91 W 15.51 4.21 696.27 12.19 304.07 693.73 21.47 N 36.23 W 21.47 5.61 723.14 13.29 305.31 719.94 24.84 N 41.10 W 24.84 4.22 786.21 16.10 303.79 780.94 33.90 N 54.29 W 33.90 4.50 879.62 19.52 305.92 869.86 50.26 N 77.70 W 50.26 3.73 973.07 22.33 304.46 957.14 69.47 N 104.99 W 69.47 3.06 1066.46 _ 25.10 301.78 1,042.63 89.94 N 136.46 W 89.94 3.18 1159.81 30.70 302.70 1,125.10 113.26 N 173.37 W 113.26 6.02 1253.21 31.20 301.78 1,205.20 138.88 N 214.00 W 138.88 0.74 1346.62 34.48 300.37 1,283.68 165.00 N 257.39 W 165.00 3.61 1440.02 39.11 305.97 1,358.47 195.70 N 304.08 W 195.70 6.12 1533.39 38.87 308.78 1,431.05 231.35 N 350.76 W 231.35 1.91 1626.74 39.25 309.57 1,503.53 268.50 N 396.36 W 268.50 0.67 I Job No AK-XX-0900480746 Well Name. 5119-FN2 Survey Report INSITE V7.4.20 Page 1 I IIHALL1BURTON ( Sperry Drur.,g 'DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg 1 (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 1720.14 39.75 309.81 1,575.60 306.45 N 442.08 W 306.45 0.56 1813.31 41.34 309.79 1,646.40 345.21 N 488.61 W 345.21 1.71 1843.94 40.95 309.73 1,669.47 358.10 N 504.10 W 358.10 1.28 1875.29 41.24 309.13 1,693.09 371.19 N 520.02 W 371.19 1.56 1905.69 42.50 308.95 1,715.73 383.97 N 535.77 W 383.97 4.16 1937.26 43.06 307.89 1,738.90 397.29 N 552.57 W 397.29 2.89 1968.71 44.20 306.70 1,761.66 410.44 N 569.84 W 410.44 4.47 1999.86 45.94 305.64 1,783.66 423.45 N 587.64 W 423.45 6.08 2030.65 47.48 305.04 1,804.78 436.41 N 605.92 W 436.41 5.20 2061.74 49.08 304.56 1,825.47 449.66 N 624.98 W 449.66 5.27 2093.41 50.33 304.52 1,845.95 463.35 N 644.88 W 463.35 3.95 2186.83 52.50 305.66 1,904.21 505.33 N 704.62 W 505.34 2.51 2280.06 54.67 306.30 1,959.55 549.41 N 765.32 W 549.41 2.39 2373.36 56.22 304.05 2,012.47 593.66 N 828.13 W 593.66 2.59 2404.38 57.35 302.86 2,029.46 607.97 N 849.78 W 607.97 4.85 2435.76 58.14 302.59 2,046.21 622.31 N 872.11 W 622.31 2.62 2466.73 58.69 301.57 2,062.43 636.32 N 894.46 W 636.32 3.32 2496.82 58.62 300.64 2,078.08 649.60 N 916.46 W 649.60 2.65 2528.40 59.30 298.97 2,094.37 663.05 N 939.94 W 663.05 5.02 2560.09 59.74 297.58 2,110.44 675.98 N 963.99 W 675.98 4.03 2588.85 60.89 296.16 2,124.69 687.27 N 986.28 W 687.27 5.86 2620.89 62.29 295.49 2,139.93 699.55 N 1,011.65 W 699.55 4.74 2653.52 63.83 295.43 2,154.71 712.05 N 1,037.91 W 712.05 4.72 2746.78 67.06 295.08 2,193.46 748.24 N 1,114.62 W 748.24 3.48 2840.03 69.31 293.94 2,228.12 784.14 N 1,193.39 W 784.14 2.67 2933.32 73.97 293.39 2,257.49 819.67 N 1,274.46 W 819.67 5.03 3026.64 77.36 294.11 2,280.60 856.08 N 1,357.21 W 856.08 3.71 3119.90 76.23 295.65 2,301.90 894.27 N 1,439.57 W 894.27 2.01 3213.21 77.08 295.68 2,323.44 933.59 N 1,521.40 W 933.59 0.91 3306.49 78.87 294.60 2,342.87 972.35 N 1,603.99 W 972.35 2.23 3399.80 77.93 294.03 2,361.63 1,009.98 N 1,687.29 W 1009.98 1.17 3493.15 82.35 293.10 2,377.62 1,046.74 N 1,771.57 W 1046.74 4.84 3586.49 83.73 293.64 2,388.93 1,083.49 N 1,856.62 W 1083.49 1.59 3679.90 82.25 294.95 2,400.33 1,121.63 N 1,941.11 W 1121.63 2.11 3773.27 81.33 295.51 2,413.66 1,161.02 N 2,024.71 W 1161.02 1.15 3866.65 79.91 295.00 2,428.88 1,200.33 N 2,108.03 W 1200.33 1.61 3878.02 80.16 295.25 2,430.85 1,205.08 N 2,118.17 W 1205.08 3.09 4035.01 79.22 296.93 2,458.94 1,273.00 N 2,256.88 W 1273.00 1.21 4128.45 79.55 295.94 2,476.16 1,313.89 N 2,339.12 W 1313.89 1.10 4221.84 79.90 296.21 2,492.82 1,354.28 N 2,421.66 W 1354.28 0.47 4315.20 80.26 295.59 2,508.90 1,394.45 N 2,504.39 W 1394.45 0.76 4408.53 79.91 295.77 2,524.97 1,434.29 N 2,587.24 W 1434.29 0.42 4501.98 79.85 294.93 2,541.39 1,473.68 N 2,670.38 W 1473.68 0.89 4595.37 80.25 295.67 2,557.53 1,512.99 N 2,753.54 W 1512.99 0.89 4688.89 79.42 294.49 2,574.03 1,552.01 N 2,836.91 W 1552.01 1.53 Job No: AK-XX-0900480746 Well Name: S119-FN2 Survey Report INSITE V7.4.20 Page 2 HALLIBURTON ( Spy D'aung DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 4782.36 79.71 294.20 2,590.96 1,589.90 N 2,920.66 W 1589.90 0.44 4875.83 79.41 293.14 2,607.90 1,626.80 N 3,004.85 W 1626.80 1.16 1 4969.16 79.74 292.79 2,624.79 1,662.62 N 3 089.36 W 1662.62 0.51 5062.52 79.35 292.82 2,641.73 1,698.20 N 3,173.99 W 1698.20 0.42 5155.91 79.40 292.11 2,658.95 1,733.28 N 3,258.82 W 1733.28 0.75 5249.24 79.15 292.20 2,676.32 1,767.86 N 3,343.75 W 1767.86 0.28 5342.65 79.44 292.32 2,693.67 1,802.63 N 3,428.69 W 1802.63 0.34 5436.13 79.48 291.52 2,710.77 1,836.93 N 3,513.95 W 1836.93 0.84 5529.54 79.57 291.97 2,727.75 1,870.96 N 3,599.27 W 1870.96 0.48 5622.95 79.61 291.38 2,744.63 1,904.89 N 3,684.64 W 1904.90 0.62 5716.41 79.45 290.57 2,761.61 1,937.79 N 3,770.45 W 1937.79 0.87 5809.80 79.52 290.90 2,778.66 1,970.30 N 3,856.33 W 1970.30 0.36 5903.18 79.36 289.59 2,795.77 2,002.07 N 3,942.45 W 2002.07 1.39 5996.60 79.55 288.12 2,812.87 2,031.75 N 4,029.37 W 2031.75 1.56 6090.03 79.63 289.29 2,829.75 2,061.22 N 4,116.40 W 2061.22 1.23 6183.47 79.63 290.30 2,846.57 2,092.34 N 4,202.88 W 2092.34 1.06 1 6276.87 79.64 291.86 2,863.37 2,125.39 N 4,288.61 W 2125.39 1.64 6370.31 79.46 292.17 2,880.32 2,159.83 N 4,373.80 W 2159.83 0.38 6463.72 80.19 293.63 2,896.82 2,195.61 N 4,458.49 W 2195.61 1.73 6557.08 81.90 298.15 2,911.36 2,235.87 N 4,541.43 W 2235.87 5.12 6650.34 82.75 301.16 2,923.82 2,281.60 N 4,621.73 W 2281.60 3.33 6743.67 81.03 301.95 2,936.99 2,329.95 N 4,700.47 W 2329.95 2.02 6837.06 79.57 300.83 2,952.72 2,377.89 N 4,779.04 W 2377.89 1.96 6930.35 79.57 299.02 2,969.61 2,423.66 N 4,858.56 W 2423.66 1.91 7023.77 79.91 300.21 2,986.25 2,469.09 N 4,938.47 W 2469.09 1.31 7117.19 79.59 298.93 3,002.88 2,514.45 N 5,018.43 W 2514.45 1.39 7210.67 79.62 298.73 3,019.74 2,558.79 N 5,098.97 W 2558.79 0.21 7303.98 79.03 296.20 3,037.03 2,601.08 N 5,180.33 W 2601.08 2.74 7397.35 79.09 295.06 3,054.75 2,640.73 N 5,262.98 W 2640.73 1.20 7490.88 78.72 294.74 3,072.75 2,679.37 N 5,346.23 W 2679.37 0.52 • 7584.23 78.39 293.62 3,091.27 2,716.85 N 5,429.69 W 2716.85 1.23 7677.61 78.59 292.99 3,109.91 2,753.05 N 5,513.73 W 2753.05 0.69 7770.96 78.74 293.03 3,128.26 2,788.83 N 5,597.98 W 2788.83 0.17 7864.38 78.62 292.32 3,146.59 2,824.14 N 5,682.50 W 2824.14 0.76 7957.68 78.38 290.32 3,165.20 2,857.38 N 5,767.66 W 2857.38 2.12 8051.05 78.92 289.62 3,183.57 2,888.64 N 5,853.70 W 2888.65 0.94 8144.44 79.04 288.71 3,201.42 2,918.74 N 5,940.29 W 2918.74 0.97 8237.82 79.56 289.30 3,218.76 2,948.62 N 6,027.04 W 2948.62 0.83 8331.23 79.61 288.53 3,235.65 2,978.40 N 6,113.95 W 2978.40 0.81 8424.68 79.47 289.84 3,252.61 3,008.60 N 6,200.74 W 3008.60 1.39 8518.07 79.76 292.59 3,269.45 3,041.84 N 6,286.37 W 3041.84 2.91 8611.42 80.51 292.19 3,285.45 3,076.87 N 6,371.40 W 3076.87 0.91 8704.82 80.24 292.72 3,301.06 3,112.04 N 6,456.51 W 3112.04 0.63 8798.23 80.03 293.75 3,317.07 3,148.34 N 6,541.07 W 3148.35 1.11 8891.63 80.05 292.60 3,333.22 3,184.55 N 6,625.64 W 3184.55 1.21 Job No: AK-XX-0900480746 Well Name: S119-FN2 Survey Report INSITE V7.4.20 Page 3 ka HALLIBURTON Sperry D�im.,g - DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 8985.00 79.54 293.52 3,349.76 3,220.54 N 6,710.19 W 3220.54 1.11 9078.35 78.78 293.06 3,367.32 3,256.79 N 6,794.40 W 3256.79 0.95 9171.75 79.14 294.77 3,385.21 3,293.95 N 6,878.20 W 3293.95 1.84 9265.02 79.41 295.56 3,402.56 3,332.92 N 6,961.14 W 3332.92 0.88 9358.22 79.46 296.32 3,419.65 3,373.00 N 7,043.53 W 3373.00 0.80 9451.47 80.65 296.83 3,435.76 3,414.09 N 7,125.67 W 3414.09 1.39 9545.02 81.05 296.23 3,450.63 3,455.34 N 7,208.31 W 3455.34 0.76 9638.44 80.61 295.47 3,465.52 3,495.55 N 7,291.30 W 3495.55 0.93 9731.67 80.48 294.49 3,480.84 3,534.39 N 7,374.66 W 3534.39 1.05 9824.97 79.85 294.39 3,496.77 3,572.42 N 7,458.35 W 3572.42 0.68 9918.34 79.38 294.14 3,513.60 3,610.16 N 7,542.08 W 3610.16 0.57 10011.71 79.36 295.23 3,530.83 3,648.49 N 7,625.46 W 3648.49 1.15 10105.13 78.63 297.11 3,548.66 3,688.93 N 7,707.76 W 3688.93 2.12 10198.39 79.82 300.62 3,566.10 3,733.15 N 7,787.97 W 3733.15 3.91 10291.64 79.75 303.27 3,582.64 3,781.70 N 7,865.84 W 3781.70 2.80 10384.93 79.60 305.79 3,599.37 3,833.72 N 7,941.44 W 3833.72 2.66 10478.25 80.53 306.95 3,615.47 3,888.23 N 8,015.46 W 3888.23 1.58 10571.51 81.76 308.70 3,629.82 3,944.74 N 8,088.24 W 3944.74 2.28 10664.82 82.78 308.18 3,642.38 4,002.22 N 8,160.66 W 4002.22 1.22 10758.10 83.36 307.63 3,653.63 4,059.11 N 8,233.72 W 4059.11 0.85 10851.41 83.18 305.87 3,664.57 4,114.55 N 8,307.97 W 4114.55 1.88 10944.76 83.37 304.35 3,675.50 4,167.87 N 8,383.81 W 4167.87 1.63 11038.10 83.39 303.35 3,686.26 4,219.52 N 8,460.81 W 4219.52 1.06 11131.51 83.37 305.71 3,697.03 4,272.11 N 8,537.24 W 4272.11 2.51 11224.88 84.10 308.02 3,707.22 4,327.79 N 8,611.49 W 4327.79 2.58 11318.26 85.00 311.85 3,716.09 4,387.45 N 8,682.75 W 4387.45 4.20 11411.62 85.89 315.72 3,723.51 4,451.83 N 8,749.92 W 4451.83 4.24 11505.01 86.87 318.84 3,729.41 4,520.30 N 8,813.15 W 4520.30 3.50 11598.38 85.88 319.66 3,735.31 4,590.89 N 8,873.97 W 4590.89 1.38 11691.78 85.83 318.83 3,742.06 4,661.45 N 8,934.78 W 4661.45 0.89 11746.00 85.83 318.83 3,746.00 4,702.16 N 8,970.38 W 4702.16 0.00 11761.71 85.20 320.63 3,747.23 4,714.11 N 8,980.51 W 4714.11 12.11 11855.07 86.63 320.92 3,753.88 4,786.25 N 9,039.39 W 4786.25 1.56 11948.41 87.29 322.35 3,758.83 4,859.33 N 9,097.24 W 4859.33 1.69 12041.79 88.72 323.00 3,762.08 4,933.54 N 9,153.83 W 4933.54 1.68 12135.21 90.50 323.22 3,762.72 5,008.25 N 9,209.90 W 5008.25 1.92 12228.58 89.38 323.29 3,762.82 5,083.06 N 9,265.76 W 5083.07 1.20 12322.05 89.35 322.33 3,763.85 5,157.52 N 9,322.25 W 5157.52 1.03 12415.44 90.19 322.50 3,764.23 5,231.53 N 9,379.21 W 5231.53 0.92 12508.87 89.32 322.87 3,764.63 5,305.83 N 9,435.85 W 5305.83 1.01 12602.30 89.72 322.66 3,765.41 5,380.21 N 9,492.38 W 5380.21 0.48 12695.76 89.58 322.51 3,765.98 5,454.44 N 9,549.17 W 5454.44 0.22 12789.15 90.48 322.50 3,765.93 5,528.54 N 9,606.01 W 5528.54 0.96 12882.53 89.88 322.12 3,765.64 5,602.43 N 9,663.10 W 5602.43 0.76 12975.91 86.49 321.51 3,768.60 5,675.78 N 9,720.79 W 5675.78 3.69 Job No: AK-XX-0900480746 Well Name: Sl19-FN2 Survey Report INSITE V7.4.20 Page 4 F HALLIBURTON I Sperry Drilling r DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 13069.30 88.48 321.29 3,772.69 5,748.70 N 9,779.00 W 5748.70 2.14 13162.69 88.57 321.45 3,775.10 5,821.63 N 9,837.28 W 5821.63 0.20 13256.12 89.91 322.04 3,776.34 5,894.99 N 9,895.12 W 5894.99 1.57 13349.60 90.72 322.68 3,775.82 5,969.01 N 9,952.21 W 5969.01 1.10 13442.95 90.56 323.12 3,774.78 6,043.46 N 10,008.51 W 6043.46 0.50 13536.30 90.89 322.47 3,773.60 6,117.80 N 10,064.95 W 6117.80 0.78 13629.69 92.05 323.74 3,771.20 6,192.46 N 10,121.00 W 6192.46 1.84 13723.07 92.91 323.99 3,767.16 6,267.81 N 10,176.01 W 6267.81 0.96 13816.51 91.84 324.60 3,763.29 6,343.62 N 10,230.50 W 6343.62 1.32 13909.90 90.02 323.19 3,761.78 6,419.05 N 10,285.52 W 6419.05 2.47 14003.26 90.49 322.74 3,761.36 6,493.58 N 10,341.75 W 6493.58 0.70 14096.59 92.07 322.25 3,759.28 6,567.60 N 10,398.56 W 6567.60 1.77 14190.04 92.08 323.23 3,755.89 6,641.92 N 10,455.10 W 6641.92 1.05 14283.43 90.77 322.61 3,753.57 6,716.40 N 10,511.38 W 6716.40 1.55 14376.95 89.63 321.78 3,753.24 6,790.29 N 10,568.71 W 6790.29 1.51 14470.42 90.09 321.61 3,753.47 6,863.64 N 10,626.65 W 6863.64 0.52 14563.89 90.05 320.45 3,753.36 6,936.31 N 10,685.43 W 6936.31 1.24 14657.22 90.14 317.49 3,753.20 7,006.71 N 10,746.69 W 7006.71 3.17 14750.58 91.39 318.67 3,751.96 7,076.16 N 10,809.05 W 7076.16 1.84 14843.97 90.77 316.64 3,750.20 7,145.17 N 10,871.95 W 7145.17 2.27 14937.30 91.51 317.05 3,748.34 7,213.24 N 10,935.77 W 7213.24 0.91 15030.71 90.24 316.32 3,746.91 7,281.20 N 10,999.84 W 7281.20 1.57 15124.19 91.25 315.71 3,745.70 7,348.45 N 11,064.75 W 7348.45 1.26 15217.60 90.48 313.96 3,744.29 7,414.30 N 11,130.98 W 7414.30 2.05 15311.01 89.53 315.01 3,744.28 7,479.75 N 11,197.62 W 7479.75 1.52 15404.47 87.69 315.04 3,746.55 7,545.85 N 11,263.66 W 7545.85 1.97 15497.86 89.96 317.82 3,748.46 7,613.49 N 11,328.00 W 7613.49 3.84 15591.24 85.87 316.10 3,751.86 7,681.67 N 11,391.67 W 7681.67 4.75 15684.66 88.78 313.94 3,756.22 7,747.67 N 11,457.63 W 7747.67 3.88 15778.09 89.06 314.25 3,757.98 7,812.67 N 11,524.72 W 7812.67 0.45 15871.53 87.50 314.56 3,760.78 7,878.02 N 11,591.44 W 7878.02 1.70 • 15964.93 86.70 311.84 3,765.51 7,941.87 N 11,659.43 W 7941.87 3.03 16058.37 87.85 310.30 3,769.95 8,003.19 N 11,729.79 W 8003.19 2.06 16151.78 90.14 310.38 3,771.59 8,063.64 N 11,800.98 W 8063.64 2.45 16245.14 91.76 310.25 3,770.04 8,124.03 N 11,872.15 W 8124.03 1.74 16338.40 91.85 311.74 3,767.11 8,185.18 N 11,942.50 W 8185.18 1.60 16431.73 90.63 311.84 3,765.09 8,247.36 N 12,012.07 W 8247.36 1.31 16525.12 91.02 312.81 3,763.74 8,310.23 N 12,081.11 W 8310.23 1.12 16618.41 90.10 312.64 3,762.83 8,373.52 N 12,149.64 W 8373.52 1.00 16711.83 86.57 312.32 3,765.54 8,436.58 N 12,218.50 W 8436.58 3.79 16805.25 88.40 311.69 3,769.64 8,499.03 N 12,287.85 W 8499.03 2.07 16898.73 91.36 312.08 3,769.84 8,561.43 N 12,357.43 W 8561.43 3.19 16992.04 90.71 310.45 3,768.15 8,622.96 N 12,427.56 W 8622.96 1.88 17085.41 91.42 312.13 3,766.42 8,684.56 N 12,497.70 W 8684.56 1.95 17178.94 90.71 312.59 3,764.68 8,747.57 N 12,566.80 W 8747.57 0.90 Job No: AK-XX-0900480746 Well Name: S119-FN2 Survey Report INSITE V7.4.20 Page 5 1 HALLIBURTON ( Sperry Drilling DIRECTIONAL SURVEY DATA IMMIM Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg li (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 17272.29 90.34 313.35 3,763.82 8,811.20 N 12,635.10 W 8811.20 0.91 17365.67 90.01 313.28 3,763.54 8,875.25 N 12,703.04 W 8875.25 0.36 17459.02 89.06 312.87 3,764.30 8,939.01 N 12,771.23 W 8939.01 1.11 17552.44 89.29 313.43 3,765.64 9,002.89 N 12,839.38 W 9002.89 0.65 17645.74 90.58 312.20 3,765.75 9,066.30 N 12,907.81 W 9066.30 1.91 17739.11 92.29 313.65 3,763.41 9,129.86 N 12,976.16 W 9129.86 2.40 17832.50 89.60 311.76 3,761.87 9,193.18 N 13,044.77 W 9193.18 3.52 17925.88 90.25 310.16 3,761.99 9,254.39 N 13,115.28 W 9254.39 1.85 18019.29 89.49 310.12 3,762.20 9,314.61 N 13,186.69 W 9314.61 0.81 18112.74 89.82 310.10 3,762.77 9,374.81 N 13,258.16 W 9374.81 0.35 18206.13 91.80 310.38 3,761.45 9,435.13 N 13,329.44 W 9435.14 2.14 18299.48 91.42 310.68 3,758.82 9,495.77 N 13,400.36 W 9495.77 0.52 18392.88 91.06 311.03 3,756.80 9,556.86 N 13,470.99 W 9556.86 0.54 18486.29 90.30 311.88 3,755.69 9,618.69 N 13,540.99 W 9618.69 1.22 1 18579.69 91.39 308.89 3,754.31 9,679.19 N 13,612.12 W 9679.19 3.41 18673.06 90.86 310.64 3,752.48 9,738.90 N 13,683.87 W 9738.90 1.96 18766.41 88.12 310.43 3,753.31 9,799.56 N 13,754.81 W 9799.56 2.94 18859.81 89.86 313.05 3,754.96 9,861.73 N 13,824.48 W 9861.73 3.37 18953.08 92.37 314.72 3,753.14 9,926.36 N 13,891.69 W 9926.36 3.23 19046.28 89.06 312.28 3,751.98 9,990.50 N 13,959.27 W 9990.50 4.41 19139.53 88.88 312.95 3,753.66 10,053.62 N 14,027.89 W 10053.63 0.74 19233.08 88.74 311.37 3,755.60 10,116.40 N 14,097.21 W 10116.40 1.70 19326.50 90.01 310.51 3,756.62 10,177.61 N 14,167.78 W 10177.61 1.64 - 19419.73 90.25 309.28 3,756.41 10,237.40 N 14,239.30 W 10237.40 1.34 19513.03 90.52 308.67 3,755.78 10,296.09 N 14,311.84 W 10296.09 0.71 19606.40 93.10 309.01 3,752.83 10,354.61 N 14,384.52 W 10354.61 2.79 19699.76 90.72 309.46 3,749.72 10,413.62 N 14,456.79 W 10413.62 2.59 19793.19 89.63 308.29 3,749.44 10,472.26 N 14,529.52 W 10472.26 1.71 19886.45 89.93 307.08 3,749.79 10,529.27 N 14,603.32 W 10529.27 1.34 19979.70 87.65 307.34 3,751.76 10,585.64 N 14,677.57 W 10585.64 2.46 20072.99 87.70 306.68 3,755.55 10,641.75 N 14,752.00 W 10641.75 0.71 20166.31 89.83 307.19 3,757.56 10,697.81 N 14,826.57 W 10697.81 2.35 20259.57 89.36 307.13 3,758.22 10,754.15 N 14,900.89 W 10754.15 0.51 20352.88 87.75 306.28 3,760.57 10,809.90 N 14,975.67 W 10809.90 1.95 20446.16 88.78 306.70 3,763.40 10,865.34 N 15,050.63 W 10865.34 1.19 20539.47 90.01 305.69 3,764.38 10,920.44 N 15,125.93 W 10920.44 1.71 20632.82 93.07 305.75 3,761.87 10,974.91 N 15,201.68 W 10974.91 3.28 20726.16 92.77 304.22 3,757.12 11,028.36 N 15,278.05 W 11028.36 1.67 20819.57 92.50 302.35 3,752.82 11,079.57 N 15,356.05 W 11079.57 2.02 20912.94 92.99 300.40 3,748.35 11,128.12 N 15,435.67 W 11128.12 2.15 21006.32 92.15 299.42 3,744.16 11,174.64 N 15,516.53 W 11174.64 1.38 21099.68 89.47 298.04 3,742.84 11,219.50 N 15,598.38 W 11219.50 3.23 21185.38 89.60 298.19 3,743.54 11,259.89 N 15,673.97 W 11259.89 0.23 21258.00 89.60 298.19 3,744.05 11,294.19 N 15,737.97 W 11294.19 0.00 Job No: AK-XX-0900480746 Well Name: S119-FN2 Survey Report INSITE V7.4.20 Page 6