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213-013
MEMORANDUM 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 SI32-W2 NIKAITCHUQ SI32-W2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 SI32-W2 50-629-23483-00-00 213-013-0 W SPT 3518 2130130 1500 658 659 658 659 210 290 225 225 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 SI32-W2 Inspection Date: Tubing OA Packer Depth 13 1719 1668 1650IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250416121135 BBL Pumped:6.3 BBL Returned:4.1 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 12:43:14 -08'00' MEMORANDUM TO: Jim Regg \\ 4q 5��3] P.I. Supervisor l FROM: Guy Cook Petroleum Inspector Well Name NIKAITCHUQ S[32 -W2 Insp Num: mitGDC210501113342 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 5, 2021 SUBJECT: Mechanical Integrity Tests Ent US Operating Company Inc. 5132-W2 NIKAITCHUQ S132 -W2 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-629-23483-00-00 Inspector Name: Guy Cook Permit Number: 213-013-0 Inspection Date: 4/30/2021 Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well �� S132 -W2 - Type Inj w. TVD 3sla ' Tubing 490 - .11)n goo - 490 �- PTD 2130130 - Type Test', SPT `Pest psi soo IA ase i ;o n n n12— BBL Pumped: 1.7 - BBL Returned: 18 - 1 OA 220 00 _ 260 250 — -- -- i--- _. Interval — avarsr — -�P/F P Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer. C5d-d-L4'_ becewbe.— 7ezz Wednesday, May 5, 2021 Page I of 1 ! • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 TO: Jim Regg Supervisor -211 ` f zl zs��/Co SUBJECT: Mechanical Integrity Tests P.I.P ENI US OPERATING CO INC SI32-W2 FROM: Jeff Jones NIKAITCHUQ 5132-W2 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:56e— NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI32-W2 API Well Number 50-629-23483-00-00Jeff Jones 1 Inspector Name: Permit Number: 213-013-0 Inspection Date: 12/10/2016 Insp Num: mitJJ161213071304 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI32-W2 Type Inj W'TVD 3518 . Tubing 338 "1 338 338 - 338 PTD 2130130 ,Type Test SPT Test psi 1500 - IA 950 I 1657 - 1629 - , 1616 - Interval 4YRTST P/F P V OA 220 230 250 - 280 Notes: 2.6 barrels diesel pumped. 1 well inspected,no exceptions noted. 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Z IZ II Z ai I— O N y O0 it I Z 7 .Ta 0 to I 0 0.. g - 0 'l W W In rn cea a.) as O • E In y m_ -3 rn co- 0 1 U Z Z `a ° Ca a W m 1', 1 Z y O N w O O) Q N J 0. C • O 'J O 0 U 1 A . M c , I' O. G r O 1 N a) a U "' U 7z c w M • co 7 } } r E M / E O OA E U N 5 G () N N ZS ca a7 C N 0 1 ill CO j 10 O▪ T j 1 i cu Cl) ~ 0 c C O CI NOW Q \ — .6 1 !. r Z .5 Co E a j Q o a ° as o Z O a) O T 1 ea z � � N M M I1, I Q 11 N N • O Z Ill 0 M N N } } } 0 C M d E o l 0 d N c N `1 I a) > CL N a) i d ce o F- of 0 0 w c I I m 1.0 0 M C Z C (a ° ( N 0 O O CO 2 a O 0 '+r C C U 0.m 1 E a a . 0 n a d O E 2 a°> 0 o as 0 E 1 E a 2 0 a 0 0 0 ce 10 1 0 Schlumberger Wireline. 2525 Gambell Street, Suite 400 E,. hIumberger Anchorage, Alaska 99503 AUG 2 0 20,E AOGCC Company: i' (_.(f f ` �` Date: -v ( � C (JG{._J -'f C'%? Location: ?_37;) \ rt ve 4- '02 Attention: 71=' 6 /rat iGt � rti �. �1 i' Well Name: S ,cam l Well Name: Services: 1-- x LI'CA(A' r V" ti Services: No. of Boxes: ) No. of Boxes: Job No: °- et)--- - Job No: Add'I Tapes: �---- X Add'I Tapes: Well Name: Well Name: Services: Services: No. of Boxes: No. of Boxes: Job No: Job No: Add'I Tapes: Add'I Tapes: Well Name: Well Name: Services: Services: No. of Boxes: No. of Boxes: Job No: Job No: Add'I Tapes: Add'I Tapes: V Schlumberger Courier: `s f' CI L m, Date Delivered: f. 1 i' /1 Received By: . Y 1�.��- `' ^. ,\A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,August 16,2013 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC S!32-W2 FROM: NIKAITCHUQ S132-W2 Petroleum Inspector Src: Operator NON-CONFIDENTIAL Well Name NIKAITCHUQ S132-W2 API Well Number 50-629-23483-00-00 Inspector Name: Permit Number: 213-013-0 Inspection Date: 5/25/2013 Insp Num: M1TOP000004358 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI32-W2 Type Inj w TVD 3518 IA 0 2600 2600 2600 PTD 2130130 Type Test SPT Test psi 1500 OA Interval Initial Test P/F Pass Tubing 1500 3500 3500 3500 Notes: Pre Injection MIT Friday,August 16,2013 Page 1 of 1 HALLIBURTON RECEIVED JUL 11 2013 Sperry Drilling AOGCC To: Alaska Oil and Gas Conversation Commission 333 W 7t' Ave Suite 100 Anchorage, AK 99501 Attn: Howard Oakland 13 3 From: Sperry Drilling - Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax 30 01 Robert.HaverfieldCa�Halliburton.com Re: Eni Well — SI32-W2 AFE # 6044 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 Ade Sign ame I Date / 0 Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. STATE OF ALASKA 1! ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended El lb.Well Class: /3 20AAC 25.105 20AAC 25.110 Developme I ] •3 Exploratory❑ GINJ ❑ WINJ El . WAG ❑ WDSPL❑ No.of Completions: Service LJ' Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. ' Aband.: 5/25/2013 • 213-013 ' 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 3/7/2013 50-629-23483-00-00 4a.Location of Well(Governmental Section): rdsvosol.....40...7.Date TD Reached: 14.Well Name and Number: • Surface: 4431.8 FSL 1467.6 FEL S19 T14N R9E UM "PION 5/11/2013 • SI32-W2 Top of Productive Horizon: 3 8.KB(ft above MSL): 53.6 15.Field/Pool(s): 1569 FSL 2230 FEL 24 T14N R8E UM _ tt ,., 'GL(ft above MSL): 13.1 Total Depth: lit 19.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 2203 FSL 3558 FEL 14 T14N R8E UM '''''"'°"" ' N/A • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511442.37 y- 6053613.37 Zone- 4 13350'MD/3607'TVD • ADL 0391283,0388574. TPI: x- 505601.59 y- 6050744.26 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 498987.83 y- 6056755.78 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1878 MD/1748 TVD 21.Logs Obtained(List all logs here and submit electronip and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic i Mb- 7 7.3•/3 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 2806 36.85 2413 16 10.7 ppg ASL: 450 bbls N/A 12.5 ma LiteCRETE:72 bbls 9.625 40 L-80 35.53 9387 35.53 3624 12.25 12.5 ppg LiteCRETE:212 bbls N/A 4.5 11.6 L-80 9188 18327 3617 3608 8.75 Blank Liner with ICD's N/A SLodi eciaers 24.Open to production or injection? Yes gi 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 4.5 9198 8099 MD/3518 TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ilk a r ,. "a DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED II ' „,.,'rs 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: 'Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate -p N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No El. Sidewall Cores Acquired? Yes ❑ No EI 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 JUN 21 2013.1, Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7543 Submit original only � / N 1s/ci/3 6 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes 12110 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 770 765 SV3 1145 1115 SV2 1435 1372 Permafrost-Base 1878 1748 SV1 2087 1920 Ugnu Top 2537 2241 UG-2 Coal Bed Marker 3380 2744 Lower Ugnu 6287 3259 Schrader Bluff Top 7536 3447 N Sequence Top 7805 3482 N top 8118 3519 N bottom 8384 3553 OA sand top 9419 3625 Formation at total depth: OA sand 18350 3607 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: Dayide Simeone Title: Well Operations Project Manager Signatu . 1 V i Phone Contact: (907)865-3338 Date: 6/13/2013 u 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 F C J '�_ • + M = N CD O W N r' 0) N = 0 V QO () 2 J M = CD p = o o Z. O Q N L 0 Z c/ v- ii 3 c0 N 4-, V p N. ILA < N p a Op d 1— m 0 •C Q ; _ OL 'C.+• a o CD o ii O d 0 y N .Q _ 0 Q N J a •3 U) p .:. N = N N M a N us N CO 0_ L Y u x xc u u x Z Cl (' d Q 0 £ a a a a a a __Ce I. L 2 — 0 �, vva � � a W J d H V3f an vii vii vii v3f vii - _ °- _� 3 0 c =N 0. J a O v ' W C o 2 Z r - m ca •_ •� 00 I d 0 Z • N 0 c = M 0 d p x = , E p N C N C - CO ° CI CI Coj , M V M eh 0 .... a 00 eut a* m H N ' _ 00 M M 0 00 0 0 Cr) d E C Lo N O 00 00 2 0 cL 11 Cs 0 000 00 CA C .cn N p • cD • N N w- N CO M it.N Cr m n' u�i �i • �. as 0 ;; a tc xt 7e it u ‘Y:''o 3t a 0) O G G O 0 0 u u u u v u u u _ to Lw 1!1 N 01 I, rl N pp N (Vi �p 0.11 N Li/ M lD l0 00 a^ tap N QO a. _ -N M CO a) > 0 ++ o - 4L° to = � ~ C 111- `1* Y _ .(N0 O M O `C N . tt N en u u t.0 tt tt CT el z M C� C I) O o0 ' o o 0000000 M N N 0- 1141 Eni E&P Division [Well Name: SI32-W2 EN!Petroleum Co.Inc. Daily Repo..}l Well Code:27080 Field Name:NIKAITCHUO ii• Date:3/5/2013 - Report#: 1 APIIUWI:50-629-23483-00-00 2" " page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 Rig Information Contractor Rig Name DOYON DRILLING DOYON 15 (Rig Type LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours)hr) 'Avg ROP(ft/hr) DFS(days) SI32-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 11269 162.8 -1.56 Daily Information End Depth(ftKB) End Depth(TVD)(f..:Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 115.0 -9.0 Mostly Cloudy.WC- ENE a 30 MPH 39" Daily summary operation 2dh Summary Finish up on SP22-FN1.R/D Rig and move to SI32-W2. Operation at 07.00 Cont.moving Rig to SI32-W2. 24h Forecast Cont.to move and rig up over SI32-W2.Load BHA tools in Pipe Shed. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 MOB A 2 P PJSA on well SP22-FN1 PT new Shear Valve to 500 PSI for 10 Min.POOH install Basket retreival tool&RIH and pull Basket.R/D Halliburton slick line and secure well.TBG=350 PSI.IA 250 PSI,OA 200 PSI. 03:00 08:00 5.00 8.00 MOB A 2 P PJSA Mobilize matt boards for next well.Disconnect inner connects&blow down Pits.Move 5"D.P.for weight balance. Blow down Rig Floor. 08:00 09:00 1.00 9.00 MOB B 2 P PJSA Perform skid Rig Floor. 09:00 12:00 3.00 12.00 MOB A 2 P PJSA Move Rock Washer&spot crane.Perform Diverter Line Ops.Skid Rig Floor back for wind block for Crane. 12:00 15:00 3.00 15.00 MOB -A 2 P PJSA Crane Ops.on Diverter,Cont Prep F/Rig Move. 15:00 16:00 1.00 16.00 MOB B 2 P PJSA Skid Rig Floor to rig move position. 16:00 18:00 2.00 18.00 MOB A 2 P PJSA Move Pits and Sub F/access to rig watts.Move rig mans to Pit side of rig. 18:00 21:00 3.00 21.00 MOB A 2 P PJSA Lay down Herculite,ACS Rep weld Herculite seam&Cont.to Lay down man boards. 21:00 22:00 1.00 22.00 MOB A 2 P PJSA Place malts and move Rock Washer farther down Pad. 22.00 00.00 2.00 24.00 MOB B 2 P PJSA Move Pit complex towards WIF.P/U move Sub to well S132-W2 begin spotting Sub. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon l5 @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 rig15 @doyondolling corn 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 CONDUCTOR 20 18.250 X.65 0.0 160.0 2/1/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(113/gal) 'P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 1 Eni E&P Division I Well Name:SI32-W2 EN!Petroleum Co.Inc. Daily Report` Well Code:27080 Field Name: NIKAITCHUC • API/UWI:50-629-23483-00-00 2^n Date:3/6/2013 - Report#: 2 II II II page 1 of 1 Wellbore name: S132-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 -0.56 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 113.0 -13.0 Blowing Snow WC- E @ 20 MPH 39' Daily summary operation 24h Summary Cont.moving Rig to SI32-W2.Work on berming,inner connects and suit cases.N/U Well Head and Stack.Test Well Head and riser.Load BHA in Pipe Shed. Operation at 07.00 Cont.Rig up. 24h Forecast Work on welding Diverter flange.P/U HWDP.Function test Annular Preventer and Knife Valve,witnessed waived by AOGCC Louis Grimaldi 3-6-13.Test Suit Case lines and transfer Spud Mud to Rig. P/U clean out BHA and clean out Conductor.P/U final BHA and drill ahead. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 MOB A 2 P PJSA Cont.spotting Sub over SI32-W2. 02:00 03:00 1.00 3.00 MOB A 2 P PJSA Spot Pits to the Sub base. 03.00 06:00 3.00 6.00 MOB A 2 P PJSA Skid the Rig Floor to drilling position.Begin working on inner connect and hook up steam system.Begin loading Schlumberger BHA tools in Pipe Shed. 06.00 1200 6.00 12.00 MOB A 1 P PJSA Work on suitcases and spot Mud Pump#3.Replace leaking hose on Top Drive&function test.Make repairs to leaking steam piping on Rig Floor&function test.Spot Rock Washer in place. 12.00 19.30 7.50 19.50 MOB A 1 P PJSA Cont.working on inner connect on Rock Washer,under Rig Floor,Pump#3.M/U easterly and westerly suit cases. Load Schlumberger BHA in Pipe Shed. 19.30 0000 4.50 24.00 MOB C 5 P PJSA N/U Starter Head as per Vetco Grey Rep.onsde.Test seals to 500 psi for 10 Min.Install Lower drilling riser.Test seals to 500 PSI for 10 Min.witnessed by Co.Rep.onsde.N/U Diverter Tee and Annular Preventer.Test seals to 500 PSI for 10 Min.witnessed by Driller.Begin working on Diverter installation.Continue working on suit cases and test lines.Cont. working on berming around the rig and rigging up innner connects.Load GYRO Data tools,HWDP and surface Hanger in Pipe Shed,install Hanger on Landing Joint and prep for dummy run. Daily Contacts Position I Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Biflington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 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 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 CONDUCTOR 20 18.250 X.65 0.0 160.0 2/1/2010 - Last Leakoff Test Depth(ttKB) TVD(ftKB) 'Fluid Type I Fluid Density(1b/gall I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name S132-W2 ffl* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • 2^,t Date:3/7/2013 - Report#: 3 APIIUWI:50 629-23483-00-00 " II II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53,60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 0.44 - Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 310.0 310.0 310.00 1.19 260.5 114.0 0.0 Blowing Snow WC- E @41 MPH Gist _ 30 to 56 MPH Daily summary operation 24h Summary Dummy run 13 3/8"Hanger as per Vetco Grey.Finish nipple up Stack and Diverter,function test Annular Bag,Knife Valve and Draw down.Test waived by AOGCC Rep Louis Grimaldi 3-6-13.Test Gas, LEL and Fire alarms.P/U M/U BHA#1 and clean out 20"Conductor to 160'MD.POOH and P/U M/U BHA#2 and drill ahead F/160'to 310'MD.Non occupational inccident man down happened in the yard;personal collapsed and was given medical aid. Operation at 07.00 Drill 16"Surface to 405'MD 24h Forecast RIH to 310'MD and continue to dell 16'Surface hole to 2,761'MD as per Well Plan. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 20 P PJSA Perform 13 3/8"dummy Hanger run as per Vetco Grey Rep onsite. 01:00 06:00 5.00 6.00 DRILL C 20 P PJSA N/U install Bell Nipple and Diverter piping.Berming outside of Rig W/ACS Rep onsite.Cont.to work on Suit Cases. Clean and clear Rig floor and prep for P/U BHA components. 06:00 07:00 1.00 7.00 DRILL E 20 P PJSA P/U BHA components&stage on Rig floor. 07:00 08:30 1.50 8.50 DRILL E 20 P PJSA N/U Diverter Assy.W/Flow Line and Clam Shell. 08:30 09:30 1.00 9,50 DRILL C 12 P PJSA Perform Diverter system test,1/25 test and LEL alarm system.State waived witness by Louis Grimaldi on 3-6-13. Diverter valve open @ 22 Sec.,Annular Bag closed in 42 Sec.Start system @ 2,900 PSI,Manifold©1,500 PSI,Annular 700 PSI.After system function @ 1,850 PSI,Manifold @ 1,500 PSI,Annular @ 750 PSI,35 Sec.to 200 PSI,137 Sec.to full charge.5 Bottles @ 2,400 PSI. 0930 12:00 2.50 12.00 DRILL E 20 P PJSA P/U M/U BHA stands&rack back in Derrick(I.E.HWDP&Jars)Schlumberger DD onsite. 12.00 13:30 1.50 13.50 DRILL E 20 P PJSA M/U P/U BHA components and stand back in Derrick as per Schlumberger DD onsite. 13.30 15:00 1.50' 15.00 DRILL E 3 P Pre Spud meeting W/all parties.Fill Stack W/Spud Mud and check Equip.for leaks.Test Mud Lines to 3,000 PSI.Wash and ream surface conductor to 124'MD.600 GPM,510 PSI,40 RPM,HST 84K,ELK 84K,ROT Wf 84K.Test Rig Gas alarm @ 14:00. 1500 16:00 1.00 16.00 DRILL E 24 U NON OCC man down,Rig crew,security and Medic responded.Brought personal to camp due to collapsing in yard.Rig crew regroup and discussed spud operations before retuming to work. 1600 17.00 1.00 17.00 DRILL E 3 P PJSA Wash and ream to 160'MD,600 GPM,510 PSI,40 RPM,TRQ 2K.HST 85K,SLK 85K,ROT 84K.Circulate until Shakers clean up,POOH and blow down Top Dove. 17.00 20.00 3.00 20.00 DRILL E 20 P PJSA P/U M/U BHA#2 perform shallow hole test 610 GPM,520 PSI,ROT 95K,HST 95K.SLK 95K. 20.00 23.30 3.50 23.50 DRILL E 3 P PJSA Drill ahead F/160'to 310'MD(310'ND)547 GPM,40 RPM,TRN 2K,TOF 2K,WOB 10-15K,HST 95K,SLK 100K. ROT 95K,MW 8.8 ppg.ADT 1.19 Hrs,TST.68.TRT.51.Bit Hrs 1.19,Jar Hrs 11.99.Monitor weH static. 23.30 0000 0.50 24.00 DRILL E 4 P PJSA Circ,hole clean&POOH and stand back 2 stands of HWDP&P/U M/U Collar.Catching Gyro data surveys as required. Daily Contacts Position I Contact Name Company Title E-mail i 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 Bruce Simonson 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 Dave Evans Doyon Dulling 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(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X.65 0.0 160.0 2/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Oft Pressure(psi) Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ • APIIt1Wl:50-629-23483-00-00 2 II^ Date:31812013 - Report#: 4 II II n page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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(TVO..lDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI32-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 1.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) IPOB Temperature(°F) Weather Wind 2,086.0 1,920.2 1.776.00 9.911 179.2 114.0 0.0 Clear WC-21' E @ 17 MPH Daily summary operation 24h Summary Finish P/U M/U BHA#2.Drill,slide and rotate 16"Surface F/310'to 2.086'MD(1,920'TVD)Shoot Gyro data and Schlumberger surveys as needed.May Gas 444 units. Operation at 07.00 Drill 16"Surface hole to 2,367'MD. 24h Forecast Cont.drilling 16"surface F/2,086'to-2,761'MD as per well plan.Start KAM BROOH schedule as per KW BROOH plan forward. 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 01:30 1.50 1.50 DRILL E 20 P PJSA P/U M/U BHA#2 as per Schlumberger DD onsite. 01:30 0600 4.50 6.00 DRILL E 3 P PJSA Slide and Rotate drilling F/310'to 620'MD(556'ND)620 GPM,850 PSI,40 RPM,TON 2-3K,TQF 2K,WOB 20- 30K,HST 115K,SLK 114K,ROT 115K.ECD 9.93 ppg W/9.0 ppg MW.Max Gas 44 units.ADT 2.18 Hrs,TST Hrs 1.78, TRT Hrs.4,Bit Hrs 3.37,Jar Hrs 13.65.Monitor well,static.Shoot Gyro surveys every 30'drilled. 06:00 12:00 6.00 1200 DRILL E 3 P PJSA Slide and Rotate drilling F/620'to 963'MD(947'TVD)720 GPM,1,290 PSI,40 RPM,TON 5-7K,TQF 2-3K,WOB 20-30K,HST 130K,SLK 127K,ROT 130K.ECD 9.99 ppg W/9.1 ppg MW.Max Gas 38 units.ADT 1.86 Hrs,TST Hrs 1.32, TRT Hrs.55,Bit Hrs 5.24,Jar Hrs 16.04.Monitor well,static.Shoot Gyro surveys as per Schlumberger DD. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Slide and Rotate drilling F/963'to 1,492'MD(1,421'ND)750 GPM,1,460 PSI,50 RPM,TQN 7-8K,TQF 3-4K, WOB 20-30K,HST 141K,SLK 128K,ROT 138K.ECD 10.36 ppg W/9.1 ppg MW.Max Gas 121 units.ADT 2.89 Hrs,TST Hrs 1.28,TRT Hrs 1.61,Bit Hrs 8.13,Jar Hrs 18.93.Monitor well,static. 18:00 0000 6.00 24.00 DRILL E 3 P PJSA Slide and Rotate drilling F/1,492'to 2,086'MD(1,920'ND)750 GPM.1,460 PSI,50 RPM,TON 7-8K,TQF 34K, WOB 20-30K,HST 160K,SLK 132K,ROT 142K.ECD 10.2 ppg W/9.4 ppg MW.Max Gas 444 units.ADT 2.98 Hrs,TST Hrs.66,TRT Hrs 2.33,Bit Hrs 11.11,Jar Hrs 21.91.Monitor well,static.Tested Cement Line F/Rig to WIF to 3,500 PSI. No losses to formation. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Bilington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HOE Steve.Millea @enipetroleum.com 907-685-0721 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 Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Ca s.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X.65 0.0 160.0 2/1/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) f Eni E&P Division (Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report l Well Code:27080 Field Name: NIKAITCHUQ • API/UWI:50-629-23483-00-00 2^ Date:3/9/2013 - Report#: 5 II II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Levet(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4_ 18,349.00 112.69 162.8 2.44 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2.821.0 2,423.5 735.00 4.57 160.8 115.0 3.0 Light Blowing Snow NE @ 17 MPH WC-16' Daily summary operation 24h Summary Cont.Rotate and Slide Dull F/2,086'to 2,821'MD(2,422'TVD).BROOH as per K&M BROOH plan forward.Lay down BHA#2.R/U Volant Csg.running tool. Operation at 07.00 RIH 13 3/8"Csg.as per K&M Csg.procedure W/Rep onsite 24h Forecast Run 13 3/8"Csg.to 2.806'MD.as per K&M RIH procedure.Break circulation and condition mud to reduce YP v20 for cement job.Perform cement job as per Schlumberger Rep onsite.R/D Volant running tool.Clean excess surface cement from dg.Install Multi Bowl Well Head as per Vetco Grey. 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 06:00 6.00 6.00 DRILL E 3 P PJSA Rotate&Slide Drill F/2,086'to 2,613'MD(2,229'TVD)750 GPM,1,460 PSI,50 RPM,TON 7-12K,TQF 4-6K,WOB 20-30K,HST 165K,SLK 132K,ROT 142K ECD 10.2 ppg WI 9.4 ppg MW.Max Gas 749 units @ 2,100'MD.ADT 2.67 Hrs,TST 1.85 Hrs,TRT 0.66 Hrs,Bit Hrs 13.78,Jar Hrs 24.58. 06 00 10:30 4.50 10.50 DRILL E 3 P PJSA Rotate&Slide Drill F/2,613' to 2,821'MD(2,422'TVD)800 GPM,1,650 PSI,50 RPM,TON 7-12K,TOE 4-6K,WOB 20-30K,HST 165K,SLK 132K,ROT 142K ECD 10.2 ppg W/9,4 ppg MW.Max Gas 225 units @ 2,571'MD.ADT 1.90 Hrs, TST 1.20 Hrs,TRT 0.70 Hrs,Bit Hrs 15.68,Jar Hrs 26.48. 10.30 11:00 0.50 11.00 DRILL E 11 P Obtain survey at TD and change mode in Gyro Data Tool. 11 00 12:00 1.00 12.00 DRILL E 6 P PJSA as per K&M plan forward.Circ.lX bottoms up per stand while BROOH F/2,821'to 2,740'MD 850 GPM,1,650 PSI, 80 RPM,TRO 8-9K.ROT 145K,HST 165K,SLK 132K 12.00 13:00 1.00 13.00 DRILL E 6 P PJSA BROOH as per K&M BROOH procedure.CBU 2X while racking back one stand per bottoms up F/2,740'to 2,553' MD.850 GPM,1,620 PSI,80 RPM,TRO 8-9K,pumps on ROT 144K. 13 00 19:00 6.00 19.00 DRILL E 6 P PJSA BROOH as per K8M BROOH procedure and hole conditions dictate F/2,553'to 314'MD.850 GPM.1,150 PSI,80 RPM.TRQ 3-4K,pumps on ROT 108K.ECD 10.75 ppg W/9.4 ppg MW.Max Gas 363 units.SLM out of hole(no Change) Correct hole fill. 1900 2130 2.50 21.50 DRILL E 20 P PJSA UD BHA#2 as per Schlumberger DD and MWD onsite.At surface the b8 was in near-new condition,the motor had some significant damage to its stab-sleeve blade surfaces,the 12 1/8 stab was wom to 12 1/16.but was in good condition, the 15 7/8 stab was worn to 15 3/4 and had some significant damage to the surfaces of its blades,and all other BHA components were in good shape with no other damages observed. 21 30 22.30 1.00 22.50 DRILL E 20 P PJSA Clear and clean rig floor and unload BHA#2 tools and Equip. 22.30 00.00 1.50 24.00 DRILL G 20 P PJSA Load floor W/GBR Volant Csg.Equip.R/U running tools to run 13 3/8"Csg. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDrilling @enipetroleum.com '907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson 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 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Darnbacher Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push I Chad Johnson Doyon Dnlling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X.65 0.0 160.0 2/1/2010 Last Leakoff Test Depth(RKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 1 Eni E&P Division 'Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • APIIUWI:50-629-23483-00-00 2^n Date:3/10/2013 - Report#: 6 (I "II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3,7/2013 18,327.0 3,583.4 18,349.00 112.69 162.8 3.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather (Wind 2.821.0 2,423.5 0.00 116.0 -2.0 Overcast WC-18° WSW @ 9 MPH Daily summary operation 24h Summary R/U Volant Tool and RIH 13 3/8"Csg.Change out 4 Joints and 2 Collars due to thread issues.P/U M/U Landing Joint and Hanger and set 13 3/8"Csg @ 2,806'MD.R/U to cement thru Volant tool and condtition mud to<20 YP as per MI Swaco plan.Press.line to 1000 PSI low and 3,100 PSI high W/10 bbl water.Rig pumped 120 bbl 10.1 ppg Mud Push and Schlumberger started pumping 10.7 ppg lead slurry.No losses to formation. Operation at 07.00 Clean and N/D Diverter Stack. 24h Forecast Cont.pumping cement as per Well Plan.Bump plug and check floats.Pull Landing Joint and R/D Volant Tool as per GBR Rep.Clean and haul off surface cement from rig.N/D Diverter Stack and N/U BOPE.RIH to displace Spud Mud W/Faze Pro Spike fluid from WIF. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL G 20 P PJSA Rig up GBR 13 3/8"Volant Equip.and tools as per GBR Rep onsite. 03:00 07:30 4.50 7.50 DRILL G 4 P PJSA Run 13 3/8"Csg per Tally and Well Program F/Surface to 834'MD.Filling casing while RIH and top off every 10 Joints.Checked Float(Good)HST 160K,SLK 110K. 07.30 12:00 ' 4.50 12.00 DRILL G 20 P PJSA Due to problems with Pin and Box threads,lay down 4 joints of 13 3/8"Csg to Pipe Shed.Replaced 2 13 3/8"Csg Collars on Joint 20 8,21. 12:00 16.00 4.00 16.00 DRILL G 4 P PJSA RIH W/Volant 13 3/8"Csg as per Tally and Well Plan F/834'10 2,767'MD.SLK 180K,Fill pipe and top off every 10 Joints.Correct displacement no losses to formation. 16:00 17.30 1.50 17.50 DRILL G 20 P PJSA Verify correct#of joints in the hole.Total of 70 joints,total number of CentralizerslS.P/U M/U 13 3/8"Landing Joint and Hanger as per Vetco Grey Rep onsite.Set Hanger and 13 3/8"Csg.@ 2,806'MD. 17:30 21:30 4.00 21.50 DRILL H 8 P PJSA Break circualtion @ 1.5 bpm,90 PSI.Stage up pumps to 7 bpm W/no losses to formation.FCP 120 PSI.CBU 5.5X as to reduce<20 YP per MI Swaco plan forward to prep for cement job. 21:30 00:00 2.50 24.00 DRILL H 9 P Have PJSM with all key personal for the Cement Job.Blow Down Top Drive.R/U to Volant Tool for cement job.Fill lines with 10 bbl water and test 1000 PSI low and 3.100 PSI high for 10 Min.Pump 120 bbl 10.1 ppg Mud Push @ 5 bpm 110 PSI.Drop bottom plug,Schlumberger pumped 450 bbl 10.7 ppg Lead Slurry @ 5 bpm 420 PSI.ICP 420 PSI. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv l SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson 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 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher dg15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Data CASING 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) • fill* Eni E&P Division I Well Name:5132-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • 2 ,1 Date:3/11/2013 - Report#: 7 n APIIU W:50-629-23483-00-00 " II II page 1 of 1 Wellbore name: SI32-W2 • Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.60 13.08 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...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.41 18,349.00 112.69 162.8 4.44 Daily Information y End Depth(RKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) I P" Temperature(°F) Weather Wind 104.0 2.821.0 2,423.5 0.00 -6.0 Overcast WC-21` W @ 8 MPH Daily summary operation 24h Summary Cont.pumping 454 bbl 10.7 ppg Lead Cement and 72 bbl 12.5 ppg Tail Cement from Schlumberger Cementers.Drop Top Plug and kick out with 10 bbl of water.Use Rig and pump 397 bbl WBM to bump plug @ 3,935 Strks.Hold 950 PSI for 10 Min.CIP @ 02:10 am excess of 195 bbl cement seen at surface.Check Floats(OK)R/D Volant Tool and Csg.Equip.Clean Rig Equip.of cement at surface.N/D Diverter Line and Diverter Stack.Install Vetco Grey Multibowifird U-180PE.L/D 5"HWDP and Jars.Test 13 3/8"Csg.to 2,500 PSI for 30 Min.P/U M/U Mule Shoe and RIH W/5"D.P.to 2,649'MD.Cut and slip drilling line and service Rig. -_ Operation at 07.00 Landing Hanger,Cleaning Pits 24h Forecast Displace Spud Mud W/OBM F/WIF for Freeze Protect.P/U M/U Hanger and Landing Joint.Land Hanger as per Vetco Grey.N/D BOPE and N/U Tree and test.Rig down to move to SD37-DSP1 RWO. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL H 9 P PJSM W/all essential personal.Cont.pumping Schlumberger's 10.7 ppg Lead Cement for a total of 454 bbls @ 5 bpm, ICP 420 PSI.Pump 72 bbl 12.5 ppg Tail Cement @ 4 bpm.Break out Volant toll and drop Top Plug,stab back in Volant Tool and kick out with 10 bbl water F/Schlumberger. 01:00 02:30 1.50 2.50 DRILL H 9 P Rig pumped 397 bbl of treated Spud Mud @ 6.5 bpm,slowed pump rate to 3 bpm prior to bumping Plug.ICP 200 PSI/FCP 450 PSI.Plug bumped @ 3,935 strokes.Press.up on Plug 500 PSI over FCP to 950 PSI and hold for 10 Min.Bleed off Press.and check Float.(Good)CIP @ 02:10 am.195 bbl excess cement was seen at surface. 02.30 05:00 2.50 5.00 DRILL G 20 P PJSA R/D Volant Tool as per GBR Rep onsite.Pull Landing Joint and lay down to Pipe Shed. 05.00 06.00 1.00 6.00 DRILL H 20 P PJSA M/U Stack flushing tool to stand of D.P.,drain and wash Well Head&Hydril of cement.Flush all lines,transfer remaining mud in pit to Rock Washer.Clean and flush surface Equip.in Pits. 06.00 07.00 1.00 7.00 DRILL G 20 P Wash out Volant Tool and L/D to ground.L/D casing running Equip.as per GBR Rep onsite.Pull 2"Demco valve on cement manifold and clean out. Y, 07:00 11:00 4.00 11.00 DRILL C 19 P PJSA N/D Surface Equip.disconnect flow line and pull riser.Disconnect 12'section of Diverter line,P/U Hydril and Diverter Tee and stand back on stump.Pull Vetco Grey high Press.Riser to Rig Floor,L/D Riser.Pull Speed Head from Well Bay and stage on BOP deck.Pull hatch in Well Bay and BOP deck. 11:00 12:00 1.00 12.00 DRILL C 20 P PJSA Install and orientate Vetco Multibowl on Well Head W/Vetco Grey Rep onsite. 12:00 16:30 4.50 16.50 DRILL C 20 P PJSA N/U Multibowt as per Vetco Grey Rep onsite.N/U high Press.drilling riser.N/U BOPE and Bell Nipple.M/U Flow Line.SIMOPS clean pits and install Bell Guide. 16:30 17:00 0.50 17.00 DRILL E 20 U PJSA P/U Mouse hole and R/U to lay down HWDP and Jars. 1200 17:30 0.50 17.50 DRILL E 20 U PJSA LID HWDP and Jars. 1730 18:00 0.50 18.00 DRILL E 20 U PJSA Fill BOPE and check for leaks on all surface Equip. 18.00 19.30 1.50 19.50 DRILL E 12 U PJSA R/U to test 13 3/8"Csg.Fluid pack lines.Test 13 3/8"Csg.to 2,500 PSI for 30 Min.45 strokes total to Press.test. (Charted)Bleed off Press,and R/D test equip. 19:30 21 30 2.00 21.50 DRILL E 4 U PJSA P/U M/U Mule Shoe&XO.Single in hole 10 joints of 5"D.P.RIH stands F/Demck to 2,649'MD.HST 127K,SLK 110K 21:30 23:00 1.50 23.00 DRILL E 20 U PJSA Cut and slip drilling line,Adjust brakes. 23:00 00:00 1.00 24.00 DRILL E 20 U Grease and inspect Top Drive,Blocks,Drawworks,Iron Roughneck and Tongs. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-605-0715 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 Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(113/gal) Leak Off Pressure(psi) !II?* Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUO • APIIUWI:50-629-23483-00-00 2� r, Date:3/12/2013 - Report#: 8 'I 0 II page 1 of 1 Wellbore name: S132-W2 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 213-013 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) 5132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 6.19 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,821.0 2,423.5 0.00 101.0 -20.0 Clear WC-20` Calm Daily summary operation 24h Summary Dislace well F/Spud Mud to Faze Pro Freeze Protect.M/U Vetco Hanger on 5"D.P.Kill String.Land Hanger and L/D Landing Joint.N/D BOPE and R/U Tree to well.Test Tree as per Vetco Grey Rep onsite.Clean Pits and start to R/D to move Rig.Rig released @ 18:00 pm. Operation at 07.00 Moving Rig. 24h Forecast Rig down and Skid Rig to SD37-DSP 1 RWO. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 8 U PJSM Have pre job meeting W/all essential personal.R/U to displace Spud Mud to Faze Pro Freeze Protect. 01:00 03:30 2.50 3.50 DRILL E 9 U Displace 9.3 ppg Spud Mud W/9.4 ppg Faze Pro to Freeze Protect well @ 5 bpm 90 PSI while reciprocating and rotating. ROT 122K,SLK 115K 0330 05:30 2.00 5.50 DRILL C 20 U PJSM Install 4 1/2"IBTM X TT525 crossover,M/U Tubing Hanger as per Vetco Grey Rep onsite. 05:30 07:00 1.50 7.00 DRILL C 20 U Land Tubing Hanger on Well Head.5"D.P.Kill String set @ 2,627'MD HST 123K SLK 115K Test seals to 5,000 PSI for 10 Min.as per Vetco Grey Rep onsite.L/D Landing Joint. 07:00 10:00 3.00 10.00 DRILL C 20 U PJSA N/D BOPE.N/D Vetco Grey high Press.riser.Disconnect and remove 3 sections of Suit Cases between Rock Washer and WIF,2 sections between Rig and Valve House.Remove bermingon eaterty and north side pf Rig.Prep for removal of sections of Diverter line. 10:00 12:00 2.00 12.00 DRILL C 20 U PJSM Install Tree and test void to 5,000 PSI for 10 Min.W/Vetco Grey Rep onsite.R/U to test Tree W/Rig test pump. 1200 14:00 2.00 14.00 DRILL C 20 U PJSA Vetco Rep set TWC.Fill Tree W/Diesel and test to 500 PSI fro 5 Min.Low and 5,000 PSI high.R/D test Equip.Vetco Grey Rep pulled TWC&installed BPV.SIMOPS continue cleaning Pits.R/D Pump#3.test moving system and check tire Press.Work on removing Diverter line. 1400 18:00 4.00 18.00 DRILL A 20 U PJSA Prep F/skidding Rig Floor.Continue to leaning Pits and work on Diverter line.Work on inner connect and Suit Cases.Rig released @ 18:00 pm. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15 @enipetroleum.com 907-685-0722 Em representative Jack Kvasnikoft ENI HSE 907-685-0721 907-398-8770 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 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) fill* Eni E&P Division I Well Name:SI32-W2 EN/Petroleum Co.Inc. Daily Report` Well Code:27080 Field Name: NIKAITCHUQ • API/UWI:50-629-23483-00-00 2^ Date:4/24/2013 - Report#: 9 I' �l page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 Rig Information Contractor I Rig Name Rig Type DOYON DRILLING I 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) SI32-W2 DRILLING 3/7/2013 18.327.0 3.583.4 18,349.00 112.69 162.81 46.44 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,821.0 2,423.5 0.00 108.0 2.0 Mostly Cloudy,WC- SW @ 15 MPH 16' Daily summary operation 24h Summary NU BOP,set test dart and test joint,RU BOP test equipment.test BOP,test witness waived by AOGCC Rep.Jones,Valves and rams tested to 250/3500,annular preventer to 250/2500,test w15"test joint Operation at 07.00 RD BOPE Test Equipment. 24h Forecast Cont.test BOP,pull test dart,PU&LD hanger.RU&displace well w/LSND,reverse circulate displacement,POOH&stand back 5"kill string,PU 216 joints 5"DP and stand back. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 8.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 18.00 20:30 2.50 2.50 DRILL C 5 P 'PJSM/NU BOP 20.30 22:00 1.50 4.00 DRILL C -5 P PJSM/set test dart and test joint,RU BOP test equip. 22.00 00:00 2.00 6.00 DRILL C -12 P Test BOP,test witness waived by AOGCC rep Jones,test all valves and rams to 250 low,3500 high,annular preventer test to 250 low,2500 high,test od 5"test joint. 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 Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0716 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 Dolling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Eni representative Davide Simeone ENI Project Manager Eni representative Nelson Carballo ENI Dilling Supenntenda Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) � Eni E&P Division �,} 'Well Name: 5132-W2 J ENI Petroleum Co.Inc. Daily Repo ` Well Code:27080 Field Name: NIKAITCHUO • Date:4/25/2013 - Report#: 10 APIIl1VJl:50-629-23483-00-00 2'r " page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327.01 3.583.41 18,349.00 112.69 162.8 49,44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(tt) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather !Wind 2,821.0 2,423.5 0.00 103.0 9.0 Light Snow.WC 4° 1SW @ 9 MPH Daily summary operation 24h Summary Cont.test BOPE 250/3500,no failures,perform Koomey test-good.BD RD test equip,PU landing joint retrieve test dart,pull TWC wl T-bar,BOLDS,pull hanger to floor,LD landing joint,hanger and XO's,PU 2 joints 5"dp,RIH to 2671'MD,displace OBM 8 wellbore by reverse circulation w/50 bbl viscosified citric spacer followed by 470 bbl LSND mud,5.5 bpm 300 psi,clean surface equip,POOH& rack in derrick vA 5"kill string,LD XO&mule shoe,PU 5"DP singles and rack in derrick,rig service,coot PU 5"DP,LD mousehole and remove thread protectors from rig floor,MU running tool and set wear bushing. Operation at 07.00 PU drilling BHA#3 24h Forecast Cut and slip drilling line,perform casing test to 2500 psi 30 min hold,PU drilling BHA,RIH to FC,drilling cement,float equip.and 20 ft.new hole.circ&cond.,perform LOT.Drill ahead as per SLB DD. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 04:30 4.50 4.50 DRILL C -12 P PJSA/cont.test BOP 250 low 3500 high,no failures,Koomey test-good. manual and hyd.choke tests to 1500 psi- good. 04.30 05:30 1.00 5.50 DRILL 'C 5 P BD RD test equip. 05:30 08:00 2.50 8.00 DRILL C 5 P PU landing joint,pull test dart(took 3 attempts),LD landing joint,pull TWC w/T-bar,PU landing joint&MU to hanger,back out lock down screws,pull hanger to floor,LD landing joint,hanger.and xo's.PU 2 joints 5"DP&RIH to 2671'MD. '08:00 11:30 3.50 11.50 DRILL M 7 P PJSM/displace OBM f/wellbore by reverse circulation vs'50 bbl viscosified citric spacer followed by 470 bbl LSND mud, stage up to 5.5 bpm.300 psi. 11:30 14:00 2.50 14.00 DRILL M 4 P 'PJSA/clean surface equip.-shakers,auger,possum belly etc.,prepare to POOH,LD 2 singles,POOH&rack in demck w/5"kill string on elevators,LD XO&mule shoe,PU wt=120k,SO we=120k 14:00 16:00 2.00 16.00 DRILL E 4 P Clean rig floor,PU 5"DP in mouse hole and rack in derrick. 16:00 17:00 1.00 17.00 DRILL E '20 P Perform rig service 17:00 22:30 5.50 22.50 DRILL E 4 P Cont.PU 5"DP in mousehole and rack in derrick 22:30 00:00 1.50 24.00 DRILL C '20 P LD mousehole&thread protectors from rig floor,MU running tool&set wear bushing 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 Bruce Simonson ENI Dolling Supv. 907-685-0715 Em representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Em representative Bemie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Em representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.cum 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Eni representative Davide Simeone ENI Project Manager Em representative Nelson Carballo ENI Dilling Superintenda Last Casing seat Cas.Type 00(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 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) I Eni E&P Division (Well Name: SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ • API/UWI:50-629-23483-00-00 2^ Date:4/26/2013 - Report#: 11 'I II page 1 of 1 Wellbore name: S13 -W2 page Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 DRILLING 3/7/2013 18,327.0 3.583.41 18,349.00 112.69 162.8 50.44 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,466.0 2.785.6 624.00 3.11 200.6 102.0 -6,0 Mostly Cloudy WC- NNE @ 10 MPH 23 Daily summary operation 24h Summary Cut 8 sip drilling line,service draw works,crown,and traveling equip./inspect brakes.Perform casing test to 2500 psi f/30 min.,PU MU drip BHA#3,RIH to 1373'perform shallow hole test on downhole tools,cost RIH to 2717',drill cement and float equip to 2806'MD.Drill 21'new hole to 2842'MD,2436'TVD.650 gpm-660 psi,60 rpm-4-10k lq,hst=152k,s1k=123k.rot--132k.CBU while POOH 1 stand to 2770'MD,RU&LOT/FIT to 13.0 ppg,RIH to 2835'shoot surveys and down links as per DD,Drip(/2842'to 3466'MD. Operation at 07.00 Drilling ahead @ 3,609'MD w/900gpm-1300psi,140-180 rpm wl 8-10k tq. 24h Forecast Cost drilling ahead w/12 1/4"hole(/3466'MD as per well plan. 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 01:30 1.50 1.50 DRILL -E 20 P PJSA/cut and slip drilling line,service draw works,crown&traveling equip./inspect brakes 01:30 _ 02:30 1.00' 2.50 DRILL E 19 P Test 13-3/8"casing to 2500 psi @ lbpm,44 strokes=2580 psi,hold for 30 min.19 psi loss over 30 min.Test plotted and charted. 02:30 06:00 3.50 6.00 DRILL E 20 'P PJSA/PU MU drilling BHA#3 F/0 T/253',HST=100k,SO=105k 06:00 '08:00 2.00 8.00 DRILL 'E 4 P PJSA/clear&clean rig floor,RIH 4 BHA#3 F/253'T/1373'MD,fill pipe and perform shallow hole test on downhole tools 650 GPM 530 psi,154 spm,HST=125k,SO=119k 08:00 10:00 ' 2.00 10.00 DRILL E 4 P Cont.RIH w/drilling BHA#3 to 2717'MD,HST=155k,SO=135k 10:00- 12:00 2.00 12.00 DRILL E 19 P Ddg cement&float equip F/2717'T/2722'MD,2356'ND/155 spm,60 rpm,8-10k tq,650 GPM,650 psi,HST=155k,SO =135k,ROT=138k 12:00 '14:30 ' 2.50 14.50 DRILL E 19 P PJSA/cont.drill out float collar and cement(/2722'tag shoe @ 2806'MD,cunt drill cement and tag bottom @ 2821'MD. Drill out 21'new hole to 2842'MD,2436'ND.SPM=155,RPM=60,TQ=8-10k,GPM=650,PSI=660,WOB=4-10k, HST=152k,SLK=123k,ROT=132k 14:30 '15:30 1.00' 15.50 DRILL 'E 7 P CBU w/650 GPM-660 PSI&60 RPM 44-8k TO,while POOH 1/2770'MD,rack back stand,BD topdrive. 15:30 16:30 ' 1.00. 16.50 DRILL 'E 19 P PJSA/RU to LOT/FIT,FIT well to 13.0 ppg,RD BD lines 16:30 '17:30 ' 1.00 17.50 DRILL 'E 6 P Wash and ream(/2770' to 2835'MD,650 GPm-660 PSI,60 RPM w/4-7k TO,shoot surveys and send down links as per • SLB DD 17:30 00:00 6.50 24.00 DRILL E 3 P Ddg(/2842't/3466'MD,ND=2786',GPM=900,PSI=1230,RPM=140-180,SPM=214,TQN=8-10k,TQF=5-7k,WOB=2-12k, HST=155k,SLK=129k,ROT=141k,ECD's=9.98ppg.MW=9.3ppg,max gas=71 units,ADT=3.11,Bit hrs=3.23.Jar Hrs= 3.23 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 Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls 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 ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondriling.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 L80 0.7 2,806.0 3/10/2013 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) 2,842.0 2437.03 LSND 9.25 470.0 12.96 1,641.0 I. * Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ • APIIUWI:50-629-23483-00-00 2^n Date:4/27/2013 - Report#: 12 II II II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator I ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 Rig Information Contractor Rig Name Rig Type DOYON DRILLING I 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) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 51.44 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) I POB Temperature(°F) Weather Wind 5.804.0 3,188.5 2.338.00 15.31 152.7 102.0 16.0 Light Snow.WC-1' W @ 14 MPH Daily summary operation 24h Summary Cont.drlg 12-1/4"hole from 3,466'MD to 5,804'MD,(3106'TVD),900 gpm/1680psi,140-180rpm412-14k tq on&7-10k tq off.HST=166k,SLK=118k.ROT=142k,ECD=10.07ppg,MW=9.3ppg,Max Gas= 18 units,18.42 total hrs on bit&jars. Operation at 07.00 Drilling ahead @ 5,844'MD w/900 GPM and 180 rpm as per SLB DD and well plan. 24h Forecast Cont ddg 12-1/4"hole(/5,804'MD to proposed TD—9,377'MD. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.30 Time Log Start End Cum I Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00'DRILL E °3 °P Cont.drlg t/3466'to 3800'MD,ND=2916',GPM=758,PSI=970.RPM=120-160,SPM=180,TQN=8-10k,TQF=7k, HST=155k,SLK=140k,ROT=129k,ECD=9.85ppg,MW=9.2ppg,Max gas=71 unhs,ADT=4.40 hrs,Bit hrs=7.63,jar hrs=7.63,monitor well-static. 06.00 12.00 6.00 12.00 DRILL E .3 'P Cont drlg f/3800'to 4268'MD,TVD=2998,GPM=893,PSI=320,SPM=211.RPM=180,TQN=9-10k,TQF=8-9k,WOB=8- 12k,HST=155k.SLK=123k,ROT=139k,ECD=10.07ppg.MW=9.2ppg,Max gas=Bungs,ADT=3.15hrs,Bit hrs=10.78,Jar hrs=10.78• 120C 18:00 6.00 18.00 DRILL E 3 P Cont.drlg from 4268'to 5197'MD,TVD=3106',GPM=900,PSI=1560,SPM=214,RPM-140-195,TQN=10-12k,TQF=8k. HST=160k,SLK=120k,ROT=139k,ECD=10.21ppg,MW=9.3ppg,Max Gas=8 units,ADT=3.71hrs,Bit hrs=14.49,Jar hrs=14.49,monitor well-static 1507 0000 6.00' 24.00 DRILL E '3 •P Cont drlg f/5197'to 5804'MD,ND=3179',GPM=900,PSI=1680,SPM=214,RPM=140-180,TQN=12-14k,TQF=7-10k, WOB=8-10k,HST=166k,SLK=118k,ROT=142k,ECD=10.07ppg.MW=9.3ppg,Max Gas=18 units,ADT=3.93hrs,Bit hrs=18.42,Jar hrs=18.42 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 Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Mais 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 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 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 - 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) 2,842.0 2,437.03 LSND 9.25 470.0 12.96 1.641.0 Eni E&P Division f Well Name:S132-W2 ffifAillil ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ • Date:4/28/2013 - Report#: 13 API/UWI:50-629-23483-00-00 i i " page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 5360 13.08 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(ftlhr) I DFS(days) SI32-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.81 52.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather !Wind 7,343.0 3,419.4 1,539.00 18.32 84.0 102.0 12.0 Light Snow,WC-1° WSW @ 12 MPH Daily summary operation 24h Summary Cont.drlg 12-1/4"hole from 5804'MD to 7343'MD,(3420'TVD),700-900 GPM/1,110-1760psi,120-200rpm/11 k Tq on btm 8 7-8k off btm.WOB=2-14k,HST=170k,SLK=115k,ROT=148k,ECD=9.77, MW=9.15,Max Gas=919 units.Total bit and jar hrs=36.74 Operation at 07.00 Drilling ahead @ 7,622'MD w/900 GPM 8 180 RPM,as per SLB DD and well plan. 24h Forecast Coot dolling 12-1/4"hole from 7343'MD to proposed TD^9377'MD,900 GPM 8 180 RPM as per SLB DD.Control drill N-sand interval f/-8000'to—8250'MD as per eni Geologist. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Cont.drilling 1/5804'to 5990'MD,TVD=3215',GPM=906,PSI=1690,SPM=215,RPM=180,TQN=9-10k,TQF=8-10k, WOB=2-l0k,HST=170k,SLK=115k,ROT=143k,ECD=9.97ppg.MW=9.2ppg,Max Gas=18 units,ADT=5.02 hrs,Bit hrs =23.44,Jar hrs=23.44 06:00 12:00 6.00 12.00 DRILL E -3 P Cont drlg 1/5990'to 6410'MD,TVD=3722',GPM=906,PSI=1770,SPM=215,RPM=182,TQN=10-11 k,TQF=8-10k,WOB=4 -8k,HST=168k,SLK=119k,ROT=144k,ECD=10.11,MW=9.3,Max Gas=13 units,ADT=4.06,Bit hrs=27.50,Jar hrs=27.50 12:00 18:00 6.00 18.00 DRILL E -3 P Cont.drlg 1/6410'to 6976'MD,TVD=3360',GPM=900,PSI=1740,SPM=214.RPM=120-200.TQN=12-14k,TQF=7-9k, WOB=4-14k,HST-167k,SLK=117k,RPT=146k,ECD=10.12,MW=9.2,Max Gas=245 units,ADT=4.77,Bit hrs=32.27,Jar hrs=32.27 18:00 00:00 - 6.00 24.00 DRILL E -3 P Cont.drlg f/6976'to 7343'MD,TVD=3420',GPM=700-900,PSI=1110-1760,RPM=120-200,TQN=11k,TQF=7-8k,WOB=2 -14k,HST=170k,SLK=115k,ROT=148k,ECD=9.77,MW=9.15,Max Gas=919 units,ADT=4.47,Bit hrs=36.74,Jar hrs=36.74 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener -ENI Senior Dulling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson 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 akrigclerksdoyonl5 @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 Dolling Tool Pusher ng15 @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 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) I P Surf Applied(psi) I Eq .Mud Weight(lb/gal) I Leak Off Pressure(psi) 2,842.0 2,437.03 LSND 9.25 470.0 12.96 1,641.0 Eni E&P Division I Well Name:S132-W2 flY* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ • APIIUW:50-629-23483-00-00 2^n Date:4/29/2013 - Report#: 14 II II ii page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° 'Operator I ENI Share)%) Well Configuration type 213-013 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 _LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) S132-W2 DRILLING 3/7/2013 18,327.01 3,583.4 18,349.00 112.69 162.8 53.44 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) !Avg ROP(ft/hr) [POB Temperature(°F) I Weather 'Wind 9,304.0 3,621.5 1.961.00 15.41 127.31 103.0 4.0 Light Snow,WC-15° NE @ 20 MPH Daily summary operation 24h Summary Cont drlg 12-1/4"hole from 7343'to 9304'MD,700-900GPM/120-200RPM as per SLB.DD.Mud weight was increased to 9.4ppg from 9.2ppg prior to drilling the N-Sand/Schrader Bluff interval. Operation at 07.00 Circulate and backream out of hole @ 9,308'MD w/900gpm&120rpm as per K&M rep.and well plan. 24h Forecast Cent to drill 12-1/4"hole to 69304'10 projected TD—9407'as per Eni geologist and SLB.DD.Circulate and backream out of hole w/900gpm and 12Orpm as per K&M.rep.&well plan. Lithology 'Shows MAASP Pressure(psi) I 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 06.00 6.00 6.00-DRILL E 3 P Cont.drlg t/7343'to 7907'MD,TVD=3493',GPM=702,PSI=1290,RPM=122,TON=11-12k,TOF=7-8k,WOB=10-12k, HST=172k,SLK=119k,ROT=148k,ECD=10.20,MW=9.4,Max Gas=122 units,ADT=4.44,Bit Hrs=41.18,Jar Hrs=41.18 06 00 -1200 6.00 12.00 DRILL E 3 P Cont.ddg(/7907'to 8050'MD,TVD=3510',GPM=655,PS1=1190,RPM=122,TQN=11-12k,TQF=8-9k,WOB=12k. HST=180k,SLK=115k,ROT=148k,ECD=10.33,MW=9.4,Max Gas units=82,ADT=3.05,Bit Hrs=44.23,Jar Hrs=44.23 12 00 -18.00 6.00 18.00 DRILL E 3 P Cont.ddg f/8050'to 8549'MD,TVD=3570',GPM=650,PSI=1170,RPM=60-200,TQN=12-13k.TQF=7-8k,WOB=15-20k, HST=175k,SLK=119k,ROT=150k,ECD=10.32,MW=9.4.Max Gas units=970,ADT=4.76,Bit Hrs=48.99.Jar Hrs=48.99. 18.00 -00:00 6.00 24.00 DRILL E 3 P 1Cont.drig t/8549'to 9304'MD,TVD=3619',GPM=650-900,PSI=2150,RPM=60-200,TQN=14k,TQF=8k,WOB=10-15k, HST=178k,SLK=112k,ROT=148k,ECD=10.7,MW=9.4,Max Gas units=475.ADT=3.16,Bit Hrs=52.15.Jar Hrs=52.15 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 Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch 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 Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doynndrilling.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 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) I Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,842.0 2,437.03 LSND 9 25 470.0 12.96 1,641.0 1119* Eni E&P Division ENI Petroleum Co.Inc. Daily Report [Well Name:SI32-W2 Well Code:27080 Field Name:NIKAITCHUQ • 2 n n Date:4/30/2013 - Report#: 15 API/UWI:50-629-23483-00-00 II I'II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 54.44 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,407.0 3,625.5 103.00 0.60 171.7 102.0 -14.0 Mostly Cloudy,WC- SW @ 10 MPH 35' Daily summary operation 24h Summary Drill ahead F/9.304'to 9,407'MD(3,625'TVD)9 5/8"Csg TD called by Geologist.Perform K&M clean up cycle pulling one stand per BU F/9,407'to 9,307'MD.Begin BROOH schedule as per K&M BROOH schedule F/9,307'to 2,680'MD.Hole unloaded @ 2,680'MD staged up pumps to 900 GPM.Continue to BROOH F/2,680'to 2,120'MD. Operation at 07.00 L/D BHA#3 as per Sclumberger DD and MWD. 24h Forecast Cont.BROOH as per K&M BROOH schedule F/2,120'MD to BHA#3.L/D BHA#3.P/U BHA#4 and RIH to 9,407'MD.Circ.hole clean as per K&M Rep onsite.POOH on elevators to 8,500'MD.MAD pass F/8.500'to 7,900'@ 300 FPH.Circ.BU and POOH on elevators. 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 E 3 P PJSA Drill ahead F/9,304'to TD 9,407'MD(3,625'TVD)895 GPM,2,080 PSI,180 RPM,TON 12K,TQF 7-8K,WOB 10K, HST 175K,SLK 112K,148K ECD 10.68 ppg W/MW 9.5 ppg.Max Gas 22 units.ADT.6 HRS,Bit Hrs 52.75,Jar Hrs 52.75.Monitor well,static.9 5/8"Csg.TD called by Geologist. SPR @ 9,407'MD(3.625'TVD)W/9.5 ppg MW MP#1 30-310,40-360 MP#2 30-310,40-360 01 30 03.30 2.00 3.50 DRILL E 7 P PJSA as per K&M Rep onsite perform BU Fl 9,407'to 9,307'MD while racking back one stand at a time.HST 175K,SLK 112K,ROT 148K,900 GPM,2.100 PSI,120 RPM,TQF 10-11K.Monitor well,static. 03.30 12.00 8.50 12.00 DRILL E 6 P PJSA Begin BROOH as per K&M BROOH schedule with K&M Rep onsde F/9,307 to 7,160'MD 900 GPM,2,000 PSI,120 RPM,TQF 10K,HST 175K,SLK 112K,ROT 143K.Monitor well,static. 1200 1800 6.00 18.00 DRILL E 6 P PJSA Begin BROOH as per K&M BROOH schedule with K&M Rep onsite F/7.160'to 4,547'MD 900 GPM,1,530 PSI.120 RPM,TOF 7-9K,ROT 135K.ECD 10.12 ppg WI 9.5 ppg MW. 18.00 22.00 400 22.00 DRILL E 6 P PJSA Begin BROOH as per K&M BROOH schedule with K&M Rep onsite F/4,547'to 2,680'MD 900 GPM,1,330 PSI,120 RPM,TOF 5-9K,ROT 128K.ECD 10.11 ppg W/9.4 ppg MW. 22.00 23.00 1.00 23.00 DRILL E 7 P Hole unloaded CBU while staging up pumps to 900 GPM,CBU 2X,1,330 PSI,80 RPM,TRO 4-5K,ECD 9.89 ppg WI 9.35 ppg MW. 23 00 -0000 1.00' 24.00 DRILL E 6 P PJSA Begin BROOH as per K&M BROOH schedule with K&M Rep onsite F/2,680'to 2,120'MD 900 GPM,1,230 PSI,120 RPM,TOF 4K,ROT 124K.ECD 9.81 ppg WI 9.4 ppg MW. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 @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 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(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.7 2.806.0 3/10/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) I Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,842.0 2,437.03 LSND 9.25 470.0 12.96 1,641.0 Eni E&P Division Name: 5132-W2 firfilikl ENI Petroleum Co.Inc. Daily Report 'Well Code:27080 Field Name:NIKAITCHUQ • APIIUW:50-629-23483-00-00 2^ii Date:5/1/2013 - Report#: 16 II 'I page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.81 55.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,407.0 3,625.5 0.00_ 104.0 -2.0 Overcast WC-21° SW @ 14 MPH Daily summary operation 24h Summary Cont to BROOH F/2,120'to 1,400'MD.Circ.BU 3 X as per K&M BROOH schedule.POOH on elevators to BHA#3.L/D BHA#3.Pull Wear Bushing and inspect.P/U M/U BHA#4 and RIH to 1,000'and perform shallow hole test.RIH F/1,000'to 9,214'MD.Wash and ream F/9.214'to 9,407'MD.CBU @ 9,400'MD 900 GPM,1,930 PSI and 120 RPM.BROOH F/9.400'to 9,022'MD 900 GPM,120 RPM, 1,900 PSI.Perform MAD pass Fl 9.022'to 8,187'MD 900 GPM,1,760 PSI and 120 RPM. Operation at 07.00 POOH on elevators to 6,983'MD. 24h Forecast Mad Pass F/8,187' to 7,900'MD as per Sclumberger MWD.CBU till hole is clean.Pull 10 stands and monitor well.Pump dry job and POOH on elevators to BHA#4.L/D BHA#4.Change out Wear Bushing for running 9 5/8"Csg.Change out to 9 5/8"Csg.Rams and test.R/U Testa Csg.running Equip.RIH WI 9 518"Csg as per tally. Lithology I Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule with K&M Rep onsite FI 2,120'10 1,400'MD 900 GPM,1,180 PSI,120 RPM, TQF 3K,ROT 121K,HST 119K.SLK 121K. 02:30 03:00 0.50- 3.00 DRILL E 7 P PJSA As per detail&K&M Rep onsite Circ.BU 3X or as hole dictates.900 GPM,1,180 PSI,TOF 3K,80 RPM,HST 119K, SLK 120K,ROT 121K,Monitor well,static. 03:00 04:00 1.00. 4.00 DRILL E 4 P PJSA As per K&M Rep onsite POOH on elevators F/1,400'to 253'MD.HST 98K,SLK 102K. 04:00 07:00 3.00 7.00 DRILL E 4 - P PJSA As per Schlumberger DD&MWD onsite,POOH and L/D BHA#3.But Grade 1-1-BT-A-X-1-No-TD 07:00 07:30 0.50. 7.50 DRILL E 20 P PJSA Pull and inspect Wear Bushing due to hanging up in stack with BHA#3 components on the way in and out.Vetco Grey Rep onsite.Waer Bushing was fine and not egged.Well head set screw was needed to be back out to resolve problem. 07:30 08:30 1.00� 8.50 DRILL E 20 P PJSA Clean and clear rig floor of BHA#3 components.Prep for P?U BHA#4 with Nuclear Sources. 08:30 11:00 2.50 11.00 DRILL E 20 P PJSA Meeting with all involved parties as per detail&Schlumberger DD.P/U M/U BHA#4 W/Nuclear Sources to 253'MD. HST 98K,SLK 102K.Monitor well,static. 11:00 12:00 1.00 12.00 DRILL E 4 P PJSA RIH W/BHA#4 and 5"D.P.F/253'to 1,000'MD HST 105K,SLK 107K. 12:00 12.30 0.50 12.50 DRILL E 7 P PJSA Perform shallow hole test @ 1,000'MD as per Schlumberger MWD.750 GPM,710 PSI,HST 108K.SLK 108K. 12:30 17:00 4.50. 17.00 DRILL E 4 P 'PJSA RIH W/BHA#4&5"D.P.F/1,000'to 9,124'MD,filling every 20 stands.HST 175K,SLK 120K,Correct displacement observed. 17:00 17:30 0.50' 17.50 DRILL E '6 P Wash and ream F/9,124'tag bottom @ 9,407'MD.400 GPM,1,930 PSI,40 RPM,TRO 9K.MW 9.4 ppg.ROT 149K,HST 176K,SLK 120K. 17:30 18:30 1.00' 18.50 DRILL E 7 P PJSA CBU as per K&M Rep onsite @ 9,400'MD.900 GPM,120 RPM,ROT 142K,ECD 10.19 ppg W/9.4 ppg MW. SPR @ 9,400'MD(3,625'TVD)W/9.4 ppg MW MP#1 30-210,40-250 MP#2 30-210,40-250 MP#3 30-210,40-250 18:30 19:00 0.50- 19.00 DRILL E 6 P PJSA BROOH F/9,400'to 9,022'MD 900 GPM,1,900 PSI,120 RPM,TRQ 9K,ROT 142K,ECD 10,08 ppg WI 9.4 ppg MW. 19:00 00:00 5.00 24.00 DRILL E 11 P PJSA Perform MAD pass as per Schlumberger MWD F/9.022'to 8,187'MD.900 GPM,1,760 PSI,120 RPM,TRQ 8K, ROT 141K.ECD 9.97 ppg W/9.4 ppg MW. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 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 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 13 3/8 12.415 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,842.0 2437.03 LSND 9.25 470.0 12.96 1,641.0 Eni E&P Division 'Well Name:SI32-W2 Ifitilli ENI Petroleum Co.Inc. Daily Report Code:27080 Field Name:NIKAITCHUO • APIIUIM:50-629-23483-00-00 2�,,t Date:512/2013 - Report#: 17 II 'I o page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(It) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327,0 3.583.4 18.349.00 112.69 162.8 56.44 Daily Information End Depth(ftKB) End Depth(TVD)(t..'Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ftJhr) POB Temperature(°F) Weather I Wind 9407.0 3625.5 0.001 104,0 2.0 Light Snow WC-17" SW @ 15 MPH Daily summary operation 24h Summary Perform MAD pass as per Schlumberger MWD F/8,187 to 7,931'MD.Circ.1 X BU until Shakers were clean.POOH on elevators F/7,931'to 253'MD.No losses to formation.UD BHA#4 and nuclear source as per Schlumberger DD and MWD onsite.Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite.C/O Variable upper rams to 9 5/8"Csg.Rams.Test rams 250 PSI low and 3,500 PSI high.Pull test plug and install 48"Wear Bushing.R/U Tesco Csg.Drive System.P/U M/U 9 5/8"Csg.Shoe Track.Perform Negitive test on Shoe track.(good)Fill Shoe Track and perform Float check. (Good)Float in 9 5/8"Csg.to 2,436'MD. Operation at 07.00 Float 9 5/8"Csg.to 5,114'. 24h Forecast Float 9 5/8"Csg.W/Tesco Drive System F/2,426'to 9,387'MD.P/U M/U Cement Head W/out Plugs and fill 9 5/8"Csg.as per Well Program.Circ.and condition LSND to<18 YP prior to cement job. Perform cement job as per Schlumberger Rep onsite.R/D BOPE and set Emergency Slips W/Vetco Grey Rep onsite. Lithology Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 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 E 11 P PJSA As per detail&Schlumberger MWD Cont.MAD pass FI 8,187'to 7,931'MD 900 GPM,1,800 PSI,120 RPM,TRF 8- 9K,HST 145K. 01:30 02:30 1.00 2.50 DRILL 'E 7 P PJSA Circ.BU 1 X until Shakers looked clean.900 GPM,100 RPM,1,790 PSI,HST 145K,SLK 138K,Monitor weN,static. 02:30 08:30 6.00 8.50 DRILL E 4 P PJSA POOH on elevators W/K&M Rep onsite F/7,931'to 253'MD.HST 155K Monitor well,static. 08:30 11:00 2.50 11.00 DRILL E 4 P PJSA PJSM with all parties,Schlumberger DD&MWD.UD BHA#4 and unload nuclear sources F/253'to 0".Calculated hole fill observed. 11:00 12:00 1.00 12.00 DRILL E 20 P PJSA Clean&clear rig floor of BHA#4 components.Prep&drain stack to change out Rams. 12:00-- 12:30 0.50 12.50 DRILL C 20 P PJSA Pull Wear Bushing and install test plug as per Vetco Grey Rep onsite. 12:30 14:30 2.00 14.50 DRILL C 20 P PJSA Change out variable upper ramds to 9 5/8"Csg.Rams.R/U&test 9 5/8"Csg.Rams W/test joint to 250 PSI low and 3,500 PSI high.R/D test Equip. 14 30 15:00 0.50 15.00 DRILL C 20 ''P PJSA Pull test plug and install Wear Bushing as per Vetco Grey Rep onsite.Length 48",ID 12.31",OD 13.438" 15:00 18:30 3.50 18.50 DRILL G 20 'P PJSA Remove Bails and Bell Guide.Load floor of Tesco Equip.R/U Tesco Csg.Equip.Prep to run 9 5/8"Csg. 18:30 21:00 2.50 21.00 DRILL G 4 P PJSA P/U M/U 9 5/8"Shoe Track.Perform negative test on Shoe.(Good)Fill Shoe Track&perform Float check.(Good). Witnessed by Company Rep onsite.F/0'to 166'MD 21:00 00:00 3.00 24.00 DRILL G 4 P PJSA Float in 9 5/8"Csg.utilizing Tesco Csg.Drive System F/166'to 2,436'MD.SLK 80K.Calculated displacement observed.Total joints in hole 60. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 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 ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool 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 L80 0.7 2,806.0 3/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type !Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,642.0 2,437.03 LSND 9.25 470.0 12.96 1,641.0 Eni E&P Division Leh Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • APIIUWI:50-629-23483-00-00 2 0111*I'^n Date:5/3/2013 - Report#: 18 II �I page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) 1Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(It) Ground Level(It) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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)(It) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 57.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 9,407.0 3,625.5 0.00 102.0 -2.0 Mostly Cloudy WC- WNW @ 4 MPH 10" Daily summary operation 24h Summary Cont.floating 9 5/8"Csg.W/Tesco Cog.Drive System F/2,436'to 4,030'MD.Begin rotating 9 5/8"Csg.W/Tesco Csg.Drive System F/4,030'to 9.387'MD.R/D Tesco Csg.Drive System.R/U Cement Head and R/U to fill 9 5/8"Csg.Stage fill 9 5/8"Csg as per Well Plan and MI Swaco plan forward.Load plugs in Cement Head as per Schlumberger Rep onsite.Break Circ.@ 1/2 bpm 280 PSI,stage pumps up to 8 bpm 390 PSI and CBU 4.5 X conditioning mud to<18 YP as per MI Swaco Engineer.No losses observed.PJSM W/all essential personal for cement job.Test cement lines 500 PSI low& 3,000 PSI high.Check OPSD on cement unit.Rig pumped 100 bbl 10.5 ppg Mud Push II @ 5 bpm 150 PSI.Schlumberger cementers dropped Bottom Plug and pumped 212 bbl 12.5 ppg Deep Crete Vit ..: cement @ 4 bpm 650 PSI.Kicked out Top Plug W/10 bbl water and fumed over to rig.Rig pumped 520 bbl 9.4 ppg LSND @ 8 bpm 190 PSI.Slow pump rate to 6 bpm prior to bumping bottom plug @ 4,920 Strks.Sheared @ 400 PSI.Cont.pumping @ 6 bpm W/Press slowly increasing to 500 PSI. h Operation at 07.00 /2as`', ,Y l� N/D BOPE / goo Forecast Cont.pumping @ 6 bpm 500 PSI,slowed pumps to 3 bpm 30 bbl prior to bumping plug.Plug bumped @ 6,885 Strks.CIP @ 00:15 am.Held 1,000 PSI for 10 Min and bleed off Press.Check Floats and good.Perform 20 bbl infectivity test in 13 3I8"X 9 5l8".N/D BOPE.Install emergency slips as per Vetco Grey rep onsite.N/U BOPE.Freeze Protect well W/LRS.Test BOPE and P/U 4"C.P. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 c Time Log Ig Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL G 4 P PJSA As per detail RIH as per K&M&Tesco Rep onsite.Float in hole 9 5/8"Csg.W/Tesco Csg.Drive System F/2,436'to 4.030'MD.SLK 55K.No loses observed while running 9 5/8"Csg. 02:00 09:00 7.00 9.00 DRILL G 3 P PJSA As per detail RIH as per K&M&Tesco Rep onsite.Begin rotating 9 5/8"Csg.in the hole utilizing Tesco Csg.Drive System F/4,030'to 9,387'MD.50 RPM,SLK 50K,ROT 65K.No loses observed while running 9 5/8"Csg. 09.00 10:00 1.00 10.00 DRILL G 20 P PJSA R/D Tesco Csg.Equip.and clear Rig Floor. 10.00 10:30 0.50 10.50 DRILL H 20 P PJSA R/U Cement Head and R/U to fill 9 5/8"Csg.as per well plan. 10:30 12:00 1.50' 12.00 DRILL G 7 P PJSA Fill 9 5/8"Csg.as per well plan and MI Swaco plan forward.Circ.@ 4 bpm pumped 320 bbl 9.4 ppg LSND. 12.00 14:30 2.50 14.50 DRILL G 7 P PJSA Cont.filling 9 5/8"Csg to hag way @ 356 bbl.wait 10 Min,fill another 178 bbl and wait 10 Min.fill another 128 bbl and wait 10 Min.fill another 40 bbl and top off for a total of 706 bbl. 14.30 15:00 0.50 15.00 DRILL H 20 P PJSA Load Plugs in Cement Head as per Schlumberger Rep onsite.R/D fill lines and R/U to cement well. 15:00 20.00 5.00 20.00 DRILL H 8 P PJSA Break Circ.@ 1/2 bpm,280 PSI.Stage pumps up to 8 bpm and CBU 4.5 X to condition mud to<18 YP for the cement job as per MI Swaco Engineer.No losses observed. 20:00 20:30 0.50 20.50 DRILL H 20 P PJSM with rig crew and all service personal involved with cement operations. 20:30 21:00 0.50 21.00 DRILL H 12 P PJSA Test cement lines 500 PSI low and 3,000 PSI high.Check OPSD on cement unit. 21:00 21:30 0.50 21.50 DRILL H 9 P PJSA Rig pumped 100 bbl 10.5 ppg Mud Push Spacer II @ 5 bpm,150 PSI. 21:30 23:00 1.50 23.00 DRILL H '9 P PJSA Turn over to Schlumberger Cementers drop Bottom Plug.Pump 212 bbl 12.5 ppg Deep Crete Cement @ 4 bpm 650 PSI.Kick out Top Plug with 10 bbl of water and turn back over to rig. 23:00 00:00 1.00 24.00 DRILL H 9 P Rig pumped 520 bbl 9.4 ppg LSND @ 8 bpm 190 PSI.Slow rate to 6 bpm prior to bumping Bottom Plug @ 4,920 Strks. 350 PSI.Sheared @ 400 PSI,continue pumping @ 6 bpm W/Press.slowly increasing to 500 PSI. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 AKRigClerksDoyonl5 @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 hg15 @doyondrilling.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 CASING 9 5/8 8.835 L-80 0.0 9.387.0 5/3/2013 Last Leakoff Test Depth(ftKB) ITVD(ftKB) Fluid Type Fluid Density(113/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,842.0 2,437.03 LSND 9.25 470.0 12.96 1,641.0 Eni E&P Division Well Name:SI32-W2 01 1* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • 2^n Date:5/4/2013 - Report#: 19 APIIUWI:50-629-23483-00-00 II Ii ii page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) IWell Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) !RKB-Tubing Spool(ft) 53.60 13.08 Rig Information Contractor Rig Name 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) IDFS(days) S132-W2 DRILLING 3/7/2013 18,327.0 3,583.4 18.349.00 11269 162.8 58.44 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9.407.0 3.625.5 0.00 102.0 -2.0 Partly Cloudy WC- ENE @ 7 MPH 16 Daily summary operation 24h Summary Displace cement @ 6 bpm 500 PSI.Slow pump rate to 2 bpm 30 bbl away from bumping plug.Plug bumped @ 6,885 Strks.Cont.to Press.up to 1,000 PSI and hold for 10 Min.Bleed off Press.and check Floats.(Good).CIP @ 00:15 am.N o losses during cement iob_Perform injectivity test,pump 20 bbl in 13 3/8"X 9 5/8"Annulus @ 1 bpm 450 PSI bleed off Press.,2 bbl returned.ICP 150 PSI FCP 450 PSI.R/D Cement Head.P/U 5"stand and disp ace 5 Csg.of LSND.Install 500 Ton Casing Slips.N/D BOPE.Install emergency slips as per Vetco Grey Rep onsite and transfer 100K of casing weight to Slips.Vetco Grey Rep cut 9 5/8"Csg and LID.Pull Wear Bushing and install Pack Off.Work on damaged alignment Pin in Multi Bowl.N/U BOPE.SIMOPS load 255 joints 4.5"D.P.8 45 joints 5"D.P.Test Pack Off to 2,472 PSI for 10 Min.SIMOPS Freeze Protect 13 3/8" X 9 5/8"Annulus @ 2 bpm ICP 600 PSI FCP 750 PSI total 175 bbl Diesel pumped.R/U P/U M/U 45 joints 5"D.P.from Mouse Hole.C/O to 4.5"D.P.handling Equip.Service Rig.P/U M/U 144 joints 4.5"D.P.from Mouse Hole. Operation at 07.00 Slip and cut drill line. 24h Forecast Cont.to P/U M/U 4.5"D.P.and stand back in Derreck.Cut and slip drilling line.Test ROPE witnessed waived by Chuck Sheavey.P/U M/U BHA#5 as per Schlumberger DD&MWD Rep.RIH and test 9 5/8"Csg. Lithology Shows MAASP Pressure(psi) I Mud Weight(1b/gall 9_40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Open.Descr. 0000 01:00 1.00 1.00 DRILL H 9 P PJSA Cont.to displace cement with 9.4 ppg LSND @ 6 bpm 500 PSI.Slow pump rate 30 bbl prior to bumping plug to 2 bpm 500 PSI.Plug bumped @ 6,885 Strks.Total of 212 bbl 12.5 ppg Deep Crete II.Cont.to pump 500 PSI over FCP to 1.000 PSI,hold for 10 Min on chart.Bleed off Press.and check floats.(Good)CIP @ 00:15 am.No losses during cement job. 01 00 02.00 1.00 2.00 DRILL H 9 P PJSM R/U to perform injectivity test.Close Annular Preventer and pump 20 bbl 9.4 ppg LSND in 13 3/8"X 9 5/8"Csg.@ 1 bpm 450 PSI,bleed off Press.2 bbl returned to surface.ICP 150 PSI,FCP 450 PSI. 02 00 02:30 0.50 2.50 DRILL H 20 P PJSA RID Cement Head,pull XO from casing and clean. 02 30 05:00 2.50 5.00 DRILL G 20 P PJSA Install Bails and elevators,latch onto stand of 5"D.P.M/U Pup Jnt and Floor Valve.Lower stand into 9 5/8"Csg,and displace mud,L/D Pup 8 Floor Valve and rack stand back in Derrek.LID 5"Elevators and install 500 Ton casing slips. 05.00 11:00 6.00 11.00 DRILL C 20 P PJSM N/D ROPE,install emergency slips with string in tension,transfer 100K of casing weight to slips.Vetco Grey cut 9 5/8"Csg.and L/D.Install 5"elevators and P/U 5"D.P.stand,pull Wear Bushing 8 UD.Prior to install Pack Off,work on damaged alignment pin in Multi Bowl.Install Pack Off.SIMOPS Load 255 joints of 4.5"D.P.8 45 Joints 5"D.P.in Pipe Shed.Haul off surface LSND and clean Pits. 11:00 13:00 2.00 13.00 DRILL C 20 P PJSA N/U BOPE.Test 9 5/8"Pack Off to 2,472 PSI F/10 Min.(Good)SIMOPS Clean Pits.R/U to Freeze Protect 13 3/8"X 9 5/8"Annular. 13:00 1430 1.50 14.50 DRILL C 20 P PJSA C/O Upper Rams Fl 9 5/8"Csg to 3.5"X 6"Variable.SIMOPS Freeze Protect 13 3/8"X 9 5/8"Csg.Annulus @ 2 bpm,ICP 600 PSI FCP 750 PSI,Total bbl pumped 175 bbl. 14:30 15:00 0.50 15.00 DRILL E 20 P PJSA Clean and clear rig floor.R/U to P/U 5"D.P.via Mouse Hole.SIMOPS Cont.to clean Pits. 15:00 17:00 2.00 17.00 DRILL E 20 P PJSA P/U M/U 5"D.P.and rack back in Derreck.Total of 45 joints P/U. 17:00 18:00 1.00 18.00 DRILL E 20 P PJSA R/D 5"D.P.handling Equip.R/U 4.5"handling Equip.Unload floor of remaining Csg.running Equip. 18:00 19:00 1.00 19.00 DRILL E 20 P PJSA Service Rig,grease Drawwurks,TDS,Blocks and Crown.SIMOPS Cont.to clean Pits. 19:00 00:00 5.00 24.00'DRILL E 20 P PJSA P/U M/U 4.5"D.P.from Mouse Hole and stand back in Derreck.Total of 144 joints P/U. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 AKRigClerksDoyonl5 @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 0915 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 0915 @doyondrilling.com 907-685-0716 Last Casing seat Cos.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 9,387.0 5/3/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type !Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,842.0 2,437.03 LSND 9.25 470.0 12.96 1,641.0 ItY#1 Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • API/UWI:50-629-23483-00-00 2^ Date:51512013 - Report 20 If I) page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13,08 Rig Information Contractor I Rig Name Rig Type DOYON DRL61NG 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) S132-W2 DRLLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 59.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(N) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,407.0 3,625.5 0.00 102.0 -11.0 Clear WC-23' SSW @ 7 MPH Daily summary operation 24h Summary Cont.to P/U M/U 4.5"D.P.from Pipe Shed and rack back in Derreck.Slip and cut drilling,inspect Top Drive and replace Saver Sub W/TT525 HT&service rig.Replace Kelly hose from Stand Pipe to Top Drive.Replace Super Choke on Mud Manifold.R/U test Equip for BOPE test.Test BOPE,perform draw down on Koomey.Witnessed waived by Chuck Scheve©10:00 Hrs on 5-4-13.Bring on 600 bbl 9.45 ppg Primo Faze OBM @ 21:00 Hrs and 93 bbl of LVT. Operation at 07.00 Testing 9 5/8"Casing 24h Forecast R/U test new lines from Pumps to Top Drive to 4,000 PSI.Set Wear Bushing.Test 9 5/8"Csg.to 3,000 PSI for 30 Min.P/U M/U BHA#5 as per Schlumberger DD and MWD Rep onsite.RIH perform MAD pass F/6,600'to 9,387'MD.Tag top of cement and displace 9.4 ppg LSND to 9.45 ppg Primo Faze OBM.Clean all surface Equip.of LSND and lign up to drill.Drill out Shoe Track and Cement to 9,427' MD.R/U and perform FIT to EMW 13 ppg or record LOT.Drill ahead as per K&M and Schlumberger prameters to TD. Lithology 'Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 20 'P 'PJSA Cont.to P/U M/U 4.5"D.P.from Pipe Shed and rack back in Derreck.SIMOPS Clean Pits. 03:30 05:30 2.00 5.50 DRILL E 20 P PJSA Slip and Cut Drilling Line.Cut off 120',inspect Brake linkage. 05:30 06:30 1.00 6.50 DRILL E 20 P PJSA Inspect&service Top Drive,open Handler door and inspect Saver Sub.Replace missing Cotter Pin on Handler. SIMOPS Clean Pits. 06:30 09:00 2.50 9.00 DRILL E 20 P 'PJSA Replace TDS-8 Saver Sub W/525 HT connection.Service Rig.SIMOPS Clean Pits. 09.00 12:00 3.00 12.00 DRILL E 20 P PJSA Break loose upper and lower Kelly hose connection.Remove chaffing from hose prior to laying down to ground. Remove Super Choke from Choke Manifold,prep flanges for install of new Super Choke.SIMOPS Clean Pits. 12.00 15:30 3.50 15.50 DRILL E 20 P PJSA UD old Kelly hose.P/U new Kelly hose and install on Standpipe.Install new Kelly hose to Top Drive.Align hose and tighten connections.Install Super Choke on Choke Manifold. 15:30 16:30 1.00 16.50 DRILL C 12 P PJSA R/U to test BOPE.M/U NC-46,NC-50&TT525 TIWs and Dart's to test Subs.Grease upper and lower IBOP. ' 16:30 17:00 0.50 17.00 DRILL C 12 P PJSA P/U M/U 5"test joint to test plug and install as per Vetco Grey Rep onsite. 17:00 00:00 7.00 24.00 DRILL C 12 P 'PJSA Fill stack&Choke Manifold&purge air.Test Annular Preventor W/4.5"&5"test Jnt to 250 PSI low and 2,500 PSI high for 5 Min.Test Choke Manifold Valves 1-18,upper and lower IBOP,Choke&Kill NCR's,Choke&Kill Manuals,Mud Line Kill Valve.NC-46,NC-50&TT525 TIW and Dart Valve's,Blind Rams,4.5"X 7"VBR&3.5"X 6"VBR W/4.5"&5"test Jnt to 250 PSI low and 3,500 PSI high for 5 Min.Test Super Choke&A&B Manual Choke to 1.500 PSI.Perform Koomey draw down test,Start 2.950 PSI,after function 1,450 PSI,200 PSI increase=38 Sec.Total recharge time 198 Sec.5 Nitrogen bottles average 2,400 PSI.Test witnessed waived by AOGCC Rep Chuck Scheve @ 10:00 Hrs on 5-4-13.Took on 600 bbl 9.45 ppg 61 Vis Primo Faze OBM @ 21:00.Took on 93 bbl LVT @ 22:00 Hrs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv 'SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Em representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mach Billington ENI Rig Clerk AKRigClerksDoyon 15 @enipetroleum.com 907-685-0722 Em 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 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 9 5/8 8.835 L-80 0.0 9,387.0 5/3/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(113/gal) Leak Off Pressure(psi) 2,842.0 2,437.03 LSND 9.25 470.0 12.96 1,641.0 It* Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • API/UWI:50-629-23483-00-00 2^rt Date:5/6/2013 - Report#: 21 II II 1] page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-013 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) SI32-'N2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 60,44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather Wind 9.407.0 3,625.5 0.00 102.0 11.0 Mostly Cloudy WC- SW @ 15 MPH 5" Daily summary operation 24h Summary R/D BOPE test Equip.Pull test plug and install Wear Bushing as per Vetco Grey.Test all mud line hoses and new Kelley hose to 4,000 PSI.R/U and test 9 5/8"Csg to 3,000 PSI for 30 Min,on chart. Witnessed by Co Rep onsite.R/D Csg.testing Equip.PJSM W/Schlumberger DD,MWD and all essential personal on P/U BHA#5.Bring source box to Rig floor.P/U M/U BHA#5 as per Schlumberger DD&MWD Rep onsite.Perform ROT WT W/pumps on and off as per K&M Rep onsite,ROT 92K,ROT pumps off 92K.RIH BHA#5 on 4.5"D.P.F/278'to 1,500'MD,perform shallow hole test.(Good) RIH F/1,500'to 6,447'MD filling every 20 stands.Send down links as per Schlumberger DD&MWD.RIH F/6,447'to 6,632'MD.Perform CBL MAD pass F/6,632'to 9,300'MD.Send down links and cycle pumps as per SLB DD&MWD.PJSM W/all essential personal.Displace LSND to Primo Faze.Pumped 50 bbl Hi Vis Spacer @ 4 bpm 380 PSI,50 bbl LVT Spacer @ 4 bpm 530 PSI,displace well bore W/690 bbl 9.5 ppg 63 Vis Primo Faze @ 11 bpm,2,120 PSI 50 RPM,TRQ 8 K. Operation at 07.00 Start drilling out 9 5/8"Csg.Shoe Track and Cement 24h Forecast Clean surface Equip.of LSND after displacement.Drill out Shoe Track and cement F/9,301'to 9,387'MD.Drill 20'new hole to 9427'MD.Perform FIT to EMW 13 ppg or record LOT.Drill ahead 8 3/4" production hole as per K&M and Schlumberger DD parameters to TD©18,314'MD. 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 01:00 1.00 1.00 DRILL C 20 P PJSA R/D BOPE testing Equip. 01:00 01:30 0.50 1.50 DRILL C 20 P PJSA retrieve test plug and install Wear Bushing W/Vetco Grey Rep onsite. 01:30 02:30 1.00 2.50 DRILL E 12 P PJSA Test all Mud line shock hoses&new Kelly hose to 4,000 PSI. 02:30 04:00 1.50 4.00 DRILL G 12 P PJSA R/U to perform 9 5/8"Csg.test to 3,000 PSI for 30 Min.Perform 9 5/8"Csg.test @ 10 Strks per Min.for a total of 89 Strks to 3,000 PSI,hold for 30 Min.on chart.Witnessed by Co.Rep onsite.Bleed off Press.8.5 bbl returned to surface. 04:00 05:00 1.00 5.00 DRILL E 20 P R/D Csg.testing Equip.Blow down Kill&Choke lines.Remove Beaver Slide doors&L/D Man Basket to ground. 05:00 05:30 0.50 5.50 DRILL E 20 P PJSM WI Schlumberger DD&MWD and all essential personal on P/U BHA.P/U BHA#5 from ground level,bring up source box. 05:30 09:30 4.00- 9.50 DRILL E 20 P PJSA P/U M/U BHA#5 as per Schlumberger DD&MWD Rep onsite. 09:30 10:00 0.50 10.00 DRILL E 7 P PJSA Break out XO stand back stand#1 of 4.5"D.P.M/U Top Drive connection in top of BHA#5,fill pipe @ 3 bpm,once pipe is full take ROT WT for K&M Rep onsite 92K.Break out Top Drive&blow down.Screw back into BHA#5 and take ROT WT with no pumps 92K.Blow down Top Drive. 10:00 10:30 0.50 10.50 DRILL E 4 P PJSA RIH BHA#5 W/4.5"D.P.F/278'to 1,500'MD.Filling pipe every 20 stands. 10:30 11:00 0.50 11.00 DRILL E 7 P PJSA Perform shallow hole test @ 300 gpm 410 PSI,400 gpm 620 PSI as per Schlumberger MWD Rep onsite.MWD system good. 11:00 13:30 2.50 13.50 DRILL E 4 P PJSA RIH BHA#5 on 4.5"D.P.F/1,500'to 6.447'filling every 20 stands.Correct displacement observed.HST 181K,SLK 101K. ' 13:30 14:00 0.50 14.00 DRILL E 7 P PJSA Send down links as per Schlumberger DD&MWD Rep onsite.400 GPM,1,080 PSI.RIH F/6,447'to 6,632'MD. HST 181K,SLK 101K. 14:00 21:30 7.50 21.50 DRILL E 11 P PJSA Perform CBL MAD pass as per Schlumberger MWD F/6.632'to 9,300'MD.Wash and reamed Fl 9,189'to 9,300' MD.Tag top of cement @ 9,300'MD.200 GPM,480 PSI,30 RPM,TRQ 16K,HST 198K,SLK 79K,ROT 142K. 21:30 22:00 0.50 22.00 DRILL E 7 P PJSA Send down links and cycle pumps as per Schlumberger DD&MWD Rep onsite.400 GPM,1,100 PSI. 22:00 00:00 2.00 24.00 DRILL E 9 P PJSM W/all essential personal.Dispalce LSND to Primo Faze.Pumped 50 bbl Hi Vis Spacer @ 4 bpm 380 PSI,50 bbl LVT Spacer @ 4 bpm 530 PSI,displace well bore W/690 bbl 9.5 ppg 63 Vis Primo Faze @ 11 bpm,2,120 PSI 50 RPM, TRQ 8 K.Total displacement 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRIgClerksDoyon15 @enipelroleum.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 Chad Johnson Doyon Drilling 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 9.387,0 5/3/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9.427.0 3,626.24 Prim Faze 9.40 680.0 13.01 2,450.7 I Eni E&P Division Name: SI32-W2 YIP* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ • API/UWI:50-629-23483-00-00 2 n g Date:5/7/2013 - Report#: 22 II II page 1 of 1 Wellbore name: SI32-W2 Well Header 213 0113 oncession N° I Operator NI PETROLEUM 'ENI Share lil 100.00'HOIRIZONTALation type Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 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) I DFS(days) S132-W2 DRILLING 3/7/2013 18.327.0 3.583.4 18,349.00 112.69 162.8 61.44 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather [Wind 10,957.0 3,637.4 1.570.00 7.65 205.2 103.0 20.0 Overcast WC 6' SW @ 16 MPH Daily summary operation 24h Summary Clean all surface Equip.of interface from displacement.Service Blocks and Wash Pipe.Drill out Shoe Track F/top of cement @ 9,300'MD,F.C.@ 9,301'MD&Shoe @ 9,387'MD.Drill 20'new hole to 9,427'MD(3,624'TVD).CBU 1X @ 400 GPM 1,850 PSI,ROT WT 138K.Pull up into 9 5/8"Csg.to 9,280'MD.R/U test Equip.&perform FIT 13 ppg EMW,680 PSI(3,625'ND). Drill 8.75"Production hole F/9,427'to 10,957'MD(3,638'ND)550 GPM,3,010 PSI,140-180 RPM,TON 14-16K,TOF 11-12K,WOB 4-14K,HST 198K,SLK N/A,ROT 142K.11.87 ppg WCD.Max Gas 1,022 units.Monitor well static. Operation at 07.00 Drill 8.75"Production hole to 11,305'MD 24h Forecast Drill 8.75"Production Hole as per K&M&Schlumberger DD&MWD parameters F/10,957'10 TD 18,327'MD 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 02:30 2.50 2.50 DRILL E '20 P -PJSM Clean all surface Equip.after displacement,clean Drip Pan&drain system of interface. 02:30 03:00 0.50 3.00 DRILL E 20 P Service Blocks&Wash Pipe. 03:00 07:00 4.00 7.00 DRILL E 19 P 'Drill out Shoe Track F/top of cement @ 9,300',F.0 @ 9,301'MD&Shoe @ 9,387'MD.Drill 20'new hole to 9,427'MD 400 GPM,1,850 PSI off 1,750 PSI on,ROT 138K,40 RPM,TRO 9-12K,WOB 2-5K. 07:00 08:00 1.00 8.00 DRILL E '7 P Circ.BU 1X @ 400 GPM 1,850 PSI ROT 138K. 08:00 09:00 1.00 9.00 DRILL E '20 P PJSA P/U into 9 5/8"Csg.to 9,280'MD.R/U&Perform FIT to 680 PSI,3,624'ND EMW 13.0 ppg.R/D test Equip.&blow down Kill Line, 09:00 12:00 3.00- 12.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/9.427'to 9,562'MD(3,630'ND)525 GPM,2,850 PSI,120 RPM,TQN 10-12K,TOF 9K,WOB 5-10K.HST 180K.SLK 95K,ROT 140K.ECD 11.2 ppg W/9.4 ppg MW.Max Gas 373 units.ADT Hrs 1.1,Total Bit Hrs 1.1.JAR Hrs 1.1. SPR @ 9,425'MD(3,621'ND)WI 9.4 ppg MW MP#2 20-410,30-490 MP#3 20410,30490 12100 18'00 6.00 1800 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/9,562'to 10,399'MD(3,626'ND)550 GPM,3,060 PSI,160 RPM,TON 14-15K,TOF 9-10K,WOB 2-15K,HST 190K,SLK 80K,ROT 141K.ECD 11.87 ppg W/ 9.45 ppg MW.Max Gas 1,022 units.ADT Hrs 3.2,Total Bit Hrs 4.30,JAR Hrs 4.30.Monitor well,static. 18.00 00:00 6.00 24.00 DRILL E '3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/10,399'to 10,957'MD(3,638'ND)550 GPM,3,010 PSI,140-180 RPM,TQN 14-16K,TQF 11-12K,WOB 4-14K,HST 198K,SLK N/A,ROT 142K.ECD 11.87 ppg W/9.4 ppg MW.Max Gas 940 units.ADT Hrs 3.35,Total Bit Hrs 7.65,JAR Hrs 7.65.Monitor well,static. SPR @ 10,770'MD(3,631'TVD)W/9.4 ppg MW. MP#1 20-460,30-550 MP#2 20-460,30-550 MP#3 20-460,30-550 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Nelson Carballo ENI Dilling Supenntenda Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Dolling Supv 907-685-0715 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 Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 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 9 5/8 8.835 L-80 0.0 9,387.0 5/3/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2.450.7 III P, Eni E&P Division 'Well Name:SI32-W2 EN!Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUO El• Date:5/8/2013 - Report#: 23 API/UWI:50-629-23483-00-00 2" " page 1 of 1 Welibore name: SI32-W2 Well Header Permit/Concession N° Operator EM Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 • Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Welibore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) SI32-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 62.44 Daily Information End Depth(itKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather I Wind 13,572.0 3,602.3 2.615.00 10.74 243.5 101.0 20.0 Overcast WC 12 ESE @ 6 MPH Daily summary operation 24h Summary PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/10,957'to 13.572'MD(3.601'TVD)550 GPM.3,160 PSI,160 RPM,TON 16-19K,TQF 18K.WOB 4-10K,HST 205K.SLK N/A,ROT 141K.ECD 12.2 ppg W/9.45 ppg MW.Max Gas 899 units.ADT Hrs 2.49,Total Bit Hrs 18.39,JAR Hrs 18.39.Monitor well,static. Operation at 07.00 Drill 8.75"Production hole to 13.929'MD 24h Forecast Drill 8.75"Production Hole as per K&M&Schlumberger DD&MWD parameters F/13,572'to TD 18,327'MD Lithology I Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/10,957 to 11,612'MD(3,628'ND)555 GPM,2,950 PSI,170 RPM,TON 15-16K,TQF 12-14K,WOB 4-8K,HST 190K,SLK N/A,ROT 139K.ECD 11.5 ppg W/9.4 ppg MW.Max Gas 1,650 units.ADT Hrs 3.27,Total Bit Hrs 10.92,JAR Hrs 10.92.Monitor well,static. SPR @ 11,612'MD(3,625'ND)W/9.35 ppg MW. MP#2 20-460,30-550 MP#3 20-460,30-550 0600 1200 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/11,612'to 12,079'MD(3,616'ND)550 GPM,2.850 PSI,170 RPM,TON 15-19K,TQF 12-14K,WOB 4-12K,HST 200K,SLK N/A,ROT 140K.ECD 11.7 ppg W/ 9.35 ppg MW.Max Gas 1,796 units.ADT Hrs 2.54,Total Bit Hrs 13.46,JAR Hrs 13.46.Monitor well,static. 1200 16.00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/12,079'to 12,828'MD(3,607'ND)550 GPM,3,090 PSI,120-170 RPM,TQN 17-18K,TQF 14K,WOB 4-12K,HST 200K,SLK N/A,ROT 141 K.ECD 12.13 ppg W/ 9.4 ppg MW.Max Gas 1,192 units.ADT Hrs 2.44,Total Bit Hrs 15.9,JAR Hrs 15.9.Monitor well,static. 18 00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/12,828'to 13,572'MD(3,601'TVD)550 GPM,3,160 PSI,160 RPM,TON 16-19K,TQF 18K,WOB 4-10K,HST 205K,SLK N/A,ROT 141K.ECD 12.2 ppg W/9.45 ppg MW.Max Gas 899 units.ADT Hrs 2.49,Total Bit Hrs 18.39,JAR Hrs 18.39.Monitor well,static. SPR @ 13,572'MD(3,601'ND)W/9.45 ppg MW. MP#1 20-530,30-610 MP#2 20-530,30-610 MP#3 20-530,30-610 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 AKRigCterksDoyon l5 @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 rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 9,387.0 5/3/2013 ' Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9427.0 3,626.24 Primo Faze J 9.40 680.0 13.01 2,450.7 f Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • APIIUWI:50-629-23483-00-00 2^II n Date:5/9/2013 - Report#: 24 • �I I� page 1 of 1 Wellbore name: SI32-W2 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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(ND..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.81 63.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather 'Wind 15,952.0 3,586.5 2,380.00 12.69 187.5 100.0 14.0 Clear WC-1° SW @ 14 MPH Daily summary operation 24h Summary Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/13.572'to 15.952'MD(3,584'TVD)550 GPM,3,420 PSI.120-170 RPM,TQN 18-19K,TQF 12-14K.WOB 4-12K,HST 205K, SLK N/A,ROT 142K.ECD 12.06 ppg WI 9.35 ppg MW.Max Gas 881 unit.Encountered ballooning @ 14,132'MD 10-15 bbl.Encountered stick slip and added 0.05%Lube,after coming up out of the OA 3 sand to OA 1 Sand stick slip seemed to level out.Observe 5-10 bbl ballooning during drilling.No losses to formation. Operation at 07.00 Drill 8.75"Production hole to 16.210'MD 24h Forecast Drill 8.75"Production Hole as per K&M&Schlumberger DD&MWD parameters F/15,952'MD to TD 18,327'MD 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 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/13,572'to 14,132'MD(3,615'ND)550 GPM,3.050 PSI,120-160 RPM,TQN 15-23K,TQF 15-17K,WOB 2-15K,HST 220K,SLK N/A,ROT 140K.ECD 11.9 ppg W/9.4 ppg MW.Max Gas 676 units.ADT Hrs 3.47,Total Bit Hrs 21.86.JAR Hrs 21.86.Monitor well,static. 06:00 1200 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/14,132'to 14,725'MD(3,603'TVD)550 GPM,3,150 PSI,120-160 RPM,TON 15-23K,TQF 15-17K.WOB 2-15K,HST 215K,SLK N/A,ROT 140K.ECD 12.1 ppg W/9.5 ppg MW.Max Gas 751 units.ADT Hrs 2.42,Total Bit Hrs 24.28,JAR Hrs 24.28.Encountered ballooning @ 14,132' MD,observe 5-10 bbl ballooning during drilling. SPR @ 14,416'MD(3,609'ND)W/9.4 ppg MW. MP#1 20-520,30-590 MP#2 20-520,30-590 1200 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/14,725'to 15,358'MD(3,591'ND)550 GPM,3,160 PSI,120-180 RPM,TQN 16-18K,TOF 13-14K,WOB 4-18K,HST 208K,SLK N/A,ROT 142K.ECD 11.95 ppg W/9.3 ppg MW.Max Gas 877 units.ADT Hrs 3.59,Total Bit Hrs 27.87,JAR Hrs 27.87.Observe 5-10 bbl ballooning during drilling. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/15,358'to 15,952'MD(3,584'ND)550 ' GPM,3,420 PSI,120-170 RPM,TON 18-19K,TOF 12-14K,WOB 4-12K,HST 205K,SLK N/A,ROT 142K.ECD 12.06 ppg W/9.35 ppg MW.Max Gas 881 units.ADT Hrs 3.21,Total Bit Hrs 31.08,JAR Hrs 31.08.Encountered stick slip and added 0.05%Lube,after coming up out of the OA 3 sand to OA 1 Sand stick slip seemed to level out.Observe 5-10 bbl ballooning I during drilling.No losses to formation. SPR @ 15,906'MD(3,585'ND)W/9.35 ppg MW MP#1 20-430,30-520 i MP#2 20-430,30-520 MP#3 20-430,30-520 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Mats 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 907-6685-0721 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 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 9,387.0 5/3/2013 I Last Leakoff Test 1 Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 Eni E&P Division !Well Name:SI32-W2 IP* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • API/UWI:50-629-23483-00-00 2^n Date:5/10/2013 - Report#: 25 II "II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) 1Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53,60 13.08 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) S132-W2 DRILLING 3/7/2013 18.327.0 3.583.4 18,349.00 112.69 162.8 64.44 Daily Information End Depth(RKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,035.0 3,604.1 2,083.00 11.65 178.8 102.01 15.0 Partly Cloudy WC-1°I W @ 8 MPH Daily summary operation 24h Summary PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/15,952'to 18.035'MD(3.604'ND)450 GPM,2,560 PSI,120-160 RPM,TON 16K,TOF 13K,WOB 2-16K,HST 212K, SLK N/A,ROT 140K.Max Gas 1,013 units.Crossed Fault @ 15,932'MD,observed losses @ 15,995'MD @ 160 bph.After drilling F/15,996'to 16,200'MD stopped and flow checked the well,118 bbl pumped away and after 15 Min.38 bbls flowed back.Reduced pump rate to 450 gpm and continued drilling.Losses continued @ 40-60 bph and slowed to 30-40 bph around 16,900',ballooning continued between connections.Total lost to formation today 868 bbl. Operation at 07.00 Circulating,Clean up cycle 24h Forecast Drill 8.75"Production Hole as per K&M&Schlumberger DD&MWD parameters F/18,035'MD to TD 18,350'MD.Begin K&M clean up cycle and BROOH schedule. Lithology 'Shows I MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/15,952'to 16,466'MD(3,579'ND)450- 500 GPM,3,420 PSI,120-170 RPM,TQN 18-19K,TQF 12-14K,WOB 4-12K,HST 205K,SLK N/A,ROT 142K.ECD 12.06 ppg W/9.4 ppg MW.Max Gas 850 units.ADT Hrs 2.84,Total Bit Hrs 33.92,JAR Hrs 33.92.Crossed Fault @ 15,932'MD, observed losses @ 15,995'MD @ 160 bph.Drilled F/15,996'to 16,200'MDstopped and flow checked the well,118 bbl pumped away and after 15 Min.38 bbls flowed back.Reduced pump rate to 450-500 gpm and continued drilling.Losses continued @ 40-60 bph and ballooning between connections. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/16,466'to 16,935'MD(3,588'ND)450 GPM,2,480 PSI,120-160 RPM,TON 18-19K,TOF 12-14K,WOO 4-15K,HST 214K,SLK N/A,ROT 140K.ECD 11.6 ppg W/9.4 ppg MW.Max Gas 696 units.ADT Hrs 2.43,Total Bit Hrs 36.35,JAR Hrs 36.35.Reduced pump rate to 450-500 gpm due to losses.Losses continued @ 30-40 bph and ballooning continued between connections.Total lost this tour 486 bbl to formation. SPR @ 16,932'MD(3,587'ND)W/9.4 ppg MW MP#1 20-490,30-570 MP#2 20-490,30-570 MP#3 20-490,30-570 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/16,935'to 17,482'MD(3,598'ND)450 GPM,2,520 PSI,120-160 RPM,TON 16-18K,TOF 11-13K,WOB 2-12K,HST 208K,SLK N/A.ROT 140K.ECD 11.75 ppg W/9.4 ppg MW.Max Gas 1,013 units.ADT Hrs 3.65,Total Bit Hrs 40.0,JAR Hrs 40.0.Reduced pump rate to 450 gpm due to losses.Losses continued©30-40 bph and ballooning continued between connections. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"production hole as per K&M 8 Schlumberger DD parameters F/17,482'to 18,035'MD(3,604'ND)450 GPM,2,560 PSI,120-160 RPM,TON 16K,TOF 13K,WOB 2-16K,HST 212K,SLK N/A,ROT 140K.ECD 11.73 ppg W/9.4 ppg MW.Max Gas 845 units.ADT Hrs 2.73,Total Bit Hrs 42.73,JAR Hrs 42.73.Losses continued @ 30-40 bph and ballooning continued between connections.Lost 232 bbl to formation this tour.Total lost to formation today 868 bbl. SPR @ 17,959'MD(3,600'ND)W/9.4 ppg MW MP#1 20-440,30-530 MP#2 20-440,30-540 MP#3 20-430,30-540 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 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 9,387.0 5/3/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 Eni E&P Division 'Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • API/UWI:50-629-23483-00-00 2 Ifil*^n Date:5/11/2013 - Report#: 26 II II II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) -Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 55.44 Daily Information End Depth(ttKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,350.0 3,607.8 315.00 1.54 204.5 101.0 29.0 Overcast WC 24° SE @ 5 MPH Daily summary operation 24h Summary PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/18,035'to TD 18,350'MD(3,607'TVD)450 GPM,2,450 PSI,160 RPM,TON 14-17K,TQF 13K,WOB 4-8K,HST 220K, SLK N/A.ROT 140K.ECD 11.6 ppg WI 9.4 ppg MW.Max Gas 661 units. Losses continued @ 30-40 bph and ballooning continued between connections.Circ.&reciprocate hole clean as per K&M clean up cycle @ 450 gpm,2,530 PSI„160 RPM,TRQ 14-15K, ROT WT 138K,SLK WT N/A,ESD 11.6 ppg W/9.4 ppg MW.Still observed losses at 20-30 bph.Shut down to observe well,flow back 44 bbl before becoming static.BROOH as per K&M BROOH schedule F/18,350'to 12,638'MD,450 GPM,2.040 PSI,140 RPM,TRQ 12K,HST 185K,SLK N/A,ROT WT 140K,ECD 10.8 ppg W/9.3 ppg MW. SLM out of hole.Cont.to observe breathing,loss rate @ 4-5 bph.Total lost today 135 bbl to formation.Total lost to formation in 8.75"production hole 1003 bbl. Operation at 07.00 Cont.BROOH as per K&M BROOH schedule @ 10,701'MD. 24h Forecast BROOH as per K&M BROOH schedule FI 12,638'MD to BHA#5. 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 03:00 3.00 3.00 DRILL E 3 P 'PJSA Drill 8.75"production hole as per K&M&Schlumberger DD parameters F/18,035'to TD 18,350'MD(3,607'TVD) 450 GPM,2,450 PSI,160 RPM,TON 14-17K,TOP 13K,WOB 4-8K,HST 220K,SLK N/A,ROT 140K.ECD 11.6 ppg WI 9.4 ppg MW.Max Gas 661 units.ADT Hrs 1.54,Total Bit Hrs 44.27,JAR Hrs 44.27.Losses continued @ 30-40 bph and ballooning continued between connections. SPR @ 18,350'MD(3,607'ND)W/9.4 ppg MW MP#1 20-430,30-520 MP#2 20-430,30-520 03.00 06:30 3.50 6.50'DRILL E 7 P PJSA Circ.&reciprocate hole clean as per K&M clean up cycle @ 450 gpm,2,530 PSI„160 RPM,TRQ 14-15K. ROT WT 138K,SLK WT N/A,ESD 11.6 ppg W/9.4 ppg MW.Still observed losses at 20-30 bph. 06 30 07:00 0.50 7.00 DRILL E 11 P Shut down to observe well,flow back 44 bbl before becoming static. 07.00 12:00 5.00 12.00'DRILL E 6 P 'PJSA BROOH as per K&M BROOH schedule FI 18,350'to 17,776'MD,450 GPM,2,440 PSI,160 RPM.TRQ 13-14K,ECU 11.3 ppg W/9.3 ppg MW.SLM out of hole.POOH 1 joint to change break.Cont.to observe Well breathing and losses slowing to 10-20 bph.Total lost to formation for tour 81 bbl. 12 00 18.00 6.00 18.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/17,776'to 15,069'MD,450 GPM,2,066 PSI,150 RPM,TRQ 13K,HST 195K,SLK N/A,ROT WT 140K,ECD 10.9 ppg WI 9.3 ppg MW.SLM out of hole,Cont.to observe breathing,loss rate @ 4- 5 bph. 18.00 00:00 6.00 24.00'DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/15,069'to 12,638'MD,450 GPM,2,040 PSI,140 RPM,TRQ 12K,HST 185K,SLK N/A,ROT W7 140K,ECD 10.8 ppg W/9.3 ppg MW.SLM out of hole.Cont.to observe breathing,loss rate @ 4- 5 bph.Calculated displacement 45 bbl,actual 95 bbl.Total lost this tour 54 bbl.Total lost today 135 bbl to formation.Total lost to formation in 8.75"production hole 1003 bbl. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDnIling @enipetroleum.com 907-6685-0715 Eni representative Ben Perry ENI Senior Dolling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5 @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 Drilling Tour Pusher ng15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(11KB) Run Date CASING 9 5/8 8.835 L-80 0.0 9,387.0 5/3/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 f Eni E&P Division 'Well Name: SI32-W2 ENI Petroleum Co.Inc. Daily Repo Well Code:27080 Field Name:NIKAITCHUQ • API/UWI:50-629-23483-00-00 2^n Date:5/12/2013 - Report#: 27 II l)ii page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 66.44 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 18.350.0 3,607.8 0.00 105.0 14.0 Light Snow WC-6` SW @ 26 MPH Daily summary operation 24h Summary PJSA BROOH as per K&M BROOH schedule F/12,638'to 8,349'MD,460 GPM,1,950 PSI,140 RPM,TRQ 10K,HST 160K,SLK N/A,ROT WT 138K,ECD 10.59 ppg W/9.4 ppg MW.SLM out of hole. Cont.to observe breathing,loss rate @ 4-5 bph.Circ.hole clean as per K&M schedule 2X BU,460 GPM,1,850 PSI.160 RPM,HST 162K,ROT WT 138K,SLK 112K.Reciprocate string F/8,349'to 8,252'MD.Monitor well.static.POOH as per K&M BROOH schedule 4.5"D.P.F/8,349'to 7,302'MD,Pull 10 stands to'ensure well was not swabbing,HST 165K.Pump Dry Job and Cont.to POOH on elevators F/7,302'to 278'MD.Make an all call for unloading Nuclear Source.Schlumberger MWD personal unload Nuclear Source.Make an all clear call when done handling source.PJSM UD BHA#5 as per Schlumberger DD and MWD.Total lost to formation for the day 59 bbl,total lost to formation of 8.75"Production section 1,062 bbls OBM.UD BHA#5 tools from rig floor.Clean and clear rig floor. P/U BHA#6 and load rid floor. Operation at 07.00 RIH BHA#6 W/8.75"Hole Opener to 3,932'MD. 24h Forecast P/U M/U BHA#6 W/8.75"Hole Opener.RIH to 9,300'MD and slip and cut drilling line.Cont.to RIH to 18,350'MD.Circ.1X BU.Spot Faze Away Breaker as per MI Swaco plan forward.POOH on elevators. Lithology I Shows MAASP Pressure(psi) 'Mud Weight(1b/gall 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 6 P PJSA BROOH as per K&M BROOH schedule F/12,638'to 9,469'MD,460 GPM,1,950 PSI,140 RPM,TRQ 12K,HST 150K,SLK N/A,ROT WT 130K,ECD 10.59 ppg W/9.4 ppg MW.SLM out of hole.Cont.to observe breathing,loss rate @ 4-5 bph. 06:00 09:00 3.00 9.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/9,469'to 8,349'MD,460 GPM.1,950 PSI,140 RPM,TRQ 10K,HST 160K,SLK N/A,ROT WI 138K,ECD 10.59 ppg W/9.4 ppg MW.SLM out of hole.Cont.to observe breathing,loss rate @ 4-5 bph.Calculated displacement 31 bbl,actual 66 bbl.Total lost 35.5 bbl. 09:00 10:30 1.50 10.50 DRILL E 7 P Circ.hole clean as per K&M schedule 2X BU,460 GPM,1,850 PSI,160 RPM,HST 162K,ROT WT 138K,SLK 112K. Reciprocate string F/8,349'to 8,252'MD. 10:30 11:30 1.00 11.50 DRILL E 20 P PJSA Break out XO,change out elevators,blow down TDS 8 and break out XO.Service Wash Pipe 8 Drawworks. 11:30 12:00 0.50 12.00 DRILL E 20 P Monitor well,static. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA POOH as per K&M BROOH schedule 4.5"D.P.F/8,349'to 7,302'MD,Pull 10 stands to ensure well was not swabbing,HST 165K.Pump Dry Job and Cont.to POOH on elevators F/7,302'to 2,082'MD. 18:00 20:00 2.00 20.00 DRILL E 4 P PJSA POOH as per K&M BROOH schedule 4.5"D.P.F/2,082'to 278'MD on elevators.HST 128K.Monitor well for 10 Min.,static.L/D XO and rack back Jar stand in Derreck. 20:00 20:30 0.50 20.50 DRILL E 20 P PJSM W/all essential personal on laying down BHA and handling Nuclear Source. 20:30 21:00 0.50 21.00 DRILL E 20 P PJSA Make an all call for unloading Nuclear Source.Schlumberger MWD personal unload Nuclear Source.Make an all clear call when done handling source. 21:00 22:30 ' 1.50 22.50 DRILL E 4 P PJSA UD BHA#5 as per Sclumberger DD and MWD.Calculated fill for trip 67.17 bbl.Actual fill 90.5 bbl.Mud lost for tour 23.33 bbl.Total lost to foramtion for the day 59 bbl,total lost to formation of 8.75"Production section 1,062 bbls OBM. 22.30 23:00 0.50 23.00 DRILL E 20 P PJSA UD BHA#5 tools from rig floor.Clean and clear rig floor.NMFC-some wear on hard banding but nothing substantial to report.NM String Stab-In gauge at 8.63". Missing very few tiles and not very much wear.NM ILS Stab- In at 8 5/8th out at 8'/:".No grooves,all tiles there,but some cut-right worn down.EcoScope-In gauge at 8.25".Groove at the bottom of the stab.Xceed stabs-Both in gauge at 8 5/8".Very minimal wear on both top and bottom stab. The bit was graded 1-2-BT-A-X-1-WT-TD 23:00 00:00 1.00 24.00 DRILL E 20 P PJSA P/U BHA#6 tools to the rig floor. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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 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 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 9.387.0 5/3/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type I Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 I Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • APIIUWI:50-629-23483-00-00 2^ Date:5/13/2013 - Report#: 28 �� II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N" I Operator ENI Share(%) Well Configuration type 213-013 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.601 13.08 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...I Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) DES(days) 0132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 67.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 18,350.0 3,607.8 0.00 101.0 11.0 Blowing Snow WC- WSW @ 39 MPH 13" W/Gust to 46 MPH Daily summary operation 24h Summary PJSM P/U M/U BHA#6 W/8.75"Hole Opener as per Schlumberger DD.RIH W/4.5"D.P.F/surface to 8,211'MD,HST 140K,SLK 120K.Install XO 8 change out Elevators F/4.5"to 5"D.P.RIH 5"D.P. F/8,211'to 9,054'MD.PJSM cut and slip drilling line.RIH W/5"D.P.F/9,054'to 18,294'MD.After entering open hole at 9,387'MD slowed to 1 Min.per stand.Filing D.P.every 20 stands while RIH. HST 170K,SLK 118K.Break Circ.@ 2.5 bpm 300 PSI.Wash down F/18,294'to tag bottom @ 18,350'MD,set 10 K down.50 RPM,TRO 14K.Circ.and condition mud,stage pumps up to 3.5 bpm 425 PSI,reciprocate D.P.F/18,350'to 18,294'MD.At 17:20 Hrs we had a 5-10 bbl OBM accidental discharge in containment.ACS and SRT responded,the spill was cleaned and contained.Circ.8 condition mud for spotting Faze Away Breaker.Stage up pump rate to 4 bpm 600 PSI.Rotate and reciprocate.At 19:00 Hrs held PJSM for spotting Faze Away Breaker with all essential personal.Build Faze Away Breaker @ Mud Plant and prep Pits for displacement.Stage up pumps to 5 bpm 710 PSI,observed slight loss,reduced pump rate to 4 bpm 600 PSI no loss observed.Total lost to formation today 3 bbl.Total lost to formation in the 8.75"Production Hole 1,065 bbl OBM. Operation at 07.00 Spot 700 bbl Faze Away Breaker in 8.75"open hole. 24h Forecast Spot 700 bbl Faze Away Breaker in 8.75"open hole as per MI Swaco Plan Forward.POOH as per KW POOH schedule to 9,187'MD.Displace OBM W/9.15 ppg Brine.Cont,to POOH as per KW POOH Schedule. Lithology 'Shows MAASP Pressure(psi) I 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 E 20 P PJSM P/U M/U BHA#6 W/8.75"Hole Opener as per Schlumberger DD. 01:30 02:00 0.50 2.00 DRILL E 20 P Change out elevators 8 lubricate Rig. 02:00 06:30 4.50 6.50 DRILL E 4 P PJSA RIH W/4.5"D.P.F/surface to 8,211'MD,HST 140K,SLK 120K. 06:30 07:30 1.00 7.50 DRILL E 4 P Install XO 8 change out Elevators F/4.5"to 5".RIH 5"D.P.F/8,211'to 9,054'MD. 07:30 09:30 2.00 9.50 DRILL E 20 P PJSM on cut and slip drilling line.Cut and slip drilling line,12 wraps=102'.Inspect linkage 8 brakes 8 secure jam nuts. 09:30 12:00 2.50 12.00 DRILL E 4 P RIH W/5"D.P.F/9,054'to 11,760'MD.After entering open hole at 9,387'MD slowed to 1 Min.per stand.Fill D.P.every 20 stands while RIH.HST 170K,SLK 118K.Calculated displacement 80.08 bbl,actual displacement 77 bbl.Lost 3 bbl for tour. 12:00 16:30 ' 4.50 16.50 DRILL E 4 P PJSA Cont.RIH W/5"D.P.@ 1 Min.per stand F/11,760'to 18,294'MD.HST 195K,SLK 80K,ROT 160K. 16:30 1800 1.50 1800 DRILL E 4 P Break Circ.@ 2.5 bpm 300 PSI.Wash down F/18,294'to tag bottom @ 18,350'MD,set 10 K down.50 RPM,TRO 14K. Circ.and condition mud,stage pumps up to 3.5 bpm 425 PSI,reciprocate D.P.F/18,350'to 18,294'MD.At 17:20 Hrs we had a 5-10 bbl OBM accidental discharge in containment.ACS and SRT responded,the spill was cleaned and contained. 18:00 00:00 6.00 24.00 DRILL E 7 P Circ.8 condition mud for spotting Faze Away Breaker.Stage up pump rate to 4 bpm 600 PSI.Rotate and reciprocate.@ 19:00 Hrs held PJSM for spotting Faze Away Breaker with all essential personal.Build Faze Away Breaker @ Mud Plant and prep Pits for displacement.Stage up pumps to 5 bpm 710 PSI,observed slight loss,reduced pump rate to 4 bpm 600 PSI no loss observed.Total lost to formation today 3 bbl.Total lost to formation in the 8.75"Production Hole 1,065 bbl OBM. Daily Contacts Position Contact Name Company Title - E-mail Office Mobile En:representative Mike Ross ENI 'Senior Drilling Supv ‘SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Matls 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 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 9,387.0 5/3/2013 Last Leakoff Test Depth(8KB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9.427.0 3,626.24 Pnmo Faze 9.40 680.0 13.01 2.450.7 fill* Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • 2^rt Date:5/14/2013 - Report#: 29 APIIUWI:50 629-23483-00-00 II li ii page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share)%) I Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.60 13.08 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) 5132-W2 DRILLING 3/7/2013 18,327.0 3,583.4 18,349.00 112.69 162.8 68.44 Daily Information End Depth(RKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,350.0 3.607.8 0.00 108.0 0.0 Scattered Clouds WC SE @ 7 MPH -13" Daily summary operation 24h Summary PJSM Circ.&reciprocate F/18,350'to 18,320'MD 168 GPM,600 PSI,60 RPM,TRQ 12K,ROT WT 140K.Test lines F/Mud Plant to Rig Pumps WI 15 bbl Brine.Pump 700 bbl 9.55 ppg Faze Away Breaker @ 2.5 bpm followed by 15 bbl Brine.Turn over to Rig and pump 71 bbl 9.4 ppg Faze Pro followed by 23 bbl 11.2 ppg Dry Job.Drop 2.5"drift WI 100'tail.Blow down Top Drive.Monitor well, static.POOH on elevators per K&M POOH schedule F/18,350'to 9,137'MD.HST 190K,SLK 110. Monitor well for 10 Min.losing 10 bph static.Break Circ.@ 2 bpm,150 PSI.Establish dynamic loss @ 10 BPH.Circ.and condition mud for displacement.PJSM W/at essential parties involved.Displace 9.4 ppg Faze Pro W/9.15 ppg NaCVKCL Brine as per MI Swaco plan forward.Displace @ 6.5 bpm, 550 PSI,rotate 70 RPM,TRQ 9K,reciprocate F/9,137'to 9,054'MD.HST 190K,SLK 110K,ROT 140K.Clean Shakers and Mud Pit Equip.of OBM and interface from displacement.Total Faze Pro lost today to formation 137 bbl.Total Faze Pro lost to formation in 8.75"Production hole 1,202 bbls.Total 9.15 ppg Brine lost to formation 10 bbl. Operation at 07.00 POOH as per K&M POOH Schedule laying down 4.5"D.P.@ 7.775'MD. 24h Forecast Clean all surface Equip.of inerface and OBM.POOH and rack back 5"D.P.LA)4.5"D.P.While POOH as per K&M POOH schedule.PJSM W/all essential personal on R/U Linear running tools and running 4.5"Linear.RIH 4.5"Linear on 5"D.P. Lithology (Shows MAASP Pressure(psi) I 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 01:00 1.00 1.00 DRILL E 7 P PJSM Circ.&reciprocate F/18,350'to 18,320'MD 168 GPM,600 PSI,60 RPM.TRQ 12K,ROT WT 140K. 01:00 07:00 6.00 7.00 DRILL E 9 P PJSA Test lines F/Mud Plant to Rig Pumps W/15 bbl 9.15 ppg NaCI/KCL Brine.Pump 700 bbl 9.55 ppg Faze Away Breaker @ 2.5 bpm followed by 15 bbl 9.15 ppg NaCI/KCL Brine.Turn over to Rig and pump 71 bbl 9.4 ppg Faze Pro followed by 23 bbl 11.2 ppg Dry Job.Drop 2.5"drift W/100'tail.Blow down Top Drive.Monitor well,static. 07:00 12:00 5.00 12.00 DRILL E 4 P PJSA POOH on elevators per K&M POOH schedule F/18,350'to 15,960'MD.HST 220K,SLK N/A.Calculated displacement 19.5 bbl,actual displacement 68 bbl.Total lost for tour 48 bbl. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA POOH on elevators per K&M POOH schedule F/15,960'to 9,137'MD.HST 190K,SLK 110. Monitor well for 10 Min. lossing 10 bph static.Calculated displacement 46.5 bbl,actual displacement 115 bbl.Total lost 68.5 bbl. 18:00 20:00 2.00 20.00 DRILL E 7 P Break Circ.@ 2 bpm,150 PSI.Establish dynamic loss @ 10 BPH.Circ.and condition mud for displacement. 20:00 23:00 3.00 23.00 DRILL E 9 P PJSM for displacement W/all essential parties involved.Displace 9.4 ppg Faze Pro W/9.15 ppg NaCVKCL Brine as per MI Swaco plan forward.Displace @ 6.5 bpm,550 PSI,rotate 70 RPM,TRQ 9K,reciprocate F/9,137'to 9,054'MD.HST 190K, SLK 110K,ROT 140K. 23:00 00:00 1.00 24.00 DRILL E 20 P Clean Shakers and Mud Pit Equip.of OBM and interface from displacement.Total Faze Pro lost today to formation 137 bbl. Total Faze Pro lost to formation in 8.75"Production hole 1,202 bbls.Total 9.15 ppg Brine lost to formation 10 bbl. 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 Ben Perry ENI Senior Dulling Supv 907-685-0715 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 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 ng15 @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 95/8 8.835 L-80 0.0 9.387.0 5/3/2013 Last Leakoff Test Depth(RKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2.450.7 11"1* Eni E&P Division .. Iweu Name: 5132-W2 EN!Petroleum Co.Inc. Daily Report Well Code:27080 • Field Name: NIKAITCHUO • API/UWI:50-629-23483-00-00 2^n Date:5/15/2013 - Report#: 30 II II�I page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) IDFS(days) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 69.44 Daily Information • End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,350.0 3,607.8 0.00 109.0 12.0 Partly Cloudy.WC- ENE @ 20 MPH __ 8" Daily summary operation 24h Summary PJSM Clean all surface Equip.of OBM&interface from displacement.POOH on elevators WI 5"D.P.Fl 9,145'to 8,214'MD.Break out XO&C/O elevators for 4.5"D.P.HST 170K,SLK 110K. Single out of the hole laying down 4.5"D.P.as per K&M POOH schedule Fl 8,214'to 143'MD.Found drift in top of 4.5"D.P.Mark 23 joints W/Yellow paint that were under gauge. HST 90K,SLK 90K.Lay down BHA#6.PJSM W/all essential personnel for R/U Liner Equip.and running 4.5"Liner.RN 4.5"Liner Equip.as per GBR Rep onsite.Stage completion jewelry in Pipe Shed.PJSA RIH 4.5"Liner and jewelry as per tally and K&M RIH schedule F/0'to 2,768'MD 67 joints,HST 100K,SLK 98K Total 9.15 ppg NaCUKCL Brine lost to formation today 130 bbl. Operation at 07.00 RIH W/4.5"Liner @ 4,526'MD. 24h Forecast RIH 4.5"Liner as per tally and K&M schedule F/2,768'to 9.219'MD.P/U M/U SLZXP Liner Packer as per Baker Rep onsite.RIH W/5"D.P.F/9,492'to 18,327'MD.Set SLZXP Liner Packer as per Baker Rep onsite.POOH 5"D.P.and Packer Assy.R/U test Equip.and test BOPE. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.15 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr.• 00:00 02:00 2.00 2.00 DRILL E 20 P -PJSM Clean all surface Equip.of OBM&interface from displacement. 02.00 03.00 1.00' 3.00 DRILL E 4 P PJSA POOH on elevators W/5"D.P.F/9,145'to 8,214'MD.Break out XO&C/O elevators for 4.5"D.P.HST 170K,SLK 110K. 03.00 0430 1.50 4.50 DRILL E 4 P -PJSA Single out of the hole laying down 4.5"D.P.as per K&M POOH schedule F/8,214'to 7,580'MD.Found drift in top of 4.5"D.P. 04.30 05:00 0.50 5.00 DRILL E 20 'P Stop and unplug floor drain from interface from displacement. 05.00 1200 7.00 12.00 DRILL E 4 P PJSA Single out of the hole laying down 4.5"D.P.as per K&M POOH schedule F/7,580'to 1,124'MD.HST 110K,SLK 115K.Mark joints WI Yellow paint that were under gauge.Calculated displacement 57 bbl,actual displacement 137 bbl. Lost 79 bbl Brine during laying down 4.5"D.P. 12 00 14 30 2.50 14.50 DRILL E 4 P PJSA Single out of the hole laying down 4.5"D.P.as per K&M POOH schedule F/1,124'to 143'MD.HST 90K.SLK 90K. Lay down BHA#6.Mark joints W/Yellow paint that were under gauge.Calculated displacement 11.5 bbl,actual displacement 30 bbl.Lost 18 bbl Brine during laying down 4.5"D.P. 14 30 1 5 00 0.50- 15.00'DRILL E 20 •P 'Clear and clean rig floor of BRA Equip. 15.00 16 30 1.50 16.50 DRILL G 20 P PJSM W/all essential personal for R/U Liner Equip.and running 4.5"Liner.R/U 4.5"Liner Equip.as per GBR Rep onsite. Stage completion jewelry in Pipe Shed. 16:30 00:00 7.50 24.00 DRILL G 4 P PJSA RIH 4.5"Liner and jewelry as per tally and K&M RIH schedule F/0'to 2.768'MD 67 joints,HST 100K,SLK 98K. Calculated displacement for trip 10.09 bbl.actual displacement-22 bbl.Lost 33 bbl of Brine to formation.Total 9.15 ppg NaCIIKCL Brine lost to formation today 130 bbl. Daily Contacts Position Contact Name _ Company • Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroteum.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 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 9,387.0 5/3/2013 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) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 fiti*1114i Eni E&P Division 'Well Name:5132-W2 ENI Petroleum Co.Inc. Daily Repa 1..}l Well Code:27080 Field Name:NIKAITCHUO • APIIUWI:50-629-23483-00-00 5/16/2013 - Repo #: 31 page 1 of 1 Wellbore name: S132-W2 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 70.44 - Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(HIM) POB Temperature(°F) Weather Wind 18.350.0 3,607.8 0.00 115.0 22.0 Partly Cloudy.WC 6' I ENE @ 14 MPH Daily summary operation 24h Summary PJSM W/all essential personal for running 4.5"Liner.RIH 4.5"Liner and jewelry as per tally and K&M RIH schedule F/2,768'to 9,107'MD 221 joints,HST 138K,SLK 98K.Calculated displacement for trip 39.8 bbl.actual displacement 66 bbl.Lost 26 bbl of Brine to formation.PJSM W/all essential personal for P/U M/U SLZXP Packer.P/U M/U SLZXP Packer @ 9,107'to 9,149'MD as per Baker Hughes Rep onsite.R/D Csg.Equip.,clear rig floor.TIH W/4.5"Liner on 5"D.P.as per tally and K&M RIH schedule F/9,149'to 9,338'MD.Establish rotary parameters per K&M Rep onsite,ROT WT 128K,40 RPM,TRO 5K,HST 132K,SLK 105K.Cont.to TIH 4.5"Liner on 5"D.P.F/9,338'to 17,084'MD.Fill D.P.via fill up hose every 5 stands.SLK 90K @ 15,404'MD.Lost SLK WT @ 17,084'MD, establish rotary parameters @ 40 RPM,TRQ 16K,ROT WT 147K.Rotate 4.5"Liner as per K&M schedule on 5"D.P.FI 17,084'to 18,333'MD,P/U to 18,327'MD and drop 1.65"ball down D.P.as per Baker Hughes Rep onsite.Pump ball down @ 2 bpm.SLK off while rotating to F/150K to 120K,P/U to 205K to set 4.5"Liner in tension.Test surface lines to 4,000 PSI.Cont.to pump 1.65"ball @ 2 bpm in 5"D.P.90 PSI,ball seated @ 980 Strks.Cont.to Press.up to 3,000 PSI and hold for 5 Min.Saw first shear @ 2,350 PSI,again @ 2,750 PSI and Packer set @ 3,400 PSI.Slack off F/170K to 120K. Press.up to 4,000 PSI and hold for 5 Min.Slack off F/120K to 90K.Test SLZXP Packer,close Annular Preventer and pump down Kill Line to 1,500 PSI for 10 Min on chart.Good Test.Total 9.15 ppg Bone lost today 66 bbl.Total 9.15 ppg NaCIIKCL Brine lost in 8.75"Production hole 206 bbl. Operation at 07.00 POOH 5"D.P.@ 4,385'MD. 24h Forecast Release from SLZXP Packer and POOH 5"D.P.F/9,188'MD to surface.Test BOPE as per AOGCC.P/U M/U retrievable bridge plug and RIH to 8.600'MD. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 6.00 6.00 DRILL G 4 P PJSM W/all essential personal for running 4.5"Liner.RIH 4.5"Liner and jewelry as per tally and K&M RIH schedule F/ 2.768'to 5,743'MD 139 joints,HST 118K,SLK 98K.Losses appear to be 10 bph. 0 .00 12.00 6.00 12.00 DRILL G 4 • 6 P PJSA RIH 4.5"Liner and jewelry as per tally and K&M RIH schedule F/5,743'to 9,107'MD 221 joints,HST 138K,SLK 98K.Calculated displacement for trip 39.8 bbl.actual displacement 65.7 bbl.Lost 25.9 bbl of Brine to formation. 1200 13.00 1.00 13.00 DRILL G 20 P PJSM W/all essential personal for P/U M/U SLZXP Packer.P/U M/U SLZXP Packer @ 9,107'to 9,149'MD as per Baker Hughes Rep onsite.R/D Csg.Equip.,Gear rig floor. 1300 18-.00 5.00 18.00 DRILL 0 4 P PJSA TIH W/4.5"Liner on 5"D.P.as per tally and K&M RIH schedule F/9,149'to 9,338'MD.Establish rotary parameters per K&M Rep onsite,ROT WT 128K,40 RPM,TRQ 5K,HST 132K,SLK 105K.Cont.to RIH 4.5"Liner on 5"D.P.F/9,338' to 15,404'MD.Fill D.P.via fill up hose every 5 stands.SLK 90K @ 15.404'MD. 18-.00 18.30 0.50 18.50 DRILL G 4 P Cont.TIH W/4.5"Liner on 5"D.P.F/15,404'to 17,084'MD.Lost SLK WT,establish rotary parameters @ 40 RPM,TRQ 16K,ROT WT 147K. • 18-.30 22.00 3.50 22.00 DRILL G 4 P Rotate 4.5"Liner as per K&M schedule on 5"D.P.F/17,084'to 18,333'MD,P/U to 18,327'MD and drop 1.65"ball down D.P.as per Baker Hughes Rep onsite.Pump ball down @ 2 bpm.Slack off while rotating to F/150K to 120K,P/U to 205K to set 4.5"Liner in tension. 200 -2330 1.50 23.50 DRILL G 19 'P - 2 Test surface lines to 4,000 PSI.Cont.to pump 1.65"ball @ 2 bpm in 5"D.P.90 PSI,ball seated @ 980 Strks.Cont.to Press.up to 3,000 PSI and hold for 5 Min.Saw first shear @ 2,350 PSI,again @ 2,750 PSI and Packer set @ 3,400 PSI. Slack off F/170K to 120K.Press.up to 4,000 PSI and hold for 5 Min.Slack off F/120K to 90K. ' 23.30 00:00 0.50 24.00 DRILL G 19 P PJSA Test SLZXP Packer,close Annular Preventer and pump down Kill Line to 1,500 PSI for 10 Min on chart.Good Test. Total 9.15 ppg Brine lost today 66 bbl.Total 9.15 ppg NaCUKCL Brine lost in 8.75"Production hole 206 bbl. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Maas 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 Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @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) I Bottom(ftKB) Run Date LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 i ft* Eni E&P Division !Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • 2^ Date:5/17/2013 - Report#: 32 APIIUWI:50-629-23483-00-00 If II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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) S132'✓V2 DRILLING 3/7/2013 18,327.0 3.583.4 18,349.00 112.69 162.8 71.44 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) 'Weather 'Wind 18,350.0 3,607.8 0.00 113.0 13.0 Cloudy,WC 0° WNW @ 8 MPH Daily summary operation 24h Summary PJSM Cont.to an SLZXP Packer as per Baker Hughes Rep onsite.Test Packer W/1,500 PSI for 10 Min.on chart.Open Annular Preventer and slack off F/120K to 80K and release Packer Assy.P/U and confirm released,Top of Packer 9,188'MD,4.5"Liner shoe @ 18,327'MD.Blow down Kill Line and TLS8.PJSA POOH on elevators 5"D.P.F/9,186'to 37'MD.HST 180K.L/D Baker running tool Assy.as per Baker Hughes Rep onsite.PJSM Pull Wear Bushing and set Test Plug as per Vetco Grey Rep onsite.PJSM W/all essential personal.R/U test Equip.for BOPE test.Test waived by John Crisp 5-17-13 @ 0600 hours.Perform BOPE test.Annular tested to 350 PSI low and 2.500 PSI high.All Rams and Valves tested to 250 PSI low and 3,500 PSI high.Test charted for 5 Min.each.4.5" D.P.&5"D.P.test joint used.Tested Rams,Manual Chokes and Hydraulic Choke was tested to 1,500 PSI.Draw down test:Manifold PSI 1,500 PSI,System 1,500 PSI,Annular 750 PSI.After function: Manifold 1,500 PSI,System 1,500 PSI,Annular 750 PSI,200 PSI increase 52 seconds.Total system recovery 207 Sec.5 bugles Nitro 2,400 PSI.Betties average 1,000 PSI.Top off annulus while testing took 17 bbls of 9.1 ppg Brine.Pull test Plug&set Wear Bushing.Blow down and R/D test Equip.Service Top Drive.Total lost 58 bbls 9.1 ppg NaCVKCL Brine today. Changed Well View to MDT AFE @ 18:00. Operation at 07.00 POOH 5"D.P. 24h Forecast P/U M/U retrievable Bridge Plug as per Baker Hughes Rep onsite.RIH on 5"D.P.to 8,595'MD.Set Bridge plug and POOH on elevators.PJSM W/all essential personnel on handling Pert Guns.P/U M/U Perf Guns as per Schlumberger Rep onsite.RIH on 5"D.P.and correlate.Set Per(Guns and POOH. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL G 19 P PJSM Cont.to se SLZXP Packer as per Baker Hughes Rep onsite.Test Packer W/1,500 PSI for 10 Min.on chart.Open Annnular Preventer and slack off F/120K to 80K and release Packer Assy.P/U and confirm released,Top of Packer 9,188' MD,4.5"Liner shoe @ 18,327'MD.Blow down Kill Line and TLS8. 00:30 06:00 5.50 6.00 DRILL G 4 P PJSA POOH on elevators 5"D.P.F/9,186'to 37'MD.HST 180K. 06:00 07:00 1.00 7.00 DRILL G 4 P PJSA L/D Baker running tool Assy.as per Baker Hughes Rep onsite. 07:00 07:30 0.50 7.50 DRILL G 20 P Clear and clean rig floor of running tools. 07:30 08:30 1.00 8.50 DRILL C 20 P PJSM Pull Wear Bushing and set Test Plug as per Vetco Grey Rep onsite. 08:30 09:00 0.50 9.00 DRILL C 12 P PJSM W/all essential personal.R/U test Equip,for BOPE test. 09:00 15:30 6.50 15.50 DRILL C 12 P PJSA Perform test BOPE.Annular tested to 350 PSI low and 2,500 PSI high.All Rams and Valves tested to 250 PSI low and 3,500 PSI high.Test charted for 5 Min.each.4.5"D.P.8 5"D.P.test joint used.Tested Rams,Manual Chokes and Hydraulic Choke was tested to 1,500 PSI.Draw down test.Manifold PSI 1,500 PSI,System 1,500 PSI,Annular 750 PSI. After function:Manifold 1,500 PSI,System 1,500 PSI,Annular 750 PSI,200 PSI increase 52 seconds.Total system recovery 207 Sec.5 bottles Nero 2,400 PSI.Bottles average 1,000 PSI.Top off annulus while testing took 17 bbls of 9.1 ppg Brine.Total lost 58 bbls 9.1 ppg NaCLIKCL Brine Changed Well View to MDT AFE @ 18:00. 19 30 16.30 1.00 16.50 DRILL C 12 P PJSA Pull test Plug and set Wear Bushing as per Vetco Grey Rep onsite. 16.30 17.30 1.00 17.50 DRILL C 20 P Blow down surface Equip.and R/D test Equip. 17.30 18.00 0.50 18.00 DRILL G 20 P Service Top Drive. 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 Ben Perry ENI Senior Dolling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Satch Bowe ENI Mails Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akhgc/erksdoyon15@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 hg15@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 LINER 5 3.960 0.0 18,327.0 5'17/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 9,427.0 3,626.24 Prime Faze 9.40 680.0 13.01 2.450.7 Eni E&P Division Well Name: SI32-W2 fil* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUQ Date:5117/2013 - Report#: 1 APIIUWI:50-629-23483-00-00 ' i i ii page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator I ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 WELL 0.00 0.00 0.00 EVALUATION/P&A Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) I Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 113.0 13.0 Cloudy,WC 0' rind @ 8 MPH Daily summary operation 24h Summary PJSM W/all essential personal.P/U M/U retrievable Bridge Plug as per Baker Hughes Rep onsite.RIH on 5"D.P.F/surface to 7,016'MD.HST 159K,SLK 120K.Total Brine lost for trip 16 bbl. Operation at 07.00 POOH 5"D.P.W/Bridge Plug running tool @ 7,002'MD. 24h Forecast RIH retrievable Bridge Plug on 5"D.P.to 8,595'MD.Set Bride Lug and POOH on elevators.PJSM WI all essential personal on handling Perf Guns.P/U M/U Perf Guns as per Schlumberger Rep onsite. RIH on 5"D.P.and correlate.Set Pert Guns and POOH. Lithology 'Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 1800 00.00 6.00' 6.00 W.T. P 4 P PJSM W/all essential personal.P/U M/U retrieviable Bridge Plug as per Baker Hughes Rep onsite.RIH on 5"D.P.Fl surface to 7,016'MD.HST 159K,SLK 120K.Total Brine lost for trip 16 bbl. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satoh 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 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 Pete Mariinusen Doyon Drilling Tour Pusher rigt5 @doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13_01 2,450.7 Eni E&P Division Well Name: 5132-W2 fifill* ENI Petroleum Co.Inc. Daily Report WelI Code:27080 Field Name: NIKAITCHUO • APIIUWI:50-629-23483-00-00 2�, Date:5/18/2013 - Report#: 2 II II page 1 of 1 Wellbore name: SI32-W2 Well Header PermiVConcession N° Operator ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 WELL 0.00 0.00 0.00 EVALUATION/P&A Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(B) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 114.0 -1.0 Partly Cloudy.WC- SSE @ 13 MPH 17" Daily summary operation 24h Summary RIH W/Bridge Plug on 5"D.P.Fl 7,016'to 8,595'MD.HST 75K,SLK 120K.Baker Hughes Rep onsite.As per Baker Hughes rep onsite set retrievable Bridge Plug @ 8,595'MD&release from Bridge Plug.As per Company Man Rep onsite Circ.drill string volume to ensure air is out of the D.P.420 GPM,450 PSI 1,600 Strks.R/U&test Bridge Plug on chart to 1,500 PSI for 10 Min.Witnessed by Company Rep.POOH W/Bridge Plug running Assy.F/8,595'to surface.HST 74K,SLK 76K.UD running tools W/Baker Hughes Rep onsite.Service Drawworks,Top Drive&Traveling Equip.Clean& clear rig floor.Mobilize Equip.for drill string convey pert guns.PJSM With all essential personal on P/U&M/U of Perf Guns W/Scraper&MWD.P/U M/U BHA#7 with Perf Guns,9 5/8"Csg.Scraper& Tele Scope 675.RIH BHA#7 on 5"D.P.F/65'to 8,000'MD.HST 160K,SLK 130K.Shallow test tools @ 1,500'MD.Perform MAD pass F/8,000'to 8,461'MD 410 GPM,460 PSI @ 250-300 FPH. Correlate logs and position Perf Guns for perforating 9 5/8"Csg. @ 8,324'MD. PJSM With all essential personal for perforating.Prep for perforation.Perform perforation as per Schlumberger Rep onsite.Cycle 1,000 PSI 6 times to engage gu*!s.Shot 12 spf F/8,324'fo S,32B'MD.Observe 6"fluid drop in BOPE stack after guns fired.Monitor well for 15 Min.,static. RIH Fl 8,328'to 8,348'MD to use 9 5/8"Csg.Scraper to ensure 9 5/8"Csg.was`ctean of burrs.POOH WI Perf Gun,9ssy-®HA#7 on 5"D.P.F/8,348'to surface.HST 165K,SLK 130K. Operation — rap I LID discharged pe pe /V rt guns. 10 P 24h Forecast L/D discharged Per Guns as per Schlumberger Rep onsite.P/U M/U retrievable Bridge Plug Assy.RIH to 8,595'MD and POOH W/Bridge Plug on 5"D.P.L/D Bridge Plug.R/U MDT Tools and RIH. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.10 - Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. I Plan Oper.Descr. 00-.00 01 30 1.50 1.50 W.T. P 4 P PJSA RIH W/Bridge Plug on 5"D.P.F/7,016'to 8.595'MD.HST 75K,SLK 120K.Baker Hughes Rep onsite.Lost 3 bbl 9.1 ppg NaCl/KCL Brine to formation. 01 30 02.00 0.50 2.00 W.T. P 19 P PJSA As per Baker Hughes rep onsite set retrievable Bridge Plug @ 8,595'MD&release from Bridge Plug. 02 00 02 30 0.50 2.50 W.T. P 7 P PJSA As per Company Man Rep onsite Circ.drill string volume to ensure air is out of the D.P.420 GPM,450 PSI 1,600 Strks. 02.30 03.00 0.501 3.00 W.T. P 19 1P PJSA R/U&test Bridge Plug on chart to 1,500 PSI for 10 Min.Witnessed by Company Rep. 0300 07:00 4.00 7.00 W.T. P 4 P PJSA POOH W/Bridge Plug running Assy.F/8,595'to surface.HST 74K,SLK 76K.UD running tools W/Baker Hughes Rep onsite. 07.00 08:00 1.00 8.00 W.T. P 20 P PJSA Service Drawrorks,Top Drive&Traveling Equip.Clean&clear rig floor.Mobilize Equip.for drill string convey pert ' guns. 08:00 08:30 0.50 8.50 W.T. P 20 P 'PJSM With all essential personal on P/U&M/U of Perf Guns W/Scraper&MWD. 08:30 09:30 1.00 9.50 W.T. P 20 -P P/U M/U BHA#7 with Pert Guns,9 5/8"Csg.Scrapper&Tele Scope 675. 09:30 12:00 2.50 12.00 W.T. P 4 'P PJSA RIH BHA#7 on 5"D.P.F/65'to 2,400'MD,HST 113K,SLK 113K.Shallow test tools©1,500'MD. 12:00 15:30 3.50 15.50 W.T. P 4 'P PJSM RIH BHA#7 on 5"D.P.F/2,400'to 8,000'MD.HST 160K,SLK 130K. 15:30 19:00 3.50 19.00 W.T. P 11 P Perform MAD pass F/8,000'to 8,461'MD 410 GPM,460 PSI @ 250-300 FPH. I 19:00 21:00 2.00 21.00 W.T. P 11 P Correlate logs and position Pert Guns for perforating 9 5/8"Csg. @ 8,324'MD. SPR @ 8,324'MD(3,545 TVD)9.1 ppg MW I MP#2 30-40,40-70 MP#3 30-40,40-70 21 00 2100 1.00 22.00 W.T. P 20 P PJSM With all essential personal for perforating.Prep for perforation. 22.00 22.30 0.50 22.50 W.T. P 16 'P 'Perform perforation as per Schlumberger Rep onsite.Cycle 1,000 PSI 6 times to engage guns.Shot 12 spf F/8,324'to 8,328'MD.Observe 6"fluid drop in BOPE stack after guns fired.Monitor well for 15 Min.,static. 22.30 0000 1.50 24.00 W.T. P 4 P PJSA RIH F/8,328'to 8,348'MD to use 9 5/8"Csg.Scraper to ensure 9 5/8"Csg.was clean of burrs.POOH W/Pert Gun Assy BHA#7 on 5"D.P.F/8,348'to 7.997'MD.HST 165K,SLK 130K. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 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@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroteum.com 907-685-0721 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(ftKB) Bottom(ftKB) Run Date LINER 5 3.960 0.0 18,327.0 5/17/2013 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) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2.450.7 • If* Eni E&P Division I Well Name: SI32-W2 EN!Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUO • Date:5/19/2013 - Report#: 3 APIIUWI:50 629-23483-00-00 en page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13,08 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) SI32-W2 WELL 0.00 0.00 0.00 EVALUATION/P&A Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 111.0 32.0 Mostly Cloudy,WC SSW @ 17 MPH 18' Daily summary operation 24h Summary POOH W/BHA#7 as per Baker Hughes Rep onsite F/7,997'to 65'MD.Calculated displacement 68 bbl,actual displacement 78 bbl.Lost 10 on top out.PJSM W/all essential personnel.LID BHA#7 (MWD,Scraper&Perf Guns)F/65'to 0'.All pert shots fired witnessed by Company Rep.Clean and clear rig floor of Perf Gun components and Scraper.Slip and cut drilling line.Service Rig,Drawv°orks, Top Drive,inspect Brakes&Traveling Equip.RIH W/Bridge Plug Retrieval Tool as per Baker Hughes Rep onsite F/surface to 8,510'MD PJSM At 8,510'MD.Break Circ.@ 3 bpm 50 PSI wash down and locate Bridge Plug.Set down 10K @ 8,598'MD and equalize plug.Observe loss of returns,pump Press.increase to 220 PSI.Shut down pumps and monitor well,fluid level falling slowly @ about 35 bph.Break Circ.@ 2.5 bpm 210 PSI.Fill hole,P/U to neutral weight 170K to retrieve return fluid path from Plug.Circ.@ 3 bpm 40 PSI monitoring losses.Still @ 35 bph.Release Plug as per Baker Hughes Rep,RIH to 8,603'MD to ensure plug is free.Lost 38 bbl while releasing Bridge Plug.Blow down Top Drive.POOH on elevators WI Bridge Plug Fl 8,603'to 17'MD.Calculated displacement 70 bbl,actual displacement 150 bbl.Lost 79 bbl on trip.Inspect Bridge Plug and clean rig floor.PJSM WI all essential personnel for RIH W/Bridge Plug.RIH F/17'to 7,203'MD HST 160K,SLK 130K. Calculated displacement 57 bbl,actual displacement 30 bbl.Lost 27 bbl on trip.Total 9.1 ppg NaCl/KCL Brine lost today 144 bbl. Operation at 07.00 POOH W/Bridge Plug Assy.@ 2,258'MD. 24h Forecast Cont.RIH W/Bridge Plug to 8,592'MD.POOH W/Bridge Plug Assy.PJSM W/all essential personnel for MDT.P/U MDT Tools as per Schlumberger Rep onsite.RIH to Perform MDT. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Start End I Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 W.T. P 4 • P PJSA POOH W/BHA#7 as per Baker Hughes Rep onsite F/7,997'to 65'MD.HST 78K,SLK 80K Calculated displacement 68 bbl,actual displacement 78 bbl.Lost 10 on trip out. 04:00 04:30 0.50 4.50 W.T. P 4 P PJSM W/all essential personnel.L/D BHA#7(MWD,Scraper&Pert Guns)F/65'10 0'.All pert shots fired witnessed by Company Rep. 04:30 05:00 0.50 5.00 W.T. P 20 P PJSA Clean and clear rig floor of Pert Gun components and Scraper. 05:00 07:00 2.00 7.00 W.T. P 20 P PJSA Slip and cut drilling line.Service Rig,Drawworks,Top Drive,inspect Brakes&Traveling Equip. 07:00 12:00 5.00 12.00 W.T. P 4 P PJSA RIH W/Bridge Plug Retrieval Tool as per Baker Hughes Rep onsite F/surface to 8,510'MD HST 169K,SLK 128K. 12:00 13:00 1.00 13.00 W.T. P 19 P PJSM At 8,510'MD P/U 170K,SLK 125K.Break Circ.@ 3 bpm 50 PSI wash down and locate Bridge Plug.Set down 10K @ 8,598'MD and equalize plug.Observe loss of returns,pump Press.increase to 220 PSI.Shut down pumps and monitor well,fluid level falling slowly @ about 35 bph.Break Circ.@ 2.5 bpm 210 PSI.Fill hole.P/U to neutral weight 170K to retrieve return fluid path from Plug.Circ.@ 3 bpm 40 PSI monitoring losses.Still @ 35 bph.Release Plug as per Baker Hughes Rep,RIH to 8,603'MD to ensure plug is free.Lost 38 bbl while releasing Bridge Plug. • 13:00 17:30 4.50 17.50 W.T. P 4 P PJSA Blow down Top Drive.POOH on elevators WI Bridge Plug F/8,603'to 17'MD HST 175K,SLK 130K.Calculated displacement 70 bbl,actual displacement 150 bbl.Lost 79 bbl on trip. 17:30 18:00 0.50 18.00 W.T. P 19 P Inspect Bridge Plug and clean rig floor. 18:00 00:00 ' 6.00 24.00 W.T. P 4 P PJSM W/all essential personnel for RIH W/Bridge Plug.RIH Fl 17'to 7,203'MD HST 160K,SLK 130K.Calculated displacement 57 bbl,actual displacement 30 bbl.Lost 27 bbl on trip.Total 9.1 ppg NaCl/KCL Brine lost today 144 bbl. 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 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 Pete Martinusen Doyon Dulling Tour Pusher rig15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9.427.0 3.626.24 Primo Faze 9.40 680.0 13.01 2.450.7 Eni E&P Division Well Name: S132-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUO • APIIUWI:50-629-23483-00-00 2�,f, Date:5/20/2013 - Report#: 4 If II II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(it) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 WELL 0.00 0.00 0.00 EVALUATION/P&A Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(it/hr) POB Temperature(°F) Weather Wind 0.0 109.0 32.0 Mostly Cloudy,WC SSE @ 8 MPH 23" Daily summary operation 24h Summary RIH W/Bridge Plug F/7,203'to 8,592'MD as per Baker Hughes Rep onsite.SLK 128K,HST 165K.Set Bridge Plug @ 8,592'MD W/Baker Hughes Rep onsite.Calculated displacement 12 bbl,actual displacement 7 bbl,lost 5 bbl.Monitor well for 15 Min.,8 bph static loss.POOH W/Bridge Plug running tool on 5"D.P.Fl 8,592'to Surface HST 76K,SLK 76K.L/D running tool as per Baker Hughes Rep onsite.Calculated displacement 71 bbl,actual displacement 106 bbl,lost 35 bbl for trip.PJSM W/Schlumberger MDT Reps and all essential personnel.Wait on orders from town due to extended losses to formation for the MDT test.Wait on the arrival of"EA"Retrievamatic for testing the Bridge Plug @ 8,592'MD.Perform PM's and general housekeeping around the rig.P/U M/U"EA"Retrievamatic Assy.as per Baker Hughes Rep onsite.RIH on 5"D.P.to 8,335'MD,HST 175K,SLK 130K.Calculated displacement 65 bbl,actual displacement 41 bbl.Lost 24 bbl on trip in hole.At 8,335'MD break Circ.@ 3 bpm 50 PSI.Turn off pumps,locate"EA"Retrievamatic @ 8,392'MD and set as per Baker Hughes Rep onsite.Set 10K down weight,observe good set.Press.up against Bridge Plug @ 8,592' MD @ 1.5 bpm to 1,500 PSI.Observed Press.loss and returns up Annulus.Bleed off Press.&relocate Retievamatic to 8,398'MD.Set down 80K as per Baker Rep onsite.Press.up against Bridge Plug to 1,500 PSI @ 3 bpm.Hold Press.on chart for 30 MIN.Circ.over top during Press.test to observe losses to Perfs,no losses.Bleed off Press.from between Packer's and Cont.to Circ.over top for 20 Min.W/no losses observed to Perfs.POOH on elevators F/8,398'to 4,415'MD HST 141K,SLK 130K.Calculated displacement 30,5 bbl,actual displacement 35 bbl.Lost 4.5 bbl on trip.Total Brine lost today 125 bbl. Operation at 07.00 P/U M/U MDT Tools. 24h Forecast Cont.POOH F/4,415'MD to surface.L/D Retrievamatic as per Baker Rep onsite.Depending on static loss to Perfs.PJSM W/Schlumberger MDT service hands.P/U M/U MDT tools and RIH to perform MDT. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr)( Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 W.T. P 4 P PJSA RIH W/Bridge Plug F/7.203'to 8,592'MD as per Baker Hughes Rep onsite.SLK 128K,HST 165K.Set Bridge Plug @ 8,592'MD W/Baker Hughes Rep onsite.Calculated displacement 12 bbl,actual displacement 7 bbl,lost 5 bbl.Monitor well for 15 Min.,8 bph static loss. 01:00 05:00 ' 4.00 5.00 W.T. P 4 P PJSA POOH WI Bridge Plug running tool on 5"D.P.F/8,592'to Surface HST 76K,SLK 76K.L/D running tool as per Baker Hughes Rep onsite.Calculated displacement 71 bbl,actual displacement 106 bbl,lost 35 bbl for trip. 05:00 05:30 0.50 5.50'W.T. P 20 P PJSA Clean and clear rig floor. 05:30 06:00 0.50 6.00 W.T. P 20 P PJSM W/Schlumberger MDT Reps and all essential personnel. 06:00 12:00 6.00 12.00 W.T. P 21 P Wait on orders from town due to extended losses to formation for the MDT test.Wait on the arrival of"EA"Retrievamatic for testing the Bridge Plug @ 8,592'MD.Perform PM's and general housekeeping around the rig.Total Brine lost this tour 85 bbl. 12:00 18:00 6.00 18.00 W.T. P 4 P PJSM P/U M/U"EA"Retrievamatic Assy.as per Baker Hughes Rep onsite.RIH on 5"D.P.to 8,335'MD,HST 175K,SLK 130K.Calculated displacement 65 bbl,actual displacement 41 bbl.Lost 24 bbl on trip in hole. 18:00 20:00 ' 2.00 20.00 W.T. P 19 P At 8,335'MD break Circ.@ 3 bpm 50 PSI.Tum off pumps,locate"EA"Retrievamatic @ 8,392'MD and set as per Baker Hughes Rep onsite.Set 10K down weight,observe good set.Press.up against Bridge Plug @ 8,592'MD @ 1.5 bpm to 1,500 PSI.Observed Press.no pressure lost on Bridge Plug test,test good.Check for fluid loss in annulus with trip tank,no loss observed.Bleed off Press.&relocate Retrievamatic to 8,398'MD.Set down 80K as per Baker Rep onsite.Press.up against Bridge Plug to 1,500 PSI @ 3 bpm.Hold Press.on chart for 30 MIN.Circ.over top during Press.test to observe losses to Perfs,no losses.Bleed off Press.from between Packer's and Cont.to Circ.over top for 20 Min.W/no losses observed to Perfs. 20.00 00.00 - 4.00 24.00 W.T. P 4 P POOH on elevators F/8,398'to 4,415'MD HST 141K,SLK 130K.Calculated displacement 30.5 bbl,actual displacement 35 bbl.Lost 4.5 bbl on trip.Total Brine lost today 125 bbl. 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 Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.corn 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl 5 @enipetroleum.corn 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Sleve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 3.960 0.0 18.327.0 5/17/2013 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) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 1 Eni E&P Division Ewen Name: sl32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUO • APIIUWI:50-629-23483-00-00 2^n Date:5/21/2013 - Report#: 5 II II II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) DFS(days) SI32-W2 WELL 0.00 0.00 0.00 EVAL UATION,PSA Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 00 107.0 33.0 Partly Cloudy,WC NNE @ 5 MPH 27' Daily summary operation 24h Summary PJSA POOH W/"EA"Retrievamatic&Bridge Plug running Assy.F/4,415'MD to surface.HST 76K,SLK 78K.UD"EA"Retrievamatic&Bridge Plug running Assy as per Baker Hughes Rep onsite. Calculated displacement 69 bbl,actual displacement 71 bbl.Total Brine lost for trip 2 bbl.Monitor well,static.Clean and clear rig Floor&prep for Schlumberger MDT tool run.PJSM W/all essential personnel on P/U MDT tools.P/U M/U MDT tools as per Schlumberger Rep onsite F/0'to 132'MD.M/U witnessed by Company Rep onsite.RIH W/MDT tools on 5"D.P.F/132'to 8,063'MD HST 128K, SLK 120K,Fill D.P.every 20 stands,Rabbit 5"D.P.on the way in the hole. No losses to formation.PJSM W/all essential personnel for R/U&P/U WE-Line.R/U E-Line,hang sheaves,M/U side entry sub and XO's as per Schlumberger Rep onsite and Company man witnessed operations.RIH W/E-Line inside 5"D.P.as per Schlumberger Rep onsite.Pump down 4,000'E-Line @ 3 bpm,50 PSI. Stage up pump rate to 7 bpm,210 PSI.Circ.230 bbl and observe Press.increase to 330 PSI.E-Line latched to running tool.Shut down pumps,test E-Line and MDT Tool.(Good)Install clamp to side entry sub.PJSM W/all essential personnel on RIH W/E-Line on D.P.Log in hole F/8,063'to 8,535'MD HST 170K,SLK 125K.Log back up F/8,535'to 8,372'MD position tool string as needed.All work done W/Schlumberger Rep onsite. Operation at 07.00 Perform MDT test. 24h Forecast Stop logging and set MDT Tool in zone.Perform formation test and capture sample from N Sand formation.POOH W/E-Line. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr( Phase Opr. Act. Plan Oper.Descr. 00.00 02.30 2.50 2.50 W.T. P 4 P PJSA POOH W/"EA"Retdevamatic&Bridge Plug running Assy.F/4,415'MD to surface.HST 76K.SLK 78K.LID"EA" Retrievamatic&Bridge Plug running Assy as per Baker Hughes Rep onsitte.Calculated displacement 69 bbl,actual displacement 71 bbl.Total Brine lost for trip 2 bbl.Monitor well,static. 02:30 03:00 0.50 3.00 W.T. P 20 P PJSA Clean and clear rig floor&prep for Schlumberger MDT tool run. 03:00 07.00 4.00 7.00 W.T. P 20 P PJSM W/all essential personnel on P/U MDT tools.P/U M/U MDT tools as per Schlumberger Rep onsite F/0'to 132'MD. M/U witnessed by Company Rep onsite. 07:00 12:00 5.00 12.00 W.T. P 4 P PJSA RIH WI MDT tools on 5"D.P.F/132'to 3,865'MD HST 128K,SLK 120K.Fill D.P.every 20 stands,Rabbit 5"D.P.on the way in the hole.Calculated displacement 32 bbl,actual displacement 32 bbl.No losses to formation. 12:00 18:00 6.00 18.00 W.T. P 4 P PJSA RIH W/MDT tools on 5"D.P.F/3,865'to 8,063'MD HST 170K,SLK 125K.Fill D.P.every 20 stands,Rabbit 5"D.P. on the way in the hole.No losses to formation. 18:00 20:00 2.00 20.00 W.T. P 20 P PJSM W/all essential personnel for R/U&P/U E-Line.R/U E-Line,hang sheaves,M/U side entry sub and XO's as per Schlumberger Rep onsite and Company man witnessed operations. 20:00 22:00 2.00 22.00 W.T. P 19 P PJSA RIH W/E-Line inside 5"D.P.as per Schlumberger Rep onsite.Pump down 4,000'E-Line @ 3 bpm,50 PSI.Stage up pump rate to 7 bpm,210 PSI.Circ.230 bbl and observe Press.increase to 330 PSI.E-Line latched to running tool.Shut down pumps,test E-Line and MDT Tool.(Good)Install clamp to side entry sub. 2200 00.00 2.00 24.00 W.T. P 11 P PJSM W/all essential personnel on RIH W/E-Line on D.P.Log in hole Fl 8,063'to 8,535'MD HST 170K,SLK 125K.Log back up F/8,535'to 8,372'MD position tool string as needed.All work done W/Schlumberger Rep onsite. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Mails Coordinator 907-685-0718 Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyon15 @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 ng15 @doyondnlling.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 LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth((MB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 9.427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 Eni E&P Division I Well Name:SI32-W2 It* EN!Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • APIIUWI:50-629-23483-00-00 2^ Date:5/22/2013 - Report#: 6 II 'I page 1 of 1 Wellbore name: S(32-W2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 WELL 0.00 0.00 0.00 EVALUATION/P&A Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 106.0 28.0 Partly Cloudy.WC NE @ 22 MPH 15' Daily summary operation 24h Summary RIH W/E-Line on D.P.Log in hole F/8,063'to 8,535'MD HST 170K,SLK 125K.Log back up F/8,535'to 8,372'MD.Set MDT depth 8,328.5'MD.All work done W/Schlumberger Rep onsite.Monitor well W/Trip Tank.Perform drill stem MDT W/Schlumberger Wireline©8,328.5'MD.Processed 85 gal @ 2 cc per Sec.Filled all six sample bottles for MDT.Start recharge formation test.Monitoring well W/ Trip Tank,no losses.SIMOPS General housekeeping and maintenance. Operation at 07.00 Disconnect W/Wireline and pull wdreline out of hole thru D.P. It 1 24h Forecast Ili-�.X) Complete recharge formation test.Disconnect from MDT Tool in 5"D.P.and POOH W/Wireline.R/D Wireline Equip.and POOH 5"D.P.L/D MDT Tools W/Schlumberger Rep onsite.P/J Bridge Plug ■ running tool as per Baker Hughes Rep onsite.RIH w/5"D.P.and pull Bridge plug @ 8.592'MD. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) ■ p 9.10 '`P Time Log 5 i Y Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 W.T. P 11 P PJSA RIH W/E-Line on D.P.Log in hole F/8,063'to 8,535'MD HST 170K,SLK 125K.Log back up F/8.535'to 8,372'MD. Set MDT depth 8,328.5'MD.All work done W/Schlumberger Rep onsite.Monitor well W/Top Tank. 01:00 12:00 11.00 12.00 W.T. P 10 P PJSA Perform drill stem MDT W/Schlumberger Wireline @ 8,328.5'MD.Monitoring well W/Trip Tank,no losses.SIMOPS General housekeeping and maintenance. 12:00 00:00 12.00 24.00 W.T. P 10 P PJSA Perform drill stem MDT W/Schlumberger Wireline©8,328.5'MD.Processed 85 gal @ 2 cc per Sec.Filled all six sample bottles for MDT.Start recharge formation test.Monitoring well W/Trip Tank,no losses.SIMOPS General housekeeping and maintenance. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5 @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 LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test 'Depth(ftKB) ,TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) I Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 9 427.0 3,626.24 Primo Faze 9A0 680.0 13.01 2,450.7 i D Eni E&P Division I Well Name: 5132-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name: NIKAITCHUO • 2 nDate:5/23/2013 - Report#: 7 APIIUWI:50-629-23483-00-00 oII " page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° 'Operator ENI Share(%) Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 WELL 0.00 0.00 C.00 EVALUATION I P&A Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather rind 0.0 109.0 26.0 Fog,WC 15' ENE @ 9 MPH Daily summary operation 24h Summary Perform doll stem MDT WI Schlumberger Wireline @ 8,328.5'MD.Recharge formation test.Monitoring well W/Trip Tank,no losses.Release F/Packers and disconnect E-Line from MDT.POOH E-Line to side entry sub.PJSM WI all essential personnel for R/D E-line.POOH E-Line to side entry sub.Remove side entry sub and R/D E-Line sheaves and tools as per Schlumberger Rep onsite.Monitor well, static.POOH 5"D.P.w/MDT tools FI 8,069'to 131'MD HST 76K,SLK76K.No losses. L/D MDT tool as per Schlumberger rep onsite.PJSM W/all essential personnel on P/U Packer running tool.P/U M/U Packer running tool as per Baker Hughes Rep onsite.RIH on 5"D.P.F/surface to 8,504'MD.HST 125K,SLK 168K. Wash down Fl 8,504'to Bridge Plug @ 8,592'MD.3 bpm,50 PSI.Latch onto Bridge Plug and unset as per Baker Hughes Rep onside.Circ.@ 3 bpm until retums seen at surface.Shut down pump and Circ.over top of hole to find static loss rate.Loss rate was 66 bph.Blow down Top Drive. POOH on 5"D.P.8 Bridge Plug as per Baker Hughes Rep onsite F/8,592'to 2,445'MD.HST 120K,SLK 115K.Calculated displacement 50 bbl.actual displacement 149 bbl.Total lost today 187 bbl 9.1 ppg NaCUKCL Brine.Static loss @ 24:00 26 bph. Operation at 07.00 Service Rig. 24h Forecast Cont.POOH on 5"D.P.W/Bridge Plug as per Baker Hughes Rep onsite.LID Bridge Plug.Slip Drilling Line,Service Rig and change out ram on IBOP valve on Top Drive.R/U GBR Tubing Equip.P/U M/U 4.5"Tubing and Jewelry as per Tally.RIH W/4.5"Tubing and space out. Lithology 'Shows J MAASP Pressure(psi) Mud Weight(Iblgal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00'W.T. P 10 P PJSA Perform drill stem MDT W/Schlumberger Wireline @ 8,328.5'MD.Recharge formation test.Monitoring well W/Trip Tank,no losses.Release FI Packers and disconnect E-Line from MDT.POOH E-Line to side entry sub.SIMOPS General housekeeping and maintenance. 06:00 08:00 2.00 8.00'W.T. P 20 P PJSM W/all essential personnel for R/D E-line.POOH E-Line to side entry sub.Remove side entry sub and R/D E-Line sheaves and tools as per Schlumberger Rep onsite.Monitor well,static. 08:00 12:00 4.00 12.00 W.T. P 4 P PJSA POOH 5"D.P.w/MDT tools F/8,069'to 2.370'MD HST 119K,SLK 113K.No losses. 12:00 '13:00 1.00 13.00 W.T. P 4 P PJSA POOH 5"D.P.w/MDT tools F/2,370'to 131'MD HST 76K,511(76K.No losses. 13:00 14:30 1.50 14.50 W.T. P 20 P PJSA L/D MDT tool as per Schlumberger rep onsite. 14:30 19:00 4.50 19.00'W.T. P 4 P PJSM W/all essential personnel on P/U Packer running tool.P/U M/U Packer running tool as per Baker Hughes Rep onsite.RIH on 5"D.P.F/surface to 8,504'MD.HST 125K,SLK 168K. 19:00 19:30 0.50 19.50 W.T. P 4 P PJSA Wash down F/8,504'to Bridge Plug @ 8,592'MD.3 bpm,50 PSI.Latch onto Bridge Plug and unset as per Baker Hughes Rep onsite. 19:30 20:00 0.50 20.00 W.T. 'P 7 P PJSA Circ.@ 3 bpm until retums seen at surface.Shut down pump and Circ.over top of hole to find static loss rate.Loss rate was 66 bph.Blow down Top Drive. 20:00 00:00 4.00 24.00'W.T. P 4 P PJSA POOH on 5"D.P.&Bridge Plug as per Baker Hughes Rep onsite F/8,592'to 2,445'MD.HST 120K.SLK 115K. Calculated displacement 50 bbl.actual displacement 149 bbl.Total lost today 187 bbl 9.1 ppg NaCl/KCL Brine.Static loss @ 24:00 26 bph. - 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 Bemie Leas ENI Rig Clerk akrigclerksdoyon15 @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 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 LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) -Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 ff* Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUG • APIIUWI:50-629-23483-00-00 2^ Date:5/24/2013 - Report#: 1 II 'I page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(14) I Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 COMPLETION 18,327.0 3,583.41 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature)°F) Weather Wind 0.0 105.0 28.0 Partly Cloudy.WC NNE @ 14 MPH 17- Daily summary operation 24h Summary PJSM W/all essential personnel for POOH W/Bridge Plug.POOH W/5"D.P.&Bridge Plug as per Baker Hughes Rep onsite F/2,445'to surface.HST 76K,SLK 78K.L/D Bridge Plug and running Assy. Calculated displacement 71 bbl,actual displacement 215 bbl.Total Brine lost 45 bbl.Monitor well,static loss 22 bph. R/U&pull Wear Bushing as per Vetco Grey Rep onsite.Cut&slip drilling line, service rig,Drawworks,traveling Equip.&Crown.Inspect Brakes and replace upper IBOP Actuator.Clean and clear rig floor.R/U GBR 4.5"Tubing Equip.PJSM W/all essential personnel for RIH 4.5" Tubing.RIH 4.5"Tubing as per Tally and Well program F/0'to 9,188'MD.Locate liner W/no go sub.HST 128K,SLK 100K.Total Joints in hole 227.Calculated displacement 50 bbl,actual displacement 152 bbl.Total lost for trip 102 bbl.Space out,POOH F/9,188'to 9,094'MD.Calculate space out 15.68'.P/U M/U Pups and RIH 9,159'MD HST 128K,SLK 100K. P/U M/U 4.5"Tubing Hanger as per Vetco Grey Rep onsite.Land Hanger,run in lock downs&test to 5,000 PSI for 10 Min.witnessed by Company Rep onsite Clear rig floor of 4.5"Tubing Equip.as per GBR Rep onsite.R/U to set Packer and testing.Total Brine lost to formation today 434 bbl. Operation at 07.00 High Press.integrity test. 24h Forecast R/U test Equip.Set Packer as per Halliburton Rep onsite.Perform 4.5"and Annulus integrity test as per well program.Shear GLM and set BPV.R/U and L/D 5"D.P.Pull BPV and install TWC valve and N/D BOPE. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.90 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 W.T. K 4 P PJSM W/all essential personnel F/POOH W/Bridge Plug.POOH W/5"D.P.&Bridge Plug as per Baker Hughes Rep onsite F/2,445'to surface.HST 76K,SLK 78K.L/D Bridge Plug and running Assy.Calculated displacement 71 bbl,actual displacement 215 bbl.Total Brine lost 144 bbls for trip out.45 bbl lost this tour.Monitor well,static loss 22 bph. 01 30 02.00 0.50 2.00 W.T. C 19 P PJSA R/U&pull Wear Bushing as per Vetco Grey Rep onsite. 000 05.30 3.50 5.50 W.T. K 20 P " 2. PJSA Cut&slip dnlling line,service rig.Drawworks,traveling Equip.&Crown.Inspect Brakes and replace upper IBOP Actuator. 05.30 06.00 0.50 6.00 W.T. K 20 P PJSA Clean and clear rig floor.R/U GBR 4.5"Tubing Equip. 06.00 12.00 6.00 12.00 W.T. K 4 P PJSM W/all essential personnel for RIH 4.5"Tubing.RIH 4.5"Tubing as per Tally and Well program F/0'to 1,266'MD. Total Joints in hole 30.Calculated displacement 6 bbl,actual displacement 45 bbl.Total lost for trip 39 bbl. 1200 21 00 9.00 21.00 W.T. K 4 P PJSA RIH 4.5"Tubing.RIH 4.5"Tubing as per Tally and Well program F/1,266'to 9,188'MD.Locate liner W/no go sub. HST 128K,SLK 100K.Total Joints in hole 227.Calculated displacement 44 bbl,actual displacement 146 bbl.Total lost for trip 102 bbl. 21 00 2230 1.50 22.50 W.T. K 20 P PJSA Space out,POOH F/9,188'to 9,094'MD.Calculate space out 15.68'.P/U M/U Pups and RIH 9,159'MD HST 128K, SLK 100K. 2230 23.30 1.00 23.50 W.T. K 20 P PJSA P/U M/U 4.5"Tubing Hanger as per Vetco Grey Rep onsite.Land Hanger.run in lock downs&test to 5,000 PSI for 10 Min.witnessed by Company Rep onsite 23.30 00.00 0.50 24.00 W.T. K 20 P PJSA Clear rig floor of 4.5"Tubing Equip.as per GBR Rep onsite.R/U to set Packer and testing.Total Bnne lost to formation today 434 bbl. 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 Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ 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 @doyondntling.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(f1KB) Bottom(ftKB) Run Date LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth)RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Pnmo Faze 9.40 680.0 13.01 2450.7 • I Eni E&P Division I Well Name:SI32-W2 ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUQ • API/UWI:50-629-23483-00-00 2 „I^ Date:5/25/2013 - Report#: 2 II "I page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%( I Well Configuration type 213-013 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 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) S132-W2 COMPLETION 18,327.0 3,583.4 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 101.0 28.0 Partly Cloudy,WC NE @ 9 MPH 20' Daily summary operation 24h Summary R/U to set Packer and perform integrity test.PJSM W/all essential personnel for high Press.testing and setting Packer.Notify all call to keep area clear during testing.Test Tubing line to 5,000 PSI,test IA line to 3,500 PSI.Press.4.5"Tubing to 1,500 PSI for 10 Min.to close Autofill valve.increase 4.5"Tubing to 3,500 PSI with Packer set between 2,200 to 2,500 PSI and hold for 30 Min.(8 Strokes) Reduce 4.5"Tubing Press.to 2,000 PSI and Press.IA to 2,500 PSI and hold for 30 Min.(71 Strokes)Bleed IA to zero PSI and increase 4.5"Tubing F/2,000 PSI to 4,610 PSI when Mirage Plug sheared. (51 Strokes)Press.IA to 1,850 PSI when GLM IA to Tubing sheared.All testing was charted.All operations witnessed by Company Rep.R/D testing Equip.&L/D Landing Jnt.Set BPV as per Vetco Grey Rep onsite.Prep for UD 5"D.P.Service Drawworks,traveling Equip.&Top Drive.L/D 5"D.P.using mouse hole,total joints laid down 270.Transfer 13 stands of 5"D.P.F/OOS Derrick to DS Derrick SIMOPS Clean Pits. UD Mouse Hole,clear rig floor. Clean Drip Pan,N/D BOPE,N/D high Press.drilling riser.N/U Tree as per Vetco Grey Rep onsite.Test Hanger void to 5,000 PSI for 10 Min.Pull BPV,set TWC.R/U to test Tree,fill Tree WI Diesel.SIMOPS Clean Rock Washer Pits.Test Tree to 500 PSI low for 5 Min.5,000 PSI high for 15 Min.charted.(Good)Witnessed by Company Rep onsite. Rig down test Equip.&blow down lines.SIMOPS Prep MP#3 for rig move.TWC as per Vetco Grey Rep onsite.Spot Halliburton Wireline unit. R/U Wireline BOPE,R/U Lubricator,P/U M/U tool string and sheaves.M/U Wireline Head to Lubricator. Operation at 07.00 Wireline work. 24h Forecast RIH WI Wireline Catcher and set,pull Shear Valve,RIH W/new Shear Valve and Freeze Protect well/Set new Shear Valve and pull Catcher.Move Rig. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.95 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. _ Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 W.T. K 20 P PJSA R/U to set Packer and perform integrity test. 01,00 04:30 3.50 4.50 W.T. P 12 P PJSM W/all essential personnel for high Press.testing and setting Packer.Notify all call to keep area clear during testing. , Test Tubing line to 5,000 PSI,test IA line to 3,500 PSI.Press.4.5"Tubing to 1,500 PSI for 10 Min.to close Autofill valve. increase 4.5"Tubing to 3,500 PSI with Packer set between 2,200 to 2,500 PSI and hold for 30 Min.(8 Strokes)Reduce 4.5" Tubing Press.to 2,000 PSI and Press.IA to 2,500 PSI and hold for 30 Min.(71 Strokes)Bleed IA to zero PSI and increase 4.5"Tubing Fl 2,000 PSI to 4,610 PSI when Mirage Plug sheared.(51 Strokes)Press.IA to 1,850 PSI when GLM IA to Tubing sheared.All testing was charted.All operations witnessed by Company Rep. V 04:30 06:00 1.50 6.00 W.T. K 20 P PJSA R/D testing Equip.&UD Landing Jnt.Set BPV as per Vetco Grey Rep onsite.Prep for L/D 5"D.P. 06:00 06:30 0.50 6.50 W.T. K 20 P PJSA Service Drawworks,traveling Equip.&Top Drive. 06:30 12:00 5.50 12.00 W.T. K 4 P PJSA UD 5"D.P.using mouse hole,total joints laid down 177. 12:00 14:30 2.50 14.50 W.T. K 4 P PJSA UD 5"D.P.using mouse hole,total joints laid down 270.Transfer 13 stands of 5"D.P.F/ODS Derrick to DS Derrick SIMOPS Clean Pits. 14:30 15:00 0.50 15.00 W.T. K 4 P PJSA UD Mouse Hole.dear rig floor.SIMOPS Clean Pits&work on cement line inner conned. 15:00 18:00 3.00 18.00 W.T. C 20 P PJSA Clean Drip Pan,N/D BOPE,N/D high Press.drilling riser.SIMOPS Clean Pits and inspect moving system. 18:00 19:30 1.50 19.50 W.T. C '20 P PJSA N/U Tree as per Vetco Grey Rep onsite.Test Hanger void to 5,000 PSI for 10 Min.Pull BPV,set TWC.SIMOPS Clean Pits&prep MP#3 for rig move. 19:30 20:00 0.50 20.00 W.T. C 20 P PJSA R/U to test Tree,fill Tree WI Diesel.SIMOPS Clean Rock Washer Pits. 20:00 21:30 1.50 21.50 W.T. C 12 P PJSA Test Tree to 500 PSI low for 5 Min.5,000 PSI high for 15 Min.charted.(Good)Witnessed by Company Rep onsite. Rig down test Equip.&blow down lines.SIMOPS Prep MP#3 for rig move. 21:30 22:00 0.50 22.00 W.T. C '20 P PJSA Pull TWC as per Vetco Grey Rep onsite.Spot Halliburton Wireline unit. 22:00 00:00 2.00 24.00 W.T. K 20 P PJSA R/U Wireline BOPE,R/U Lubricator,P/U M/U tool string and sheaves.M/U Wireline Head to Lubricator. 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 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 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 LINER 5 3.960 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.40 680.0 13.01 2,450.7 • Eni E&P Division wzgazwit 11191* ENI Petroleum Co.Inc. Daily Report Well Code:27080 Field Name:NIKAITCHUO • API/UW1:50-629-23483-00-00 en2�,,t Date:5/26/2013 - Report#: 3 II page 1 of 1 Wellbore name: SI32-W2 Well Header Permit/Concession N° Operator ENI Share(%) 1Well Configuration type 213-013 ENI PETROLEUM 100.001 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 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) SI32-W2 COMPLETION 18,327.0 3.583.4 _ 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..-Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) PO8 Temperature(°F) Weather d 0.0 101.0 32.0 Partly Cloudy.WC 1Win.NE @ 13 MPH 22' Daily summary operation 24h Summary PJSA.Continue to R/U for slickline ops as per Halliburton Rep onsite.R/U LRS with proper permitting.PJSA w/all essential personnel.Press test lubricator to 3,000 psi.RIH w/run#1 catcher basket (successful).Set basket @2,340'MD.RIH with run#2 kick over tool to retrieve valve(successful).RIH w/run#3 kick over tool w/replacement valve.Set and press.test to 6,000 psi for 5 min(successful). Operation at 07.00 Move Doyon 15 to well SI19-FN2. FINAL COMPLETION REPORT. 24h Forecast Move Doyon 15 to well SI19-FN2. Lithology 'Shows MAASP Pressure(psi)1 Mud Weight(lb/gal) 8.95 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 W.T. K 12 P PJSA.R/U slickline ops as per Halliburton Rep onsite.R/U LRS%nth proper permitting. 01:30 06:00 4.50 6.00 W.T. K 12 P PJSA w/all essential personnel.Press test lubricator to 3,000 psi.RIH w/run#1 catcher basket(successful).Set basket @2,340'MD.RIH with run#2 kick over tool to retrieve valve(successful).RIH w/run#3 kick over tool wlreplacement valve.Set and press.test to 6,000 psi for 5 min(successful). Daily Contacts Position Contact Name Company 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 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @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 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) I Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 3.9601 0.0 18,327.0 5/17/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 9,427.0 3,626.24 Primo Faze 9.401 680.0 13.01 2,450.7 • 0. 00,-,-W 0000(0 vOMMM 0M.-v0 0 4 v,v0M 040030 (00000 (60(0(0 a 2 00,7..92p L. 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O.- 0 M 0 0 M 0 N N r 1)400)00 0 V n M O n 0..V M 0 0 V 0 n O V N O r O o n M 0 M 0 0 N V O V O O r 0 0 0 M O M N V 0 `0(0 0(0 0 MMMM 0 0(N. 00 006 rAt6 V M,,r 6000 N 0n 0 600,6 036 r rr 00000 00000 03 O3 03 03 CO CO 000 CO 00000 00000 0u,000 00000 00000 tiltilit MMMMM MMMMM LO MMMMM MMMM MMMMM MM(°° MM°Mc° QQQQQ W m Q E , .....00 00 00 00 00 0 0 _,N 0 r 0 V r.-0 r n 0 n 0 n 0 0 0 0 0 0 0,-0 a M 0 0 0 0 O N.-V 0 M N 0.-0 7 q 0 0 0( V O r M 7 0 n d'- M M O I 0 6n 0 00 .-0 0 0 O N O r V r 0 0 N 0 0 L• LWg 60 .MMMM NNNN 206p 2 OO«g R0<0V N W g .222 0000 .-000 220 0 0 22222 M M M M M M M M N. M M M M M M M M M M ...mm ..... M M M M M N m 2 N 2 0 W m° 0 d d 0 0 r d 0 0•- o o 0 M M 0 0 d d o 0 0 0 0 0 pp 00 M 0 0 QQ pp MCp{p 00N.4-,( o O 0000. j M 2 d O 6 N l0 0 d d O V 0 0 0 0 0 V O 3 N 0 0 r M O.-O O CO O 3 O 0 1 h O N N O 0 0 0 0 0 3 U r- m N r r 0 Z W W f 66466 666r6 r6MniN m-MNMM McNrr 0010-160 rnl6rnr 6 66666 0 000 E CO M M CO CO M M CO CO CO M CO CO M CO M M M M M M M M M M M MMMM MMMM CO M CO M M0y 0 NCO M M 0OO F z z N O CO n0101 00_0 i 00j N 1-1- A u_ 0.00 •Y° O 0 N 0 V or-N 0 0 C000, co,0 0 M 0 d 0 M 0 O n r 0 M 0 0 00,0 0 n 004.,, • E 0 0 0 0 0 n LL LL C O. M0O N70101 N 0000,0 MO00N 0.-00 0 ONO.-0 0 V,r, 00N00 O O 00000 000 0 0 0 0 0 0 0 0 003 66666 060 6 6 6 6 0 0 6 6 6 60666 0 0 0 0 0 0 LL 06660 0 J.-N LO m m O 0 O 66666 0 0 0 0 0 06066 0 0 0 0 0 W 0 Q 0 O N W M LL.. CO 0 LL LL U von C V,-N 0 m.- M mo O .-0 N N ) rO r NO.-W. r-.V , 0m V r 8615:J J Lom.- MCO LO ,- 0 COOM 00 M M 6 0 6 -0 0,6 6, O 0, d 0 N d 0 -r O 0,pp 0,6 0, 66,66 ,3 O 0,I O 0,0 N p .C W U m 0000 r r 000 d MMN.- �00,mm r r CO n n V MM N, 0000 -0,000 'C. 0 0(DO.- N M 00 r 000, N CO CO Vp 0 <O r COMO N M V 0 CON-F.-COO, O.-0101 Cry m W VV..000 LOCO... ...COW 00000000 c0 CO CO CO P.- N n n n r n n n n n 00000 Q0. O 0 W 0 O 0 0 J 9 fm` u N 2 a m U O O C c . m T 0 C C m m o U N N 0 am''> `,{,' ,f L_ @H%e �`sY.Sk 1 3 AY 0 9.013 Schiumberger k } A c Drilling&Measurements MWD/LWD Log Product Delivery 2_2_,G 7G, Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No S132-W2 Date Dispatched: 28-May-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs S132-W2 Log 1 2 in MD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 Received By: 4e--40‘Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto(a�slb.com Hector Echeto Fax:907-561-8317 Transmittal#:6381 --z,` RECEIVED i ' "` MAY 21 2013 1 Aeeec-7-7„ lost En PetlroIIeiuilrn HALLIBURTON ' n II■ Sperry Drilling PACKING LIST Spy Island Drillsite SI32-W2 Shipping Date: 18-May-2013 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 301 East 92nd Avenue;Suite 2 Anchorage,AK 99501 Anchorage,AK 99515 Attn: Howard Oakland 907-739-1235 Stem Description Interval Packaging Box Description°' SI32-W2 Washed and Dried Samples-50' 2,800'to 5,050' Paper envelopes Box 1 of 7 Washed and Dried Samples-50' 5,050'to 7,100' Paper envelopes Box 2 of 7 Washed and Dried Samples-50' 7,100'to 9,200' Paper envelopes Box 3 of 7 Washed and Dried Samples-50' 9,200'to 11,600' Paper envelopes Box 4 of 7 Washed and Dried Samples-50' 11,600'to 13,850' Paper envelopes Box 5 of 7 Washed and Dried Samples-50' 13,850'to 16,150' Paper envelopes Box 6 of 7 Washed and Dried Samples-50' 16,150'to 18,350'TD Paper envelopes Box 7 of 7 41 J CI One(1)Bundle Contains all Seven(7)Boxes of Dried Samples Notes: Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Andrew Buchanan 907-865-3388 Received by Expediter: '24---(2_____Cj) Date: r.3 1 M U—tl3 d-1 — 3► 3 � s THE STATE '' of 771,\ Alaska Oil and Gas °fKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O� *hgP Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 James Wright Drilling and Completion Engineering Manager 1 Eni US Operating Co. Inc. a 13- © F 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI32-W2 Sundry Number: 313-119 Dear Mr. Wright: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7°4C,--) Cathy . Foerster Chair DATED this I 2 day of March, 2013. Encl. sS RECEIVED 5'0e MAR 082013 STATE OF ALASKA P75 VII 1(3 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown 0. Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co. Inc. Development ❑ Exploratory ❑ 213-013 3.Address: ra 6.API Number: Strati graphic ❑ Service , g p 3800 Centerpoint Drive Suite 300 Anchorage,AK 99503 50-629-23483-00-00- 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No S132-W2- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0391283,0388574 • Nikaitchuq 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): • 2761 2424 2761 2424 Casing Length Size MD TVD Burst Collapse Structural Conductor 120 20 160 160 4980 3240 Surface 2729 13.375 2761 2424 5020 2260 Intermediate Production • Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal 0, 13.Well Class after proposed work: Detailed Operations Program El• BOP Sketch ❑ Exploratory ❑ Development ❑ Service El • /43 14.Estimated Date for 3/12/2013 15.Well Status after proposed work: 14 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: WINJ Q/ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: T 1•l .l'S GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Luca Born 907-865-3328 Printed Name Ja right Title Drilling and Completion Engineering Manager Signature Phone 907-865-3321 Date 3/7/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 'd( 1. 9 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: F h ri:1 k�r& •: ❑ YES a7,0, RBDMS MAR 14 20; 4 k f c t �ov rS a � Subsequent Form Required: /6 O t �!Jf V j if to APPROVED BY N Approved by: ✓�--__COMMISSIONER THE COMMISSION Date: 3 J (3 AI ;�? 1 f3 RECEIVED vIAR 0'8 2013 AOGCC • Enil 0 Lr eni Pet�rolleum 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907)865-3321 Email: James.Wright @enipetroleum.com March 7,2013 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approvals 10-403 for Nikaitchuq Injector SI32-W2. PTD#: 213-013 API#: 50-629-234837-00-00 Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Sundry Approval 10-403 for the offshore injector well SI32-W2. The well will be tem porar l ..�.andtined usi g Doyon 15. The planned date of operations is 3/12/2013. Due to a tubing leak on the Nikaitchuq disposal well SD37-DSP1,Eni is asking for approval to temporarily abandon SI32-W2. Currently the 16" surface hole is being drilled. 13-3/8" Casing will then be run and cemented to surface. The well will then be displaced to oil base mud,to effectively freeze protect the well. A kill string consisting of 5" 19.5#TT525 drill pipe will be run to—2579' MD(50' above float collar). A full opening TIW valve and Gray Valve will be set above the 5"DP along with a crossover to 4-1/2" IBT- M and finally to the tubing hanger. A back pressure valve (BPV)will be set in the tubing hanger and well will be secured. Please find attached for the review of the Commission forms 10-403 If you have any questions or require further information,please contact Luca Borri at 907-865-3328 Sincerely, 0„ , es Wright Drilling&Completion Engineering Manager Eni tr. - urn Application for Permit to Drill Saved:7-Mar-13 Application for Sundry Approval — 10-403 Table of Contents 1. Well Name 2 2. Proposed Drilling Program 2 3. Attachments 3 1. Approved Application for Permit to Drill 3 2. Temporary Shutdown Schematic 3 3. Schlumberger Surface Cement Plan 3 AOGCC PERMIT Document.doc Page 1 of 3 Printed:7-Mar-13 Eno• ' tIr leum . .4 Application for Permit to Drill Saved:7-Mar-13 1. Well Name Well Name: SI32-W2 2. Proposed Drilling Program Current Operations Summary: Currently the 16"surface hole is planned to be drilled to the estimated total depth of 2761'MD/ 2424' TVD. Estimated date of start of temporary shutdown of operations is 03/12/13. 1. Directionally Drill to estimated TD of 2761' MD/ 2424'TVD 2. Circulate hole clean and back ream out of hole. 3. Rig up casing equipment and run 13-3/8"68# L80 BTC Casing to —2711'MD/ 2392'TVD. 4. Break circulation and prep for cement job. 5. Rig up cementing equipment and cement 13-3/8"casing to surface as per submitted cement plan -- (PTD#: 213-013). 6. Install Vetco-Gray well head and Rig up BOP's. BOP's will be used effectively as a riser to take returns from drill pipe displacement while running in the hole and later for returns while displacing well to OBM. The BOP's will not be functioned and therefore not tested. 7. Run in hole with 5" 19.5#17525 drill pipe to —2579' MD (50'above float collar). 8. Perform 13 3/8"casing test to 2500 psi for 30 min. 9. Displace/ Freeze protect well with Oil base mud. • 10. Install full opening 11W valve, Gray valve, 4-1/2"IBTM x TT525 crossover, and tubing hanger. 11. Land tubing hanger in wellhead and set back pressure valve (BPV). 12. Rig down BOP's and secure well. 13. Rig down move off SI32-W2. AOGCC PERMIT Document.doc Page 2 of 3 Printed:7-Mar-13 ,. - _ lima " tale Application for Permit to Drill Saved:7-Mar-13 3. Attachments 1. Approved Application for Permit to Drill 2. Temporary Shutdown Schematic 3. Schlumberger Surface Cement Plan AOGCC PERMIT Document.doc Page 3 of 3 Printed:7-Mar-13 g�\I yy 8 THE STATE Alaska Oil and Gas LASS Commission Conservation GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4' ASI°' Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 James Wright Drilling&Completion Superintendent ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage,AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI32-W2 ENI US Operating Co. Inc. Permit No: 213-013 Surface Location:4433' FSL, 1468' FEL, SEC. 19,T14N,R9E,UM Bottomhole Location: 2314' FSL, 3558' FEL, SEC. 14, T14N, R8E,UM Dear Mr. Wright: 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, 1.°7 & Cathy P oerster y Chair DATED this S 1 day of February, 2013. cc: Department of Fish& Game, Habitat Section w/o encl.(via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: 1b Proposed Well Class: Development-Oil U Service- Winj U Single Zone el lc.Specify if well is proposed for: Drill El Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coelbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Ei Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 SI32-W2 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpolnl Drive Suite 300.Anchorage 99503 MD: 18327 TVD: 3583 Nikaitchuq!Schrader Bluff 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4433 FSL,1468 FEL,S19 T14N R9E UM ADL 0391283.0388574 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1609 FSL,2237 FEL,S24 T14N R8E UM. ADL 417493 2/23/2013 Total Depth: 9.Acres in Property: + oi5 14.Distance to Nearest Property: 2314 FSL,3558 FEL,S14 T14N R8E UM 1'280"gt0e) li3l" 9200'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- 511442 y- 6053613 Zone- 4 GL Elevation above MSL. 13.1 feet to Same Pool: 1000'to SP33-W3 16.Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.42 degrees Downhole: 1624 psig Surface: 1230 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 1272 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2726 35 35 2761 2424 LEAD:1064 sx 10.7 ppg ASL _ TAIL:208 sx 12.5 ppg DeepCrete 702 TOTAL sx 12.25" 9-5/8" 40 L-80 Hydril 563 9344 33 33 9377 3629 702 sx 12.5 ppg DeepCrete 8-3/4" _ 4-1/2" _ 11.6 L-80 Hydril 521 9150 9177 3616 18327 3583 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(fl): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface REIC�1 lit Intermediate Production JAN 3 1 ?013 Liner Perforation Depth MD(ft). Perforation Depth ND(ft): A JGCC 20. Attachments: Property Plat El BOP Sketch s Drilling Program Q Time v.Depth Plot U Shallow Hazard Analysis pi Diverter Sketch 7 Seabed Report U Drilling Fluid Program IS 20 AAC 25.050 requirements Fl 21. Verbal Approval: Commission Representative: Date 1/30/2013 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni 907-865-3328 Email luca.borri@erbetroleum.com Printed Name James Wright Title Drilling&Completion Superintendent Signature 40 - Phone Phone (907)865-3320 Date 1/30/2013 Commission Use Only Permit to Drill API Number: Permit Approval i#r 1 1. See cover letter for other Number: p(/ 3 • 3 50- (o a9- 23'1f$ -OO- 00 Dale. L requirements. Conditions of approval: �w Iff box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Q Other: 'F 356°PS` DVP f:-Sfi ����0 3G Samples req'd: Yes❑ No2 Mud log req'd: Yes ❑ No Q y. (�(({ry ..t_ v,�' ;a'< <h .4......-,12 HZS measures: Yes❑ No Directional svy req'd: Yes 2 No❑ A �4� p �` C G.i"'� Spacing exception req'd: Yes❑ No[ Inclination-only svy req'd:Yes❑ Not .�o.►J' �, zo/A/1-G Zs•4t .Lb} i M f r s ca.- 'tea. , APPROVED BY Approved by 4-- COMMISSIONER THE COMMISSION Date:2-5 / 3 D ( I .t l /mil' /�. Submit Form and F t( ed 0 )F This permit is valid for 24 months from the date of approval(20 AAC 25.005(8)) gttachments In Duplicate RECEIVED JAN 3 12013 • Enli (. tir4eurn AOGCO ens 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907)865-3321 Email: james.wright @enipetroleum.com January 30,2013 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI32-W2 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the Offshore Injector well SI32-W2.This well will be drilled and completed using Doyon 15. In order to expand the current Nikaitchuq project to include the N Sand,Eni's sanctioning protocols require the acquisition of a "live" fluid sample from the formation. The N sand is a highly unconsolidated formation that has proven extremely difficult to gather a fluid sample utilizing standard MDT techniques. It is for these reasons that the procedure described in the permit to drill will be utilized to acquire a fluid sample and pressures in cased hole. This procedure is seen as having the highest probability of success for acquiring a live oil sample.Attached also the completion schematic. The planned spud date could be as early as 2/23/2013. 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, Iii a� 2 7V 6 4 J: right - ing&Completion Superintendent II' Spy Island Nikaitchuq Field o 2rn1n peVoOeum S132-W2 Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface Gray 20" 0 0 ° TIW X-65 N/A Welded/Driven 20"Conductor Shoe 160' 160' N/A GR/Res o Surface Csq :I 0 tC Dir y 13-3/8" Base Permafrost 2.000' 1.858' N 68 lbs/ft MW(ppg) Wellbore Stability o 9.2-9.5 Lost Circulation O Mud Motor m L-80,BTC Hole Cleaning O r C ¢1 lV A A fD y PIJ Top of Tail 2.307' 2,105' 01 -o Dn CD CD C) 5"DP Kill String 2,579' 51 Deg 13-3/8"Casing Point 2,761' 2,424' 16" 50°F WBM CemCAD L. well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : SI-32-W2 Country : USA Field State : Alaska Prepared for : Mr.Luca Berri Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 12/18/2012 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (907)273-1765 E-Mail Address : slauper @slb.com • 4 c 4VAT E .• " Disclaimer Notice: Schlumberger submits-his document with the benefit s'hs judgment.experience.and good oilf ield practices This information is provided in accordance w th genera'l 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 p,ovidec Information All proposals.recommendat ons.or predictions are opinions only NO WARRANTY IS GMFN CON:FRNING ACCURACY OR COMPtFTFNFSS OF DATA,INFORMATION FRFSFNTFD,EFFFCTNFNESS OF MATFRIA:.PRODUCTS OR SUPPI IFS RFCOMMFNDATIONS MADE.OR RFSUI TS OF THE SFRVICFS RFNOFRFO Freedom from infringement nt any intellectual properly rights of Schlumberger or others is not to be inferred and no intellectual prope'ty rights are granted hereby • Mark of Schlumberger Page 1 S132-W2 ml.cfw;12-182012;Version wcs-cetr472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2761.0 ft BHST : 40 degF Bit Size : 16 in ft (x 1000) psi t 1 - - l > , 0 1 2 SV-4 Frac I Fore SV-4 - SV-3 • SV-2 6? Permafrost • • • 1 Ugnu Top (UG-1; ti • j TD 1 0 1 - Well Lithology Formation Press Page 2 SI32-W2 vl.cfw;12-18-2012:Version wcs-cern472_05 Client : Eni Petroleum Well : SI-32-W2 Stingier String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2681.0 ft Casing/liner Shoe MD : 2761.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2761.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 144.7 % Mean OH Equivalent Diameter: 19.171 in Total OH Volume : 928.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 2000.0 16.000 190.0 20.063 2761.0 16.000 35.0 16.822 Max. Deviation Angle : 51 deg Max. DLS : 3.666 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 160.0 11.70 8.40 SV-4 Siltstone 773.0 11.50 8.40 SV-4 Siltstone 1141.0 11.50 8.40 SV-3 Sandstone 1430.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2084.0 12.00 8.40 SV-1 Sandstone 2488.0 12.50 8.40 Ugnu Top(UG4) Shale 2761.0 12.50 8.40 TD Shale Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1858.4 32 0.6 3766.0 3057.2 50 1.0 Page 3 SI32-W2 vt-cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 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 lbf.sAn/ft2 n : 0.262 Ty:0.48 Ibf/100ft2 Displacement Volume 401.4 bbl Total Volume 1014.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Surface Lead Slurry 450.0 2256.4 10.70 k:2.08E-1 Ibf.s^n/ft2 n:0.187 Ty:16.36 Ibf/100ft2 12.5ppg DeepCRETE 63.0 504.6 2256.4 12.50 k:1.68E-1 Ibf.s^n/ft2 n:0.301 Ty:0.44 Ibf/100ft2 Surface Tail Mud 401.4 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48Ibf/100ft2 Static Security Checks: Frac 8 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2009 psi at 2681.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 177 psi ft (x 1000) psi < 0 J ,-Hydrostatic -Frac -Pore - � o_ c. 1 i---- ti Q iG- F i 1 __-__ o 1.I 0 0 - c,- Fluid Sequence Static Well Security Page 4 SI32-W2 vt.cfw;12-18-2012:Version wcs-cen412 05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 3: pumping schedule - Spacer/Cement Max Rate is 8-BPM - (No significant amount of time to be spent outside of+/- O.2ppg Density Range) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 8-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Maintain returns during cement job if possible - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from highlighted Rates in Job Report 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(2-8 BPM) 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 5.0 450.0 90.0 450.0 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 03:08 1014.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 1 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2008 psi at 2681.0 ft Burst 4719 psi at 0.0 ft Temperature Results BHCT 60 degF Simulated Max HCT 71 degF Simulated BHCT 70 degF Max HCT Depth 2761.0 ft CT at TOC 61 degF Max HCT Time 02:50:45 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 60 degF 20 degF Bottom Hole (degF) 70 degF 40 degF Page 5 5132-W2 v1 ctw:12-18-2012:Version wcs-cem472 05 Client : Eni Petroleum Well : SI-32-W2 String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl;2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time <30 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Top Plug is not Bumped at calculated Volume a) Pump%shoe track volume MAX b) If Bump not seen,shut in and hold pressure 4) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time<10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume =volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Page 6 SI32-W2 vl.cfw:12-181012,Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated ECDs at Surface Shoe 0 DDepth= 2761 ft vi --- Frac ■ Fbre -I 1 } -s }-} - j i in - F-tvdrostatic _. _.. ref_.. — Dynamic 1- ='sE�� =-= ; iiiiiii■11iiii ' A I INIM=z MU 1 ::�=:�'s=:='c=S: aE I IN --- �. ►ENINIMIN �� . ........ . .� . .. .... .....- }— ___ _ ...� ... �i w o 11111•111111111111M11111•11111111111= CC= r .....r=�r:/Ii..QiliilG i1 11 0 _ -a ..-� :., . I =:a.�ivy...IN 1.111111••■• ...ip- . c o �./ "ii MI . �.� .: in .� ..i...+.�........ rn ................ ii=ii_��:as_:__w=_=_=.... CD._ - • MI_ + �����/I•....r...... II-. a) . ..r................. --f -}- ........... ....... coo._ t. 0 06-1 r 1 I 1 r— I 1 , , 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 7 SI32-W2 vl.cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Seim huger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated ECDs at Conductor Shoe o Depth= 160 ft (Ni — Frac Ire ..._ Hydrostatic ' ' i ' • Dynamic IIMIMUMMO 111 , _ x N. ■...C. i■� II � ,.111111111111 11111111 F-- 111111 ■.. �M..M. .■ sm■. O ..M. _ 111'1111'11 :1=m1=111 1s1 .- 11°- ....i.. ..l...■. �_■�... .■... ■._.....■..... .1mm.:mm:...... ■. ■■■■■■..■■.M■ N a) mm :m:m:mmmmmmsm-::mmmmmma::=- a �� 2 M I C°_ mil • • 'C . ■.■■■..■■..■■.■■■..■■.■_■ ... • sm=mm::m:mm::mm m:mm umm:m _ IIIMMMOMBOIMMMEMMOIMMOMMMOMMM MM. 0 ■■M■■..■■M - ■■•i■.■..■■..• i ■■■ 06- . ■__ _. _. ._■ _ 111 _ 111111111111 ... _ ___ ._ ... ___. . - . . _ _ __t_!__i co Tr 0 441liiiilillllj4Illiii ? liili iii c , , , , , , , , I , 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 8 SI32-W2 vl.cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase Simulated Surface Pressures O O - Cale.Cerrtl-IP Calc.Pump Press. 1_ 111111111111 1111 1 1111111111111 1111 EAI 1 111111111 I 1 1 111 1 o_ 11 1111 11 EMI 1 . N nooll111111111111111 11111 4 a ; PHrT 1 11111111 .111!H1 , 1 IF M _ . 1. 1 O I I I1 11 4 _ 11111111111 111111 I . _ 00— ! - 111 1111 111111 - ■ 111 III 111111 . _ 1 . _ .I_ 111 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 SI32-W2 v1 cfw:12-18-2012•Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 S hlumherger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Slurry Temperatures during placement _o — Last Sack Temp. • First S- k Temp. Ln ARB _. _N co 1 O o _____. _rA O In _. .. e_..._. _ O . ..___ O _ —O N , 1— Pi, . 11111 Lk ____ , — — _N°O NCO .—= (.O_ 0 03 O I 00 N CI . 0 30 60 90 120 150 180 210 Time(min) Page 10 S132-W2 vl.cfw;12-18-2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Slurry Temperatures up to 24hrs after Placement 'n - _o oo — Last Sack Terrp. .4 - First Sack Temp. - N Mir o- API BHCT _�.�.1•��_�. ..s..� s .s ' o ssssss s.......sss.ss s. -0 s....s....�s....s...�.ss.ss.. 0 g-2-. AIMMOMMOIMMEMMEMMOMIUMMEMOMOM - Lo ssssssssssssssssssssssssss: ...1...�.�..NI♦......�._!♦...._.. O o_ � m ... �...... ..�.M�.�.� _o r ..r i�'r�..�..r...r..IM.r..�.. IL ..s.MN..∎-"∎1111_...._..____.1�._ rn ../..___..._���......�... �.. Ln o ...... ..._..i1i��/.-�. ..-.. _N 0 LO ...___ss.___._....��ON_s.._... o ..._L......_.._....._0.�=�_.__.. x •a�coo_ ,_ gym .�_� m. ammonium MINIMUM k 0 0- CO cn_ .__ - ■ ..LM __ ...___..__ __o IIIMMINN I le s ssssssss::Emslm.111ssssssn _N o_ _. r.......�...Z\....�....�a. I�1 El � s ss ....� ILIs.s_s- __-i- 0' s - ..� .......�. �.� N In ....MO.. _...._...._...._.._��r .......sM....M......_..M.r..M.��2 _ . .... .................. .. .. t`i L, 0 0 O I I I I I I 1 I M 0 250 500 750 1000 1250 1500 1750 Time (min) Page 11 SI32-W2 vl.cfw;12-1&2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 SiIimierier String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 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 Ibf/100ft2 MUD Mud Type :WBM Job volume :401.4 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 lbf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl 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 Ibf/100ft2 DESIGN BLEND SLURRY Name :ASL(0.79) Mix Fluid : 11.075 gal/sk Job volume :450.0 bbl Dry Density : 108.69 lb/ft3 Yield :2.40 ft3/sk Quantity : 1052.50 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 Page 12 S132-W2 v1.cfw;12-18-2012;Version wcs-cem412_05 Client : Eni Petroleum Well : SI-32-W2 ScI �rg�r String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 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 :0.44lbf/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 Ib/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 Page 13 S132-W2 vl.cfw;12-19-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2741.0 ft Casing Shoe :2761.0 ft NB of Cent. Used :25 NB of Floating Cent. :16 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2121.0 17 1/3 NW-ST-13 3/8-8-ST A3B W131 0.0 2068.8 2761.0 8 1/2 NW-ST-13 3/8-8-ST A3B W131 33.3 2701.0 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 ft % 0 20 0 60 80 100 .Erse :s-I l I 11 I +. -AI •:B't •'r"—i- +' i I ++ a. ++ 1 - 4 + _— O i . O r'1 Pipe Standoff Page 14 S132-W2 vl.clw:12-18-2012:Version wcs-cem472_05 ,..1 Client : Eni Petroleum Well : SI-32-W2 Srihmlerger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 6: WELLCLEAN II Simulator ft % % 0 25 50 75 100 0 20 40 60 80 100 o- L. I — d 1 Std Betw.Cent. Z -Mud Contamination -Cement Coverage - Uncontaminated Slurry c -■ --. ---"-- I o r o o- S- N /1 1 t+a Cement Coverage Uncontaminated Slurry ila Ca,a«.,, z 3 3 z,.., 500 500 500 500 1000- 1000 „ 1000- 1000 .c "...o II. 1500 1500 a a 1500 1500 a iu d a) m o 0 0 _ 0 2000 2000 2000 e. 2000 2500 • 2500 2500 S 2500 a) 3 a) a) 3 a) 0 o -o -o o v 3 3 3 t 3 0 0 z z ■ `sw DeetTETE 5vlce it •MUDr151115' .Ion ■Nme Page 15 SI32-W2 vl.cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 ScIinkerger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 7: operator summary MIXING PREPARATION MUDPUSH 11 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:450.0 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 ASL(0.79) 105249.492 Fresh water 277.530 bbl 10.001 bbl lb 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 16 S132-W2 vl.cfw:12-1 8-2012:Version wcs-cem472_05 Bettis, Patricia K (DOA) From: Born Luca [Luca.Borri @enipetroleum.com] Sent: Monday, March 11, 2013 10:51 AM To: Bettis, Patricia K(DOA) Subject: RE: Sundry Application: SI32-W2 Hi The date of resume for the drilling operations will be March 26th 2013.We need to send you something before the restart of the operations? Regards L.Borri From: Bettis, Patricia K (DOA) [mailto:patricia.bettis @alaska.gov] Sent: Monday, March 11, 2013 10:41 AM To: Borri Luca Subject: Sundry Application: SI32-W2 Good morning Luca, Per our telephone conversation this morning, ENI applied for a sundry approval for temporary operations shutdown for the SI32-W2 well. Under 20 AAC 25.072(a), a request for operation shutdown must include the approximate date when drilling or completions operations will resume. Thank you for your help in this matter. Have a wonderful day, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1 i) rrOF IW.it THE STATE Alaska Oil and Gas Conservation ofALAs Commission GOVERNOR SEAN PARNELL �� � 333 West Seventh Avenue ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1 433 Fax: 907.276.7542 James Wright Drilling& Completion Superintendent ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, 5132-W2 ENI US Operating Co. Inc. Permit No: 213-013 Surface Location: 4433' FSL, 1468' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 2314' FSL, 3558' FEL, SEC. 14, T14N, R8E, UM Dear Mr. Wright: 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 et-ay of February, 2013. cc: Department of Fish& Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALA, OIL AND GAS CONSERVATION COMMIE .J PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: 1 b.Proposed Well Class: Development-Oil U Service- Winj U• Single Zone 0 • lc.Specify if well is proposed for: Drill El• 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 p Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627' S132-W2 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 18327' TVD: 3583 • Nikaitchuq/Schrader Bluff' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4433 FSL,1468 FEL,S19 T14N R9E UM • ADL 0391283,0388574 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1609 FSL,2237 FEL,S24 T14N R8E UM.• ADL 417493 2/23/2013" Total Depth: 9.Acres in Property: pµa •14.Distance to Nearest Property: 2314 FSL,3558 FEL,S14 T14N R8E UM • 4280-- 5-kio NZ-45 9200'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- 511442 y- 6053613 Zone- 4• GL Elevation above MSL: •13.1 feet to Same Pool: 1000'to SP33-W3. 16.Deviated wells: Kickoff depth: 200 feet• 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.42 degrees . Downhole: 1624 psig • Surface: 1230 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 1272 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2726 35 35 2761 2424 LEAD:1064 sx 10.7 ppg ASL TAIL:208 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 9344 33 33 9377 3629 702 TOTAL sx 702 sx 12.5 ppg DeepCrete 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 9150 9177 3616 18327 3583 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface RECEIVED Intermediate Production JAN 3 1 2013 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): A®GCC 20. Attachments: Property Plat Q . BOP Sketch .i • Drilling Program .i • Time v.Depth Plot _ Shallow Hazard Analysis 4 Diverter Sketch 7 ` Seabed Report _ Drilling Fluid Program 7 • 20 AAC 25.050 requirements •! 21. Verbal Approval: Commission Representative: Date 1/30/2013 22. I hereby certify that the foregoing is true and correct. Contact Luca Borri 907-865-3328 Email luca.borri @enipetroleum.com Printed Name James Wright Title Drilling&Completion Superintendent Signature Phone (907)865-3320 Date 1/30/2013 Commission Use Only Permit to Drill API Number: Permit Approv See cover letter for other Number: a/3 Q/ 50- ,Q9-23 y e3-00-0c) Date: '� I (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: ❑ Other: if" 3500 00 psi, Y,p /L n Samples req'd: Yes❑ NoEj Mud log req'd: Yes ❑ No Q If (�(4- of. c- pb.e.r i A- �. G.ccca -.Y W(14t!0 3 Co H2S measures: Yes❑ No[rj Directional svy req'd: Yes [r No❑ AL/x,� re p/ -y..�.,., Spacing exception req'd: Yes❑ No[� Inclination-only svy req'd:Yes❑ No[" 'C p f^►_-ki r---- Z O cAc_. -z-5:4 l 2-(b) -eF,CIA lT s c.6/._ ret D / APPROVED BY Approved by:� ��t� COMMISSIONER THE COMMISSION Date: �• ,. 1 3 •2'��� ubmit Form and rel.' OicfjrfP02lL This permit is valid or 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate \�\` RECEIVED ■ t JAN 3 12013 nrolleul AOGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907)865-3321 Email: james.wright @enipetroleum.com January 30,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI32-W2 Dear Commissioners, Eni US Operating Co. Inc.hereby applies for a Permit to Drill for the Offshore Injector well SI32-W2_This well will be drilled and completed using Doyon 15.. In order to expand the current Nikaitchuq project to include the N Sand,Eni's sanctioning protocols require the acquisition of a "live" fluid sample from the formation. The N sand is a highly unconsolidated formation that has proven extremely difficult to gather a fluid sample utilizing standard MDT techniques. It is for these reasons that the procedure described in the permit to drill will be utilized to acquire a fluid sample and pressures in cased hole. This procedure is seen as having the highest probability of success for acquiring a live oil sample.Attached also the completion schematic. The planned spud date could be as early as 2/23/2013. 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 Born 907-865-3328. Sincerely, Z--(-)E-096 .72/ J. - right •- ing&Completion Superintendent Eni ttroHeu , Application for Permit to Drill SI32-W2 Saved:29-Jan-13 Application for Permit to Drill Document Producer Well SI32-W2 Table of Contents 1. Well Name 3 Requirements of 20 MC 21005(t) 3 2. Location Summary 3 Requirements of 20 MC 21005(c)(2) 3 P/ease see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(6) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 21005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 21005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 Requirements of 20 MC 25005(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 21005(c)(9) 6 9. Seismic Analysis 7 Requirements of 20 MC 21005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 13 Printed:29-Jan-13 EMI '' Al um Application for Permit to Drill SI32-W2 Saved:29-Jan-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 8 Requirements of 20 MC 25005(c)(13) 8 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 12 Requirements of 20 MC 25 005(c)(14) 12 14. Area of Review 12 15. Attachments 13 Attachment 1 Drilling Procedure 13 Attachment 2 Directional P/an 13 Attachment 3 Drilling Hazards Summary 13 Attachment 4 BOP and Diverter Configuration 13 Attachment 5 Cement Loads and CemCADE Summary 13 Attachment 6 Formation Integrity And Leak Off Test Procedure 13 Attachment 7 Surface Platt 13 Attachment 8 % Mile Scan Report 13 Attachment 9 Casing Design Program 13 AOGCC PERMIT Document.doc Page 2 of 13 Printed:29-Jan-13 , ...... o ? Evil 'J �J trole�I ig. Application for Permit to Drill SI32-W2 Saved:29-Jan-13 1. Well Name Requirements of 20 MC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(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: SI32-W2 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 4433 FSL, 1468 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation feet'AMSL Northing: 6,053,613' Easting:511,442' Pad Elevation feet'AMSL Location at Top of Productive Interval 1609 FSL, 2237 FEL, S24 T14N R8E UM. ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9,377' Northing: 6,050,783' Easting: 505,595' Total Vertical Depth, RKB: 3,629' Total Vertical Depth, SS: 3,575' Location at Total Depth 2314 FSL, 3558 FEL, S14 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 18,327' Northing: 6,056,765' Easting: 498,988' Total Vertical Depth, RKB: 3,583' / Total Vertical Depth, SS:: 3,529' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(6); Requirements of 20 MC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan and AOGCC PERMIT Document.doc Page 3 of 13 Printed:29-Jan-13 .ice Enhi tirck ull Application for Permit to Drill SI32-W2 Saved:29-Jan-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 (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 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/ft, or 8.6 ppg EMW(equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,580'TVDss)(0.45 - 0.11 psi/ft) = 1230 psi • (8)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 app lication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(f) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4of13 Printed:29-Jan-13 i 1111* ■ tr4eum I�1N ) - Application for Permit to Drill SI32-W2 Saved:29-Jan-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/7VD 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 1272 TOTAL sx 13-3/8 16 68 L-80 BTC 2726' 35/ 35 2761'/ 2424' TAIL: 208 sx 2x 10.7 ppg ppg Cr TAIL: 208 sx 12.5 ppg DeepCrete 702 TOTAL sx 9-5/8 12-1/4 40 L-80 ❑ LINK 9344' 33/ 33 9377'/ 3629' 702 sx 12.5 ppg DeepCrete Feral Shin TOC: 7,119'MD/3,375'TVD 8-3/4"OA 4-1/2 Sand 11.6 L-80 Hydril 521 9150' 9177'/ 3616' 183277 3583' 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); /4 ,. Please see Attachment 4: BOP Configuration. AOGCC PERMIT Document.doc Page 5 of 13 Printed:29-Jan-13 iroot,- , EnI 4' 'tir4um Application for Permit to Drill SI32-W2 Saved:29-Jan-13 Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) _ 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 8.7-9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy Funnel Viscosity (CP) 15 - 25 ty (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100.0) 15 - 20 (CP) 12 - 18 HTHP Fluid loss Yield Point 18-24 (ml/30 min ca <5.0 (lb/100 sf) 200psi& 100°F API Filtrate 4 _ 6 Oil/Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/0 <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 AAC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. AOGCC PERMIT Document.doc Page 6 of 13 Printed:29-Jan-13 Ira* • DJ En! 'tF N Un Application for Permit to Drill SI32-W2 Saved:29-Jan-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 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. i AOGCC PERMIT Document.doc Page 7 of 13 Printed:29-Jan-13 roil ') �.,tr t ti Application for Permit to Drill SI32-W2 Saved:29-Jan-13 12. Proposed Drilling Program Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 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. 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 pp' 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. 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 regulations. Record results. 18) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 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. eA I ( Son i� 21) PU dumb iron assembly and TIH to TD Cgt_ ? 22) Displace well to 9.5 ppg FazeAway Delayed Breaker AOGCC PERMIT Document.doc Page 8 of 13 Printed:29-Jan-13 En Petroleum Application for Permit to Drill SI32-W2 Saved:29-Jan-13 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 (Tieback assembly included in hanger assembly)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. 29) PU Perforation guns. ➢ 1-2'Deep penetrating shot. ( possible perforated interval 8,225'MD, need to be confirmed with log after drilling) 30)TI H with perforation assembly to N-Sand target depth ( include scraper in this assembly). 31) Hold minimal over pressure and pulse fire head. 32) Fire guns, confirm reduction in surface pressure ensuring that guns fired. 5tC 33)TIH past perforation interval with scraper to clean possible perforation debris. ��Q 34) Circulate bottoms up and POOH. 5 35) PU MDT Tools and TIH to sampling depth 36) RU WL and pump WL to latch. ( .�. -r-z c ca,,v 7 is 37)Take MDT Samples / ➢ Run MDT Dual packer tool-string set the packer across the perforated interval ➢ Inflate packer, and perform seal test ➢ Collect PVT sample and perform final build up ➢ Ensure to not draw down below bubble point ➢ Contamination less than 10% -Target 5% ➢ Confirm Sample volume ➢ Deflate dual packer and POOH 38) POOH MDT Assembly. 39) L/D DP as required. 40) RU tubing running equipment and run 4-1/2"tubing. • Running Tubing string with: • 7" No go—Tieback Seal Stem • Halliburton PHL Injection Packer(pck 8,062'MD) see schematic below. • Upper GLM 41) RIH to liner tieback assembly and sting in the tieback seal stem. AOGCC PERMIT Document.doc Page 9 of 13 Printed:29-Jan-13 • 11; CH II Application for Permit to Drill SI32-W2 Saved:29-Jan-13 42) Land tubing hanger and test seals. 43)Test upper and lower seals to 5000 psi for 10 min. 44) RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. 45) Pressure down tubing string to 1200 psi to close autofill valve and monitor for leaks. 46) 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. 47) 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. 48) Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 49) 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. 50) Pull landing joint and set BPV. 51) 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. • Wellhead schematics should be on file with the AOGCC. 52) Pull BPV and set TWCV. 53) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 54) Pull TWCV. 55) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 56) Set BPV and secure tree and wellhead. 57) RDMO AOGCC PERMIT Document.doc Page 10 of 13 Printed:29-Jan-13 0,1*• Enil P 2nli Application for Permit to Drill SI32-W2 Saved:29-Jan-13 Final completion schematic SI32-W2 Nkaitchuq Field-Spy Island SI32-W2 Injector rfirt 4-•z 12.6# Monobore with Injection Control H563 Tubing evil operating I [ As Planned 2,149'MD. 1,981'TVD.35°Inc-3.81"X-nipple for possible injection valve p6c 2,247'MD.2.062'TVD,37°Inc-4-'h"x 1"KBMG GLM,2,000 psi A to T shear valve ‘N 8,062'MD.3,514'TVD,83°Inc-PHL Retr. Packer 8,082'MD •3.81"X-nipple 13-3/8"68 ppf 0 9,020'MD,86°Inc-HAL Mirage Plug with Auto-fill valve Casing, J. , 1- 2,760'MD. .! rwr 9,121'MD- SLZXP Liner Top 2.424'TVD. ' 51°Inc 9.131'MD - No Go-Tieback Seal Stem-Bottom entry guide Zonal Isolation Injection Control Interm. Perf—8,225'-8,226' r Pac ers Devices MD ! ,, . ON Noe Mils MN Noe 101 No • ! 9-5/8"40 ppf 4-1/2"11.6#H521 Intermediate Production Liner, Casing. 9,377'MD, 18,327'MD, 3,583' 3,629'TVD,86°Inc TVD.90°Inc Confidential AOGCC PERMIT Document.doc Page 11 of 13 Printed:29-Jan-13 i ■ s' (=Emil �tIr(. q - iii Application for Permit to Drill SI32-W2 Saved:29-Jan-13 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point - or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. . 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 Y4 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 12 of 13 Printed:29-Jan-13 Enil Application for Permit to Drill SI32-W2 Saved:29-Jan-13 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional P/an 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 13 of 13 Printed:29-Jan-13 eat us operating WELL SI32-W2 Drilling Procedure SI32-W2 Spy Island Conductor slot #32 Reservoir location #W2 Injector (Schrader Bluff) Nikaitchuq Project SI32-W2 Drilling Wellplan Page 1 of 43 01/29/13 ff* • 2nd us operamins WELL SI32-W2 Spy Island Nikaitchuq Field en° p foOeum North Slope - Alaska SI32-W2 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD - SIZE SPECS INFO Cement to Surface 20" Hole Angle °0 x-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A 0 GR/Res a xx Surface C50 Dir/PWD °a o 13-3/8" y 68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 2,000' 1,850 r L-80,BTC 8.8-9.5 Lost Circulation w Hole Cleaning ll e Casing Sections KOP:200' ° Casing Wear DLS: Surface T/Tail Cement 2,307 1,105 0-3.7°/100' 4. Hole Angle 50.95 Deg 13-3/8"Csg 2,761' 2,424' lit 16" 50°F WBM GR/RES/PWD Inter.Casino Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40 0 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 Irte-r,ed ate IOC 7,119' 3,375' Pick-up Top of Sand PHL Injection Packer 8,062' 3,514' c-:$ N Top 8,119' 3,522' ... g Possible 1'perforation interval li to m evaluated by Gee 8,225' 3,534' Hole Angle TOL 9,177' 3,616' ���.r� 86.00 Deg 9-5/8"Csg 9,377' 3,629' - 1 12.25" 85"F WBM r GR/RES p� Ec0SCOPE/PWD g SI Wellbore Stability Lost Circulation ' ICD Liner Hole Cleaning ,-' Torque&Drag n ES El 11.6 4 MW(ppg) Casing Sections Xceed 675 ap L-80,Hydril 521 8.7-9.4 Casing Wear - o ICD BHA Expense Fi IE El ICD CS SI Hole Angle 89.29 Deg 4 1/2"liner 18,327' 3,583' r 8-3/4" 85"F MOBM SI32-W2 Drilling Wellplan Page 2 of 43 01/29/13 Wil° x# us itperrahhng WELL SI32-W2 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 36 Recommended Drilling Practices 37 Health, Safety & Environment 38 Safety Meeting Topics 39 Well Shut In Procedure While Running Production Tubing 41 Conductor Broach—Contingency Cementing Plan 42 TAM PORT COLLAR Utilization Decision Tree 43 SI32-W2 Drilling Wellplan Page 3 of 43 01/29/13 us operating WELL SI32-W2 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Injector Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 4-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SI32-W2 Drilling Wellplan Page 4 of 43 01/29/13 us operating WELL SI32-W2 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. SI32-W2 Drilling Wellplan Page 5 of 43 01/29/13 . ...__.._..._. . 00, . _ 2rn10 us operating WELL SI32-W2 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPf) 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. D Each conductor is to be marked with a common pad elevation survey mark by the surveyors D 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. I SI32-W2 Drilling Wellplan Page 6 of 43 01/29/13 •enl us operating WELL SI32-W2 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (6) Measured True Formation Tops Depth, ft Vertical Comments Depth, ft SV-4 773 768 SV-3 1141 1 1 18 SV-2 1430 1376 B/ Permafrost 2000 1858 SV-1 2084 1927 Ugnu Top (UG4) 2488 2240 13-3/8" Csg 2761 2424 SCP UG-2 Coal Bed Marker 3364 2752 Lower Ugnu 6375 3273 Schrader Bluff Top 7464 3434 N Sequence Top 7829 3485 N Top /J v` 8119 3522 ReCalc Intermediate Cement w/Actual N Bottom 8299 3542 N Sequence Base 8971 3601 9-5/8" Csg 9377 3629 ICP- Set ABOVE OA Sand Top OA Top 9449 3634 OA-2 Top 9550 3640 4 1/2" liner 18327 3583 Total Depth SI32-W2 Drilling Wellplan Page 7 of 43 01/29/13 firi* 2nd �s op&t� ng WELL SI32-W2 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/3Omin) 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 /D(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections SI32-W2 Drilling Wellplan Page 8 of 43 01/29/13 W , em us operating WELL SI32-W2 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 ➢ 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: ➢ 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. SI32-W2 Drilling Wellplan Page 9 of 43 01/29/13 us *perating WELL SI32-W2 • 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. SI32-W2 Drilling Wellplan Page 10 of 43 01/29/13 Iff* 2rnno us operating WELL S132-W2 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (ppf) Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) OD WT Opt. (in) (PPI) Grade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casine Runnine 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. 1. Inspect and drift all surface casing to 12.259". !,I 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 II I � SI32-W2 Drilling Wellplan Page 11 of 43 01/29/13 us operating WELL SI32-W2 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 +/- 18 13-3/8"Tandem Rise Weatherford SI32-W2 Drilling Wellplan Page 12 of 43 01/29/13 ffi* en us opera ins WELL SI32-W2 Surface Centralizer Placement )MIC ■I t10' oa 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 1St 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 SI32-W2 Drilling Wellplan Page 13 of 43 01/29/13 c can operafing WELL SI32-W2 Surface Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Mudpush II 100 bbls Densityl0.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 455 bbls Yield 2.40 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 58 bbls yield 1.56 ft3/sk Top of Tail @ 2,307'MD 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. ➢ To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool ➢ If necessary,rack TAM running tool in derrick and ready to run ➢ Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. ➢ Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than'A the shoe joint volume). SI32-W2 Drilling Wellplan Page 14 of 43 01/29/13 us operahng WELL S132-W2 ➢ 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 - • . omp - •: •: .•, i - , •nd place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC 'e • : : . 1-s ➢ 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 SI32-W2 Drilling Wellplan Page 15 of 43 01/29/13 ift* 2nn us ope fang WELL SI32-W2 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 D 120— 140 RPM 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. 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 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. SI32-W2 Drilling Wellplan Page 16 of 43 01/29/13 end us oiler ins WELL SI32-W2 INTERMEDIATE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (6) Measured True Formation Tops Depth, ft Vertical Comments Depth, ft SV-4 773 768 SV-3 1141 1118 SV-2 1430 1376 B/Permafrost 2000 1858 SV-1 2084 1927 Ugnu Top (UG4) 2488 2240 13-3/8" Csg 2761 2424 SCP UG-2 Coal Bed Marker 3364 2752 Lower Ugnu 6375 3273 Schrader Bluff Top 7464 3434 N Sequence Top 7829 3485 N Top 8119 3522 ReCalc Intermediate Cement w/Actual N Bottom 8299 3542 N Sequence Base 8971 3601 9-5/8" Csg 9377 3629 ICP- Set ABOVE OA Sand Top OA Top 9449 3634 OA-2 Top 9550 3640 4 1/2" liner 18327 3583 Total Depth ICI SI32-W2 Drilling Wellplan Page 17 of 43 01/29/13 us operating WELL SI32-W2 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density PV 6 RPM API FL PH Drill Solids MBT (ppg) Reading (ml/3Omin) (/o) 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 Joint Body DP WT Conn. Joint Tool Body Make Up Torsion Torsional capacity Tensile Pipe (ppg Grade Type OD Joint ID(in) Torque al yield Yield w/corm. Capacity (in) ID(in) (ft.lbs) (ft lbs) (ft.lbs) (gal/ft) (GPs) 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: -r- e. 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. SI32-W2 Drilling Wellplan Page 18 of 43 01/29/13 rim 2no us operrafing WELL SI32-W2 Intermediate Drilling 1. Directionally Drill 12-1/4"hole ➢ Use the following Parameters: • Flow rate of 900 GPM • 120— 140 RPM 2. Casing Point:Land Intermediate casing 50' into the 0A2 sand reservoir 3. LOW ROP:Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: ➢ Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-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. SI32-W2 Drilling Wellplan Page 19 of 43 01/29/13 Iff* en us operating WELL SI32-W2 Intermediate Casing Program: (all depths feet RKB) OD N'T Conn. Cplg OD Collapse Burst Tensile Yield Grade ID(in) Drift(in) (in) (ppf) Type (in) (psi) (psi) (kips) **Special 9-5'8 40 L-80 H5y6d31 ' 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque (ft.lbs) Mu'' Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield Torque (in) (ppfl Torque, ft- Torque Torque lbs 9-5/8 40 L-80 H56d31 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 ➢ 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. ➢ If the drawn line does not move more than''A"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 Y2"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than'''A",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than Y2",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''A". SI32-W2 Drilling Wellplan Page 20 of 43 01/29/13 us . peratong WELL SI32-W2 • 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. SI32-W2 Drilling Wellplan Page 21 of 43 01/29/13 Iffy* • 2rnl� us operr ions WELL SI32-W2 Intermediate Centralizer Placement PM, 10' oa 9-5/8" x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. • 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 5 5, SI32-W2 Drilling Wellplan Page 22 of 43 01/29/13 1119* n us operrahng WELL SI32-W2 Intermediate Cementing Program Section Casing Size Type of Fluid/ Cmt Volume Properties Intermediate 9-5/8" Mudpush II 70 bbls Density 10.5 ppg DeepCrete 195 bbls ✓ Density 12.5 ppg Top of Cement @ 7,119' MD (702 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'Y2 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 Schlumberaer 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 SI32-W2 Drilling Wellplan Page 23 of 43 01/29/13 US operating WELL SI32-W2 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. D. Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. • 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) D. Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) D. Test rams and choke manifold components to 3500 psi high/250 psi low ➢ 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 5I32-W2 Drilling Wellplan Page 24 of 43 01/29/13 /I* 2n0 us operainc WELL SI32-W2 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly. ➢ 8-3/4"PDC ➢ Rotary Steerable ➢ Flow rate: 550 GPM ➢ 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 ➢ 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. LU /F rr- 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 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. ➢ Plot on LOT form in N drive SI32-W2 Drilling Wellplan Page 25 of 43 01/29/13 Itlyf* •e • nno us opera Hrnng WELL SI32-W2 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (6) Measured True Formation Tops Depth,ft Vertical Comments Depth,ft SV-4 773 768 SV-3 1141 1118 SV-2 1430 1376 B/Permafrost 2000 1858 SV-1 2084 1927 Ugnu Top (UG4) 2488 2240 13-3/8" Csg 2761 2424 SCP UG-2 Coal Bed Marker 3364 2752 Lower Ugnu 6375 3273 Schrader Bluff Top 7464 3434 N Sequence Top 7829 3485 N Top 8119 3522 ReCalc Intermediate Cement w/Actual N Bottom 8299 3542 N Sequence Base 8971 3601 9-5/8" Csg 9377 3629 ICP- Set ABOVE OA Sand Top OA Top 9449 3634 OA-2 Top 9550 3640 4 1/2" liner 18327 3583 Total Depth SI32-W2 Drilling Wellplan Page 26 of 43 01 29 13 W. ... .....■ Min us operating WELL SI32-W2 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP Oil:water Stability (ppg) (m1/30min) mlvoits 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 SD N l c— jsc. Ca L- Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile WT Conn. Joint Body Torsion Torsional capacity Pipe (pp� Grade type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity (in) ID(in) (ft.lbs) (ft lbs) (ft.lbs) (gal/ft) (GPs) 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. SI32-W2 Drilling Wellplan Page 27 of 43 01/29/13 11* 2fn11 us operrahns WELL SI32-W2 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. D Geosteering will be required to remain in the target boundary 100%of the time D Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. D Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: D At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM D Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE: 2-3/8" OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreamin2 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. D Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA D When out of hole,down load the recorded tool data and send to the Geologist in town 5I32-W2 Drilling Wellplan Page 28 of 43 01/29/13 it* 2no us operating WELL SI32-W2 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) Min. Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield (in) (ppJ) Torque, ft- Torque Torque* Torque lbs 4-1/2 11.6 L-80 Hydril 521 3600 6300 N/A 16,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 4-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover 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: SI32-W2 Drilling Wellplan Page 29 of 43 01/29/13 us c perating WELL SI32-W2 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 RIH 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. SI32-W2 Drilling Wellplan Page 30 of 43 01/29/13 IW- — fffil us it perating WELL SI32-W2 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. SI32-W2 Drilling Wellplan Page 31 of 43 01/30/13 Iff* 2n� us op rc tong WELL SI32-W2 8 PERFORATING AND MDT Notes: 1. Pre job safety meeting should be held before beginning operations listed below. Topics covered should include general personnel safety,well control,spill prevention,tasks and assignments,maximum safe pumping pressures and contingencies. Safety meetings should also be held prior to each major step in the procedure. 2. Only"essential personnel"should be on the rig floor while picking up and running the perforating string. All other personnel to stay off rig floor and out of the cellar until string is at least 300 feet below rotary table. !� 3. Radio silence is not required with the system planned for this perforation operation. `/ 4. All guns must be handled with slips and dog collars. 013 5. All drill pipe should be cleaned and drifted prior to running with TCP operations. ,Rv Procedure: 1. Hold pre job safety meeting discussing at minimum the items listed in the Notes section above. 2. Make up t h e bottom-hole assembly with th pe rf o r tin g guns us i ng s li ps and dog co ll ars o n the gu n sections. 3. Run in the hole with the string on drill pipe. 4. Run in the hole,filling DP as necessary. 5. Company Man,Eni on-site geologist,TCP specialist and all involved parties must be in agreement on depth measurements.(8,225'planned depth). 6. Prepare to pump in order to fire guns( 1' of perforation). Keep the rig floor clear from this point and be aware that significant losses may occur after firing. TCP specialist may send training pulses as needed. Fire guns by pressuring up and bleeding off pressure per direction of TCP specialist on location. 7. Rig up shot detection equipment to verify the guns have fired. 8. POOH while ensuring the hole is full using NaCl brine. After the guns are above the perforation interval,stop and monitor the well for losses or gains and circulate as necessary. 9. Continue POOH with perforating guns. Monitor fill-ups closely while accounting for the static loss rate observed after perforating. 10. Conduct a safety meeting before the first gun reaches surface. SLB specialist will address well control,gun handling and trapped pressure issues. 11. Continue POOH and lay down TCP equipment. Inspect and report all shots fired. 12. Rig up SLB e-line and MDT tools. 13. Run in hole on DP stands taking care to mini unnecessary stresses on the tools by avoiding sudden starts and stops. 14. Dope drill pipe on pin and not boxes.Use a minimum amount of dope. 15. The compressional and tensional strengths of the tools are relatively low.Do not set weight down on the tools.DO NOT rotate drill pipe 16. Tool compression is monitored in the logging unit.The team must be ready to stop the drill pipe immediately in case the tool sits down 17. Break circulation every 400'to clean down hole wet connections. When tools are at 7,000',circulate full DP volume to clear wet connection. SI32-W2 Drilling Wellplan Page 32 of 43 01/30/13 W — u, us operating WELL SI32-W2 18. Make up side door entry sub and insert pump down wet connection head.Pump down connection head.At 500' above down hole wet connection,shut down pumps and allow SLB to take up and down weights.Pump at 500 psi while RIH with wet connection;pump pressure will increase as latch is made 19. Clamp cable to side door entry sub. SLB E-line will test connection 20. Circulate every 5 stands to ensure the wet connection is clear of debris.RIH to below proposed location with GR or CCL tool and log up with the GR or CCL tool and correlate depths to LWD log or perforations. 21. Collect pressure and fluid samples at 8,225'. 22. POOH until side door entry sub reaches surface.Have E-line slack off on wire and remove clamp. SLB will unlatch from wet connection.POOH with wet connection.LD side door entry sub. 23. POOH with drill pipe LD/RD MDT tools and SLB E-line. SI32-W2 Drilling Wellplan Page 33 of 43 01/30/13 i 2rn11 us operating WELL SI32-W2 COMPLETION 1. RU tubing running equipment and run 4-1/2"tubing. a. Running Tubing string with: i. 7"No go—Tieback Seal Stem ii. Halliburton PHL Injection Packer(pck 8,062' MD)see schematic below. iii. Upper GLM 2. RIH to liner tieback assembly and sting in the liner tieback seal stem. 3. Land 4-1/2"tubing hanger and test seals. 4. Test upper and lower seals to 5000 psi for 10 min. 5. RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. 6. Pressure down tubing string to 1200 psi to close autofill valve and monitor for leaks. 7. 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. 8. 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. 9. Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 10. 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. 11. Pull landing joint and set BPV. 12. Nipple down BOP,nipple up tree and test void to 5000 psi for 10 min. 13. ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265.(c).(1). 14. 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. 15. Wellhead schematics should be on file with the AOGCC. 16. Pull BPV and set TWCV. 17. Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 18. Pull TWCV. 19. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus,taking returns from tubing. 20. Set BPV and secure tree and wellhead. 21. RDMO SI32-W2 Drilling Wellplan Page 34 of 43 01/30/13 11* • en!' us operating WELL SI32-W2 Proposal completion schematic SI32-W2 Nikartchuq Field-Spy Island SI32-W2 Injector 4-Wrz°12.6# Monobore with Injection Control eno H563 Tubing :' 9 L S. c-1:0;f.ce:C 1 Ilk] r 2,149'MD, 1,981'TVD.35°Inc•3.81"X-nipple for possible injection valve 2,247'MD,2.062'TVD,37°Inc-4-'6"x 1"KBMG GLM.2,000 psi A to T shear valve .� " I 8,062'MD, 3.514'TVD.83°Inc-PHL Retr. Packer Aik 8,082'MD •3.81"X-nipple 13.318"68 ppf N'S� 9,020'MD. 86°Inc-HAL Mirage Plug with Auto-fill valve Casing, 1111400,0 2.760'MD. • • 9,121'MD- SLZXP Liner Top 2.424'TVD, , 51°Inc 9.131'MD - No Go-Tieback Seal Stem •Bottom entry guide Zonal Isolation Injection Control Interm, Perf—8,225'-8,226' ' Packers Devices MD ,(/ al pi It ill Nis pis use 1 , ',' 9-518"40 ppf 4-'2" 11.6#H521 Intermediate Production Liner, Casing, 9,377'MD, 18,327'MD. 3,583' 3,629'TVD,86°Inc TVD.90°Inc Confidential SI32-W2 Drilling Wellplan Page 35 of 43 01/30/13 f fk em us operating WELL SI32-W2 ATTACHMENTS 1. Recommended Drilling Practices 2. Health,Safety,and Environment 3. Safety Meeting Topics 4. Well Shut In Procedure While Running Tubing 5. Conductor Broaching Contingency Plan 6. Port Collar Decision Tree SI32-W2 Drilling Wellplan Page 36 of 43 01/30/13 c's* 2rnl� �s operr inns WELL SI32-W2 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. SI32-W2 Drilling Wellplan Page 37 of 43 01/30/13 • eno us operr li nng WELL SI32-W2 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 H2S 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. SI32-W2 Drilling Wellplan Page 38 of 43 01/30/13 Iff* e 11 us operratons WELL SI32-W2 Safety Meeting Topics Move In,Rig Up > Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. ➢ A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. > An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. > Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. > Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. > Perform and document all drills. > Designate crew member to control access at the pad entrance in case of diverter operation. Surface > A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. > A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate > Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production > Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. > Stuck pipe,Lost circulation. SI32-W2 Drilling Wellplan Page 39 of 43 01/30/13 .. ... ...._..__.. twill IW— _ us #perating WELL SI32-W2 ➢ 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. SI32-W2 Drilling Wellplan Page 40 of 43 01/30/13 vtik en i us operrafinc WELL SI32-W2 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. SI32-W2 Drilling Wellplan Page 41 of 43 01/30/13 WELL SI32-W2 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. 5I32-W2 Drilling Wellplan Page 42 of 43 01/30/13 eni us operraiing WELL SI32-W2 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job No Cement to Surface Drilling Foreman and Nipple Up an Engineer determine the X Test POP's: Top of Cement I — Top of Cement Cement Continue* above Port below Port Collar Collar (1000'TVD) . 1000'TVD) X X Indicators of Cement Top • Perform Top Job \ as per ■ Open Port Co 1. Observation of Tracers in Spacer ahead of lead cement requirements of If Top Job is ineffective or using drillpi.. AOGCC unacceptable to AOGCC 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job • 4. Other indications that cement is near surface Nipple Up and Circulate Ce Test BOP's to Surface and close Port Collar • 7 Continue with Nipple Up and Completion Test BOP's Continue with Completion SI32-W2 Drilling Wellplan Page 43 of 43 01/30/13 M O C n j Wp AM 7-13271, W.71b N�p4 N Sg ar0p 27.-ASS P-!2:1-22 ;712. �,:c6 N NN N 6 pNg W N N Mil O WS M tPS Y 22424 N V OM N N NN a ..... ..... N N y N N y N N y N N y N N N NyNNN N y N N N N y N N N 1010 ,. 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I ; 2 4 §t PI ■ o ' ' k f2; ! 3 & IL j ! 80 a? !..§ .... ..., . & ■ &§| !li ! §■ 8 4' .. a $§ - | . |■ | !, § , ( ƒ. �� 0 , . - S <5 . . &;5 ! .& �&- 2 ;2 -| -= ! & I-& 3/| • t• Srg ° ! 2 !§ 6 8 �� Q m . . . 2. . .3 -- cl - 3 N 3 Cl) |) ! 2° ! §3 ; 1 (») £ .,i° if 0 7 0 III P ® ,- \ § <« N Um&4=oleos S »» Schiumherger SI32-W2(P6c)Anti-Collision Summary Report en p Analysis Date-24hr Time: December 05,2012-11:18 Analysis Method: Normal Plane Client: Eni Petroleum Reference Trajectory: 6132-W2(P6c)(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Spy Island Rule Set: D&M AdlC011ielon Standard S002 v5.1/5.2 Slot: SP32 Min Pts: All local minima indcated. Well: 5132-W2 Borehole: 5132-W2 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scam Not performed! Selection filters. Definitive Surveys-Definitive Plans-Definitive surveys occlude definitive plans -Al Non-Def Surveys when no Del-Survey is set in a borehole-All Non-Def Plans when no Del-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 DR Dev.(ft) Fact Rule MD(8) I TVD(n) Alert I Mirror I Major • OP1453(Del Swey) Fail Minor 15343.98 96.80 15278.78 15247.1:M111E2E OSF 1.50 5753.55 3180.52 Min%-0-SF 737.59 228.51 58217 509.08 4.98 OSF 1.50 7457.23 3432.67 OSF05.00 Enter Alert 293.18 293.20 94.97 -0.02 1.50 OSF 1.50 8026.48 3510.14 OSF<1.50 Enter Minor 1 227.201 306.20 MEM=EMMEN OSF ISO 8228.96 3534.35 MinPts SP33-W3(Def Survey) Warning Alert 8.09 6.72 586 1.37 WA MAS•2.05 On) 0.00 0.00 CrCl<=15m<15.00 Enter Aled ::.- 572 6.86 1.371 N/A MAS•2.05(m) 40.82 40.82 Min%s ::r. 6.72 6.56 1. 16.65 16.65 MAS•2.05(m) 160.00 160.00 MinPts 8.27 6.721 6.44 1.55 11.62 MAS•205(m) 189.98 189.98 MINPT-0-EOU 11.04 6.72 8.63 4.32 MAO.205 lm) 279.86 279.85 Min%-0-SF ll 6.99 17.88 15.96 5.6 OSF 1.50 66253 660.17 Mn%-CICt 2299 7.1 15.86 5.53 OSF 1.50 67263 670.09 MINPT-O.EOU 23.08 7.25 17.: j=j2E 5.44 OSF 1.50 680.95 678.26 M5Mt-O-ADP 24.27 7.81 18.66 16.> OSF 1.50 733.22 729.46 MinPt-OSF 48.23 10.17 41.05 38.06 7.88 OSF 1.50 975.12 962.67 CrCro t5m>t5.00 Eric Alert 259.33 26.47 241.28 232.•MEE OSF 1.50 2064.21 1911.46 98.49-0SF 283.38 28.85 263.74 254.5 OSF 1.50 2151.17 198223 MinPt-0SF 323.16 3267 300.97 290.•MEE OSF 1.50 226.61 2073.00 Min%-0-SF 447.54 47.78 415.33 399.71 MO2U OSF 1.50 2784.27 2438.83 Min%-0-SF 46.25 48.18 43277 417.•:Illlllll EE OSF 1.50 3017.07 +279.95 Min%-0-SF 1 ,7 56.51 417.34 399.16 12.48 OSF 1.50 361232 2840.6 MnPt-CtCt 454.96 6. 398.59 12.29 OSF 1.50 369.97 2854.52 MINPT-O-EOU 455.25 56.72 417.1 r= j ; 12.23 OSF 1.50 3679.06 28698 Mn%-O-ADP 519.32 84.52 462.-- 9.31 OSF 1.50 5156.21 3091.96 Mn%-O-ADP 571.90 09.47 46.5-.1111-M 7.89 OSF 1.50 6076.21 3228.36 Mn%-O-PAP 574.41 12<IIIIIIIII 461.93 7.71 OSF 1.50 6181.49 3243.97 MINPT-O-EOU 578.38 17.54 499..•�. .•r-n, 7.43 OSF 1.50 636.14 3274.31 MnPt-O-ADP 619.97 37.14 528.22 482:4=III OSF 1.50 7104.36 3390.80 Mn%-OSF 1149.59 41.26 106.09 1008.4 MEE OSF 1.50 9583.56 3641.20 MinPt-O-SF 1145.27 40.34 1051.:MEIZMU 1232 OSF 1.50 966.83 3644.01 Mn%-O-ADP 1145.22 40 MEM 1004.95 12.32 OSF 1.50 565.8 3644.12 MINPT-O-EDU MEM 40.21 1051.41 106.00 12.33 OSF 1.50 970287 3644.21 MnPt-CtCt 1171.26 45:=MAU 103261 11.89 OSF 1.50 1016.6 363627 MINPT-0-EOU 1173.79 51.67 1072- 10221• 11.67 OSF 1.50 10758.80 3634.14 MinPl-O.4DP MjElal 87.11 1031.74 96.70 9.31 OSF 1.50 11103.6 3648.13 MnPI-CICI 1165.13 99.88 1021.54 955.231 8.704 OSF 1.50 11472.18 3642.93 MnPt-0-SF MIZE 202.71 1019.19 951.95 8.58 OSF 1.50 1159.37 3641.64 MnPt-CrCt 1159.01 214.0.MIME 944.79 8.15 OSF 1.50 11879.32 3636.92 MINPT-D-EOU 101506 305.61 810.99 709.45 4.99 OSF 1.50 14131.93 3611.76 DSF45.00 Eder NM 1005.25 317.87 793.01 687.: 4. OSF 1.50 14535.48 3608.91 MinPt-0SF 1005.22 317:=MEM MaiE5 4.75 OSF 1.50 14542.6 3608.6 MinPts 317.84 793.00 687.38 4.75 OSF 1.50 14560.28 3608.80 MnPt-CtCI 1064.80 326.48 846. 738. 4.90 OSF 1.50 15208.51 360158 Min%-0-ADP 1097.98 34262 69.24 76. 4. OSF 1.50 15626.21 684.22 Min%-0-6F 115157 358.r=ME 794.87 4.83 OSF 1.50 16257.98 3578.6 MINPT-O-EOU 115418 359.44 914.2 Wag 4.83 OSF 1.50 1627795 3578.35 Min%-0-ADP 116.72 368.54 919.7.INIIE 4.75 OSF 1.50 16517.6 3574.62 Min%-0-ADP 1192.58 384.76 98.75 807,IMUM OSF 1.50 1690298 873.45 Min%-0SF 1237.62 400.84 970.•:Illlllllr•"<....3�: 4.64 OSF 1.50 17277.75 878.55 Min%-0-ADP 1246.6 404.49 976.86 842.a IIIIIIIIIIIIjO ' OSF 1.50 1736.25 3578.29 Min%-0-SF 1297.20 420.83 1016.31 876.: 1E0. OSF 1.50 17796.07 3577.05 Min%-0-SF 1328.21 470.1 MUM IIMMIE IMMO OSF 1.50 1816.54 3581.42 MinPts SP30-1/V1PB1(Def Swey) W11i0 PM 23.95 19.40 2272 4.54 WA MAO=5.91(m) 0.18 0.18 CtCt<=15m<15.00 Eder Alen 1 23.951 19.40 22.-:It s 556.92 MAS=5.91(m) 54.10 54.10 MinPts 24.19 19.••] 4.78 51.29 MAS•5.91(m) 140.18 14018 MINPT-0-EOU 27.96 19.••�.. 8.56 4.15 MAS•5.91(m) 559.55 558.53 MINPT-O-EOU 50.43 43.•MNI.L. 6.93 1.75 OSF 1.50 965.31 953.36 MINPT-0-EOU 51.26 44.72 21.• 1.73 OSF 1.50 980.99 96.25 Min%-D-ADP 52.03 45.44 21.33 6.,MiG OSF 1.50 994.91 981.43 Min%-O-SF 141.37 43.75 111.79 97.61 4.94 OSF 1.50 1677.02 158697 OSF>5.00 Eat AIM 250.63 37.93 225.01 MIEU 10.14 OSF 1.50 2911.00 2517.60 Mn%-O-ADP 248.50 8. 213.12 10.79 OSF 1.50 2981.61 259.58 MINPT-0-EOU 224.95 46.6 193.36 178.. 7.e. OSF 1.50 3896.16 2905.12 Min%-D-SF 223.37 45.6 1924 MZE. 7.43 OSF 1.50 3995.11 2919.81 MinPl-D-ADP 2226 45.< 192': 177.6 7.50 OSF 1.50 4034.84 2325.71 MINPT-O-EOU =:4, 45.00 19251 177.84 7.56 OSF 1.50 4074.61 2931.60 Mn%dYCt MEM 69.34 228.11 205.33 6.01 OSF 1.50 6440.48 328237 MnPI-CtCt 281.08 85.. 223..: 16.44 4.96 OSF 1.50 659295 3304.97 OSF45.00 Eder Alert 26.88 6.40 225.:IIIIIIIIII'< r-- 4.54 OSF 1.50 6677.61 3317.52 Min%-0-ADP 339.09 125.61 255.02 213. 4.. OSF 1.50 607.49 3351.61 Min%-0-SF 513.68 155.82 409.47 357.6 4.97 OSF 1.50 7354.17 3417.67 OSF>5.00 Eat Alert MERE 177.04 1108.75 1050.00 10.45 OSF 1.50 1106.31 364818 M4rPt-CtCt 976.27 294.03 779.93 682.25 4.99 OSF 1.50 13976.66 3608.80 OSF6.00 Eder Alert 335.:MIZIE Mak5M�,' OSF 1.50 14138.54 3611.72 MinPts SP30-W1(Del SVVey) ~hp Mort • 23.95 19.40 22.72 4.54 WA MAS= .91(m) 0.18 0.18 CICt<=15m<15.00 Eder Alert 1 23.951 19.40 22.-:It ' 556.92 MAS• .91(m) 54.10 54.10 MinPts 24.19 19.•MD211 4.78 51.29 MAS• .91(m) 140.18 140.18 MINPT-0-EOU 27.96 19.•• -'. 8.6 4.15 MAO. .91(m) 559.55 558.53 MINPT-9-EOU 60.43 43.-•MEE 6.93 1.75 SF 1.50 96.31 953.36 MINPT-O-EOU 51.26 44.72 21...MEM 1.73 SF 1.50 990.99 968.25 Mn%-0-ADP 52.03 45.44 21.33 6.1=ME SF 1.50 994.91 981.43 Min%-D-SF 141.37 43.75 111.79 97.61 4.94 SF1.50 1677.02 1586.97 OSF>5.00 Eat Alert 250.63 37.93 225.01/MUM 10.14 SF 1.50 2911.00 2517.60 Mn%-D-ADP 248.50 8. 213.12 10.79 SF 1.50 2981.61 2559.58 MINPT-0-EOU 224.95 46.88 193.36 179.• 0AE.. SF1.50 366.16 7905.12 Min%-0-SF 223.37 45.85 1924 7.43 SF 1.50 3980.11 2919.81 Min%-0-ADP 22298 45.< 192 177.58 7.50 SF 1.50 4034.84 2925.71 MINPT-0-EOU M=IM 45.00 192.51 177.84 7.56 SF 1.50 4074.61 2931.60 Mn%-CtCt MEM 69.34 228.11 205.33 6.51 SF 1.50 6440.48 328237 MaPt-CtCt Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 1 of 10 Offset Trajectory Se•.ration Allow Sep Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft) MAS Dev.(ft) Fact Rule MD(ft) I TVD(ft) Alert I Minor I Major 281.08 85.• 195.44 4.96 OSF1.50 6592.5 3304.97 OSF/5.00 Enter Alen 289.88 96.40 225.:MOE 4.54 OSF 1.50 6677.61 3317.52 Min%-O-ADP 339.09 125.61 255.02 213.4 4.. OSF 1.50 6907.49 3351.61 MinPt-0-SF 513.68 15.82 409.47 357.86 4.97 OSF 1.50 7354.17 3417.67 OSF>5.00 Exit Alert ME1E6E 177.04 1108.75 1050.06 10.45 OSF 1.50 1105.31 3648.38 MnPt-C1101 MIME 29333 871.75 725.10 5.21 OSF 1.50 14009.67 3610.13 MnPI-0C1 1019.88 296. •Ma'( 723.40 5.17 OSF 1.50 14080.23 3611.70 MINPT-O-EOU 102226 300.'•MEM 722.23 5.12 OSF 1.50 14174.70 3611.46 MINPT-0-EOU 1023.15 301.11 822.;1111= 5.11 OSF 1.50 14202.53 3611.26 MnP1-5-ADP 104202 310.99 834.37 731., 5.. OSF 1.50 14461.81 3609.43 MinP1-0-SF 306.45 845.39 743.57 5.15 OSF 1.50 15050.89 3603.79 MnPI-C1Ct 1051.25 309.: 844.. 741.46 5.10 OSF 1.50 15127.78 3602.77 MINPT-O-EOU 106275 311.59 844.,<MIME 5.08 OSF 1.50 15151.87 3602.30 MinPt-O-ADP 1061.14 316.66 849.70 744.: 5.. OSF 1.50 1522897 399.90 MinPt-O-SF 1108.64 330.36 888.07 778•• 5.•' OSF 1.50 15872.41 3584.37 MinPt-0-SF 1159.92 348.73 927.10 811.18 5.00 OSF 1.50 16397.14 357649 06F6.00 Enter Merl 118242 36224 940.>r MEEIE 4.91 OSF 1.50 16748.13 3571.45 MinPt-O-ASP 1234.28 387.12 975.87 847.1:l OSF 1.50 17318.28 3578.44 86451-0-SF 1290.31 402.70 1021.51 887.61 l : OSF 1.50 17743.96 3577.20 MinPt-0-SF 1331.34 415.00 1054.35 916.•MEE OSF 1.50 1809215 3500.47 MinPt•0SF 1354.87 47122 1073.07 932.>,l OSF 1.50 18290.74 3582.94 MinPt-O-5F 1359.24 423.5 10765 93569 4.82 OSF 1.50 18327.24 3583.40 OSF>5.00 Exit Alert 12554.94 119.23 12475.12 12435.71' 25 OSF1.50 2200.85 2021.98 MinPt-O-SF 8135-W4(P2)(Def Plan) Warring Alert 24.08 19.51 22.85 4.57 N/A MAS=5.95(0) 0.00 000 CICI<=150<15.00 Enter Alert OB 19.51 22.. 4.57 28.37 MAS=5.95(0) 200.00 200.00 MinPts 24.08 19.51 -r^, 4.58 28.05 MAS•5.95(m) 210.00 210.00 MINPT-0-EOU 27.20 19.51 23.1 7.69 9.15 MAS=5.95(0) 430.30 430.08 MINPT-0-EOU 41.91 19.51 31.72 22.l MAS•695(m) 681.22 67652 M inP1.0-SF 49.02 19.51 37.14 29.51 MIKE MAS•5.95(m) 751.61 747.41 MFrIPI-O-SF 57.5 19.92 43.86 37.0 l LIIE OSF 1.50 822.09 815.90 MinP1-O-SF 89.62 27.89 70.62 61.73 4.97 OSF 1.50 1024.07 100697 OSF15.00 641 Alert 825.57 150.5 724.88 875.rr, OSF 1.50 7194.42 3394.14 MinPt-0-SF 2299.39 135.92 2309.45 2163.4 NUM OSF 1.50 945.33 3633.26 MinPt-O-SF 2251.37 131.17 2163.a MEM 25.93 OSF 1.50 9797.29 3644.45 MinPt-O-ADP 2251.34 131.1• 2163.ti 212120 25.94 OSF 1.50 9002.70 3644.41 MINPT-0-EOU 31 131.11 2163.60 2120.23 25.94 OSF 1.50 9808.11 3644.36 MIPI-CICt 2287.23 192-MGEE ME:2E 17.88 OSF 1.50 11468.44 394298 MinPts 315.02 1890.41 175.73 10.03 OSF1.50 14607.73 3608.40 MirPt-CtCt 2100.77 315.1 IC=MEM 10.03 085 1.50 14619.27 3608.32 MinPts 2100.82 315.16 1890.38 1785.."IMEE OSF1.50 14625.03 3608.28 MinPt-O-SF 2103.53 315.44 1892.91 1768.re MEM OSF 1.50 14705.81 3607.67 MinPt-0-SF 2161.03 328.13 1941.'=mum 9.90 OSF 1.50 152025 3600.80 Ming-0-ADP 2202.08 344.97 1971.77 1857.11 • OSF 1.50 15624.64 3584.28 MinP1-0-SF 2439.09 407.54 2167.':ltd 9.00 OSF 1.50 17277.74 3578.5 MinPt-O-ADP 2528.72 438.05 2236.36 2090.• MILE OSF 1.50 18041.64 3579.84 MinPt-0-SF 512352(Def Survey) Warning Alert jjjj EM 25.:• WA MAS=7.87(m) 0.08 0.08 CtCt<=15m<15.00 Enter Alert ME1E 25.82 29. ;;I• 2297 MAS=7.87(m) 299.71 299.69 MinPts 31.96 25.,r, 29.> 6.14 20.78 MAS•7.87(m) 319.43 319.41 MINPT-O-EOU 38.02 25.82 34.44 1221 MEM MAS•7.87(m) 436.34 436.10 MinP1-0-SF 47.99 28.82 44.15 2217 17.89 MAS•7.87(m) 503.23 50266 CICIr15m>15.00 631 Alert 273.68 25.82 25668 247.:•1plplpljpk2 MKS•7.87(m) 966.88 954.85 MinPt-O-SF 2753.35 60.79 2706.41 2683.-- -'r yl OSF 1.50 2759.36 2423.13 MinPt-O-SF 250.76 134.94 2760.48 271562 31.91 OSF 1.50 1035.54 3631.70 TD 570.12 118.49 490.80 451.641 OSF 1.50 6383.56 3273.93 MinPt-0-SF 89.57 396.64 367.11 7.72 OSF 1.50 6574.05 3302.17 M inPI•CICI 457.87 92. jam, 365.60 7.51 OSF 1.50 6592.94 3304.97 MINPT-O-EOU 461.45 96.39 396.. 1ppjjjj 2 7.24 OSF 1.50 6613.71 3308.05 MinPI-O-ADP 546.58 132.38 457.93 414.1-: OSF1.50 6767.59 3330.87 Min%A-SF 203..'MraM MrEILE MUM OSF 1.50 3690.44 2562.66 MnP18 SP36-W5(P2)(Def Plan) Warring glen 32.14 25.95 30.91 6.18 N/A MAS=7.91(0) 0.00 0.00 CtCt<=15m515.00 Enter Akin 25.95 30.11 IIIIMM 38.33 MAS=7.91)0) 270.00 200.00 Mi81s 3214 25.==MEM 619 37.87 MPS•7.91(0) 210.00 210.00 MINPT-0-EOU 48.75 25.6 39.29 2280 5.76 MAS•7.91(m) 631.11 629.24 CtCtee15m>75.00 Exit Net 70.93 25.95 5.76 44.98 5.00 MAS•7.91(m) 822.06 81588 05Fe5.00 Enter Alert 97.74 31.54 76.30 66.201 4.771 OSF 1.50 983.22 970.36 MinP1-0-SF 107.63 33.42 84.94 74.21 4.96 OSF 1.50 1033.68 1018.02 OSF>5.00 Exit Net 1057.92 151.83 956.37 906.r<ljjljjljjljjl']Eia OSF 1.50 7109.12 3381.50 MinPt-O-SF 332223 132.41 3233.63 3189.:•J OSF 1.50 9433.05 3633.10 MinP1-0-SF 4J• 129.56 319119 3148.43 38.23 OSF 1.50 9760.68 3644.58 MnPt-CtCt 3278.00 129.> ME= 3813 OSF 1.50 976.17 3644.58 MinPts fi01 313.52 266.73 27515 14.71 OW 1.50 14649.05 360611 MinPt-CICt 306614 313.7 M=E:' 275240 14.70 08F1.50 14635 3608.00 MINPT-0-EOU 3065.19 313.81 2856,MEM 14.70 OSF 1.50 14668.39 3607.97 MinP1-0-ADP 3078.76 316.27 2867.59 2762.••1p!)))))))) M 085 1.50 14837.36 3606.42 MinPt-0-SF 3119.04 329...l .1=.^r. 14.26 OSF 1.50 15203.29 3000.77 MinPts 3154.92 345.84 2924.03 2806.:lP OSF 1.50 15631.26 3564.03 MinPt-O-SF 3369.47 409. ,M=,S'm=6 12.37 OSF 1.50 17286.78 3578.53 MinPts 3443.90 437.70 3151.77 3006..MEM OSF 1.50 18001.82 3579.34 MinPt-O-SF SP27-N1(Def Survey) Waning Alert 47.94 32.81 46.71 15.13 N/A MAS=10.00(m) 0.23 0.23 Ctet<=15m<15.00 Enter Merl 32.81 44.4 14... 38.92 MAS•10.00(m) 330.12 300.09 MinFls 46.98 32.81® 14.17 31.61 MAS•10.00(m) 369.92 369.85 MINPT-O-EOU 47.58 32.81 44. 14.77 23.13 MAS•10.00(m) 419.66 419.47 MINPT-O-EOU 49.06 32.81 44.76 1615 15.56 MAS•10.00(m) 479.30 47687 ClCt<65m>7500 Eet Alert 70.27 3281 5.13 37.46 4.96 MAS•10.00(m) 806.36 799.69 OSF<5.00 Enter Alert 98.63 4296 69.5 5.671-"R OSF 1.5 1099.66 1079.77 MinP1-0-6F 140.97 43.52 111.55 97.46 4.96 OSF 1.5 1429.20 1375.44 05F•800 Exit Alert 59263 88.51 533.29 504.12 10.141 OSF 1.50 5196.25 3097.90 MinP1-0-SF 2364.03 163.17 2254.92 2270.86 21. OSF 1.50 7913.64 3495.76 MinP1-0-SF 2220.13 126.04 2135.74 2094.10 26.62 OSF 1.50 8801.99 3588.93 M1nPI-O-ADP 2277.03 141,89 218211 2135.14 24.231 OSF 1.50 945.5 3632.86 MinPt-0-6F 1 °9 133.90 2192.03 2147.72 25.74 OSF 1.50 992271 364210 MnPt-C19 2281.95 134.:MIME 2147.39 28.62 OSF 1.50 994260 3641.62 MINPT-0-EOU 223227 134.6 2192,.E 25.56 OSF 1.50 9562.68 3641.39 58451-0-ADP MTEM 200.49 2028.98 196248 1628 085 1.50 11627.19 3640.64 P1.r%-CtCt � . 219.28 2003.93 1931.16 14.77 OSF 1.50 1210260 3633.96 5611.4 ICt 215243 224.:<l '®' 1927.74 14.43 OSF 1.50 12167.83 3631.33 MINPT-0-EOU 2157.08 230.01 2003.41 MEM 14.12 OSF 1.50 121326 3628.05 MinPt-0-ADP 2152 254.96 198202 1897.36 1271 OSF 1.50 12594.64 3604.13 Mn171-C1Ct 2130.41 269.46 1950.44 1860.941 OSF 1.50 12971.87 89833 MinPt-O-SF 39 311.45 1687.43 1583.94 9.15 OSF 1.50 14323.16 3610.41 MinPt-CICI 165.58 312.,- 1687.11 1583.36 9.13 OSF 1.50 14343.15 3610.27 MINPT-O-EOU 166.23 312.98 1687.a MEM 9.11 OSF 1.50 14363.13 3610.13 MinPt-0-ADP 1906.49 316.6 1695.06 1589.:. 9..: OSF 1.50 14483.74 3609.42 MnPt-0-SF 199516 321.97 178028 1673.- 9.r. OSF 1.50 15286.5 3597.52 MnPI-O-SF 2160.49 33324 1847.00 1736.: 9. OSF 1.50 15617.17 884.57 MinPI-0SF 2079.43 331.75 1857.93 1747.68 9.43 OSF 1.50 15749.8 830.95 TD 9906.67 74,37 966.75 983229 585 1.50 200202 1864.21 MinPI-0-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\S132-W2\SI32-W2\S132-W2(P6) 12/5/2012 11:21 AM Page 2 of 10 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 SD37-DSP1(Def Survey) Wertire)Alert 48.76 32.81 4753 15.95 N/A MAS=10.00(m) 045 045 CtCt<=15m<15.00 Enter Alert =321 32.81 43.52 14.121 20.91 MAS=10.00(m) 410.40 410.24 MinPts 47.39 32811 42.89 14.58 14.09 MAS=10.60(m) 480.04 479.60 MINPT-0-EOU 48.94 3281 43.21 16.13 10.59 MAS=10.00(m) 539.36 538.52 CtCt<=15m.55.00 Exit Alert 59.72 32.81 51.17 26.91) 7.99) MAS=10.00(m) 676.04 673.44 MinPt-0.SF 4455.21 32.81 4437.41 4422.41 264.84 MAS=10.00(m) 3568.22 2827.20 TD S125-N2(Def Survey) 63.96 32.81 62.73 31.15 N/A MAS=10.00(m) 0.00 0.00 Surface 1 60.241 32.81 56. 27.44 19.92 MAS=10.00(m) 459.06 458.73 MinPts 61.56 32.81 55.1 28.75 11.72 MAS=10.00(m) 548.50 547.88 MINPT-0-E00 101.30 32.81 80.00 68.49 4.99 MAS=10.00(m) 917.31 907.57 OSFG5.00 Enter Alert 118.47 3724 93.24 81.231 ) SF1.50 996.44 98288 MinPt-O-SF 123.09 38.03 97.32 85.05 4.97 SF 1.50 1016.22 1001.57 05815.00 Edt AIM 515.86 64.37 47261 451..,MOM SF 1.50 2783.56 2438.38 MinP5.0-SF 510.75 63.98 467.77 446. MIME SF 1.50 3190.91 2672.46 MinP1-0SF 509.05 63.78 466.20 445. l 3 SF 1.50 3212.77 2683.19 MinPt-0SF 457.94 47.62 425.. MEE 14.70 SF 1.50 3605.65 2839.85 MinPt-0-ADP 456.62 46.11 M.-:', 410.51 15.15 SF 1.50 3624.49 2844.46 MINPT-0-EOU r 7' 43.05 426.54 412.52 1621 SF1.50 366243 2855.20 MinPt-CtCt 721.34 67.38 676.09 653.•=MEE SF 1.50 4546.82 3001.61 MinPt-O-SF 3150.72 167.07 3039.02 2983...'M.: SF 1.50 8266.38 3538.57 MinPt-0-SF • 3061.05 156.22 2356._fir ( 29.57 SF 1.50 966.98 3643.60 MinP1-0-ADP 3059.80 154.==1 --• 1l 2905.15 29.86 SF1.50 9738.60 3644.52 MINPT-0-EOU 3290.87 206.,lam'/ 3084.66 24.05 SF 1.50 11312.03 3645.19 MINPT-O-EOU 3292.82 209.70 3153.=M=11IE 23.77 SF 1.50 11362.00 3644.20 MInPI.0-ADP 245.11 3133.51 3052.14 20.25 SF 1.50 12118.47 3628.84 MinPFCICI 3299.6 247.•la 3050.67 20.06 SF 1.50 12147.75 3627.21 MINPT-0-E00 111111=1E 261.30 3124.79 3038.01 19.01 SF 1.50 12459.49 3608.88 MInPt-CICt 3300.1. 292.29 3104.97 3007.87 16.99 SF 1.50 13357.22 3595.42 MinPt-C1C1 3300.82 294.,•Ijjjjjjr)!( 306.38 16.87 SF 1.50 13414.08 3595.09 MINPT-0-EOU 3301.56 295.31 3104.=lam-' 16.82 SF 1.50 13437.20 3594.95 MinPt-0-4.DP 3329.78 313.%r jam- 3015.98 15.96 SF 1.50 1396.62 3938.45 MINPT-0-EOU 3330.44 314.57 3120.r 3015. 15.93 SF1.50 13969.48 3609.36 Mi40t-0-ADP I3372 329.07 3153.28 3043.92 15.42 SF 1.50 14629.44 3908.25 MoPt-CICI 3393 338.41 3117.39 3004.92 14.86 SF 1.50 15299.04 3597.04 MinPI-CICI 3343.80 339..=IIIIDEM 3003.94 14.80 SF 1.50 15339.03 3595.47 MINPT-O-EOU 3344.38 340.59 31172* 3003.• 14.77 SF 1.50 15359.02 3594.69 MinPt-O-ADP 3374.41 349.79 3140.89 3024.w.MEM SF1.50 15616.97 3584.58 MinPt-0.SF 3390.57 405.8 MEM ' r'MEE' SF 1.50 15919.95 3580.17 MinPts SP23-N3PB1(Def Survey) Warring Alen 1®'-r 32.81 M:IiE=1M N/A MAS=10.00(m) 0.11 0.11 MinPts 101.98 32.81 87.27 69.17 7.47 MAS=10.00(m) 677.64 675.01 MINPT-0-EOU 116.42 35.86 9211 60.57 4.99 OSF 1.50 874.06 86607 050<5.00 Enter Alert 193.03 44.51 99.96 85.531 4.461 OSF 1.50 1000.6 96.77 MInP1-0-SF 156.76 48.02 124.33 108.73 4.99 OSF 1.50 1193.62 1166.50 OSF>5.00 Exit Alert 401.29 59.80 361.02 341.•MEE OSF 1.50 2506.57 2253.36 MinP5OSF 416.68 109.7.MEM==a Ilia OSF 1.50 2601.72 2319.84 MinPts 1230.25 76.70 1178.79 1153 a=EU OSF 1.50 4573.56 3005.58 MinPt-0.SF 4389.58 156.16 4285.15 4233. 42.. OSF 1.50 8279.59 3540.04 MInPt-O-SF 4456.73 250.07 4289.68 4206.66 26.83 OSF 1.50 11583.75 3641.28 TD 500567 134.57 4915.63 4871.10 55.2, OSF 1.50 5492.89 3141.88 MinP1-0-SF SP23413(Der Survey) a '`_ , )74M),T Warning Alen ®'.r 3261 1111.1ME IIIIIIIIIIIQ•v'^ N/A MAS=1.00(m) 0.11 0.11 MinPts 101.98 32.81 87. 69.17 7.47 MAS=1.00(m) 677.64 675.01 MINPT-0-005 116.42 35.6 92.11 80.57 4.99 SF 1.50 874.06 866.07 OSF•.00 Enter Alert 130.03 44.51 99.96 85.531- SF 1.50 1000.55 96.77 MinPt-0-SF 156.76 48.02 124.33 108.73 4.99 SF 1.50 1193.62 1166.50 OSF>5.00 Edl Alert 401.29 59.80 361.02 341.'r MEE SF 1.50 2506.57 223.36 MinPI-O-SF 416.58 109.7 EMEIE=..'.n,maga SF 1.50 2601.72 2319.84 MinPts 1230.25 76.70 1178.79 1153.'2 24..• SF 1.50 4573.56 3005.58 MinP1-0-SF 4389.58 156.16 4295.15 4233.•. 424. SF 1.50 8279.59 3540.04 MinP1-0.SF 41 482.6 223.83 4333.08 4258.79 30.17 SF 1.50 11946.89 3635.63 Mint-CICt 4483.60 226.2r lam,' 4257.00 29.80 SF 1.50 11984.75 3634.56 MINPT-0-EOU 4484.87 228.11 4332• l 29.61 SF 1.50 12005.64 3633.6 MinPI-0-ADP 9166.42 125.73 9082.28 9040.t MINIM SF 1.50 1361.31 1308.02 MinPt-0.SF 9229.49 124.42 914621 91052 =HU SF 1.50 2515.82 2259.95 MinPl-0.SF 4664.11 274.67 4480.67 4389., lam: SF 1.50 13032.84 3597.58 MinPt-0-SF 4702.93 295.. 4505.41 4407.14 23.92 SF 1.50 13757.89 3599.10 MINPT-0-EOU 4703.87 296.88 4505.x. 23.84 SF1.50 13787.79 3600.43 MinPI-0480)P 4751.79 319.87 4538.i. 226 SF 1.50 14617.54 3608.33 MinP1-0-ADP 4751.34 319.- 4538.1' 443205 2239 SF 1.50 14663.26 3608.01 MINPT-0-EOU r 99 318.18 4538.54 4432.81 2246 SF 1.50 1473.82 3607.38 M1Pt-CICI 4664.70 463.40 4355.44 4201.30r15.13 SF 1.50 16055.74 3579.75 TD 8574.53 212.31 843266 8362.211-1 SF 1.50 6780.34 3332.76 Min%-0.SF 0115-S4(0e1 Survey) Warning Alert 125552 386.04 995.57 869.48 4.95 OSF 1.50 8503.18 3563.29 85F<5.00 Enter Alert 1 1247.931 406.211 974.561 841.711 4.671 OSF 1.50 8525.30 3565.41 MinPls SP24-SE1(P2)(Def Plan) fir- 'o Pass 87.06 32.81 6.84 54.26 N/A MAS=10.00(m) 0.00 0.00 Surface • '' 3281 69.07 43. 12.22 MAS=10.00(m) 532.41 531.62 MinPts 76.73 3281 6.84 43.93 11.31 MAS=10.00(m) 551.03 550.08 MINPT-0-EOU 78.95 3281 70.15 46.141 28 MAS=10.00(m) 587.78 586.46 MinPt-0.SF 2232.76 66.01 2188.42 2166.75 51.48 OSF 1.50 3842.78 296.21 TD 1329.33 6.87 126.09 1263.-= EZ OSF 1.50 3478.12 2796.34 50nPt-0.SF 1302.42 63.1-1111=11111EZE 31.38 OSF 1.50 3524.92 281286 MinPls M' I 63.05 1260.01 1239.32 31.45 OSF 1.50 627.47 2813.73 MinPt-CICI SP22-FN1(P6)(Del Plan) 103.10 32.81 101.88 70.29 N/A MAS=10.00(m) 0.00 0.00 Suface 1 93.761 32.81 85.961 60.961 14.07 565=10.00(m) 542.33 541.46 MinPts 95.18 32.811 84.82 62.37 10.29 MAS=10.00(m) 598.15 596.71 MINPT-0-EOU 115.81 32.81 98.80 83.00 7.26 MAS=10.00(m) 723.06 719.53 MinP1-0-SF 5203.84 193.68 5074.40 5010.16 40.5% OSF 1.50 774262 3472.92 MinPt-0-SF 4996.20 171.51 4881. 4824.69 43.94 OSF 1.50 8260.28 3537.6 MinPt-O-ADP 496.50 170.6) 4881. 4824.82 44.15 06F 1.50 8274.90 639.52 MINPT-0-E0U 1-� 16.01 4881.91 4825.90 44.58 OSF1.50 8304.14 3542.75 MnPt-CtCt 2899.91 327.'NEM 111EME MESE OSF 1.50 14454.05 3609.48 MinPts 2485.98 340.89 2258.39 21452- 10.• OSF 1.50 15638.28 3563.77 MinPt-0SF 351.62 2172.92 2056.04 10.30 OSF 1.50 16261.71 3578.60 MInPt-CICt 2408.00 352=INEWE, 206.41 10.27 OSF 1.50 16291.63 678.13 MINPT-O-EOU 2408.53 353.24 2172.71 10.25 OSF 1.50 16311.57 3577.82 MinF1-0-ADP 2426.19 36.63 2180.11 9.89 OSF 1.6 16729.32 3571.49 MinPt-O-ADP 2480.95 393.62 2218.21 2087.c 9.4 OSF 1.50 17315.98 3578.44 MInPt-0SF 2620.96 430.02 2333.94 2190.93 9.16 OSF 1.50 18327.24 3583.40 TD 20461.27 6.70 20423.81 20405. 560." OSF 1.50 891.92 863.23 MInPt-0SF 20128.70 54.89 20091.78 460/4.81 560.0 OSF 1.50 896.12 887.27 Min151-0SF 13053.60 53.09 13017.88 13000.51 MEM OSF 1.50 1220.97 1191.47 MinF1-0SF 11260.73 63.10 11218.34 11197.,=EOM OSF 1.50 223214 2046.75 MInPt-0.SF 13148.02 70.97 13100.38 130772=MIME OSF 1.50 2429.42 2197.38 MinPt-0SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\S132-W2\S132-W2\S132-W2(P6) 12/5/2012 11:21 AM Page 3 of 10 Offset Trajectory Se•-.ration Allow Sep Controling Reference Trajectory Risk Level Alert Status MAS(ft) EOU 81 Dev.MI, Fact Rule MD(ft) 1 TVD(tt) Alert 1 Minor 1 Major 61.61 18206.11 18179.23 339.73 OSF 1.50 2646.23 2349.89 MinPts 111194N2(P2)(Dar Flop Pass 127.07 32.81 125.85 94.26 N/A MAS=10.00(m) 0.00 0.00 Surface 32.81 109. 84.47 18.11 MAS•10.00(m) 560.26 559.23 MinPts 117.57 32.81 109. 84.76 16.34 MAS•10.00(m) 586.00 586.68 MINPT-0-EO0 122.54 32.81 113.32 89.73 MEM MAS•10.00(m) 660.31 657.98 MinPt-O-SF 293.88 32.81 28245 261.0 MEW MAS•10.00(m) 1001.43 987.60 MinPt-0.SF 6177.89 189.89 6051.30 5988..MOE OSF 1.50 7958.00 3501.48 MinPt•0•SF 5679.31 144.80 5682 59.23 OSF 1.50 8878.97 3579.18 MinPt-0•ADP 5678.26 143.,MIZIM 5534.69 59.73 OSF 1.50 869.06 3580.52 MINPT-O-EOU W- 140.76 5583.17 5536.57 60.91 OSF 1.50 8731.36 3583.47 M8Pt-CtCt 8774.14 195.24 8643.66 8578.901- 4 OSF 1.50 6891.27 3349.20 64,49.0-01' 4309.70 446.49 4011.72 3863.22 14.51 058'1.50 18327.24 3583.40 TD 9D0.N4P81(Del Survey) Pee I 118.191 3261 116.101 85.381 135.43 MAS•10.60(m) 300.17 300.16 MinPts 118.33 32.811 115.961 85.52 102.53 MAS•10.00(m) 329.82 329.79 MINPT-0-EOU 200.77 45.70 169.89 155.07 EWE OSF 1.50 1096.02 1076.39 MinPt-0-SF 1894.62 49.94 1861.00 1844.•,Mt:1y; OSF 1.50 3096.43 2623.73 MinPt-O-SF 5120-N4(Del Survey) Pee I 115.191 32.81 116.10 85.381 135.43 MAS•10.00(m) 300.17 300.16 MinPts 118.33 32.811 115.96) 85.52 102.53 MAS=10.00(re) 329.82 329.79 MINPT-O-E00 200.77 45.70 169.89 155.07 6.73 SF 1.50 1096.02 1076.39 MinP1-0-SF 2117.49 4228 2088.97 2075.21 •-r2 SF 1.50 3137.89 2645.57 65n71•0-SF 6366.10 160.97 6258.46 6205.1•�^ SF 1.50 8255.07 3537.30 MinPt-0-SF 5793.15 137.35 5701.:MLIE 63.71 SF 1.50 9738.41 3644.52 MinPt-0-ADP 579228 136.. 5701., 565.98 64.20 SF 1.50 9773.52 3644.57 MINPT-0•E00 MM1E 14286 5691.39 5644.10 61.17 SF 1.50 10156.62 3636.56 MnP1-C1C1 149.73 5658.36 5638.78 58.36 SF 1.50 1035286 3631.93 MnPt-CtC1 5789.41 15251 565.90 57.30 SF 1.50 10391.78 3631.37 MINPT-0-EOU 5790.43 153.73 5687.m.NEM 5636 SF1.50 10409.06 3631.27 MinP1-0-ADP 7449.93 104.02 7380.25 7345.91 SE= SF 1.50 4927.41 3058.04 Min1,1-0SF 8506.02 116.58 8427.97 8389. =am SF 1.50 529021 3111.83 MinP1-0SF 591525 211.79 5773. bra,5, 4208 SF 1.50 11909.44 3636.44 MinP1-0•ADP 5984.94 242"MT= 5741.98 37.09 SF 1.50 12409.10 3611.61 MINPT-0-EOU 5985.44 243.55 58227'mmE 37.01 SF 1.50 12416.71 3611.16 MinPt-0•ADP 5998.06 255.),MIME 5742.18 35.29 SF1.56 1257213 3504.66 MINPT-0-EOU 5998.80 256.78 5827.= 35.17 SF 1.50 12583.49 3064.38 MinPt-0-A5P 6131.28 308.72 5925.1-IIII=a 29.88 SF 1.5 14770.26 3607.10 MinPt-0405P 6130.86 308. MUM) 5822.63 29.93 SF 1.50 14786,67 3606.94 MINPT-0-E09 MZUCE 307.42 5925.39 5823.25 30.00 SF 1.56 14813.21 3606.67 MinPt-CtCt mann 327.71 5883.63 5774.72 28.01 SF 1.56 15504.47 3588.99 MnPt-C6Ct 6103.01 329..WM 5773.75 27.88 SF 1.56 15546.95 3587.32 MINPT-0-E09 6103.65 329.99 5883. IffaZE 27.82 SF 1.50 15566.94 586.54 MinPt-0-ADP 6104.22 330. • 5883.4. 5773.79 27.79 SF 1.50 15690.29 582.14 MINPT-0.EOU IMEIME 329.79 5883.87 5774.27 27.84 SF 1.5 15717.36 3581.50 MnPI-CIC1 6067.66 376.66 5816.23 5691.00 24.22 SF 1.50 16229.97 579.08 TD 191 63..4 SF 1.50 3104.13 2627.83 MinPls SI17.SE2(P2)(Dot Plan) Pas 151.10 32.81 149.88 118.30 N/A MAS=10.00(m) 0.00 000 Surface 3281 129. 105. 17.79 MAS•10.00(m) 585.82 584.52 MinPts 15.26 32.81 129.21 106.45 17.51 MAS•10.00(m) 594.83 593.43 MINPT-0.EOU 14253 32.81 13261 109. •=ILE MAO•10.00(m) 66.23 662.82 MinPt-0-SF 347.29 3281 334.79 314.•M•'' MAS•10.00(m) 1000.87 987.07 MinFt•0SF 2178.45 56.57 2141.07 212287 59.83 OSF 1.50 2933.06 2530.91 TD 2028.41 85.55 1971.05 1942), 5.•4 OSF 1.50 2910.52 2517.31 MinPt-04F 1950.16 77.81 1897.•.,MEM 38.06 OSF 1.50 2921.06 2523.70 MinPt-O-ADP 1949.85 77.• 1897.:" 1872.40 38.23 OSF 1.60 2921.52 2523.97 MINPT-0-EOU 77.10 1898.03 1872.66 38.41 OSF 1.50 2921.98 2524.25 MnPI-CtCt S1,18-145(Def Survey) Pee MEE 32,81 NEM MEE N/A MAS•10.00(m) 0.23 0.23 MinPts Man 32.81 138. 62.98 MAS•10.00(m) 418.89 418.71 MinPts 143.46 32.81 137.4 110.6 29.81 9865•10.00(m) 537.51 536.68 MINPT-0-EOU 227.61 45.11 197.13 18251 7.7 OSF 1.50 1100.63 1080.68 MinP1-0-SF 7188.04 156.92 70133..,MEM 69.13 OSF 1.50 961667 364234 MinPI.0-ADP 7187.65 156. 7063., 703122 69.35 OSF 1.50 965.6 3642.69 MINPT-0-E0U MIMI 155.70 7083.28 7031.71 69.67 OSF 1.56 9646.69 3643.17 MrPt-C1Ct MIME 163.20 705226 6998.18 66.21 OSF 1.50 1038026 3631.49 MOPt-CICt 7161.58 163.'4 MialE, 8997.63 6.91 OSF 1.50 10390.61 3631.38 MINPT-0-EOU 716201 164.50 7052".1 6.89 OSF 1.50 10398.19 3631.32 MinPI-0-ADP 7216.36 187.' .0-'. 7028.42 57.89 OSF 1.50 10921.31 3649.94 MINP1'-0-EOU 7218.26 190.28 7091...NEM 57.19 OSF 1.50 10995.45 3649.65 MinPt.0-45P 8427.91 204.07 8291.54 8223.: MZ.M OSF 1.50 8045.17 51246 MinPI-0SF 8100.89 196.58 7969.51 7904.31 E OSF 1.50 8180.52 528.76 MinPl-0.SF 213.68 7118.37 7047.47 51.20 OSF 1.50 11708.34 3639.43 MnP1-CtCI 7261.67 215. 7046.26 50.79 OSF 1.50 11759.33 55.69 MINPT-O-E0U 228.33 7111.94 7036.15 47.92 06F 1.50 11976.87 534.80 68nPt-CICI 726.00 231.:MULE 7033.42 47.25 OSF 1.50 12010.73 3633.67 M8IPT-0.E05 7265.44 232.16 7110. 47.14 OSF 1.50 12016.77 533.45 MinP1-0-ADP 4331 257.55 7114.40 7028.87 42.59 OSF 1,50 12440.56 3609.84 kenPt-CICI 7286.80 258.,,=ME 7028.11 42.41 OSF 1.50 12454.00 3609.15 MINPT-0-EOU 7287.31 259.26 7114.1 7028..: 42.32 OSF 1.50 12460.72 3808.81 Mink-0.ADP 7477.32 319.34 7264.1.MIME 5.23 OSF 1.50 14630.10 3606.25 MinP1-0-ADP 7475.52 316."MEM 7158.53 35.48 OSF 1.50 1489262 3607.78 MINPT-0-EOU 7472.73 314.02 7263..-111115EIZIE 5.80 OSF 1.56 14767.72 3607.12 MinPI.0•ADP 7471.69 312. d•+'T, 7158.92 5.94 OSF1.50 14799.03 3606.82 MINPT-O-EOU I5j,• 311.49 7263.24 7159.74 36.09 OSF 1.50 14830.5 3806.49 k nPI-CtC1 7384.50 351.97 7149.53 7032.53 31.55 OSF 1.50 16389.10 576.62 TD 2914.91 75.67 2864.13 2839. • 58.5. OSF 1.50 2313.90 2110.38 MinPt-0SF MOE 52.• MIMIEM11:11EiliLE OSF1.50 2543.11 2279.23 MinPts SP18-N5PB1(Def Survey) PIP IIIIME 32.61 N/A MAS•10.00(m) 0.23 0.23 MinPts 32.81 138.3, 109.01 62.98 MAS•10.00(m) 418.89 418.71 MinPts 143.46 32.81 137.4 110.6 29.81 MAS•10.00(m) 537.51 536.6 MINPT-0-EOU 227.81 45.11 197.13 182.51 7.74 OSF 1.50 1100.63 1080.68 M1nPt-0-SF 7204.07 151.73 7102. 7052 71.68 OSF 1.50 9736.5 3644.51 MinPI-0•ADP 7203.56 151.11 7102.4 7052.45 71.96 OSF 1.50 9751.88 3644.57 MINPT-0-EOU 150.30 7102.75 7052.98 72.5 OSF 1.50 9772.19 3644.57 MnPt-Clef MIME 157.21 7090.79 7038.72 69.08 OSF 1.50 10252.15 3634.30 MnPI-CICt 7196.16 158.., 6.70 OSF 1.5 1028211 3633.59 MinPts 11 181.36 7128.21 7068.09 6028 OSF 1.50 10715.84 3642.14 MnPt-CtCt 7251.80 188. MUIE11.E 706283 57.6 OSF 1.56 10961.10 3650.02 MINPT-0-E00 7254.40 200.05 7120.70 7054.34 54.66 OSF 1.50 11230.09 3646.34 TD 2914.91 75.67 2864.13 2839.. 56 - OSF 1.50 231390 2110.38 MinPt-0SF E 53."Mil OSF 1.50 2543.11 2279.23 MinPts SP16-FN3(Def Survey) he ,,3 I 151.04 32.81 146. 11621 4034 MAS•10.00(m) 501.15 500.59 MinPts 151.37 32.81 145. 118.57 33.74 MAS•10.00(m) 538.19 537.36 MINPT-0-EOU 165.37 32.81 157.62 132,MEC MAS•10.00(m) 680.71 678.03 MinP1-0-SF 464.28 32.81 451.68 431.•MEE MAS•10.00(m) 1099.29 1079.44 MinPt-O-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\5132-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 4 of 10 Offset Trajectory Separation Allow Sep. Contro8inp Reference Troia-W.ry Risk Level Alert Status Ct-Ct(ft)I MAS IR)I EOU(R) Dev.(ft) Fact, _ Role MD(R) I TIM(ft) Alert I Minor I Major 6469.46 177.77 6150.62 6291.69 54.86 SF 1.50 7986.08 3505.06 1.4.46-OSF 5889.98 136.72 5798.51 5753.26 46.08 SF 1.50 8689.54 3580.06 MinPt-0-ADP t 5889.54 136.191 5798.4 5753.5 65.33 SF 1.50 8697.20 3580.69 MINPT-0-EOU t aat 13276 5799.16 5756.23 67.01 SF 1.50 8747.03 3584.72 MnPt-CtCt 4711.39 8283 455.84 4628.a MZE SF 1.50 596.64 2923.04 MinPt-O-SF 4981.44 87.45 492282 4894. .-- r5 SF1.50 4151.56 2943.01 MinPt-O-SF 506275 88.86 5003.18 4973. M-- r5 SF1.50 4198.24 2949.93 MinP1-0-5F 8988.05 170.70 8883.92 8827.:MTEt SF 1.50 650269 3291.59 Min%-0SF 11 1 367.72 4721.71 4599.46 20.31 SF 1.50 16791.36 3571.78 M,Pt-C1Ct 4968.80 373,III 4594.91 19.98 SF 1.50 16960.21 574.30 MINPT-O-EOU 4975.75 391.'MaCrE 4584.04 19.10 SF 1.50 1755.75 3578.33 MINPT-O-E00 4976.93 393.16 4714.,l= 19.03 SF 1.50 17395.66 578.21 MinPt-O-ADP 4980.27 397.,E 4583.05 18.85 SF 1.50 17505.57 3577.89 MINPT-O-EOU 498288 400.34 4715.-'Mff= 18.71 SF 1.50 17590.22 577.5 MinPt-O-ADP 4986.13 404.8 jl j 4581.26 18.51 SF1.50 1771538 577.28 MINPT-0-EOU 4987.36 406.33 4716.1 /11a10 18.45 SF 1.50 17756.45 3577.16 MinPt-O-ADP 5033.16 426.45 4748.53 4606.71 17.74 SF 1.50 1832724 583.40 TD MiEZIAZ 76.'-III MIME SF 1.50 2998.31 2569.24 MinPts 5113-F64(Def Survey) Pass MEM 32.81 166. 141. 23.12 MAS=10.00(m) 549.27 548.34 MinPts 177.27 3281 164. 144.46 15.05 MAS=10.00(m) 640.83 638.81 MINPT-0-EOU 182.23 3281 166.48 149.-• 124 MAS=10.00(m) 702.39 699.29 MnPt-OSF 6228.48 13884 615." >:r 2)-j 67.76 OSF 1.50 9525.46 3638.64 MinPt-O-ADP 6227.86 138.11 615.t 6089.76 68.12 OSF 1.50 9544.48 3639.56 MINPT-O-EOU X11 133.78 6137.13 609286 70.32 OSF 1.50 9651.85 3643.29 MnPt-CtCt 6936.71 17201 6821.70 6764.• Mlan OSF 1.50 8087.91 3517.71 MinPt-0SF - 7(- - 220.46 5906.47 5833.32 41.37 OSF 150 12050.02 3632.12 MnPt-CtCt 6054.72 223. 8905. 5831.18 40.80 OSF 1.50 12084.68 3630.55 MINPT-0-EOU 6055.76 224.76 5905. 5831.' 40.59 OSF 1.50 12098.50 3629.87 MinPt-0-ADP 5923.76 84.56 5867.06 5839.2C •0627 OSF 1.60 4066.47 2930.40 MinPt-O-SF 8639.96 124.16 8556.86 8615.80\ 105.21 OSF 1.50 5267.02 3108.39 MinPt-O-SF 13939.82 168.04 13627.47 13771.78 125.16 OSF 1.50 6513.01 3293.12 Min71-0-SF 14390.04 173.59 14263.99 14206. 114.% OSF 1.50 6664.60 3315.60 MinP40.SF 14646.07 176.77 14527.89 14469.30 124.97 OSF 1.50 6751.60 3328.50 MinPl-0-5F 6174.25 306./m$':/9. 5867.67 30.30 OSF 1.50 14215.49 3611.17 MINPT-0.EOU 6175.79 308.47 5969.81 M-- r'•. 30.12 OSF 1.50 14264.49 3610.83 MinPl-0-ADP 6181.39 314.48 5971.41 VIII J 29.57 OSF 1.50 14421.17 3609.72 Min1/1-0-6DP 6181.40 315.01 5971.,'( 29.52 OSF 1.50 14504.15 3609.13 MinPI-0-ADP 6181.05 314.<11111ZEE 5966.46 29.56 OSF 1.50 14521.08 3609.01 MINPT-0-EOU M,MIEE 313.72 5971.34 5867.10 29.64 OSF 1.50 14554.93 3608.77 M.Pt-CICt 349.69 585084 5734.61 26.17 OSF 1.50 16438.13 575.85 M.Pt-C1C4 608473 351.1 NEM 5733.60 26.06 OSF 1.50 16477.61 3575.24 MINPT-O-EOU 6085.37 351.85 5850.4 5733. • 26.01 OSF 1.50 16497.38 3574.93 MnPI-0-ADP 6290.68 42234 6006.79 5868.34 2239 OSF 1.50 18327.24 3583.40 TD 73.'Milia-Ez Mils- Ed=IIIIEEM OSF 1.50 3188.73 2671.38 MinPts 511446(P2)(Def Pi n) Pen 175.01 3281 173.78 14220 N/A MAS=10.00(m) 0.00 0.00 Surface =1121ZE1 3281 17Z'' 5.'' 21558 MAS=10.00(m) 200.00 200.00 MinPts 175.03 32811 14222 20512 M6S=10.0099) 230.05 23805 MINPT-O-EOU 175.34 3281 11111ERIEt 14253 163.62 MA5=10.80(m) 309.98 309.97 MINPT-0-E00 243.25 43.88 213.59 199. 851 OSF 1.50 1096.79 1077.10 MinFl-0.SF 8485.42 129.45 898.:• 9907 OSF 1.50 9717.20 3644.37 MinPt-O-ADP 8485.21 129.1• 8398. • 856.02 99.27 OSF 1.50 9726.55 3644.45 MINPT-0-EOU IIIIMME 128.55 8398.95 8356.43 99.76 OSF 1.50 9749.95 3644.57 MnPI-435t M. , ..Jr 15243 8354.30 8303.82 8175 OSF 1.50 10555.22 3634.25 MnPI-C4Ct 10214.93 19262 10086.19 10022.311 OSF 1.50 7967.23 350266 MinPt-O-SF 19855 8324.02 8258.16 64.20 OSF 1.50 11900.09 3636.61 M.PI-CtCt 8458•60 203.l't 1111aM 8254.62 6253 OSF 1.50 11956.60 3835.41 MINPT-0-EOU 8460.94 206.81 83227 IE 61.5 OSF 1.50 11986.25 3634.51 MinPt-O-ADP 8673.07 30258 8471.'4 . 43.13 OSF 1.50 14581.61 3608.58 MinPt-O-ADP e 867259 302" 8470.•, 8370.59 43.21 OSF 1.50 14596.43 3608.48 MINPT-O-EOU r vc 1 300.42 8471.44 8371.63 43.44 OSF 1.50 1465.96 3608.20 MnPI-C1Ct 855.88 343.56 8306.51 819232 37.37 OSF 1.50 16648.89 3572.57 TD i 5886.38 63.30 584186 5823." OSF 1.50 1366.13 1320.10 MinPt-O-SF 3996.97 46.67 3965.51 3960.31 Imo: OSF 1.50 2009.18 1866.00 MinPt-O-SF 3875.71 45.21 3845.22 3830.•=HL OSF 1.50 2040.43 1891.88 MinPt-O-SF 383258 44.76 380239 3787.'-Man OSF 1.50 205200 1901.43 MinPt-O-SF 3764.03 44.28 3734.15 3719.`11 l OSF 1.50 2071.13 1917.15 MinPt-O-SF 3706.26 43.83 3675.69 3661., MEM OSF 1.50 2088.53 1931.40 MinPt-O-SF Milia 45.''Imo2 IIM IMEilliE OSF 1.50 2485.93 2224.09 MinPts SP12-003(P2)(Def Plan) Pas 206.15 32.81 204.93 173.34 N/A MAS=10.00(m) 0.00 0.00 Surface 1 198.301 32.81 189.79 165.49 27.05 MAS=10.00(m) 565.85 564.77 MinPts 198.42 32.81 189. 165.61 25.24 MAS=10.00 On) 583.85 58257 MINPT-O-EOU 211.54 3281 200.42 178.741 21.241 MAS=10.00(m) 720.68 717.20 MinPt-0.4F r 90 68.65 2658.77 2636.25 60.02 OSF 1.50 245270 2214.46 MnP1-CtCt 2705.25 69.'lE- 2635.68 59.22 OSF 1.50 2454.02 2215.42 MINPT-O-EOU 2705.65 70.02 2658.61 5483 OSF 1.50 2454.67 2215.89 MInPt-0-ADP 2934.85 93.25 28725 2841.n' 47.. OSF 1.50 2510.22 2255,96 MinPt-O-SF 10091.89 94.06 10028.86 9997.83 16263 OSF 1.50 2669.21 258.53 TD 6108-FN6(P3)(Del Plan) Pass 1 214.121 32.81 211.1 181.311 14294 MAO=10.00(m) 339.24 339.21 MinPls 215.41 32.811 208. 18260 38.11 MA2710.0 On) 569.23 568.11 MINPT-0-E50 250.32 3281 237.78 217.51 MEE MAS=10.00(m) 820.15 814.03 MInP1-0SF 8255.47 162.59 8146.74 8092. Ili OSF 1.50 8426.80 3555.71 MinPI-0.SF 9100.98 330.97 8880.01 8770.,.=MU OSF 1.50 14570.86 3608.66 MinPt-O-SF 9158.97 446.78 8860.79 871219 30.81 OSF 1.50 18327.24 3583.40 ID 919570 333.-+ '�'. '.Man OSF1.50 14462.87 3609.42 MinPts SPIO.FN5(Def Survey) Pas 1 122.261 32.81 220.96 189.451 2904.17 MAS010.00(m) 66.18 6.18 MinPts 222.43 32.811 220.84 189.63 592.44 MAS=10.00 On) 140.18 140.18 MINPT-0-EOU 11 32.81 22222 194.141 64.52 MA0=10.00(m) 501.10 500.54 MinPts 227.47 32.811 221.56 194.66 4825 MAS=10.00(m) 547.20 546.29 MINPT-O-EOU 250.53 3281 239.74 217.721 26.071 MAO=10.00 On) 779.82 774.88 MinPt-O-SF 1 r 145.81 6643.36 595.09 69.81 OSF 1.50 10428.85 3631.26 Me/Pt-ClOt 6741.89 148.' 6593.82 68.75 OSF 1.50 10457.13 3631.48 66NPT-O-EOU 6744.94 152•jC 659260 66.83 OSF 1.60 10510.33 363259 MINPT-0-EOU 6746.16 153.81 6643.•'ManEt 66.21 OSF 1.50 10528.13 3633.17 MinPt-O-ADP 6778.19 182-'' 6595.21 55.86 OSF 1.50 11351.77 3644.63 MINPT-O-EOU 6779.72 184.76 6656..-WIZIE. 55.33 OSF 1.50 11400.42 3643.94 MinP1-0-ADP 7681.90 15.93 7570.95 7515.9 111.1111M OSF 1.50 8151.94 3525.40 Min111-0.6F 6789.12 197.' x/ E 59209 51.94 OSF 1.50 11746.50 3638.88 MINPT-0-EOU 6792.95 202'•MEM 690.47 50.56 OSF 1.50 11891.03 3636.75 MINPT-O-EOU 6794.50 204.31 6657.-' ' 50.12 OSF 1.50 11911.09 3636.41 MinPt-0-ADP 7216.13 308.75 7009.97 6907.:MCffi OSF 1.50 14522.87 3609.00 Min71-0-SF 7193.20 30244 6991.,11111=XE 5.79 OSF 1.50 14742.29 3607.5 MnPt-0-ADP 7192.48 301.:E 690.90 5.89 OSF 1.50 14768.23 3607.12 MINPT-S-E0U Man 298.25 6992.24 6893.15 36.28 OSF 1.50 1486.36 3606.11 MnPt-C1C1 MEE 323.17 6957.61 685021 33.39 OSF 1.50 15579.58 586.05 MnPI-CtCt 8990.00 90.80 8929.14 8899..'�r OSF 1.50 4293.65 2964.08 MinPt-0.SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 5 of 10 Offset Trajectory Separation Mew Sep Controlling Reference Trajectory Risk Level Alert Status Ct•Ct(ff)I MAS(ft)I EOU(1t) Dev.(II) Fact. RIIIe MD(tt) I TVD(ft) Alert I Minor I Major 9037.41 91.28 8976.24 8946.14 150.12 OSF 1.50 4309.03 2966.36 MnPI-0-SF 12579.58 110.76 12505.41 12468.82` 171.88 OSF 1.50 4919.31 3056.84 MinPt-0-SF 16625.84 158.11 16520.10 16467.73 158.71 OSF 1.50 6265.48 3256.42 Mm%-O•SF MEM 351.21 6912.53 6795.79 30.61 OSF 1.50 16631.97 3572.83 Mi,Pt-CtCt 7147.75 353.71 6911.61 6794.04 30.39 OSF 1.50 16690.18 3571.80 MINPT-0-EOU 7148.01 354.02 6911.• M:: 30.37 OSF 1.50 16702.96 3571.74 66nPI-O-ADP 7457.08 416.35 7179.18 7040. • 26.' OSF 1.50 18327.24 3583.40 Min%-0-SF SP11-N7(P48)(Del Plan) 1 Pre 238.19 32.81 236.96 205.38 N/A MAS=1.00(m) 0.00 0.00 Surface I 238.191 32.81 236.1 205.38 300.51 MAS=1.00(m) 20070.00 200.00 MinPts 238.19 32.81 236.1 205.38 296.36 MAS a 1.00(m) 210.02 210.02 MINPT-0-EOU 354.68 44.95 324.31 309. 121 SF 1.50 1095.18 1075.60 MnPt-0-SF 9669.37 167.15 9557.61 la= 87.28 SF 1.50 9750.47 3644.57 1.1oPI-0-A02P 9669.35 167.1• 9557.61 950223 87.29 SF 1.50 9754.32 3644.58 MINPT-O-EOU NE= 167.08 9557.62 950225 87.31 SF 1.50 975617 3644.58 Mln%-CICt • -y 180.15 952247 946275 80.72 SF 1.50 10537.01 3633.50 MInPI-CICt 11245.87 203.59 11109.81 11042 l SF 1.50 8080.20 3516.77 11,P1-0-SF 10708.88 193.12 10579.80 10515.• ) SF1.50 8234.12 3534.94 MnP1.O-SF III 213.04 9504.68 9433.99 68.23 SF 1.50 1189242 3536.73 MInPt-CICt 9648.19 216.41Zrs 9431.78 67.17 SF 1.50 11937.99 3635.85 MINPT-0-EOU 9649.63 218.12 9503.0%1) 66.65 SF1.50 11960.77 3335.27 MnPt-O-ADP 9868.18 300.50 9667.5. ; 49,42 SF 1.50 14591.36 3608.52 Mt481-0-ADP 9867.64 2938 L 9567.77 49.52 SF 1.50 14607.73 3608.40 MINPT-O-EOU r-, 298.75 9667.74 9568.49 49.70 SF 1.50 14636.38 3608.20 MInPt-CICt 9720.66 341.33 9492.78 9379.33 42.84 SF 1.50 16744.30 3571.45 TD 5484.06 104.27 5414.22 5379.7' 79.44 SF 1.50 1373.85 1327.70 MinPt-O-SF 4875.62 67.55 4830.23 4808., 109.-0 SF 1.50 1652.99 1566.58 Min%-0-SF MEM 58.'<ME7-EL MEM M:' IJj SF 1.50 2416.67 2187.96 MinPts S107-SE4(P2)(Del Plan) P.O 246.15 32.81 244.92 213.34 N/A MAS=10.00(m) 0.00 0.00 Solace 32.81 238.1 211 51.42 MAS 410.00(m) 472.57 47217 MinPts 244.89 3281 236. 212.08 36.43 MAS•10.00(m) 537.10 53627 MINPT-0-EOU 275.34 32.81 263.33 24254-q MAS•10.00(m) 747.88 74378 MinP1-0-SF 17..'".4 67.49 3533.63 3511.49 80.80 OSF 1.50 212272 1959.23 MnPt-CICt 357640 68..s j 3510.58 79.22 OSF 1.50 2128.16 1963.60 MI6PT-O-EOU 3579.98 5950 3533.•MODE 78.45 OSF 1.50 2130.84 1960.81 MinPI-0-ADP 4063.85 108.98 3990.87 3954.:+ 56. OSF 1.50 229643 2096.92 MinPI-0-SF 10535.90 121.76 10454.40 10414.15 130.84 OSF 1.50 2540.08 2277.11 TD SPO5-FN7(P5)(Def Plan) Pap 270.26 32.81 269.03 237.45 N/A MAS•10.00(m) 0.00 0.00 Surface 1 269.321 32.81 265.77 236.511 115.17 MAS•10.00(m) 425.23 425.03 MinPts 269.83 32.81 265.17' 237.02 78.10 MAS•10.00(m) 491.04 490.54 MINPT-O-EOU 270.22 32.81 265.16 237.41 70.25 MAS•10.00(m) 509.56 508.95 MINPT-0-EOU 328.51 32.81 315.86 295., Z3M MAS•10.00(m) 826.02 819.71 MinPt•0-SF 8522.84 162.07 8514.46 8460. �-.,%' OSF 1.50 8455.71 3558.63 MinP1-0SF 9434.08 337.91/.: :•M=IE 42.00 OSF 1.50 15337.25 3595.54 MIPIs 9533.48 330.70 9312.69 9202• OSF 1.50 1480253 3608.44 MinP1-0SF 9902.47 448.27 9603.34 9454.27 33.21 OSF 1.50 18327.24 3583.40 70 19531.66 39.93 19504.71 19491. 7521' OSF 1.50 699.14 336.11 MinPI.0-SF 1881628 38.49 18790.30 18777.• 752 OSF 1.50 727.07 723.44 MInP1-0SF 18634.25 37.97 18608.62 18596.:WZE OSF 1.50 730.40 726.70 M1nP1-0SF 18567.43 37.83 18541.88 18529.• 755.7. OSF 1.50 731.79 728.06 MinP1-0SF 18472.00 37.65 18446.57 18434. 755.7 OSF 1.50 733.79 730.02 MInP1-0SF 18386.15 37.48 18360.84 18348.0• 755. OSF 1.50 735.61 731.79 M1nP1-0SF 1773300 35.96 17708.70 17697.,: 760.- OSF 1.50 752.29 748.07 MinP1-0SF 17666.55 35.82 17642.34 17630. 702 • OSF 1.50 753.80 749.55 MinPt-0SF 1665279 33.80 16629.93 16618.'= 761.1- OSF1.50 776.97 772.12 M1nP1.0SF 16567.26 33.63 16544.51 16533=•• 761.1 OSF 1.50 778.56 773.66 MinP1-0SF 16472.27 33.45 16449.64 16438... 761 1. OSF 1.50 780.34 775.39 MinP1-0-SF 16245.24 32.81 16223.04 16212. 765.•• MAS•10.00(m) 785.21 780.13 MinPI.0SF 16151.13 32.81 16129.06 16118.••li -`� MAS•10.00(m) 787.56 782.41 MinPl-OSF 16047.69 32.81 16025.76 16014.•: ., MAS•10.00(m) 780.16 784.94 MinP1.0SF 15944.34 32.81 15922.54 15911.-n MAS•10.00(m) 79279 787.49 MinPI-0SF 15889.23 32.81 15847.52 15836.• MAS•10.00(m) 794.71 789.36 MinPI-0SF 15822.29 32.81 15800.65 15789. MAS•10.00(m) 785.91 790.53 MinP1.0SF 157,021 3281 15725.67 15714., .'' MAS•10.00(m) 797.83 79238 MinP1-0SF 15503.53 3281 1548229 15470. •I MAS•10.00(m) 804.13 798.50 MinP1-0SF 1448270 3281 1446276 14449.:•NEM MAS•10.00(m) 834.86 828.26 MinPI-0SF 9563.51 324.02 9337.16 9229.. 44.• OSF 1.50 14194.74 3611.32 MinP1-0-SF SP04SE5(P2)(ON Plan) Pass r-� 3281 275.59 245.291 215.28 MAS=10.00(m) 309.99 309.93 MnPls 278.34 32811 275.33 245.54 155.17 MAS•10.00(m) 377.77 377.68 MINPT-0-EOU 279.34 32811 275.09 246.53 91.97 MAS830.00(m) 454.68 454.36 MINPT-O-EOU 349.13 32.81 334.23 316.••=OM MAS•1600(m) 867.27 858.53 MinPt-OSF 5519.89 120.20 5439.43 5399,Mr= OSF 1.50 2174.79 2001.19 MinPl-O-SF 11060.34 14509 10963.29 10915.25 115.12 OSF 1.50 2423.38 2192.92 TD 502-056(P2)(Del Plan) Pass 294.13 32.81 292.91 261.32 N/A MAS=10.00(m) 0.00 0.00 Surface 1 294.134 32.81 3921..1113310 363.27 MAS•10.00(m) 200.00 MAX MinPts 294.35 3281=DM 261.54 243.53 MAS.10.00(m) 290.20 290.19 MINPT-0-EOU 294.57 3281a 261.76 198.24 MAS•1000(m) 319.55 319.53 MINPT-O-EOU 41225 3281 397.33 379. MEM MAS•10.00(m) 850.18 843.06 MirP1-0SF 6970.73 158.84 6864.51 6811.0•j OSF 1.50 2100.46 1941.14 814nPt-OSF 11679.02 192.11 11550.62 11486.91 91.65 OSF 1.50 232257 2117.04 TD SP0I-5E7(P2)(Del Plan) Pass 302.24 32.81 301.02 26643 N/A MAS=10.00(m) 0.00 0.00 Surface 1 302.201 32.81 299.7/n 247.41 MAO=10.00(m) 300.26 300.24 MinPts 30233 3281 NW= 269.53 199.79 MAS=10.00(m) 338.97 338.94 MINPT-O-EOU 448.43 3281 430.66 415.. MAS•10.00(m) 928.06 917.85 Mi1%-0-8F 8674.14 187.11 8549.08 8487.,c m:-." OSF 1.50 2069.64 1915.93 814/481.0-SF 11760.70 220.69 11613.25 11540.01 80.29 OSF 1.50 2218.89 2036.29 TD Tuvpq ST 1(De!Survey) Pass ACME 32.81 4924.40 MralE 7157.20 MAS=10.00(m) 169.07 16607 MlnPls 4927.12 32.81 Mr= 4894.31 5717.49 MAS.10.00(m) 199.07 199.07 MINPT-0-EOU 4939.72 32.81 M=E. 4906.91 33278 MAS•10.00(m) 86206 854.51 MINPT-0-EOU 494296 32.81 4910.15 27299 MAS•10.00(m) 930.19 919.89 MINP1'-O-EOU 1401.47 90.16 1340.77 1311.,ME OSF 1.50 8517.70 3.564.68 MnPt-0SF 484.62 136.64 392.99 347.': OSF 1.50 11111.23 3648.02 P9691-0-5F 483.05 135.81 391.9 MIME 5.38 OSF 1.50 11165.28 3647.26 141,P1•0-ADP l�48293 136.0- 391.•0 347.29 5.39 OSF 1.50 11174.31 3647.13 MINPT-0-EOU 1 135.30 39209 347.53 5.40 OSF 1.50 11192.39 3646.87 MI1PI-0CI 1338.78 120.15 1258.15 1218.. 111111111M OSF 1.50 13714.33 3597.17 814485-0SF 2411.50 161.56 2303.26 2249.• MEE OSF 1.50 15797.43 3580.54 FAMP1-0-SF 3810.34 234.50 3653.47 3575.84 24.53 OSF 1.50 18327.24 3583.40 TD =1 222.,•M=Fli Wit. OSF 1.50 17836.02 357727 MinPts OP09-S1(Del Survey) Pass 15759.60 85.14 15702.25 15674..•�' - OSF 150 4965.23 3063.65 MinPt-0-SF 15781.57 85.25 15724.15 15696. .MEM OSF 1.50 4974.38 306500 9021.0-5F Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\S132-W2\S132-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 6 of 10 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 1585233 8658 15794.71 15766.75 283.52 OSF 1.50 5003.35 3069.30 M1n%-0-SF 15986.20 86.22 15928.17 15899.98 283.50 OSF 1.50 5056.62 3077.20 Min Pt-O-SF 16004.01 86.39 15945.85 15917.63 283.50 OSF 1.50 5063.62 3078.23 M81%-0-SF 16103.70 86.89 16045.22 16016.82 283.41 OSF 1.50 5103.13 308409 Min%-0-SF 801.93 158.59 695.88 643.35 7.62 OSF 1.50 5166.74 3093.52 M1n191-0-SF 801.62 158.47 695.64 643.15 7.63 OSF 1.50 5176.80 3095.01 M9n%-0-ADP 801.57 158.411 695.64 643.16 7.63 OSF 1.50 5181.17 3095.66 MINPT-0-EOU 1 801.571 158.40 695.64 643.17 7.63 OSF 1.50 5181.86 3095.76 M81%-CtCt 1600.13 152.25 1498.31 1447.89 1686 OSF 1.50 6075.53 3228.26 TD Kgtan 1(Del Survey) 4894.261 Pas '1 32.81 4924.46 4894.261 7157.20 MAS=10.00(m) 169.07 169.07 MinPts 4927.12 32.81 4924.34 4894.31 5717.49 MAO=10.00(m) 199.07 199.07 MINPT-0-EOU 4939.72 32.81 4922.96 4906.91 332.78 MAS=10.00(m) 862.06 854.51 MINPT-0-EOU 4942.96 32.81 4922.94 4910.15 272.99 MAO=10.00(m) 930.19 919.89 MINPT-0-000 965.37 114.78 888.26 850.591 12.791 OSF 1.50 8198.56 3530.86 M'm%-0-OF 960.86 113.70 884.481 847.17 12.85 OSF 1.50 8221.01 3633.44 Min%-0-ADP 980.73 113.531 884.46 847.21 12.87 OSF 1.50 8223.74 3533.75 MINPT-0-EOU 1 960.701 113.35 884.55 847.35 12.89 OSF 1.50 8226.45 3534.06 Min%-CtCI 5522.33 66.13 5477.66 5456.20 128.65 OOF 1.50 9039.57 3505.65 TD t6gun 1 P81(De(Surrey) r Pets 32.81 4924.44 4894.1 7157.20 MAS=10.00(m) 169.07 169.07 M1n%s 4927.12 32.81 4894.31 5717.49 MAS=10.00(m) 199.07 199.07 MINPT-0-EOU 4939.72 32.81 4906.91 332.78 MAO=10.00(m) 862.06 854.51 MINPT-0-EOU 4942.96 32.81=MC 4910.15 272.99 MAS=10.00(m) 930.19 919.89 MINPT-0.EOU 1 1277.821 105.22 INKRE111113E0 MEM OSF 1.50 8019.22 3509.23 MinPts 0P10419(De(Stavey) Pas MIEZME 32.81 MIEME.MIEEM N/A MAO=10.00(m) 0.97 0.97 MinPts 17860.79 32.81 MIME 17827.99 14974.85 MAS=10.00(m) 213.38 213.38 MINPT-O-EOU MEZIE 32.81 17858.- 17827.•: 15129.48 MAO=10.00(m) 216.11 216.11 MinPts • 405.73 2361.25 2228.22 9.87 OSF 1.50 8568.23 3569.43 Mm%-CtCt 2634.96 408. 2360.2 2226.14 9.80 OSF 1.50 8591.14 3571.52 MINPT-0-EOU 2636.62 410.85 2360.5 2225.77 9.76 OSF 1.50 8606.40 3572.89 Min%-0-ADP 2732.45 440.22 2437.14 2292. 9.411 OSF 1.50 8870.09 3593.83 Min%-O-OF 2737.50 440.99 2441.67 2296.51 9.41 OSF 1.50 8895.55 3595.61 TD 0113.93(Del Survey) Pass 1 4135.141 402.27 3865.05 3732.87 15.62 OSF 1.50 8600.02 3572.31 MnPt-CtCt 4135.77 404.191 3864.42 3731.58 15.55 OSF 1.50 8614.23 3573.58 MINPT-O-EOU 4136.75 405.33 3864.65 3731.44 15.50 OSF 1.50 8622.77 3574.34 Mit45t-O-ADP 4140.77 411.311 3864.73 3729.46 15.28 OSF 1.50 8668.38 3578.28 MINPT-O-EOU 4142.00 412.77 386.01 3729.231 15.23 OSF 1.50 8679.78 3579.24 MinPt-0-ADP 1 4224.291 449.13 3923.30 3775.15 14.24 OSF 1.50 9397.12 3630.59 Min%-C8C8 4224.60 450.31 3922.8- 3774.28 14.20 OSF1.50 9434.38 3633.19 MINPT-O-EOU 4225.02 450.86 3922.8•=Ma 14.19 OSF 1.50 9442.10 3633.72 MinPt-O-ADP 19 538.-6 IllaM MUNI ME3:? OSF 1.50 11292.54 3645.46 Min%s OP17-02(Del Survey) pus MERE 32.81 17872. 17841.21 41441.67 MAO=10.00(m) 114.82 114.82 MinPts 17874.14 32.81 17872.2 17841.33 27740.59 MAS=10.00(m) 140.85 14085 MINPT-0-EOU 17874.33 32.81 17871.97 17841. 15660.2' MAS=10.00(m) 213.40 213.40 MinPt-O-SF MEEK 32.81=MI E 15691.52 MAS=10m(m) 218.85 218.85 MinPts 17874.33 32.81 17871.96 17841.5. 15681.0 MAO=10.00(m) 225.15 225.15 MnPt-0-SF 1 5646.161 404.66 5374.65 5241.50 21.18 OSF 1.50 8520.93 3564.99 Mn%-C8Ct 5646.79 406.41 5374.1 5240.38 21.09 OSF 1.50 8532.21 3566.06 MINPT-0-EOU 5647.69 407.45 5374.39 MEDEE 21.04 OSF 1.50 8538.97 3566.70 Min01-0-ADP 5713.80 422.90 5430.28 5290.•6 20. OSF 1.50 8645.53 576.33 Min%-O-SF O017-02PB1(Def Savoy) J Pas 1 17874.04 32.81 17872.:MIMED 41441.50 MAS=10.00(m) 114.82 114.82 MinPts 17874.14 32.81 INKEIEfi 17841.33 27740.51 MAS=10.00(m) 140.85 140.85 MINPT-O-EOU 17874.33 3281 17871.97 17841. 15660.2 MAS=10.00(m) 213.40 213.40 Mn%-0.SF NOME 32.81 : :I MEM 1569162 MAS=10.00(m) 218.85 218.85 MinPts 17874.33 32.81 17871.96 17841. • 15681.0 MAS=10.00(m) 225.15 225.15 MinPt-O-SF MIME 392.86 5470.64 5341.48 22.18 OSF 1.50 8444.78 3557.53 MnPI-CtCt MMEU 406.06 5456.43 532278 21.41 OOF 1.50 8527.23 3565.59 Mn%-CtCt 5731.45 111. 5455.6 5319.88 21.13 OSF 1.50 8563.00 3568.94 MINPT-0.EOU 5732.01 412.25 5455.51 -�' 21.09 OSF 1.50 8567.47 3569.35 1060-0-ADP 5827.46 444.37 5529.85 5383.6: 19.:• OSF 1.50 8811.62 3589.65 Min%-0-SF 01,12-01(Del Stevey) Pan MIEIMC 3281 -•.):�M:•�'MEMO MAS=10.00(m) 20713 200.13 MinPts 596.76 166.05 5853.73 5800.71 56.21 OSF 1.50 7291.68 3408.50 TD 1 17862.361 32.81 MEMO MEM MIME, MAO=10.00(m) 199.51 199.51 MinPts 0124-08(Del Sway) Pan U 32.81 MIE:=6'MEMO N/A PASS=10.00(m) 1.90 1.90 MinPts 17886.87 32.81 17884.50 17854..1 N X MAS=10.00(m) 221.95 221.95 Min%-O-OF ' 1 6492.621 46.•6 :6 31/E OOF 1.50 8817.97 3690.11 MinPts 01148k Pon 1-2 Pet Savoy) Pas 1-7 221."M:MEEMEEE=ME OSF 1.50 7558.31 3447.18 MinPts 0018-08(Der Survey) Par 1 7455.791 479.77 7134.93 6976.02 23.45 OSF 1.50 9319.45 3625.17 Mn%-CICI 7456.08 480.7. 7134..6 6975.38 23.40 OOF 1.50 9349.38 3627.26 MINPT-0-EOU 7456.36 481.00 7134.. 11112:102 23.39 OSF 1.50 9359.35 3627.96 M1n%-0.ADP 7451.98 484.6 7137.95 6977.4 23. OOF 1.50 9449.64 3634.23 Min%-0.SF OF18-68P82(De(Savoy) Pas 1 7677.971 445.53 NEM MffrEO�.6. OSF 1.50 8682.81 3579.50 MinPts OPO4-07(Del Swey) Cf.T.�� Pan MIE:S8 3281 MIME M: 6E N/A MAS=10.00(m) 0.74 0.74 Min%s 17850.18 32.81 : 17817.37 15306.05 MAS=10.00(m) 213.46 213.46 MINPT-0-EOU L4 32.81 178477• 17817.. 15436.20 MAO=10.00(m) 216.19 216.19 MinPts 16556.26 80.32 16502.23 16475.94 314.84 OSF 1.50 5190.12 3096.99 TD 13689.99 6.69 13645.30 13624.30 325.89 OOF 1.50 4014.01 2922.62 1401191-0-SF 14418.71 69.93 14371.32 14348.78 319.81 OSF 1.50 4372.10 2975.71 Min%-0-SF 15682.51 77.24 15630.41 15605.27 311.6 OSF 1.50 4957.72 3062.53 MinPt-O-SF 15889.86 78.19 15837.16 15811.67 311.69 OSF 1.50 5029.11 3073.12 M1n%-0-SF 16172.97 79.20 16119.64 16093.77 312.55 OSF 1.50 5100.63 3083.72 Min%-0.SF 16232.92 79.48 16179.41 16153.44 312.49 OSF 1.50 511611 3086.11 MinPt-O-SF 16347.85 79.97 16294.03 16267.88 OSF 1.50 5149.93 3091.03 MinPt-O-SF N4teitcM02 4(Del Survey) Pas 111 32.81 8289. 8258.1 322712.43 MAS=10.00(m) 52.90 52.90 MinPts 8291.00 32.81 8289.0 8258.19 138919.55 MAS=10.00(m) 62.84 62.84 MINPT-0-EOU 8384.95 45.24 8354.15 8339.711 290.251 OSF 1.50 1100.82 1080.85 Min%-0-SF 8345.71 55.28 8308.22 8290.44 234.56 OSF 1.50 2055.95 1904.67 TO 7999.32 77.17 7947.24 7922.1 159.41 OOF 1.50 1722.6 1625.57 Min%-O-ADP 7999.21 77.04 7947.21 7922.17 159.68 OSF 1.50 1725.75 1628.23 MINPTA-EOU I 7999.091 76.79 7947.26 7922.30 160.21 OSF 1.50 1732.06 1633.57 MnPt-C1CI Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 7 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert I Status Ct-Ct(ft)1 MAS(ft)1 608(n) Dev.(ft) Fact Rule MD(ft) 1 TV()(ft) Alert 1 Minor 1 Major N8etchu9 3(Del Survey) 8043.01 32.81 8041. 8010.23 312389.76 MAO=10.00(m) 52.90 52.90 MinPts 8043.46 32.81 8040.1 8010.65 5866.27 MAO=10.00(m) 318.10 318.08 MINPT-0-EOU 8043.91 32.81 8040.41 8011.1.j MAS=10.00(m) 37237 37229 MinPl-0-SF 8744.67 32.81) C 8011.86 39225.60 MAS=10.00(m) 434.12 433.89 MINPT-O-EOU 8111.99 45.27 8081.17 8066. .=OE OSF 1.50 1140.49 1117.65 MinPt-0SF 8135.44 45.32 8104.59 8%90.1. OSF 1.50 1265.15 1231.48 MinP1-0.SF 8296.14 51.85 8260.93 8244.-r MEM OSF 1.50 1994.31 1853.64 MinPt-O-OF 11469.66 54.48 11432.70 11415.17 327.23 OSF 1.50 2574.00 2300.78 TD 13226.72 62.66 13184.31 13164.06 326.55 OSF 1.50 2538.21 2775.79 MInP1-0-0F 11804.66 55.43 11767.07 11749.23 330.81 05F 1.50 2565.17 2294.65 MinPt-O-OF 11764.79 55.25 11727.31 11709.53 330.82 OSF 1.50 2566.14 2295.32 MinPt-0-0F 54A91 11435.911 11418.39 327.27 OSF 1.50 2574.00 2300.78 MinPts N181100110 31981(Dee Survey) Pan I 8043.031 32.81 8041. 8010. 312389.76 MAS=10.00(m) 52.90 52.90 MinPts 8043.46 32.81 8040.1 610.6 5866.26 MAS=10.00(m) 318.10 318.08 MINPT-0-EOU 8043.91 32.81 8040.41 8011.1.EIMEfi MAS=10.00(m) 372.37 37229 MinPt-O-SF 8044.67 32.81r "q 8011.86 3925.60 MAS=10.00(m) 434.12 433.89 MINPT-0-E0U 8111.99 45.27 8081.17 8066.7.11111/C•Y.- OSF 1.50 1140.49 1117.65 MinP1-0-SF 8135.44 45.32 8104.59 8090.1= OSF 1.50 1265.15 1231.48 MinPt-0-SF 8296.14 51.85 8260.93 8244.29 MMIECI OSF 1.50 1994.31 1853.64 Min%-0-SF 11358.26 55.03 11320.94 11303.23 320.74 OSF 1.50 2606.37 2323.00 TD Mkailchtp 31982(Dee Survey) Pass 8043.0 32.81 8041. 8010.23 312389.76 MAS=10.00(m) 52.90 52.90 MinPts 8043.46 32.81 8040.1 8010.65 5866.26 MAS=10.00(m) 318.10 318.08 MINPT-0-EOU 8043.91 32.81 8040.41 8011.1.MUM MAS=10.00(m) 37237 372.29 MinP1-0-SF 8044.67 32.811 8011.86 3925.60 MAS=10.00(m) 434.12 433.89 MINPT-0-EOU 8111.99 45.27 8081.17 8066..MZIE OSF 1.50 1140.49 1117.65 MinPI-OSF 8135.44 45.32 8104.59 8090.1. OSF 1.50 1265.15 1231.48 MinP1-0-SF 8296.14 51.85 8260.93 8244.a MB= OSF 1.50 1994.31 1853.64 66461.0SF 11009.25 53.98 10972.63 10955.27 317.14 OSF 1.50 2588.62 2310.86 TD IIII1 53.--MEM llll MM OSF 1.50 2588.62 2310.86 MinPts Mkatchuq 31983(Dot Survey) Pass 1 8043.031 32.81 8041. 8010.23 312389.76 MAS=10.00(m) 52.90 52.90 MinPts 8043.46 32.81 8040.1 8010.6.5 5866.26 MAS=10.00(m) 318.10 318.08 MINPT-0-EOU 8043.91 32.81 8040.41 8011.1.• MAS=10.00(m) 372.37 372.29 MInPt-0-SF 8044.67 32.811 C{ 8011.86 3925.60 MAS=10.00(m) 434.12 433.89 MINPT-0-E0U 8111.99 45.27 8081.17 8066. .my= OSF 1.50 1140.49 1117.65 MinPt-O-SF 8135.44 45.32 8104.59 8090.1= OSF 1.50 1265.15 1231.48 M1nPt-0SF 8296.14 51.85 8260.93 8244..)MIME OSF 1.50 1994.31 1853.64 MinPt-0SF 11537.92 54.64 11500.86 11483.29 328.21 OSF 1.5D 2574.94 2301.42 TD N4mt4Mp 1(Def Strvey) Pass I 8174.601 32.81 8171.42 8141.791 6502.39 MAS=10.00(m) 365.98 365.91 MinPts 8174.66 32.81 8171.37 8141.85 5943.57 MAO=10.00(m) 387.07 386.97 MINPT-O-EOU 8174.87 32.81 8171.45 8142.06 544200 MAS=10.00(m) 406.50 406.35 MINPT-0.EOU 8346.18 48.36 8313.31 8297.: =ME OSF 1.50 1127.04 1105.20 MinPt-O-SF 8433.57 49.97 8399.62 8383.•.=ME OSF 1.50 1215.61 1186.58 MinPt-0-SF 3585.23 49.68 3551.47 8535. .-.; OSF 1.50 1295.35 1258.54 MinPt-0SF 8619.17 49.87 8585.28 8569.. OSF 1.50 1306.11 1268.13 MinPt-0SF 8923.51 49.99 8899.55 8873. .MEE OSF 1.50 1383.07 1335.70 MinPt-0SF 9095.24 50.72 906.79 9044. • ME.- 05F 1.50 1435.32 136.70 MinPt-O-SF 932234 52.02 9287.02 9270.31=MEM OSF 1.50 1536.30 1467.19 MinP1-65F 946.19 52.90 9430.28 9413.•=KIM OSF 1.50 1594.92 1517.20 MinPt-O-SF 9951.79 56.46 9913.51 9895.•hh EM 05F 1.6 1793.43 1685.35 MinPt-O-SF 10283.87 58.78 10244.05 10225..-=ME OSF 1.50 1932.41 1801.98 MinPt-O-OF 10441.06 59.74 10400.59 10381.31 EWE OSF 1.50 1994.25 1853.59 MinPt-O-OF 11018.05 61.50 10976.41 109=56..hhhltt .. OSF 1.50 2044.09 1894.90 Mint-0-SF 13063.12 63.90 13019.88 12999.21 316.07 OSF 1.50 2242.84 2055.17 TD 0111-01(Der Survey) Pass 17861.91 3281�:-r-'T:,MIME N/A MAS=10.00(m) 0.85 0.85 MinPts 8260.21 119.. MIME MEM=IIIM OSF 1.50 6203.92 3247.30 MinPts WreicMo 4PB7(Def Survey) I� Pass t mt 32.81 8289. 8258.181 322712.43 MAS=10.00(5) 52.90 52.90 MinPts 8291.00 32.81) 8289.01 8258.19 138919.55 MAS=10.6(m) 62.84 62.84 MINPT-0.EOU 8384.95 45.24 8354.15 8339.71 290.251 OSF 1.50 1100.82 1080.85 M1nP1-0-SF 8608.41 52.07 8573.06 8556.34 257.431 OSF 1.50 1994.04 1853.41 M19PI-0-SF 8863.77 52.26 8828.29 8811.50 264.03 OSF 1.50 2130.60 1965.62 TD OP0804(Der Survey) Pan 16504.69 82.58 16449.16 1642212 355.17 OSF 1.50 5221.49 310164 TD 12771.84 68.67 12724.89 12703.1 =EDEf. OSF 1.50 3908.10 2906.91 M1n1,1-0-SF 13114.26 70.28 13066.30 13043.9'MUM OSF 1.50 4062.97 2929.88 MinPt-O-SF 13635.53 72.90 13585.91 13562.9'=allE OSF 1.50 4285.38 2964.33 MinPt-0SF 14265.96 76.59 14213.99 14189.n=E:/2. OSF 1.50 4634.57 3014.62 MinPt-O-SF 14885.45 79.10 14831.94 14806. =ME OSF 1.50 4882.17 3351.33 MinPt-O-SF 15011.91 79.73 14958.01 14932.1:M'. OSF 1.50 4934.75 3059.13 MinP1-0-0F 15171 08 80.39 15116.78 15090.9e==M OSF 1.50 4993.17 3067.79 MinPt-O-OF 16290.40 8219 16235.09 16208.21=EEO OSF 1.50 5180.65 3095.59 MinP1-0-SF 1 8360.851 85.75 :M. ELM= ht j OSF 1.50 4750.85 3031.86 MinPts 0P16-03(Dee Survey) Pan -ME 381.95 8778.63 8652.65 35.84 05F 1.50 8348.38 3547.54 MnPt-CtCt MOH 45251 MEM MIIMM:E OSF 1.50 8858.13 359299 MinPts OPO4.07P81(Del Survey) Pan EIEEE 32.81 MIEMM qtr. N/A MAS=10.06(m) 0.74 074 MinPts 17850.18 32.81 MEM 17817.37 15306.05 MAS=10.00(m) 213.46 213,46 MINPT-0-EOU MIEZIE 32.81 17847.7• 17817.. 15436.20 MAO=10.6(m) 216.19 216.19 MinPts 16556.26 80.32 16502.23 16475.94 314.84 OSF 1.50 5190.12 3096.99 TD 13689.99 65.67 13645.31 13624.32 325.97 OSF 1.50 4014.01 2922.62 MinPt-6-6F 14418.71 69.91 14371.33 14348.80 319.90 OSF 1.50 437210 2975.71 MinPt-O-SF 15690.45 77.27 15638.33 15613.18 311.89 OSF 1.50 4960.48 3062.94 MinP1-0-SF 15889.86 78.18 15837.16 15811.68 311.69 OSF 1.50 5029.11 3073.12 MinPt-0-SF 1617297 79.20 16119.64 16093.77 312.56 OSF 1.50 5100.63 3383.72 MinP1-0-SF 1623292 79.48 16179.42 16153.44 312.49 05F 1.50 5116.71 3086.11 MinPt-O-SF 16347.85 79.97 16294.03 16267.88 312.56 OSF 1.50 5149.93 3391.03 MinP1-0-SF OM&Poke 42982 Me S....9) Pass 1 9191.491 180.40C..'mmENEEN OSF 1.50 7344.90 3416.31 MinPts 0107-04(Def Survey) Pan 16624.84 81.46 16570.05 16543.37 311.54 OSF 1.50 5217.50 3101.05 TD 14633.54 76.05 14582.00 14557.49 298.441 OSF 1.50 3829.64 2893.79 MinPt-O-SF 16438.44 76.671 16386.811 16361.77 328.200 0511.50 4899.05 3053.84 MinPts 6 16604.15 81.77 149.15 16522.37 310.061 OSF 1.50 5213.27 316.42 MinPt-0-Off 012307(Del Survey) I 9539.9/' 453.' IIIIII�aS .®:. Ihlllllllh�u OSF 1.50 9072.91 367.98 MinPts Pau Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 8 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert pass Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(ft)_ Fact Rule MD(ft) I TVD(ft) Alert I Minor I Major 0120•07P82(Def Survey) l� t oq 425.30 1�:r MM OSF 1.50 854246 3567.03 Mlnpls OPO8-04PB1(Def Survey) ;.... Pass 16504.69 82.58 16449.16 16422.12 305.17 OSF 1.50 5221.49 3101.64 TD 12771.84 68.67 12724.89 12703.1 =•'s• OSF 1.50 3908.10 2906.91 MinPt-O-SF 13114.26 70.28 13066.30 13043.9 293.:x. OSF 1.50 406297 2929.88 MinPt-O-SF 13615.53 72.90 13585.91 13562.o MOM OSF 1.50 4295.38 2964.33 MinPt-O-SF 14265.96 76.59 14213.99 14189.>�:�•>3, OSF 1.50 4634.57 3014.62 MinPt-O-SF 14885.45 79.10 14831.94 14806.s NEM OSF 1.50 4882.17 3051.33 MinPt-0-SF 15011.91 79.73 14958.01 14932.1. •r .• OSF 1.50 4934.75 3059.13 MinPt-O-SF 15171.08 80.39 15116.78 15090..E OSF 1.50 4993.17 3067.79 Minpt-O-SF 16290.40 82.19 16215.09 16208.21 tom"I OSF 1.50 5180.65 3095.59 Min18-0-SF 1 10447.281 72 10397.n OSF 1.50 3838.59 2895.45 Minds OP03P05(Def Survey) Pas 32.81 17846.91,... 77151.82 MAS=1.00(m) 90.90 90.90 Moron MEEK 32.81 MEIM MEEM 15724.26 MAS=1.00(m) 210.68 210.68 MinPls 16598.92 79.84 16545.22 16519.08 31751 SF 1.50 517214 3094.32 TD 15877.54 78.47 15824.66 15799.. WIDE SF1.50 3713.58 2868.52 MInPI.0-SF EMEI 74.18 16381.24 16357.03 339.26 SF 1.50 4774.49 3035.37 MinPt-0000 16431.24 74.24 may., 338.98 SF 1.50 4780.43 3036.25 MinPts 16548.01 79.81 16494.32 16468.. 3167. SF 1.50 5161.76 3092.78 MinPt-O-SF 010648(Def Survey) ..444. C.'§.1.t gw` ,-+vac.A.e',V§ # .. y.5 ., pya• 32.81 Mb= E NIA MAS=10.00(m) 1.01 1.01 MinPts 17852.90 32.81 NEMO 17820.10 26731.69 MAS=10.00(m) 141.01 141.01 MINPT-O-EOU 17853.011 32.81 .',. 15639.88 MAS=10.00(m) 218.84 218.84 MinPls 16696.7 80.34 16642.72 16616.41 317.25 OSF 1.50 5197.53 3098.09 MinPt-Ctct 16696.78 80._ >�- -r. 317.05 OSF 1.50 5198.92 3098.29 MinPts 16744.93 82.75 16689.29 1666218 308.78 OSF 1.50 5235.40 3103.70 TD 11673.18 106.46 11601.38 11566. imam OSF1.50 2999.89 2570.15 MinPt-O-SF 12117.84 106.99 12045.67 12010.,. OSF 1.50 3071.60 2610.30 MinP1-0-SF 12751.51 104.58 12680.96 12646.•' "y OSF1.50 3159.37 2656.61 MinP1-0SF 13314.89 107.16 1324267 13207. OSF 1.50 3219.63 2686.52 M Pt-OSF 1380224 108.50 13729.19 13693.7=ULM OSF 1.50 3259.60 2705.23 MinPt-0SF 14450.25 111.46 14375.30 14338.==ILE OSF 1.50 3307.23 2727.16 MinPt-0SF 15595.08 111.21 15520.43 15483.. MIIIMIE OSF 1.50 341230 2771.31 MnPt-0-SF 16483.17 111.27 16408.59 16371•r OSF 1.50 3495.36 2802.55 MinPt-O-SF 17610.51 74.23 17560.19 17535. MEM OSF 1.50 4215.02 2952.42 MinPt-O-SF 17588.35 74.13 17538.60 17514.,1 OSF 1.50 429200 2963.83 MinPt-0-SF MEEM 82.• =IMC1- OSF 1.50 5235.39 3103.70 MinP[s 0t06-03PB1(Def Survey) 32.81 MEM MkgrA.B., N/A MAS=10.00(m) 1.01 101 MinPts 1785290 32.81 MEMUI 17820.10 26731.69 MAS=10.00(m) 141.01 141.01 MINPT-0-EOU 17853.011 32.812.- y 15639.88 MAS=10.00(m) 218.84 218.84 MinPts 16696.7 80.34 1664272 16616.41 317.25 OSF 1.50 519753 3038.09 MoPI-0000 16696.78 80.a MB=ME= 317.05 OSF 1.50 5198.92 3098.29 MinPts 16744.93 82.75 16689.29 16662.18 308.78 OSF 1.50 5235.40 3103.70 TD 11997.56 107.03 11925.37 11890- .1M11002 OSF 1.50 305270 2560.92 MinPt-O-SF 12751.51 104.58 12680.96 12646.•.=OE OSF 1.50 3159.37 2656.61 MinPt-O-SF 13314.89 107.16 1324267 13207. •tom" / OSF 1.50 3219.63 2686.52 MinPt-O-SF 1380224 10850 13729.19 13693.7 M:: OSF 1.50 3259.05 2705.23 MinPt-O-SF 14450.25 111.46 14375.30 14338.•=UM OSF 1.50 3307.23 2727.16 MinPt-O-SF 15595.06 111.21 15520.43 15483.. =EIEE OSF 1.5D 341230 2771.31 MinPt-O-SF 16483.17 111.27 16406.69 16371...IMM3I OSF 1.50 3495.36 280255 MinPt-O-SF 17610.01 74.23 17560.19 17535.:M>.,,-• OSF 1.50 4215.02 295242 MinPt-O-SF 17588.35 74.13 17538.60 17514 MZ,-n, OSF 1.50 429200 2963.83 M rrPt-O-SF 16746.771 82.7•MIME 16663.•:M. -y' OSF 1.50 5235.39 3103.70 MitrPts 0I11-0IPB1(Def Survey) mum 32.81-.-':MIME WA MAS=10.00(m) 0.85 0.85 MinPts 15841.64 86.50 15783.41 15755.14 280.19 OSF 1.50 5371,24 3123.84 TD 0120-07PB1(Def Survey) "� Pas ( 11600.251 311.04' ,MEMEDMIO OSF 1.50 7658.71 3461.33 MinPts OP05.06(Def Survey) e,/(33 Pass 32.81 :®. :�'. , N/A MAS=10.00(m) 084 084 MinPts 17851 61 32.81�--•M. 17818.80 18854.38 MAS=10.00(m) 170.84 170.84 MINPT-0-EOU 111111TME 32.81 :O' 7 MERME 15420.97 MAS=10.00(m) 213.43 213.43 MinPts .117=' 81.02 16615.50 16588.96 314.09 OSF1.50 5186.81 8086.50 MnPt-6131 16670.03 81.17 16615.44 16588.86 313.51 OSF 1.50 5186.86 3096.50 TD 12163.68 99.54 12096.84 12064.1 �:-•L• OSF 1.50 2757.69 2422.08 MinPt-O-SF 12748.65 97.82 1268291 12650.:5 MZU OSF 1.50 2910.17 2517.10 MinPI.0-SF 13231.20 100.62 13163.59 13130.':Marri OSF 1.50 2979.81 2558.54 MinPt-O-SF 13593.63 103.03 13524.41 13490...=E1Ija OSF 1.50 3030.32 2587.44 MinPt-O-SF 14136.07 104.96 14065.58 14031.11®`-• OSF 1.50 3095.03 2622.98 MinPt-O-SF 14403.71 107.24 14331.72 14296..Mly')f. ,a OSF 1.50 312283 2637.72 MinPt-O-SF 15124.07 113.40 15048.05 15010.• MOE OSF 1.50 3185.12 2669.58 MinPt-O-SF 15301.49 114.07 15225.05 15187.4.1 OSF 1.50 3198.50 2676.21 MinPt-O-SF 15429.56 114.28 1535299 15315 is OSF 1.50 3208.94 2681.32 MinPI.0SF 16066.37 117.84 15987.47 15948. =ME. OSF 1.50 327226 2711.35 MinPt-O-SF 16828.11 123.23 16745.63 16704.::=KM OSF 1.50 3349.86 2745.69 MinPt-O-SF 17068.32 125.40 16984.39 16942-. ".. OSF 1.50 337270 2755.27 MinPt-O-SF 17564.55 128.61 17478.49 17435.•- ,351, OSF 1.50 3415.40 2772.54 MInPt-0SF 17089.39 73.81 17039.78 17015. =.: ,7 OSF 1.50 4065.90 2930.31 MinPt-0-SF 16675.38 8271 16619.77 16592. =UM OSF 1.50 5179.07 309.3.35 MinPt-O-SF 4 16670.10 81.25 16615. EL= 313.18 OSF 1.50 5186.82 3096.50 MinPt-0.ADP l url 81.21- r, 16588.85 313.E OSF 1.50 5186.84 3096.50 MinPls Ofilctok Punt 1-2PB1(Def Survey) I 12064 35) 158.90 MENEMEZZIESMEE OSF 1.50 7213.68 339699 MinPts OP03-P05PB2(Def Survey) , ;,agp.z..�g k^. -f•Ma .. mum 32.81 17846.•'x: -'.y 77151.82 MAS=10.00(m) 90.90 90.90 MinPts 40697/ 32.81 mikaa.Namm 15724.26 MAS=10.00(m) 210.68 210.68 MinPts 16598.92 79.84 16545.22 16519.08 317.51 OSF 1.50 5172.14 3094.32 TD 15877.54 78.47 15824.66 15799.071 310.211 OSF 1.50 3713.58 2868.52 48961-0SF 74,18 16381.24 16357.03 339.26 OSF 1.50 4774.49 3035.37 MnPt-CtCl 16431.24 74.2 ''s r�,. 338.98 OSF 1.50 4780.43 3036.25 MinPts 16548.01 79.81 16494.32 16468.-. 316.7, OSF 1.50 5161.76 3092.78 MinPt-0SF OP23W W 02(Def Survey) ✓,7� w. v, ""+. a Pas 16275.68 89.66 16215.36 16186.02 277.28 OSF 1.50 5544.82 3149.58 TD 84 77..®:'.MEM 250.78 OSF 1.50 3804.93 2889.00 Min%s 13507.10 68.97 13459.89 13438.1 MEE OSF 1.50 4111.55 2937.08 MInPt-0-SF 16076.71 89.28 16016.61 15987. =EEO OSF 1.50 5507.98 3144.11 Min18-0.SF 12226.58 77.43 12173.61 12149.15=ME OSF 1.50 3803.96 2888.80 MIn8-0.SF OP05•06PB2(Def Survey) 38ff f /:- Pass EIENE 32.81 . WA MAS=10.00(m) 0.84 0.84 MinPts 17851.61 32.81 MBEZIM 17818.80 18854.38 MAS=10.00(m) 170.84 170.84 MINPT-0-E00 32.81 :i1 4 MOM 15420.97 MAS 10.00(m) 213,43 213.43 MinPts Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6) 12/5/2012 11:21 AM Page 9 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(j_MAS(ft)I EOU(ft) Dev.(ft) Fact Rule MD(1t) I TVD(ft) Alert I Minor I Major 16669.98 81.02 16615.50 6588.96 314.09 OSF 1.50 5186.81 3096.50 Min%-C1C1 16670.03 81.17 16615.44 6588.86 313.51 OSF 1.50 5186.86 3096.5D TD 12912.92 98.13 12846.97 2814.•MOE OSF 1.50 2932.90 2530.82 Min%-0-SF 13231.20 1016 13163.57 3130.. OSF 1.50 2979.81 2558.54 M8P1-0-SF 13593.63 103.07 13524.38 3490.0 OSF 1.50 3030.32 2587.44 M8PI-O-SF 14136.07 16.01 1406.55 4031..:=MO OSF 1.50 3095.03 2622.98 M8F1-0-SF 14403.71 107.29 14331.69 4296.-•MEM OSF 1.50 3122.83 2637.72 Ming-0-SF 15124.07 113.45 15048.02 5010.•.WM OSF 1.50 3185.12 2669.58 Min%-0-SF 15301.49 114.11 15225.02 5187.:=KM OSF 1.50 3198.50 2676.21 MinP1-0-SF 15429.56 114.33 15352.96 5315.2-Ma/M. OSF 1.50 3208.94 2681.32 Min%-0-SF 16066.37 117.89 15987.44 5948.,:MMIEfi. OSF 1.50 3272.26 2711.35 Min%-0-SF 16828.11 123.28 16745.60 6704,' 7 OSF 1.50 3349.86 2745.69 M8%-0-SF 17068.32 125.45 16984.36 6942.8 MM OSF 1.50 3372.70 2755.27 Mln%-5-SF 17564.55 128.65 17478.46 7435.•.M....., OSF 1.50 3415.40 2772.54 Mln%-0-SF 17069.39 73.81 17039.77 7015.. OSF 1.50 406.90 2930.31 Min%-0-SF 16675.38 82.71 16619.77 692.6 NEM OSF 1.50 5179.07 3095.35 Min%-5-SF 16670.10 81.25 1615.-•IL= 313.18 OSF 1.50 5186.82 3096.50 M0%-0-ADP EMU 81.21 >�,] 688.6 313.35 OSF 1.50 5186.84 3096.50 Min%s 0P26-DSPO2(D.4 Survey) Pass :.T r 32.81 -'M"• :.T .s N/A MAS=10.00(m) 0.89 0.89 Min%s /MEE 32.81 :.�'1j 15541.36 MAS=10.00(m) 205.13 205.13 Min%s 16191.18 90.77 16130.14 16100.42 272.33 OSF 1.50 5584.57 3155.47 TD 85.08 12756.82 12729.80 237.05 OSF 1.50 5001.24 3068.98 Min%-ClCt 12814.88 85.101 12756.811 12729.78 236.97 OSF 1.50 5002.18 3069.12 Mln%s 12942.93 87.24 12883.63 12855.69 231.531 OSF 1.50 5123.97 3087.18 Min%-0-5F OP22-W W03(P4)(Def Plan) Pass MIME 84.25 16621.90 1694.20 302.04 OSF 1.50 5372.54 3124.03 Min%-CtCt 1678.55 84...MIME 111113ZM 301.83 OSF 1.50 5374.47 3124.32 Min%6 MOE 119. Mii=MOM 177.59 OSF 1.50 6381.58 3273.64 Min%s 1426.37 128.02 14174.69 14132.34 168.36 OSF 1.50 6820.46 3338.70 Min%-0-SF OP21-WW01(Del Survey) Pass 32.81 :E:..', :M'' ., N/A MAS=10.00(m) 0.48 0.48 Min%s 17882.15 32.81 MEMO 17849.34 18472.89 MAO=10.00(m) 170.48 170.48 MINPT-O-EOU MENE 32.81 MEMZE MEM 15387.35 MAS=10.00(m) 213.49 213.49 Min%s ELIM'2. 83.••jam'1 II= 303.55 OSF 1.50 5355.12 3121.45 Min%s 16766.46 6.6 16706.74 16677.60 287.70 OSF 1.50 5513.89 3144.99 TO 15358.20 67.47 15312.89 15290.73 346.67 OSF 1.50 3762.23 2879.96 Min%-S-SF 15316.12 67.25 15270.94 15248.87 347... OSF 1.50 3764.13 2880.38 MinP1-0-SF 15212.67 65.-.MaME 15147.27 358.93 OSF 1.50 3762.38 2884.34 Min%s /IEEE 65.37 1516.46 15147.29 359.10 OSF 1.50 3782.70 2884.41 Mn%-CICI 1549229 62.29 15450.02 15430...Mi.•n, OSF 1.50 367.40 2903.76 Min%-0-SF 16743.15 88.89 16683.40 1654.26 -- y., OSF 1.50 5506.37 3143.88 Min%-0-SF 15573.51 69.08 15527.13 15504. Nom OSF 1.50 3759.17 2879.28 Min%-0-SF 15607.07 73.33 15557.85 15533.7'MEE15 OSF 1.50 3759.34 2879.32 M1ng-0-SF OP03•P05PB1(Del Survey) Pm MEM 32.81 17846.•'O:, 77151.82 MAS=10.00(m) 90.90 90.90 Min%s MEM 3281 MIME MEW 15724.26 MAS•10.00(m) 210.68 210.68 Mm%s 16598.92 79.84 16545.22 1619.08 317.51 OSF 1.50 5172.14 3094.32 Ts 15830.69 78.61 15777.70 15752..• OSF 1.50 3708.96 2867.37 Min%-0SF 74.18 16381.24 16357.03 339.27 OSF 1.50 4774.49 3035.37 MnP1-CICt 16431.24 74.2 MEIBE MIME 338.98 OSF 1.50 4780.43 3036.25 MinPts 16548.01 79.81 16494.32 16468.. 316.70 OSF 1.50 5161.76 3092.78 Min%-O-SF 206.689,2(Del Survey) Pass 16078.411 32.81 ..1 -,-,�I93j1C'. N/A MAS=10.00(m) 14.15 14.15 Min%s 16049.3 51.64 16014.26 5997.68 484.10 OSF 1.50 1821.62 1709.09 Min%-CICt 16050.08 53.48 5996.59 46.82 OSF 1.50 1925.49 1796.20 MINPT-5-EOU 16050.51 54.01 16013.8 ISIEME 462.11 OSF 1.50 1955.33 1821.13 MInP1-0-ADP 16166.71 61.10 16125.34 6105.61�"•1 OSF 1.50 2051.51 1901.02 Mln%-O-SF 16252.64 64.82 16208.79 6187.8.MEM OSF 1.50 2073.83 1919.36 MinPt-5-SF 16312.60 64.85 16268.73 6247.'M', OSF 1.50 2086.51 1929.75 Min%-O-SF 16378.43 6.01 16334.45 6313.41 Man OSF 1.50 2096.76 1938.12 Min%-O-SF 16500.13 64.62 16456.41 6435.51 MEE OSF 1.50 2115.10 1953.05 MinPI-O-SF 16594.71 6.50 1650.40 629.21=cm OSF 1.50 2123.55 1959.91 Mine/-0-SF 1632.80 65.44 16568.53 6567. < .`='D, OSF 1.50 2126.73 1962.49 Min%-S-SF 16715.36 66.17 1670.61 6649.1•,'. 'r OSF1.50 2133.34 1967.83 MinP1-0-SF 16862.86 67.54 16817.20 6795. . T: E•, OSF 1.50 2145.74 1977.85 Min%-0-SF 17132.38 69.32 17085.52 7063...May OSF 1.50 2169.24 1996.75 Min%-O-SF 17435.64 70.83 17387.78 7364.81 MOM OSF 1.50 2197.35 2019.20 Ming-0-SF 17867.83 72.22 17819.04 7795.•.MaNE OSF 1.50 2234.47 2048.58 Min1R-0-SF 18397.74 73.02 18348.42 8324.72 388.08 OSF 1.50 226.46 2088.43 TD OP18-06PB1(Def Survey) Pass MEM 90.11 Eir=EMILE Mme, OSF 1.50 5547.6 3150.00 Min%s OWak Pont 1-1(DA Survey) Pass 16659.51 78.48 16606.75 1681.04 323.90 OSF 1.50 5120.93 306.73 TD 17315.40 136.82 17222.53 17176.58 OSF 1.50 3285.41 2717.35 Min%-O-SF 16698.63 70.37 16651.26 1628..MM. OSF 1.50 4064.94 2930.17 Min%-0-SF 16677.68 70.54 1630.20 16607.1 MI1E OSF 1.50 4243.57 2956.65 Min%-O-SF Man 70.50 16623.65 16600.61 361.75 OSF 1.50 4397.76 2979.51 MnPI-CICt 16671.14 70..EIMM 1600.5 361.41 OSF 1.50 4412.51 2081.70 M8%6 I 16643.231 77.29 16591.25 1665.94 328.74 OSF 1.50 5034.56 3073.93 Mn%-CICI 16643.32 77.m 16591.1 16565.70 327.32 OSF 1.50 5054.76 3376.92 MINPT-0-600 16643.36 77.67 1691.1 •-•'.•"•, 327.11 OSF 1.50 5057.82 3077.37 Mn%-S-ADP 1661.96 78.52 16599.16 1673..' 323. OSF 1.50 5117.68 3086.25 M1nR-0-SF OP0506P81(Def Surety) Pass MEM 32.01 :®. Elii3IM N/A MAS=10.00(m) 0.84 0.84 Min%s 17851.61 32.81 MEMO 17818.80 18854.38 MAS=10.00(m) 170.84 170.84 MINPT-5-EO0 MILE 32.81 IR=MIME 15420.97 MAS=10.00(m) 213.43 213.43 Min%s e. 81.02 1615.50 166.96 314.09 OSF 1.50 5186.81 3096.50 Min%-C/Ct 16670.03 81.17 16615.44 16588.86 313.51 OSF 1.50 5186.86 306.50 TD 17069.39 73.81 17039.78 17015.0 = ' OSF 1.50 4065.90 2930.31 MinP1-0-SF 1675.38 82.71 16619.77 16592.67 MM OSF 1.50 5179.07 3095.35 Min%-O-SF 16670.10 81.25 16615.• .r®::: 313.18 OSF 1.50 5186.82 3396.50 MInR-O-ADP I..4 81.211111= 166.85 313.35 OSF 1.50 5186.84 3096.50 Min%s Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\S132-W2\S132-W2(P6) 12/5/2012 11:21 AM Page 10 of 10 Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based — — on: Oriented EOU N Client: Eni Petroleum Dimension Well: SI32-W2 --■i Field: Nikaitchuq NoGo Region Anti- Collision rule used: Minor Structure: Spy Island Risk- Separation Factor North Date: December 05, 2012 350 0 10 340 .� �' �� _ n. '� $� �01211:20 P2)330 .y`� ` :. E2(P2) 320 4k44W 4I ', �� �� �`1 :IAN, 40 � * �•� 120 .% ��,:1S7�`, . 310 �. ,�VP14110/* ��,/.-►\ 1Cy� � '�65�IIIP 300 ,' \ mil r 'p r \l���. ;:.'f,-;-:.,'"",,z :∎ `i�,-41,,N60 &Si* Nap 14i0■4)1'k% kfOli•-%-11-ti4'it.%:;;;;■ '-ktiiV., ,-: ,N P27-N 1 290 I ��` w 60 /%r' 11�.' -�•,� �. e1 ,,. .► .- ♦.' • c .1 � ;a ;: ,�, 1i..11 280 ��ir��10 ,i��. pflbailifiiiit.A .g_%:;1,.. '1,\IA\ .�1 14.P18-�W� I, if ii,/ 2. �! ;�j.0 ; \‘' 1 .j,'p. iii,`;tiff., N5P61 ILIIII1I& LIIr4p 270 \\ ``�1�����• k46: ,i /� :j t�� 'i 90 ��. .. , ? / II Vii i N !a . g' • �, ` 1j �• A � ( ` R �- "xi ��il \111�11\ t 00 260 4o;,` ,i�� v .�, . tt. * inii 120-imy N4PB1\a J• '4' ' `� ° f ,�` 110 250 ' ' 120 AixtrlY"."-tvg„wit4tittsw$4■4 240 , �� •V ''alp Ilits.. 8\',�' S125 N2 230 ,��• � r,..____two, ♦ Vo if w 130 VI 220 "Nip:,...... , ,.... apt"11740 140 .4:t1411,11 /111 allatoodk 210 .• Ill liria& 150 2 0 . SP33-1 190 180 170 Well Ticks Type: MD on SI32-W2(P6c) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg e Scale: IN=%50.00 ft f Y Schlumberger TRAVELING CYLINDER PLOT NoGo Region EOU's based .■ Client: Eni Petroleum on: Oriented EOU / Well: SI32-W2 Dimension • '• Field: Nikaitchuq NoGo Region Anti- Collision Structure: Spy Island Collision rule used: Minor Date: December 05, 2012 Risk - Separation Factor North 340 345 350 355 0 5 10 15 30 ; •20 335 25 330 30 325 ig 35 320 ;`,91 315 , \' � ii...._4_0_310 $ P`', �j 45 50 305 `,� 1111111111,18/7,' ���/ 55 300,,, .... ,` �,� 60 �JJ 295 ,4`\ ```� ` ,''•� 65 290 , ` � � � 285 �� ` �'l{li ,1`��� i = )4705-W1PB1 280 �` ' _ \ ►. G , I" 80 275 ,-Al ' i� , `fs .1 „, I�It 85 270 tri*"\ ` ' 90 265 cl 11111111111 95 260 At� \N \ vaiii-i■.' 100 jell.255 ISI"o �' �` 3 , 1►ce.' I ori t„`�` \ � �,`) 105 it � �� 250� 135-W4( `�`` o `\��=-�110 245 ` ' \ ��-115 2400 �.��`11 `„`` ````` `~- 235 ✓!,' f '`44/\=' � �,Ø't$� `` \� `12 120 % . i , �,� � 5 230 i % % 1 30 225 // `'� �, % 135• 220 ' ',, ,, 140 215 145 210` 150 205 155 200 160 195 190 185 180 175 170 165 h Well Ticks Type: MD on SI32-W2(P6c) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 5.00 deg Scale: 1 INCH= 10.00 ft , Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based N Client: Eni Petroleum on: Oriented EOU Well: SI32-W2 Dimension ' Field: Nikaitchuq NoGo Region Anti- Structure: Spy Island Collision rule used: Minor Date: December 05, 2012 Risk - Separation Factor North 350 0 10 340 .`,1.��� �i \`�PB 1 30 330 ` �� 320 �� �/r—',N al,'"4��-.�� 40 40 40 310 ' � ��1"..i4 i _.�,,r �� ,, a . 50 ' NW 200 \\;,,,-:,:- ...;`�.'. 4, ` 'e 300 frb �, 180 a:: . ,. % ` 1Iv/Y), 60,,� ,,,� 160 •,.4• 10,6,4 •`Mpi I!, , ,,�,,.•. •� 140 ` '%/�i/Y 290 , ,, I • iiiii ..4, 00.111.7'.°".47 ei�►�r�'� I 280 1///,j,,r�,i,,,*Si..••�• 60 ---.;�0\\� 80 1/111111111188/1p 40 ; a..��4VaUl 270 I""„"1,iIII_- o,, ■20 -.�"r�i�M V�_....,,��`\ 90 II Ili II °° s o o� ° 260 �`,'' . � o� � -��JIiii&q$ 100 o �,,, o �` a oA o\, ��,, 250 0 0d� - a ti 110 0 0�' 4fr,4 oa 0 co -, o w 240 t� o° �w 120 230 ®i . h , �' 14-S3 'y 130 �� ti. e` IK 220 / o1e / 140 _; / 210 ! ,.1%614-S3 200 160 k 190 1R(1 170 Well Ticks Type: MD on SI32-W2(P6c) 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 N Dimension Well: SI32-W2 Field: Nikaitchuq NoGo Region Anti- / Structure: Spy Island Collision rule used: Minor Date: December 05, 2012 Risk - Separation Factor North 350 0 10 340 640 20 33000� 660 30 '� 560 ��`,���1 320 520 '�/�•���'� 40 q ST 1 '' 480 ,I'��,r�`�_ ice 310 0O 440 �',,�` '1"- •� 50 400 0 .� _i�._: / 300 .. 360 Ntil�� ' •/ 60 ® *a 320 `'•�L�' ./.,1 • 280 ,'.4-46' " k 290 44, 10. . 240 1,'!�i !.;, 70 .:tL 'IPIitil _...r���� / � 90 IIII ',�-! !�i', 260 rj�It11► ° °ti , !;eii $14 100 OW \250 °c, ca IkRIP`rk♦ ° a� �,�•.�� r�• ,0 °° S ' .4411111111.3■� ° 1r�' �1���/�Tuvaaq ST 1 240 `` g�.0 , o �t2► 120 ftb •V 230 ` 1 ., 130 ►♦ ammo 220 ♦ -_ 140 210 _i� 150 20' �60 190 1R0 170 Well Ticks Type: MD on SI32-W2(P6c) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=200.00 ft S132-W2(P6b)Anti-Collision Detailed Report Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 20.00(0)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory IC Azimuth Reference: North Analysis Date-24hr Time: December 11,2012-08:05 North Reference: True Analysis Machine: CSD-JJVCLV1 Client Eni Petroleum Database I Project: localhost\drilling-Nikaitchuq Version I Patch: 2.6.1120.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. All local minima Indicated. Results filtered:Depth 9351.00 ft<n MD 4=18327.24 ft,Ct-Ct separation<=1500.00 ft Anti-Collision Rules Used Rule Set Name D8M AntiCollision Standard 5002 v5.1/5.2 Exemption Risk Level: Minor Jtuie Name Rbk Level Rule Woe Rule Label No00 Ruk SLB Alert Zone Threshold OSF=5.0 5002 v5.1/5.2 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 v5.1/5.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule S002 v5.1/5.2 Major CT_CT MAS=32.81(ft) SLB Alert Zone Threshold CICt<=15m 5002 v5.1/5.2 Alert CT_CT MAS=40.21(8) Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 1 of 24 Reference Trajectory Summary • Field: Nikaifchuq Well: 5132-W2 Structure: Spy Island Borehole: SI32-W2 Slot: SP32 Trajectory: 7132-W2(P6b) Client: Eni Petroleum Type: Def Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08849757° Grid Scale Factor: 0.999900149 Magnetic Declination: 20.152° Magnetic Declination Date: May 01,2013 Magnetic Model: BGGM 2012 Reference Point: Northino Eas((yg levation Structure(Inc. of Unc. 6053613,370((WS) 511442.370(ftUS) 54,100(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 Pro Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.000 1/100.000 SLB_GYRO-MWD-Depth Only-No Global 16.000 5132-W2/SI32-W2(P6b) 41.000 1000.000 1/100.000 SLB_GYRO-MWD-No Global 16.000 SI32-W2/SI32-W2(P6b) 1000.000 2760.891 1/100.000 SLB_MWD-STD-No Global 16.000 SI32-W2/SI32-W2(P6b) 2780.891 9423.310 1/100.000 SLB_MWD0GMAG-No Global 12.250 SI32-W2/SI32-W2(P8b) 9423.310 18327.242 1/100.000 SLB_MWDcGMAG-No Global 8.750 SI32-W2/SI32-W2(P8b) Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 2 of 24 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:4 Boreholes Selected:5 Definitive Surveys Selected:4 Non-Def Surveys Selected:0 Definitive Plans Selected:I Non-Def Plans Selected:0 Total Trajectories:5 None OSF filter in detailed report Trajectory Borehole Well Type SP33-W3 SP33-W3 SP33-W3 Def Survey SP30-W1P01 SP30-WIPB1 SP30-W1 Def Survey SP30-W 1 SP30-W 1 SP30-W1 Def Survey 5114-N6(P2) 5114-N6 SI14-N6 Def Plan Tuvaaq ST 1 Tuvaaq ST 1 Tuvaaq ST 1 Def Survey Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 3 of 24 �V CL d V N 0_ • • c\II. 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'OP n MMl. ,ry�.`!o Q� jt`p Ce• „ LL f f • 'f •p `l�a.�t, • 0, JAC. f �1-.. -.5 •Q�� r W o r • q' ,4„,,,H 3 8 ,(��I •r Qle/.9rlf f ®'CF fy.�,£ , ,,h/°t 1t 9f \\ O _ e. ec?,c (�M °I .alb�6f w t'p! • 1 , 6/ •,, �'f 8 ill Z /gf 2� f 2� rr! r �!r - �' M O •§ M •-V,,1f LtQr� •°� `�� �+� •Oft! °^� -s r fr ° F�, r °fir •_ _ r! i� ry •° N c 2w O 28/�c• �� • f`j- •eltr8blf ° miff 614, Q� �• , �OG.rr (0 o O �j • "/ �Sf>• b!f r f99f • ”!• '.k ('/�O U r f 9S! /::e 4VS. V r Z '� �'` •�y�•�dy f• �1C 6/ `�C �f •�/r A 0.1 •O a f , �y OfO `4_,i e •- o N 6re o S LL d �i��„ • `8r��3 MY°'11, 'yrf r ryff Si r f • 11• ppc • • 6 ! o o m C a O N r£ 09 •rr `•r,':,r 61S9 I. O N --1r4/0 N Cl R "Or r CO g d E `�0 u O O a m f o N o _ V 6/ ' CO N >> M > N Cn ch •..e, v o a . LO 0 0 °o (/) o S o V F- N N 1 N V cn a m CO 'cr > . «< N (44)000Z I. = eteoS S »> D LO F- M_ U) Field: Nikeitohuq Well: OP14-S3 Structure: OIIFtok Point Borehole: OP14-S3 Slot: OP14 Trajectory: OP14-S3 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12842137° Grid Scale Factor: 1999900315 Magnetic Declination: 21.155° Magnetic Declination Date: April 18.2011 Magnetic Model: BGGM 2010 Reference Point: jyoRhing Laid= Elevation Structure Una Slot Unc 6038520.670(SOS) 518647.470(ftUS) 53.230(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 Prog: Description MD Front(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole/Survey 0.000 41.030 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 18.000 OP14-S3/OP14-S3 41.030 922.460 Act-Stns SLB_GVRO-MWD-No Global 18.000 OP14-S3/OP14-S3 922.400 2259.120 Act-Sms SLB_MWD+GMAG-No Global 16100 OP14-S3/OP14-S3 2259.120 10384.510 Act-Stns SLB_MWD*GMAG-No Global 12.250 OP14-S3/OP14-S3 10384.510 21340.000 Act-Stns SLB_MWD*GMAG-No Global 1750 OP14-S3 I OP14-S3 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 (5) (5) (ft) (5) (ft) (5) (5) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9351.00 ft m MD<=1832724 ft Results filtered:Ct-Ct separation r_150100 ft Results highlighted:Ct-Ct separation<=1320.00 ft 9340.00 3626.61 -2842.17 -5821 57 21340.00 3672.68 -3531 91 -4870 85 141.45 11 75.48 160 31 1066 20 11 45 OSF 1 50 Pass 9360.00 3628.00 -2831.01 -5838.11 21340.00 3672.68 -3531 91 -4870.85 141.45 1195.35 160 30 1086.08 11.64 OSF 1 50 Pass 9380.00 362940 -2819.85 -5854.65 21340.00 3672.68 -3531.91 -4870.85 141.45 1215.23 160.29 1105.97 11.84 OSF 150 Pass 9400.00 3830.79 -2808.70 -5871.20 21340.00 3672.68 -3531.91 -4870.85 141.45 1235.11 160.27 1125.86 12.03 OSF 1.50 Pass 9420.00 3632.19 -2797.54 -5887.74 2134000 3672.68 -3531.91 -4870.85 141.45 1254.99 160.26 1145.76 12.23 OSF 150 Pass 9440.00 3633.58 -2786.38 -5904.27 21340.00 3672.68 -3531.91 -4870.85 140.40 1274.88 160.25 1165.66 12.42 OSF 1 50 Pass 946000 363490 -2775.11 -592074 21340.00 3672.68 -3531.91 -4870.85 137.16 129478 16023 1185.57 12.62 OSF 1.50 Pass 9480 00 3636 14 -2763.71 -5937 13 21340 00 3672.68 -3531.91 -4870 85 133.38 1314 70 160 22 1205.50 12.81 OSF 1 50 Pass 9500.00 363729 -2752.19 -595143 2134010 3672.68 -3531.91 -487185 12101 1334.63 160.20 122145 13.01 OSF 1.50 Pass 9520.00 363136 -274154 -596185 21340.00 387268 -3531.91 -487185 12198 1354.50 160.17 124140 1121 OSF 1.50 Pass 9540.00 363135 -2728.76 -5985.79 2134010 3672.68 -3531.91 -4870.85 11127 1374.51 160.15 1285.37 1140 OSF 1.50 Pass 9560.00 3640.25 -2716.85 -6001.84 21340.00 3672.68 -3531.91 -4870.85 111.91 1394.48 160.12 1285.34 13.80 OSF 1.50 Pass 9580.00 3641.06 -2704.83 -8017.79 2134010 387268 -3531.91 -487015 105.01 1414.41 16019 130512 1180 OSF 1.50 Pass 9600.00 3641.79 -2692.68 -6033.86 21340.00 3672.68 -3531.91 -4870.85 97.78 1434.37 16018 1325.30 14.00 OSF 1.50 Pass 9620.00 3642.44 -2680.40 -6049.44 21340.00 3872.68 -3531.91 -4870.85 90.48 1454.33 180.03 1345.28 14.19 OSF 1.50 Pass 9640.00 3843.00 -2888.01 -8065.13 21340.00 3672.88 -3531.91 -4870.85 83.37 1474.29 159.99 1365.27 14.39 OSF 1.50 Pass 9660.00 3643.48 -2655.49 -6080.72 21340.00 3672.68 -3531.91 -4870.85 76.70 1494.24 159.98 1385.25 14.59 OSF 1.50 Pass End of results • Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:09 AM Page 4 of 4 Field: NikaHChuq Well: SP33-W3 Structure: Spy Island Borehole: SP33-W3 Slot: SP33 Trajectory: SP33-W3 Client: Ent Petroleum Type: De!Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.088436141 Grid Seale Factor: 0.909900149 Magnetic Declination: 20.4191 Magnetic Declination Date: August 01,2012 Magnetic Model: BGGM 2011 Reference Point: NorthinS Eaating flevatlor Structure Unc, Slot Unc, 6053611.830(ftUS) 511434.430(ftUS) 54.100(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 Proe: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.000 Act-Sins SLB_NSG*SSHOT-Depth Only-No Global 16.000 SP33-W3/SP33-W3 41.000 848.000 Act-Stns SLB_NSG*SSHOT-No Global 16.000 SP33-W3/SP33-W3 848.000 3080.350 Act-Stns SLB_MWD*GMAG-No Global 16.000 SP33-W3/SP33-W3 3060.350 8585.140 Act-Stns SLB_MWD*GMAG-No Global 12.250 SP33-W3/SP33-W3 8585.140 19484.210 Act-Stns SLB_MWD*GMAG-No Global 8.750 SP33-W3/SP33-W3 19484.210 19544.000 Act-Stns SLB BLIND*TREND-No Global 8.750 SP33-W3/SP33-W3 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 (ft) (ft) (ft) (ft) - (ft) (ft) (0) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9351.00 ft<=MD<=18327.24 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 9340 00 3626 61 -2842.17 -5821 57 10594 52 3568 88 -3727.93 -6584.72 217.31 1170.59 126 54 1085.91 13.97 OSF 1 50 Pass 9360.00 362800 -2831.01 -583811 10613.63 3569.88 -3715.51 .6599 22 217.33 1168.33 127.28 108315 13.86 OSF 1 50 Pass 9380.00 3629.40 -2819.85 -5854.65 1063273 3570.89 -3703.11 -6613.71 217.35 1166.07 128.03 108039 13.76 OSF 1.50 Pass 9400.00 3630.79 -2808.70 -5871.20 10651.83 3571.90 -3690.72 -6628.21 217.38 1163.83 128.77 1077.66 13.65 OSF 1.50 Pass 9420.00 3632.19 -2797.54 -5887.74 10870.94 3572.92 -3678 34 -6642.73 217.40 1161.61 129.52 1074.94 13.54 OSF 1.50 Pass 9440.00 3633 58 -2786.38 -5904.27 10690 04 3573 95 -3665.98 -6657.24 217.55 1159.41 130.26 1072 24 13.44 OSF 1.50 Pass 9460.00 3634.90 -2775.11 -5920.74 10709 05 3574 97 -3653.68 -6671 71 217.95 1157.33 131.01 1069.66 13.34 OSF 1.50 Pass 9480.00 3636.14 -2783.71 -5937.13 10728 08 3575 99 -3641 37 -6686.19 218 35 1155 42 131 76 1067 25 13.24 OSF 1.50 Pass 9500.00 3637.29 -2752.19 -5953.43 1074712 3577.01 -362907 -6700.70 218.75 1153.67 132.51 1065.00 13.15 OSF 1.50 Pass 9520.00 3638.36 -2740.54 -596965 10766.19 357802 -3616.77 -6715.22 219.15 115299 133.26 1062.92 13.05 OSF 1.50 Pass 9540.00 3639.35 -2728.76 -5985.79 10785.23 3579.02 -3604.49 -6729.75 219.55 1150.66 134.00 1061.00 12.96 OSF 1.50 Pass 9560 00 3640.25 -2716.85 -6001.84 10804 17 3580 04 -3592.30 -6744.20 219.94 1149.40 134 77 1059.23 12.88 OSF 1 50 Pass 958000 364106 -2704.83 -6017.79 1082312 358107 -3580.11 -6758.67 220.34 1148.31 135.53 105763 12.79 OSF 150 Pass 9600.00 3641.79 -2692.68 -6033.68 10842 07 3582 14 -3567 93 -6773.16 220.73 1147.38 13629 1056 19 12.71 OSF 1 50 Pass 9620.00 3642.44 -2880.40 -6049.44 1086103 358322 -355576 -678766 221.12 1146.61 137.05 1054.92 12.63 OSF 1.50 Pass 964090 3643.00 -2668.01 -6065.13 10880.01 3584.33 -3543.60 -6802.18 221.51 114692 13762 105381 12.55 OSF 1.50 Pass 9660.00 364148 -2655.49 -6080.72 10899.01 3585.41 -3531.43 -6816.74 221.90 1145.58 138.59 1052.86 12.48 OSF 1.50 Pass 9680.00 3643.87 -2642.86 -6096.22 10918 03 3586.44 -3519.26 -6831.31 222.29 1145.32 139 36 1052 08 12.40 OSF 1 50 Pass 9700 00 3644 17 -2630.10 -6111.62 10937 04 3587 43 -3507 11 -6845.89 222 69 MENERREID 140 12 1051 47 12.34 OSF 1 50 Pass 9720 00 3644 40 -2617.23 -6126 93 10953 39 3588 25 -3496 67 -6858.45 223.09 1145.29 141 17 1050 85 12.24 OSF 1 50 Pass 9740.00 3644.53 -2604.24 -6142 13 10968 46 3588 98 -3487.09 -6870.07 223.49 1145.60 142.34 1050 38 12.15 OSF 1.50 Pass 9760.00 3644.58 -2591.14 -6157.24 10983.53 3589.69 -3477.57 6881.73 223.90 1146.15 14351 1050.14) 12.05 OSF 150 Pass 9761.96 364458 -2589.85 -6158.72 10985.01 3589.76 -3476.64 -6882.87 223.94 1146.21 143.631 1050.1.1 12.04 OSF 1.50 Pass 9780.00 3644 55 -2577.92 -6172.25 10998 59 3590.39 -3468 10 -6893.42 224 31 1148.92 144.68 1050 14 11 96 OSF 1 50 Pass 9800.00 3644 43 -2564.59 -6187 16 11013 64 3591 07 -3458.69 -6905.14 224 72 1147.94 145 84 1050 38 11 88 OSF 1 50 Pass 9820.00 3644 22 -2551.14 -6201 96 11028 67 3591 73 -3449.33 -6916.89 225 14 1149 18 147 01 1050 85 11 79 OSF 1.50 Pass 9840 00 3643 94 -2537.58 -6216.66 11044.26 3592 39 -3439.68 -6929.11 225 55 1150.66 148 12 1051 59 11 72 OSF 1.50 Pass 9860.00 3643.56 -2523.92 -8231.26 11061 71 3593 11 -3428.92 -6942.83 225.96 1152.34 149.04 1052.66 11.66 OSF 1.50 Pass 9880.00 3643.11 -2510.15 -6245.76 11080.04 3593 85 -3417.64 -6957.26 226.22 1154.21 149.87 1053.96®. OSF 1.50 Pass 9900.00 3642.63 -2496.35 -6260.23 11105.43 3594.86 -3401.97 -6977.21 226.13 1156.07 15001 1055.73 11.63 OSF 1.50 Pass 9920.00 3642.16 -2482.55 -6274 70 11130 83 3595 90 -3386.20 -6997 10 226.04 1157.83 150 16 1057.40 11.63 OSF 1.50 Pass 9940.00 3641 69 -2468.76 -6289.18 11156 26 3596 97 -3370.33 -7016 93 225.96 1159.50 150 30 1058 98 11.64 OSF I 50 Pass 9960.00 3641.21 -2454.96 -6303.65 11182.10 3598 06 -3354.09 -7037 01 225 87 1161.08 150.39 1060.49 11.65 OSF 1.50 Pass 9980.00 3640.74 -2441.17 -6318.12 11208.52 359894 -3337.37 -705744 225.79 1162.55 150.43 1081.93 11.66 OSF 1.50 Pass 10000.00 364027 -2427.37 -633259 11234.99 3599.56 -3320.49 -7077.82 225.72 116391 150.46 1063.27 11.67 OSP 1.50 Pass 10020.00 363979 -2413.58 -6347.07 11261.51 3599.91 -330346 -709814 225.67 1165.15 150.49 1064.50 11.68 OSF 1.50 Pass 1004000 3639.32 -2399.78 -6361.54 11287.41 360008 -328670 -711789 225.63 1166.29 150.60 1065.57 1168 OSF 1.50 Pass 10060.00 3638.85 -2385.99 -6376.01 11313.24 3600.21 -3269 90 -7137 51 225.59 1167.33 150.70 1066 54 11 69 OSF 1.50 Pass 10080.00 3638.37 -2372.19 -6390.48 11339.08 3600.32 -3252.98 -7157.05 225.56 1168.27 150.80 1067.41 11.69 OSF 1 50 Pass 10100.00 3637.90 -2358.40 -640496 11365.46 3600.40 -323562 -717690 225.52 1169.11 150.84 1068.22 11.69 OSF 1.50 Pass 10120.00 3637.43 -2344.60 -6419.43 11393.29 3600.44 -3277.16 -7197.73 225.48 116982 150.75 1068.99 11.71 OSF 1.50 Pass 10140.00 3636.95 -2330.80 -6433.90 11421 13 3600.44 -3198.56 -7218.44 225.45 1170.40 150.65 106964 11 72 OSF 1.50 Pass ' 1016000 3636.48 -2317.01 -6448.38 11448.98 360038 -3179.81 -7239.04 225.42 1170.85 15055 107015 1173 OSF 1.50 Pass 10180 00 3636.01 -2303.21 -6462.85 11467.19 3600 34 -3167 52 -7252.47 225.40 1171.23 151.40 1069 97 11 67 OSF 1 50 Pass I 10200 00 3635.53 -2289.42 -6477.32 11484.49 3600 34 -3155 86 -7265.25 225.38 1171.66 152.34 1069 78 11 60 OSF 1.50 Pass 1022000 3635.06 -2275.62 -6491.79 11501.78 3600.38 -314424 -7278.06 225.36 1172.14 153.28 1069.63 1153 OSF 1.50 Pass 10240.00 3634.59 -2261.83 -6506.27 11519.07 3600.46 -3132.65 -7290.90 225.33 1172.67 154.22 1069.52 11.47 OSF 1.50 Pass 10260.00 3634.11 -2248.03 -6520.74 11536.36 3600.57 -3121.10 -7303.75 225.31 1173.24 155.16 106947 11.40 OSF 1.50 Pass 10280 00 3633.64 -2234.24 -6535.21 11553.68 3600 72 -3109.55 -7316.66 225 28 1173.85 156 1 r 1069 46 11.34 OSF 1.50 Pass 10300 00 3633.17 -2220.44 -6549.69 11571 03 3600 95 -3098 02 -7329.62 225 25 1174.51 157 03 1069.50 11 28 OSF 1 50 Pass 10320.00 3632.69 -2206.65 -6564.16 11588.37 3601 27 -3086 52 -7342.60 225.21 1175.22 157.97 1069.58 11.22 OSF 1.50 Pass 10340.00 3632.22 -2192.85 -6578.63 11605.70 3601 66 -3075 07 7355 60 225 17 1175.97 158.90 1069 71 11.16 OSF 1 50 Pass 10360.00 3631.79 -2179.08 -6593.13 11623.02 360213 -3063.65 7368.61 224.87 1176.73 159.85 1069.84 11.10 OSF 1.50 Pass 10380.00 3631.49 -2165.38 -6607.70 11641.24 3602 71 -3051.67 -7382.33 224.53 1177.45 160.70 1069.98 11.05 OSF 1.50 Pass 10400.00 3631.31 -2151 75 -6622.33 11665.35 3603 46 -3035 79 -7400.45 224.19 1178.04 161.01 1070.37 11.03 OSF 1 50 Pass 10420.00 363125 -2138.19 -6637.04 11689.47 360412 -301984 -7418.54 223.86 1178.47 161 31 1070.60 11.02 OSF 1 50 Pass 10440.00 3631 32 -2124.70 -6651 80 11713 61 3604 68 -3003 81 -7436 58 223.58 1178.73 161 61 1070.66 11.00 OSF 1 50 Pass 10460.00 3631.52 -2111.28 -6666.62 11736.98 360513 -2988.23 -7453.98 223.32 117885 161.99 1070.53 10.97 OSF 1.50 Pass 10480.00 3631.85 -2097.92 -6681.50 11758.16 3605.47 -2974.08 -7469.75 223.07 1178.84 162.60 1070.11 10.93 OSF 1.50 Pass 10500.00 3632.31 -2084.63 -6696.44 11779.35 3605.75 -2959.90 -7485.49 222.84 117813 163.21 1069.60 10.89 OSF 1.50 Pass 10520.00 3632 89 -2071.40 -6711 43 11800 53 3605.97 -2945 72 -7501 22 222.62 1178 52 163 82 1068 98 10 85 OSF 1 50 Pass • III Drilling Office 2.6.1120.0 Nikaitchuq\Sp Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 4 of 24 I Y � ) 9 Trajectory:SI32-W2(P6b)Vs.SP33-W3 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North An Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) 10540.00 3633.61 -2058.25 -6726.48 11821.70 3606.13 -2931.52 -7516.93 22641 1178.20 164.42 1068.28 1 80 OSF 1.50 Pass 10560.00 3634.46 -2045.16 -6741.58 11841.15 3606.22 -2918.48 -7531 34 22262 1177.79 165.20 1067.33 1 75 OSF 1 50 Pass 10580 00 3635.43 -2032.14 -6756.73 11860.30 360624 -290564 -7545.55 222.13 1177 32 166.01 1066.32 1 69 OSF 1 50 Pass 10600.00 3836.42 -2019.13 -6771.89 11879.44 3606 19 -2892.81 -7559.76 222.18 1176 85 166.81 1065.31 1 64 OSF 1 50 Pass 10620 00 3637.41 .2006 12 -6787.05 1189857 3606 07 -2880.00 -7573 97 222.23 1176 39 167.61 1064 32 1 5 OSF 1 50 Pass 10640 00 363839 -1993 11 -6802.21 11917 70 3605.88 -2867.20 -7588 19 222.29 1175 95 168.41 1063.351 1 5331 OSF 1 50 Pass 10660 00 3639.38 -1980.10 -6817.37 11949 06 3605.49 -2846.12 -7611 39 22638 117542 168 00 1063.09 1 55 OSF 1 50 Pass 10680 00 364037 -196709 -6832.52 1198054 360508 -2824.72 -763448 222.48 1174 70 16755 106267 1 57 OSF 1.50 Pass 10700 00 364136 -195408 -6847.68 1201169 360465 -2803.33 -765712 222.58 117378 167.12 1062.04 1 59 OSF 150 Pass 10720 00 3642 35 -1941 07 -6862.84 12031 95 3604 36 -2789.34 -7671 78 22264 1172 77 167.81 1060.57 1 54 OSF 1 50 Pass 10740 00 3643.34 -1928 06 -6878 00 12052.22 3604 06 -2775 35 -7686 44 222.71 1171 75 168.49 1059.10 1 48 OSF 150 Pass 10760 00 3844.32 -1915 06 -6893 16 1207248 3603 74 -2761 35 -7701 09 222.78 1170 73 169 16 105763 1 43 OSF 150 Pass 10780 00 3645 31 -1902.05 -6908 32 12092 74 3603 42 -2747 35 -7715 73 222.84 1169.71 169 83 1056.16 1 38 OSF 1 50 Pass 10800 00 3646.30 -1889.04 -692347 12113 80 3603.07 -2732.80 -7730 94 22261 116868 170.42 1054 73 1 34 OSF 150 Pass 10820 00 3647.25 -1876.02 -6938.63 12135 96 3602.64 -2717.45 -7746 92 22360 116762 170 94 1053 33 1 30 OSF 1 50 Pass 10840 00 3648.06 -1862 99 -6953.78 1215812 3602.14 -2702.08 -7762 87 22368 1166.53 17144 1051.91 1 26 OSF 150 Pass 10860 00 3648.73 -1849.95 -6968.93 12180.28 3601 57 -2686.67 -7778 78 223.16 116541 171.93 1050.46 1 22 OSF 1 50 Pass 1088000 3649.27 -1836.90 -6984.08 12201 18 3600.98 -2672.11 -7793 77 22324 116426 172.54 1048.91 1 17 OSF 1 50 Pass 10900.00 3649.67 -1823.84 -6999.22 12217.40 3600.52 -2660.83 -780542 22369 1163.16 17365 1047.06 1 10 OSF 1.50 Pass 1092000 3649.92 -1810.76 -7014.35 1223364 380069 -2649.57 -7817.11 223.34 1162.12 174.74 1045.30 1 02 OSF 150 Pass 10940.00 3650.04 -179767 -7029.47 12249.88 359969 -2638.35 -7828 85 223.38 1161.16 17583 104361 95 OSF 150 Pass 1096000 3650.02 -178458 -704459 1226614 3599.31 -262716 -784064 223.41 118026 176.91 1041.99 88 OSF 1.50 Pass 1098000 3649.86 -1771.48 -7059.70 1228241 359896 -2616.00 -785247 223.43 1159.43 17797 104645 82 OSF 150 Pass 11000 00 3649.59 -1758.37 -7074.80 12296 89 359868 -2606.10 -7863 03 223.44 115868 17928 1038.83 74 OSF 1 50 Pass 11020.00 364931 -174527 -7089.91 1230929 359842 -259768 -787213 223.44 1158.04 18086 1037.14 65 OSF 1.50 Pass 11040 00 364902 -173216 -7105.02 12321 69 359814 -2589 31 -7881 29 223.45 115754 182 39 103562 56 OSF 1 50 Pass 11060 00 3648 74 -171906 -712012 1233410 3597.84 -2581.01 7890 50 223.45 1157 16 18388 103425 48 OSF 1 50 Pass 11080 00 364846 -170595 -7135 23 12346 51 3597.53 -2572 76 -7899.77 22346 1156.' 185.32 1033.05 41 OSF 1 50 Pass 11100 00 364818 -169285 -7150.33 12358.92 3597.19 -256457 7909 09 223.4 illiElail 186 72 1032.00 33 OSF 1 50 Pass 11120 00 3647 90 -1679 74 -7165 44 12371.33 3596.84 -2556 45 -7918 46 223.48 1156.83 18810 1031.10 27 OSF 1 50 Pass 1 1 1 4 0 00 364761 -1666 64 -7180.54 12383.74 3596 47 -2548 38 -7927.89 22349 1156.98 189.48 11.7E OSF 1 50 Pass 11160 00 364733 -165353 -719565 1241060 3595.58 -253094 -7948 29 223.51 1157 15 189.42 103054 20 OSF 1 50 Pass 11180 00 3647.05 -164043 -7210.76 12438.30 359450 -251281 -796921 223.54 1157.18 189 35 103062 21 OSF 1 50 Pass 11200 00 3646.77 -1627 32 -7225.86 12466.00 359325 -249454 -7990.00 223.59 115708 189.38 103060 20 OSF 1 50 Pass 11220.00 3646.49 -161422 -7240.97 1248868 359212 -247950 -8006 92 22363 1156.87 18988 1029.96 18 OSF 1 50 Pass 11240.00 3646.20 -1601 12 -7256.07 1250768 359116 -2466.90 -8021.11 22366 1156.67 19068 1029.22 14 OSF 1.50 Pass 11260.00 3645.92 -158801 -7271.18 12526.67 359020 -2454 30 -8035.30 223.70 1156.48 191.49 102849 10 OSF 150 Pass 11280.00 3645.64 -1574.91 -7286.28 1254567 358964 -2441.72 -804960 223.73 1156.31 19231 1027.78 06 OSF 1.50 Pass 11300 00 3645.36 -1561.80 -7301.39 1256467 358828 -242916 -8063.72 223.77 115616 19314 102767 02 OSF 1.50 Pass 11320.00 364508 -154870 -731649 1258360 358731 -241645 -807812 223.80 1156.03 19363 102641 98 OSF 1.50 Pass 1134000 364479 -153559 -7331.80 1260325 3586.39 -240367 -809262 223.83 1155.90 194.70 1025.78 94 OSF 1.50 Pass 11360 00 364451 -1522.49 -7346.71 12622.60 3585.52 -2390.89 -810713 223.86 1155.79 795 46 1025.15 91 OSF 1.50 Pass 11380 00 3644.23 -1509.38 -7361 81 12641.96 358470 -2378 12 -812165 223.89 115569 196.23 102454 87 OSF 1.50 Pass 11400.00 3643.95 -1496.28 -7376.92 12661.32 3583 94 -2365 36 -8136.19 223 92 1155.60 197.00 1023.94 84 OSF 1.50 Pass 11420.00 3643.67 -148317 -739202 12683.10 3583 11 -2351 00 -815254 223 94 1155.50 197.53 102349 81 OSF 1 50 Pass 11440 00 3643.38 -1470.07 -740713 12705.31 3582.25 -2336 33 -816919 223 97 1155.37 198 01 102363 79 OSF 1 50 Pass 11460 00 364310 -1456.96 -742223 12727.52 3581 38 -232162 -818581 224 00 1155.20 198 50 102254 77 OSF 1.50 Pass 11480.00 3642 82 -1443.84 -7437.33 12749.73 3580 50 -2306 87 -820240 22424 1155.01 198 98 102203 74 OSF 1 50 Pass 11500.00 364252 -143068 -7452.38 1276864 3579 76 -2294 31 -8216 51 22466 1154.85 199 79 1021.33 71 OSF 1 50 Pass 11520.00 364223 -1417.52 -7,76744 12785 75 357916 -2282 97 -8229.31 22428 1154.74 200 79 102055 66 OSF 1 50 Pass 11540.00 364193 -1404.36 -748250 1280287 357864 -227166 -824215 22429 115467 20179 1019.82 62 OSF 150 Pass 11560 00 364163 -1391.20 -7497 56 12819 99 3578 21 -2260 38 -825502 224.3. 1154.86 202 80 1019 13 57 OSF 1 50 Pass 11580 00 3641.34 -1378.04 -7512.62 1283711 3577 65 -224914 -8267.93 224.30 1154.70 203 80 1018.50 53 OSF 1.50 Pass 11600.00 3641.04 -1364.88 -7527.68 1285415 3577.57 -223798 -828081 224.31 1154 78 204 80 1017.92 49 OSF 1 50 Pass 11620 00 3640.75 -1351.73 -7542.73 12870.88 3577 30 -222706 -829348 224.31 1154.92 205 85 1017.36 45 OSF 1 50 Pass 11640.00 3640.45 -1338.57 -755779 1288761 3576 99 -2216.18 -8306.18 224.31 115512 206 90 1016.86 41 OSF 1.50 Pass 1166000 3640.16 -132541 -757285 1290433 357665 -2205.33 -8318.90 224.31 1155.37 207 94 101642 37 OSF 150 Pass 1168000 3639.86 -1312.25 -7587.91 1292166 357627 -219452 -833166 22432 1155.68 20898 1016.04 33 OSF 1.50 Pass 1170000 363957 -129969 -7602.97 12937.78 3575 86 -2183.74 -834444 224.33 1156 05 21001 1015.71 29 OSF 150 Pass 1172000 3639.27 -128593 -7618.02 1295849 3575.33 -217043 -8380.29 22434 1156.45 210.67 P 1 27 OSF 150 Pass 11740 00 3638.98 -1272.77 -7633.08 1298167 3574 80 -215549 -8378.00 224.34 1156.81 211.08 1015.76 25 OSF 150 Pass 11760.00 363868 -125961 -7648.14 1300484 3574.36 -214050 -839568 22435 115711 211.49 1015.79 24 OSF 1 50 Pass 11780 00 363839 -1246.45 -7663.20 1302802 357401 -2125.46 -8413 31 224.35 1157 36 211.90 1015 76 22 OSF 1 50 Pass 11800 00 3638 09 -123329 -7678.26 13047.93 3573.76 -2112.52 -8428 44 224.35 115756 21262 101549 20 OSF 1 50 Pass 11820 00 3637.80 -122013 -7893.32 1306555 357359 -2101 09 -8441 85 22434 1157 80 21357 1015.10 16 OSF 1 50 Pass 11840 00 363750 -1206 97 -7708 37 1308317 357345 -2089.69 -8455 28 22433 1158 09 214.52 1014 74 13 OSF 1 50 Pass 11860 00 3637.21 -119382 -7723.43 13100.79 3573.35 -2078 32 -8468 74 22433 1158 41 215 47 1014 43 09 OSF 1 50 Pass 11880 00 3636.91 -118066 -773849 1311840 357329 -2066 98 -8482 22 224.31 1158 77 216 42 101416 06 OSF 1 50 Pass 11900 00 363661 -116751 -7753.56 13135.34 3573.27 -2058 11 -849521 22413 1159.16 21744 1013.88 03 OSF 1 50 Pass 11920.00 363624 -115444 -776869 1315068 357329 -2046 30 -8507.00 223 77 1159.52 218.63 101344 98 OSF 1 50 Pass 11940.00 3635.80 -1141 46 -7783 90 13166.02 3573 36 -2036 55 -8518.84 22341 1159.83 21981 1012.97 94 OSF 1 50 Pass 11960.00 363529 -1128 57 -7799.19 13181 35 357347 -2026 85 -853071 223.03 116010 22099 101245 90 OSF 1 50 Pass 11980 00 363471 -111578 -7814.55 13196 67 357362 -2017 20 -854262 22265 1160.33 22217 1011 89 86 OSF 1 50 Pass 12000.00 3634.05 -1103.08 -7829 99 13211 99 3573 82 -200761 -855456 22227 1160.52 223 35 1011.29 82 OSF 1.50 Pass 12020.00 3633.32 -109048 -784550 13228.03 3574.08 -199762 -8567.10 221.86 116066 22448 101668 78 OSF 1.50 Pass 12040.00 363254 -1077.97 -7861.09 13248.21 3574.39 -1985.07 -858290 221.43 1160.70 225.23 101062 76 OSF 1.50 Pass 12060.00 3631.68 -1065.56 -7876 75 13268.38 357464 -197252 -8598.70 221.00 116061 225 97 1009.64 73 OSF 1 50 Pass 12080.00 3630.77 -105326 -789249 13288.56 3574 85 -195966 -8614.49 220.57 116040 226.71 100863 70 OSF 1.50 Pass 1210000 3629.79 -1041.05 -790830 13308.74 357501 -1947.39 -863028 22014 1160.05 22745 100869 68 OSF 1.50 Pass 1212000 3628.75 -102894 -792419 1332844 357510 -193513 -864568 219.71 115957 22825 1007.08 65 OSF 150 Pass 12140 00 3627.65 -1016 94 -794015 13347.78 357506 -1923.08 -8660.82 21927 115898 229.07 1005.93 62 OSF 1 50 Pass 12160 00 3626.49 -100504 -7956.18 1336713 357488 -1911.03 -8675 96 21886 115827 229 89 100468 58 OSF 1 50 Pass 12180.00 362529 -993 18 -7972 24 13386 50 357457 -1898.98 -8691 11 218.82 115751 230.72 1003.37 55 OSF 150 Pass 12200 00 362410 -981 32 -7988.30 13405.87 357413 -1886 93 -8706.28 218.79 1156 77 231 54 1002.08 52 OSF 1 50 Pass 12220 00 3622 90 -969 47 -8004.36 1342420 3573.64 -1875 54 -872063 218.76 1156 04 232 48 1000 73 48 OSF 1 50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 5 of 24 Trajectory:SI32-W2(Fob)W.SP33-W3 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 (ff) (ft) (h) (ff) (ff) (ft) (h) (N) (°) (h) ((t) (ff) 12240 00 3621 71 -957.61 -8020.43 13442 20 3573.22 -1864.38 .8734.74 218.73 1155.35 233.43 999.40 7.45 OSF 1.50 Pass 12260 00 3620.51 -945.76 -8036.49 1346019 3572.88 -1853.25 -8748.87 21869 1154.69 234.37 998.12 7.42 OSF 150 Pass 12280 00 3619 32 -933 90 -8052.55 1347818 3572.60 -184215 -8763.02 218.65 1154.06 235 29 996 88 7 38 OSF 1 50 Pass 12300 00 361813 -922.05 -8068.61 1349616 3572.40 -183107 -8777.19 21861 1153.47 23620 995.68 7.35 OSF 1.50 Pass 12320 00 3616.93 -910.19 -8084.68 1351473 3572.25 -181986 -8791 84 218.56 1152.92 237.20 994.46 7.31 OSF 1.50 Pass 12340 00 3615.74 -898.33 -8100.74 13533 76 3572.07 -180798 -8806.87 218.52 1152.38 238.03 993.36 7.29 OSF 1.50 Pass 12360 00 361454 -886.48 -8116.80 13552 80 357186 -1796.31 -882190 218.47 1151.86 23876 992.36 7.26 OSF 1.50 Pass 12380 00 3813.35 -874.62 -8132.87 13571 84 3571.62 -178485 -8836.95 218.43 1151.36 239.55 991 33 7.23 OSF 1.50 Pass 12400 00 361215 -862 77 -8148.93 13590 88 3571.35 -1772 99 -8852.01 218.39 1150.87 240.46 990 23 7.20 OSF 1.50 Pass 12420 00 3610.97 -850.93 -8165.00 13609 77 3571 05 -1761 44 -8866.96 218.15 1150 38 241 30 989 18 7.17 OSF 1.50 Pass 12440 00 3609.87 -839 17 -8181.14 13628 59 3570.76 -1749.96 -8881.86 217.78 1149.81 242.15 988.05 7.15 OSF 1.50 Pass 12460 00 3608.85 -827.49 -8197.35 13647 41 3570.48 -173848 -8896.77 217.41 1149.15 243.01 986.82 7.12 OSF 1.50 Pass 12480.00 3607.91 -815.91 -8213.63 13666 23 3570.20 -1727.02 -8911.70 217.06 1148.41 243.88 985.49 7.09 OSF 1.50 Pass 12500.00 3607.06 -804.42 -8229.98 13685.05 3569.93 -1715.58 -8926.63 216.70 1147.57 244.76 984.07 7.06 OSF 1.50 Pass 12520 00 3606.28 -793.02 -8246.39 1370490 3569.68 -1703.52 -8942.40 216.36 1146.64 245.51 98264 7.03 OSF 1.50 Pass 1254000 3605.59 -78171 -8262.87 1372517 356951 -169120 -8958.50 216.01 1145.60 246.22 98t t2 7.00 OSF 1.50 Pass 12560 00 3604 99 -770 49 -8279.41 13745.44 3569 45 -167889 -897469 215.66 1144.43 246.93 97949 6.97 OSF 1 50 Pass 12580 00 3604.46 -759.36 -8296.02 13765 69 3569.48 -1666.58 -8990.68 215.32 1143.16 247.65 977.73 6.95 OSF 1.50 Pass 12600 00 3604.01 -748.32 -8312.70 13785 75 3569.60 -1654.38 -9006.61 214.98 1141.77 248.38 975.85 6 92 OSF 1.50 Pass 12620.00 3603.65 -737.38 -8329.44 13804.21 3569.81 -1643.17 -9021.27 214.64 114028 24926 973.78 6.88 OSF 1.50 Pass 12640.00 3603.35 -726.51 -8346.22 13822.67 3570.12 -1631.99 -9035.95 214.54 1138.73 250.14 971.65 6.85 OSF 1.50 Pass 12660.00 3603.04 -715.64 -8363.01 13841 13 3570.52 -1620.82 -9050.64 214.51 113722 251.02 969.54 6.82 OSF 1.50 Pass 1268000 3602.74 -704.77 -8379.79 13859.58 3571.03 -1609.69 -906535 21447 1135.72 251.92 967.45 6.78 OSF 1.50 Pass 12700.00 3602.44 -693.90 -8396.58 13878.20 3571.63 -1598.47 -9080 20 214.42 1134.26 252.80 965.40 6.75 OSF 1.50 Pass 12720 00 3602.13 -683.03 -8413.36 13900.45 3572.47 -1585.07 -9097 94 214 37 1132 78 253.34 963.56 6 73 OSF 1.50 Pass 12740 00 3601.83 .672.16 -8430.15 13922.68 3573.40 .1571 64 -911563 214.30 1131.26 253.89 961.68 6.70 OSF 1.50 Pass 1276000 3601.53 .661.29 -8446.93 13944.90 3574.43 -1558.19 -913329 21424 1129.71 254.44 959.75 6.68 OSF 1.50 Pass 1278000 3601.22 -650.42 -8463.72 13967.09 3575.57 -1544.72 -9150.89 214.16 1128.11 255.00 957.79 6.86 OSF 1.50 Pass 1280000 3600.92 -639.55 -8480.50 13999.30 3577.18 -1525.04 -9176.33 214.06 1126.42 25461 956.35 6.66 OSF 1.50 Pass 12820.00 360062 -628.68 -8497.29 1403548 357844 -1502.51 -920461 213.97 1124.44 25379 954.92 6.67 OSF 1.50 Pass 12840.00 3600 32 -617 81 -8514.07 14076 29 357917 -1476.58 -923612 213 91 1122.18 2524 IIgEtl 6 69 057 1.50 Pass 12860.00 3600 01 -606.94 -8530.86 14170.72 357917 -1413.32 -9306 20 213 85 1118.66 24514 955.10 6 87 OSF 1.50 Pass 12880.00 3599.71 -596.07 -854765 1418925 3579.13 -140048 -931957 213.84 1115.06 246.01 950.73 6.82 OSF 1.50 Pass 12900.00 359941 -585.20 -856443 1420779 3579.24 -1387.66 -9332.95 213.82 1111.29 246.87 946.38 6 77 OSF 1.50 Pass 12920.00 359910 -574.33 -8581.22 14226.33 357950 -1374.85 -9346.34 213.79 1107.54 24774 942.05 6.73 OSF 1.50 Pass 12940 00 3598.80 -56346 -8598.00 1424486 357993 -136206 -9359.75 213.76 1103.80 24861 937.73 6.68 OSF 1.50 Pass 12960.00 3598.50 -552.57 -861478 1426358 358051 -1349.15 -9373.31 213.92 1100.10 24946 933.47 6.64 OSF 1.50 Pass 12980 00 3598.22 -541.59 -8631.49 14284 75 3581.21 -1334.57 -938862 214.28 1096.52 250.02 929.51 6.60 OSF 1.50 Pass 13000 00 3597.96 -530.49 -8648.12 1430593 3581.84 -1319.94 -9403.93 21485 1093.04 25059 92565 6.56 OSF 1.50 Pass 13020 00 359772 -519.27 -866468 1432713 3582.40 -130528 -9419.24 215.02 1089.68 25114 92192 653 OSF 150 Pass 13040 00 359750 -507.94 -8681.16 14348.36 358290 -129058 -943454 215.39 1086.42 25169 918 30 6.49 OSF 1.50 Pass 13060 00 3597.30 -496.50 -8697.56 1436764 358328 -127721 -944843 215.77 108328 25248 914.63 6.46 05F 1.50 Pass 13080.00 3597.12 -484.94 -8713.88 1438525 358352 -126502 -9461.14 216.15 1080.31 25347 911.01 6.41 OSF 1.50 Pass 13100.00 3596.96 -47328 -8730.13 14402.89 358365 -125283 -947389 216.55 1077.52 25446 90755 6.37 OSF 1.50 Pass 1312000 3596.82 -461.49 -8746.29 1442057 358365 -124064 -948669 216.95 1074.91 25545 90428 6.33 OSF 1.50 Pass 13140.00 359669 -44960 -8762.37 1443816 358354 -122846 -949953 217 34 1072.47 256 44 901 19 6 29 OSF 1.50 Pass • 13160.00 3596.58 -437.66 -8778.41 1445597 358332 -1216.31 -9512 39 217 35 1070.14 25744 898 19 6 25 057 1.50 Pass 13180.00 3596.46 -425.71 -879445 1447360 3583.03 -120422 -9525.23 217.36 1067.85 25844 895.23 6 22 OSF 1.50 Pass 13200.00 3596.34 -413.77 -8810.49 14491 23 3582.73 -1192.17 -953810 217.37 1065.60 25945 892.31 6.18 OSF 150 Pass 13220.00 3598.22 -401.82 -8826.53 14508.88 3582.41 -118013 -9551.00 217.38 1063.39 26046 889.42 614 OSF 1.50 Pass 13240.00 3596.11 -389.88 -8842.57 14528.53 358206 -116811 -956393 217.40 1061.22 26147 886.58 6.11 OSF 1.50 Pass 1326000 3595.99 -377.94 -8858.62 1454419 358170 -1156.12 -957688 217.41 1059.10 26249 88378 6.07 OSF 150 Pass 13280 00 3595.87 -365 99 -8874.66 1456011 3581 37 -1145 34 -958859 21743 1057.02 26371 880 89 6 03 OSF 1.50 Pass 13300.00 3595.75 -354.05 -8890.70 14575 04 3581.07 -1135.28 -959962 21744 1055.04 26505 87801 599 OSF 1.50 Pass 13320 00 359564 -342.10 -8906.74 14589.98 3580.81 -1125.27 -961070 217.45 1053.15 266.38 875.24 5 95 057 1 50 Pass 13340 00 3595.52 -330.16 -8922.78 1460494 3580.57 -111529 -9621 84 21746 1051.36 26771 872 55 5.91 OSF 1.50 Pass 13360 00 3595.40 -318.22 -8938.82 1461990 3580.36 -1105.36 -9833.04 217.47 1049.65 26904 869.97 5.87 057 1.50 Pass 13380.00 359529 -306.27 -8954.86 14634.88 3580.18 -109548 -964430 21747 1048.05 27037 86747 5.83 OSF 1.50 Pass 13400.00 359517 -294 33 -8970.90 14650.34 3580.02 -1085.34 -9655.96 217.48 1046.53 27164 86511 579 OSF 1.50 Pass 13420 00 3595.05 -282.38 -8986.95 14667.73 3579 85 -107397 -966912 217.48 1045.08 27269 862 86 5.76 057 1.50 Pass 13440 00 3594.93 -270 44 -9002.99 14685 12 3579.70 -106263 -9682.30 217.49 1043.68 27374 860 86 5 73 OSF 150 Pass 13460 00 3594.82 -258.50 -9019.03 14702.51 3579 55 -1051.32 -969552 217.49 1042.33 27478 858.81 5.70 OSF 1 50 Pass 13480 00 3594 70 -246.55 -9035.07 1471992 3578 42 -104004 -970877 217.49 1041.03 27583 856.81 568 OSF 1.50 Pass 13500 00 359458 -23461 -9051.11 14737 32 3579 30 -1028.79 -9722.05 217.49 1039.77 276 88 854.86 565 OSF 1.50 Pass 13520.00 3594.46 -222.66 -9067.15 14756 71 3579.17 -1016.29 -9736.87 217.50 1038.56 277.71 853.09 5.62 OSF 1.50 Pass 13540.00 3594.35 -210.72 -9083.19 1477709 3579.03 -1003.14 -975244 217.50 1037.33 27843 851.39 560 OSF 1.50 Pass 13560.00 359423 -198.77 -909923 14797.47 3578.89 -989.99 -976800 21750 1036.10 279.14 84968 5.58 OSF 1.50 Pass 13580 00 359415 -186 82 -911527 1481785 3578 73 -976.83 -978356 21759 1034.87 27985 847.98 5.56 OSF 1.50 Pass 13600 00 359421 -174 85 -913129 14838 22 3578 57 -96366 -979912 217.89 1033.86 28053 846 32 5.54 OSF 1 50 Pass 13620 00 359440 -162 86 -9147.30 14856.40 357842 -951 93 -981300 217.78 1032.49 28145 844 53 5.52 OSF 1 50 Pass 13640.00 3594.73 -150.86 -9163.29 14874.46 3578.25 -940.30 -9826.81 217.89 1031.37 282 39 842 78 5.49 OSF 1.50 Pass 13660.00 3595.20 -138.85 -917928 14892 51 3578.07 -928.69 -9840.63 21800 1030.31 283.33 841.10 547 0871.50 Pass 13680.00 3595.81 -126.82 -9195.24 14910.57 3577.86 -91711 -9854.48 218.11 1029.31 284.27 83947 545 OSF 1.50 Pass 13700.00 3596 56 -114 78 -9211.20 14928.62 3577.65 -905.56 -986835 21823 1028.37 285.20 83791 542 OSF 1.50 Pass 13720 00 359742 -102 73 -922713 14945 41 357743 -894 84 -988127 218.32 102750 28628 836 31 540 OSF 1.50 Pass 13740 00 3598 31 -9068 -9243.07 14961 41 357725 -88467 -989364 218.37 1026 70 28745 83473 5.37 0071 50 Pass 13760.00 359920 -7862 -925901 14977 43 3577 07 -874 54 -9906 04 218.42 102598 28862 83323 5 35 OSP 1.50 Pass ■ 13780.00 360008 -66 57 -927494 1499345 3576 92 -86446 -991849 218.47 102533 289 79 831 81 5.32 007150 Pass 13800.00 360097 -5452 -9290.88 1500948 3576.79 -85442 -9930.98 218.52 1024.77 29096 830.47 5.30 OSF 1.50 Pass • 13820.00 3601.86 -42.47 -9306.81 1502552 3576.67 -84442 -9943.52 218.57 1024.28 29214 829.20 527 OSF 1.50 Pass 13840.00 3602.74 -3041 -932275 1504513 3576.53 -83223 -9958.89 21862 1023.85 29293 82824 526 OSF 1.50 Pass 13860.00 360363 -18.36 -9338.69 15067 07 3576.37 -81858 -9976.06 218.69 102339 29346 82743 5.24 OSF 1.50 Pass 13880.00 360452 -6 31 -935462 15089 00 3576 19 -804 89 -9993.20 218.75 102290 293.99 826 57 523 OSF 150 Pass 1390000 3605 40 5 74 -937056 15110 93 3575 99 -791.18 -1001031 218.82 1022.36 294.53 825.68 522 OSF 150 Pass 13920 00 3606 29 17 79 -9386.50 1513316 3575 77 -777 24 -1002762 218.89 1021.79 29502 824 78 5 21 OSF 1.50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 6 of 24 Trajectory.SI32-W2(P8b)Vs,SP33-W3 • Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Atm Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) • 13940 00 380718 29.85 -9402.43 1515647 3575.54 -762.58 -10045.74 218.96 1021.17 295.39 823.91 5.20 OSF 1.50 Pass 13960 00 3608 06 41 90 -9418 37 15179 78 3575 34 -747 85 -10063.81 219.03 02047 295 75 822 98 5 19 OSF 1 50 Pass 13980 00 3608 95 53.95 -9434 30 15203 08 3575 16 -733.07 -10081 82 219.10 1019 72 296 11 821 98 5 18 OSF 1 50 Pass 14000 00 3809 78 66.01 -9450.24 15225 89 3575.00 -718.55 -10099.41 21920 1018.90 296.52 820.89 5 17 OSF 1 50 Pass 14020.00 3610.46 78.09 -9466.16 15243.38 3574.87 -707.41 -10112 89 21928 1018 11 297.55 819.41 5.14 OSF 1.50 Pass 14040 00 3611.01 90.19 -9482 08 15260.87 3574.72 -696.31 -10126.41 219.36 1017.37 29857 818.00 5.12 OSF 1 50 Pass 14060.00 3611.43 102.30 -9497.99 15278.37 3574.53 -685.23 -10139.95 219.43 1016.70 29959 816.64 5.10 OSF 1.50 Pass 14080.00 3611.70 114.43 -9513.89 15295.88 357432 -674.18 -10153.53 21950 1016.09 300.62 815.35 5.08 OSF 1.50 Pass 14100 00 361183 126.58 -9529.78 15313.39 357408 -663.16 -1016714 219.56 1015.55 301.65 814.12 5.06 OSF 1.50 Pass 14120 00 3611 83 138.74 -9545.65 15332 28 3573.78 -651.30 -10181 83 219.62 1015.05 302.53 813.04 5.04 OSF 1 50 Pass 14140 00 3611.71 150.91 -9561.52 15352 11 3573.33 -638.85 -10197 27 219.65 1014 58 303.31 812.05 5.03 OSF 1 50 Pass 14160 00 3611 56 163 08 -9577 39 15371 95 3572.75 -626.40 -10212 70 219.68 1014 11 304.08 811.06 5.01 OSF 1 50 Pass 14180 00 3611.42 175.25 -9593.26 1539177 3572.04 -613.96 -1022812 219.71 101364 304.86 810.07 5.00 OSF 150 Warning 14200 00 361128 18743 -960913 15411 59 3571.18 -601.53 -1024353 219.75 101317 305.64 809.09 498 OSF 150 Warning 14220 00 3611 14 199 60 -9625 00 15430.91 3570.24 -589 41 -10258 55 219.80 1012 71 306.46 808.08 4.97 OSF 1 50 Warning 14240.00 3611.00 21177 -9640.87 15450.04 3569.25 -577.43 -1027342 219.85 101227 307.32 807.07 4.95 OSF 1.50 Warning 14260 00 3610.86 223.94 -9656.74 15469.16 3568.21 -565.46 -10288 30 219.90 1011.85 308.17 806.08 4.94 OSF 1 50 Warning 14280 00 3610.72 236.12 -9672.60 15488.27 3567.12 -553.51 -10303.18 219.95 1011.45 309.02 805.11 492 OSF 1.50 Warning 14300.00 3610.57 24829 -9688.47 15507.39 3565.98 -541.57 -10318.06 220.01 101t06 309.87 80415 491 OSF 1.50 Warning 14320.00 3610.43 26046 -9704.34 15529.99 3564.64 -527.44 -10335.66 220.08 1010.67 310.31 803.46 4.90 OSF 1.50 Warning 14340.00 361029 272.63 -9720.21 15554.21 356346 -51223 -10354.47 220.14 1010.19 310.57 802.82 489 OSF 1.50 Warning 14360 00 361015 284.81 -9736.08 15578 44 356254 -49694 -1037324 220.18 1009.64 310.83 802.09 488 OSF 150 Warning 14380 00 361001 296.98 -975195 1560268 356190 -48157 -1039197 220.21 1009.00 31109 801.28 4.88 OSF 150 Warning 14400 00 3609 87 309.15 -9767 82 15622 73 3561 57 -468.82 -10407 44 220.22 1008 31 311 83 800 09 4 86 OSF 1 50 Warning 14420 00 3609.72 321.32 -978368 1564111 356145 -457.15 -10421.64 220.23 1007.64 31277 79881 484 OSF 150 Warning 14440 00 3609 58 333.49 -9799 55 15659 50 3561 50 -445.51 -10435 87 220.22 1007 01 313 70 797 55 4 83 OSF 1 50 Warning 14460 00 360944 345.67 -981542 1567788 356172 -433.90 -10450.13 220.20 1006.41 31464 79632 481 OSF 150 Warning 14480 00 3609.30 357.89 -9831.25 15696 26 356210 -422.33 -10464.40 22055 1005.90 315.57 79519 479 OSF 150 Warning 14500 00 3609.16 370.22 -9847.00 15716 07 356268 -409.88 -10479.79 220.91 1005.56 316.36 794.33 4.78 OSF 1 50 Warning 14520 00 3609 02 382.66 -9862.66 15737 41 3563.27 -396.45 -10498 37 221.27 1005.34 316 96 793 70 4.77 OSF 1.50 Warning 14540.00 3608.88 395.21 -9878.23 15758.75 3563.80 -383.00 -10512.93 221.64/ 1005.231 317.56 793.19 4.76 OSF 1.50 Warning 14560.00 3608.74 407.87 -9893.71 15780.10 3564.28 -369.51 -10529.47 222.00 1005.23 318.16 792.80 4.75 OSF 1.50 Warning 14580 00 3608.60 420.64 -9909 11 15801.45 3564 70 -356.00 -10548 00 222.37 1005.35 318.76 792.51 4.74 OSF 1.50 Warning 14600.00 3608.46 433.51 -9924.41 15822.00 356504 -342.98 -1056189 222.75 1005.59 319.46 79.29 4.73 OSF 1.50 Warning 14620.00 3608.32 446.49 -9939 63 15842 52 3565 29 -329.96 -10577 75 223.13 1005.95 320 1`MIIIIIITIME 4 72 OSF 1 50 Warning 14640 00 3608 18 459.58 -9954 75 15863 04 3565.46 -316.93 -10593.61 223.51 100645 320 85 792.22 4 72 OSF 1.50 Warning 14660.00 3608.03 472 77 -9969 78 15883.57 3565 54 -303 89 -10609.48 223.90 1007.07 321 54 792 39 4 71 OSF 1.50 Warning 14680.00 3607.88 486.06 -9984 72 15904.93 3565.53 -290.31 -10625.94 224.29 1007.82 322.13 792 74 4.70 057 1.50 Warning 14700 00 3607 72 499.46 -9999 57 15928 38 3565 39 -275.34 -10643 99 224 89 1008.66 322 47 793 35 4 70 055 1 50 Warning 14720.00 3607.55 512.96 -10014 32 15951 82 3565.11 -260.31 -10661 98 225.10 1009 56 322.81 794.03 4.70 OSF 1 50 Warning 14740.00 3607.38 526.57 -1002898 15975.27 3564.69 -245.21 -10679.92 225.52 1010.54 323.14 794.78 470 OSF 150 Warning 14760.00 3607.19 540.28 -10043.54 15998.05 3564.14 -230.48 -10697.29 225.94 1011.58 323.54 795.56 4.70 OSF 1 50 Warning 14780.00 3607.01 554.08 -10058.01 16017.82 356385 -217.69 -1071234 226.36 1012.75 324.28 796.23 4.69 OSF 1.50 Warning 14800.00 3606 81 567.99 -10072.38 16037.57 3563.20 -204.90 -10727 40 226.77 1014.06 325.03 797.04 4.69 OSF 1.50 Warning 14820.00 3606.60 582.00 -10086.66 16057.32 3562 79 -192 12 -10742.45 227.19 1015.51 325.77 798.00 4.69 OSF 1.50 Warning 14840.00 3606.39 596 11 -10100.83 16077.05 3562 42 -179.36 -10757 49 227.60 1017.10 326.51 799 10 4.68 OSF 1.50 Warning 14860.00 3606.17 610.31 -1011491 16096.35 356210 -166.88 -10772.21 228.01 1018.84 327.30 800.31 4.68 OSF 1 50 Warning 14880.00 3605.94 624.62 -10128.88 16114.64 3561 72 -155.07 10786 17 228.42 1020 74 328.20 801.60 4.67 057 1 50 Warning 14900 00 3605.71 639.02 -10142 76 16132.90 3561.25 -143.30 -10800 13 228.84 1022 80 329.11 803 07 4.67 OSF 1 50 Warning 14920.00 360547 653.52 -10156.54 16151.15 356068 -131.56 -1081408 229.26 102504 33000 80472 4.67 OSF 150 Warning 14940 00 3605 22 668.11 -10170.21 16169.37 3560 02 -119.86 -10828 03 22989 1027.45 330 89 806 53 4 67 OSF 1 50 Warning 14960.00 3604.96 682.79 -10183 79 16187 50 3559 26 -108 24 -10841 92 229.98 1030.02 331 79 808 50 4 67 OSF 1 50 Warning 14980.00 3604.70 697.49 -1019735 16203.59 355857 -97.95 -10854.28 230.00 1032.68 332.93 810.39 4.66 OSF 1.50 Warning 15000.00 3604.44 712.19 -10210.90 16219.67 3557 94 -87.72 -10866 67 230.02 1035.40 334.07 812 36 4.66 OSF 1.50 Warning 15020.00 3604.19 726.89 -10224.46 16235.73 3557.36 -77.55 -1087908 230.04 1038.20 335.21 814.40 4.66 OSF 1.50 Warning 15040.00 3603.93 741.60 -10238.02 16251.78 3556.83 -67.43 -10891 53 230.05 1041.07 336.35 816.51 4.65 OSF 1.50 Warning 15060.00 3603.67 756.30 -10251 57 16267.81 3556.35 -57.36 -10904.00 230.06 1044.00 337.48 818.69 4.65 OSF 1.50 Warning 15080.00 3603.41 771 00 -10265.13 16284.27 3555.92 -47.08 -10916 84 230.06 1047 01 338.57 820.97 MINNErgi OSF 1 50 Warning 15100 00 3603.15 785 70 -10278.69 16312.58 3555.06 -29.33 -10938.88 230.08 1049 97 338.40 824.04 4.66 OSF 1 50 Warning 1512000 3602.89 80040 -10292.25 16340.94 3553.90 -1136 -1096080 230.06 1052.76 338.21 82697 4.68 OSF 150 Warning 15140 00 3602 55 815 06 -10305.85 16369.38 3552.45 6.83 -10982 60 229.89 1055 33 337.99 829.67 4.69 OSF 1 50 Warning 15160.00 3602 11 829.65 -10319.52 16400.92 3550 56 27.24 -11006 58 229.72 1057.62 337.40 832 36 4 71 OSF 1 50 Warning 15180.00 3601 55 844 18 -10333.25 16434.24 3548 46 49.11 -11031 63 229.53 1059.57 336 58 834.86 4 73 05F 1 50 Warning 15200.00 3600.89 85865 -10347.04 16467.65 354624 7135 -1105646 229.34 106118 335.70 837.04 4.75 OSF 150 Warning 15220 00 3600.13 873 05 -10360 90 16487.63 3544.89 84.77 -11071 20 229.20 1062.53 336.43 837.92 4.75 OSF 1 50 Warning 15240.00 3599.35 887.44 -1037477 16503.32 3543.84 95.27 -11082.82 229.22 1063.93 337.66 838.50 4.74 OSF 150 Warning 15260.00 3598.57 90183 -10388.64 16519.01 3542.81 105.72 -1109447 229.23 1065.41 338.89 839.16 4.73 OSF 150 Warning 15280.00 3597.78 916.22 -10402.51 16534.69 3541.79 116 11 -11106 16 229.25 1066.98 340.11 839.91 4.72 OSF 1 50 Warning 15300.00 3597 00 930.61 -10416.38 16550.36 3540.80 126.46 -11117 89 229.27 1068.62 341.33 840.74 4.71 OSF 1.50 Warning 15320 00 3596 21 945.00 -10430.25 16568.02 3539 83 136 74 -11129 66 229.29 1070.34 342.54 841.65 4.70 OSF 1 50 Warning 15340 00 3595 43 959.38 -10444.12 16585.10 3538 71 149 24 -11144 04 229.30 1072.12 343.37 842 88 4.69 OSF 1 50 Warning 15360 00 3594 65 973 77 -10457.99 18606.26 3537 74 163 11 -11159 99 229.30 1073.89 343.96 844.25 4 69 OSF 1 50 Warning 15380 00 3593 86 988 16 -10471 85 16627.42 3537 07 176 99 -11175 95 229.29 1075.63 344.56 845 60 4.69 OSF 1 50 Warning 15400 00 3593 08 1002.55 -10485.72 16648.57 3536 69 190 88 -11191 90 229.26 1077 35 345 16 846 91 4 69 OSF 1 50 Warning 15420.00 3592 30 1016.94 -10499 59 16669.63 3536 59 204 71 -11207 77 229 21 1079.04 345.79 848 19 4 69 057 1 50 Warning 15440.00 3591 51 1031 33 -10513 46 16689.62 3536 78 217 84 -11222 84 229.16 1080.73 346 54 849 38 4.69 OSF 1 50 Warning 15460.00 3590 73 1045 71 -10527 33 16709.57 3537 24 230 93 -11237 89 229.09 1082.42 347.30 850 56 4.68 OSF 1 50 Warning 15480.00 3589.95 1060.10 -10541.20 16729.48 3537.96 24398 -1125291 229.00 1084.11 348.07 85173 4.68 OSF 1.50 Warning 15500 00 3589.16 1074.49 -10555.07 16749.35 3538 95 256.99 -11267.90 228.91 1085.80 348.85 852.90 4.68 OSF 1 50 Warning 15520.00 3588.38 1088.88 -10568.94 16769.86 3540.25 270.40 -11283.37 228.79 1087.49 349.58 854.11. 4.88 OSF 1.50 Warning 15540.00 3587.60 1103.27 -10582.81 16792.54 3541.73 285.25 -11300.44 228.66 1089.15 350.08 855.43 4.68 OSF 150 Warning 15560.00 3586.81 1117.66 -10596.68 16815.24 3543 18 300.17 -11317 48 228.53 1090.76 350.58 856 71 4.68 OSF 1 50 Warning 15580 00 3586.03 1132.05 -10610 55 16837 95 3544 58 315.14 -11334.50 228.41 1092.32 351.07 857 95 4.68 OSF 1 50 Warning 15600.00 3585 25 1146.43 -10624 42 16860 69 3545 95 330.18 -11351 51 228 29 1093.84 351.56 859 14 OSF 1 50 Warning 15620 00 3584 46 1160 82 -10638 29 16885 03 3547 32 346 34 -11369 65 228 16 1095.29 351 88 860 37 4 68 OSF 1 50 Warning Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 7 of 24 Trajectory:SI32-W2(P6b)Vs.SP33-W3 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 Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (fl) ((t) (ff) (0) (5) (ff) (5) (°) (ft) (6) (0) 15640.00 358171 1175.24 -10652.13 1690942 3548.54 382.62 -11387.77 228.32 1096.70 352.17 861.59 468 OSF 1.50 Warning 15660.00 3583.02 1189.74 -10665.89 16933.84 3549.61 379.01 -11405.85 228.55 1098.15 352.44 862.87 468 OSF 1.50 Warning 15680 00 3582.42 120432 -10679.56 1695779 3550.51 395.16 -1142351 228.80 1099.65 352.75 86415 4.68 OSF 1.50 Warning 15700 00 3581.89 1218.98 -10693.15 1697355 3551.06 40578 -11435.14 229.06 1101.26 353.97 86495 4.68 OSF 1.50 Warning 15720.00 3581.45 1233.72 -10706.67 16989 30 3551 60 416 36 -11446.79 229.31 1103.07 355 17 865.96 4.67 OSF 1.50 Warning 15740 00 3581.09 1248.54 -10720.10 17005 03 3552.12 426 88 -11458.48 229.56 1105.06 356 36 867 16 4.66 OSF 1 50 Warning 15760 00 3580.82 126342 -10733.45 17020.74 3552.64 43735 -11470.19 229.81 1107.24 35754 868.55 4.65 OSF 150 Warning 15780.00 3580.63 1278.39 -10746.72 1703644 3553.15 447.75 -11481.92 230.07 1109.61 358.71 870.14 4.65 OSF 1.50 Warning 15800 00 3580.53 1293.42 -10759.91 17052 11 3553.65 45811 -11493.68 230.29 1112.16 35988 87191 464 OSF 1.50 Warning 1582000 3580.47 1308.49 -10773.06 1707067 355424 470.33 -11507.64 230.26 111480 360.77 87396 464 OSF 150 Warning 15840 00 3580.41 1323.55 -10786.22 17089 43 355484 482.67 -1152175 230.22 1117.47 36164 87605 4.•4 OSF 1.50 Warning 15860.00 3580.35 1338.62 -10799.37 17108 17 3555 44 494.99 -11535.87 230.18 1120.16 362.51 878 16 OSF 1.50 Warning 15880.00 3580.29 1353.68 -10812.53 17126 92 3556.05 507.29 -1154999 230.15 1122.88 363.38 880.28 4.64 OSF 1.50 Warning 15900.00 3580.23 1368.75 -10825.68 17145.65 3556.66 519.58 -11564.13 230.11 1125.59 36425 88243 4.64 OSF 1.50 Warning 15920 00 3580.17 1383.81 -10838.83 17168 29 3557.38 534.43 -1158120 230.06 1128.30 36472 88483 4.65 OSF 1.50 Warning 15940.00 3580.10 1398.88 -10851.99 17191 96 355806 550.02 -11598.99 230.02 1130.95 36508 88724 466 OSF 1.50 Warning 1596000 3580.04 1413.94 -10865.14 17215 65 3558.67 56569 -11616.75 22999 113354 365.43 88959 4.66 OSF 1.50 Warning 15980.00 3579.98 1429.01 -10878.30 17239 37 3559 21 581 44 -11634.48 229.95 1138 05 365.78 891.87 4.67 OSF 1.50 Warning 16000.00 3579.92 144407 -10891.45 17272 50 3559.92 603.60 -11659.09 229.91 1138.44 365.10 894 71 4.69 OSF 1.50 Warning 16020.00 3579.86 1459.14 -1090461 17309.18 3560.81 628.52 -11685.99 229.85 1140.55 363.99 897.56 4.71 OSF 1.50 Warning 16040.00 3579.80 147420 -10917.76 17344.56 3561.77 65292 -11711.59 229.80 114236 362.97 900.05 4.73 OSF 1.50 Warning 1606000 3579.73 148927 -10930.92 17368 26 3562.41 669.41 -11728.60 229.76 1144.02 363.29 90150 473 OSF 1.50 Warning 16080 00 3579.87 150433 -10944.07 1739198 356297 68597 -1174558 229.72 114561 36360 902.88 4.73 OSF 1.50 Warning 16100.00 3579.81 1519.40 -10957.22 17415 72 356348 70259 -1176251 229.69 114713 363.90 904.20 4.74 OSF 1.50 Warning 16120 00 3579.55 153446 -10970.38 17440 01 356392 71968 -1177979 229.67 1148.59 364.14 905.51 4.74 OSF 1.50 Warning 16140.00 3579.49 1549.53 -10983.53 17474.79 356448 74433 -1180430 229.63 1149.88 363.10 907.48 4.76 OSF 1.50 Warning 16160.00 3579.43 1564.59 -10996.69 17509.61 3564.98 76934 -1182853 229.60 1150.91 362.01 909.24 4.78 OSF 1.50 Warning 16180.00 3579.36 1579.66 -11009.84 17542.59 356540 79331 -1185118 229.57 1151.69 361.11 910.62 4.79 OSF 150 Warning 16200 00 3579.30 1594.72 -11023.00 17570 82 3565 81 814 00 -11870.38 229.55 1152.29 360.76 911 45 4 80 OSF 1 50 Warning 16220.00 3579.19 1609.79 -11036.15 17599 05 3566 33 834 82 -11889.44 229.53 1152.75 360.41 912.15 4.81 OSF 1 50 Warning 16240.00 3578.94 162486 -11049.30 17627.28 356694 85578 -11908.34 229.51 115107 360.05 912.71 4.81 OSF 150 Warning 16260.00 3578.62 1639.93 -11062.44 17642.11 3567.30 866.81 -11918.25 229.48 115136 301.49 912.04 4.79 OSF 1.50 Warning 18280.00 3578.31 1655.00 -11075.59 17655.00 3567.62 876.34 -11926.92 229.46 1153.77 363.17 911.33 4.77 OSF 1.50 Warning 16300 00 3578.00 1670.07 -11088.73 17667.89 3567 95 885 82 -11935 64 229.43 1154 30 364 84 910.74 4.75 OSF 1 50 Warning 16320.00 3577.69 1685.14 -11101.88 17680.77 356829 895.24 -11944.42 229.40 115495 366.50 910.29 4.74 OSF 1.50 Warning 16340.00 3577.38 170021 -11115.02 1769385 3568.65 90460 -11953.26 229.37 1155.73 368.15 909.96 4.72 OSF 1 50 Warning 16360.00 3577.07 171528 -11128.17 17706.51 3569.01 913.90 -11962.14 229.35 1156.63 369.79 909.77 4 70 OSF 1.50 Warning 16380.00 3576.76 1730.35 -11141.31 17719 37 3569.38 923 14 -11971.08 229.32 1157.65 371 41 909.71 4.68 OSF 1.50 Warning • 16400.00 3576.45 1745.42 -11154.46 17735.96 3569.86 93499 -11982.67 229.28 1158.78 37258 910.07 4.67 OSF 1.50 Warning 16420.00 3576 13 1760.49 -11167.60 17758.01 3570 39 950.76 -11998.08 229.24 1159.91 373 09 910 85 4.67 OSF 1.50 Warning 16440 00 3575 82 1775.56 -11180.75 17780 07 3570 80 966.56 -1201346 229.20 1161 00 373 59 911 61 4 67 OSF 1.50 Warning 1646000 3575.51 1790.63 -11193.90 1780215 3571.08 982.41 -1202883 229.17 116205 374.10 91232 4.67 050 1.50 Warning 16480 00 3575.20 1805.70 -11207.04 17824 33 3571.24 998.36 -12044.24 229.14 1163.07 374 58 913 02 OSF 1.50 Warning 16500.00 3574.89 1820.77 -11220.19 17848.39 3571.26 1015.71 -12060.92 229.12 116403 374.85 91380 4.67 OSF 1.50 Warning 16520.00 3574.58 1835.84 -11233.33 17872.47 3571.16 1033.13 -12077.54 229.11 1164.92 375.11 914.52 4.67 OSF 1 50 Warning 16540.00 3574.27 1850.91 -11246.48 17896.56 3570.93 1050.61 -1209410 229.10 1165.74 375.36 91517 4.67 OSF 1 50 Warning 16580.00 357395 1865.98 -11259.62 1792017 3570.56 1067.81 -1211028 22910 1166.50 37567 91572 4.67 OSF 1.50 Warning 16580.00 3573.64 1881.05 -1127277 17934.43 3570.36 1078.18 12120.06 229.10 1167.27 37714 915.51 465 050 1.50 Warning 16600.00 3573.33 1896.12 -11285.91 17948.68 3570.18 1088.50 -12129.89 229.10 1168.14 378.6. MiiiiMii 464 OSF 1.50 Warning 16620.00 3573.02 1911.19 -11299.06 17962.93 3570.04 1098.77 -12139.77 229.09 1169.11 380.05 915.41 4.62 OSF 1.50 Warning i 16640.00 357271 1926.26 -11312.20 17977.17 3569.96 1108.99 -12149.69 229.09 1170.18 381.50 915.52 4.61 OSF 1.50 Warning 16660.00 3572.40 1941.33 -1132135 17991.40 3569.91 1119.15 -12159.65 229.08 1171.34 38294 91573 4.60 OSF 1.50 Warning 16680.00 3572.09 1956.40 11338.49 18005.62 3569.92 1129 25 -12169 65 229 07 1172.61 384 36 916 04 4 58 OSF 1 50 Warning 16695.86 3571.84 1968.35 -11348.92 18017.23 3569.95 1137.46 -1217786 229.06 1173.68 38545 91638 458 OSF 1.50 Warning 16700.00 357178 1971.47 -11351.64 1802099 356997 1140.12 -12180.52 229.01 1173.97 385.64 91654 457 OSF 1.50 Warning 16720.00 3571.55 1986.51 -1136482 1803916 357002 1152.94 -1219340 228.79 1175.33 386.52 917.32 4.57 OSF 1.50 Warning 16740.00 3571.46 2001.51 -11378.04 18057.33 3570.06 1165.74 -12206.30 228.58 1176.65 387.40 918.06 4.56 OSF 1.50 Warning 16760.00 3571.48 2016 47 -11391.32 18075.50 3570.07 1178 52 -12219 21 228.39 1177.95 388.28 918.77 4 56 OSF 1.50 Warning 16780.00 3571.64 2031.40 -11404.63 18093.67 3570.07 1191.28 -1223215 22823 1179.23 389.15 919.46 4.55 050 1 50 Warning • ■ 16800.00 3571.91 2046.29 -11417.98 18111.84 3570.04 120402 -1224510 22813 1180.49 39004 920.13 4.55 OSF 1 50 Warning 16820.00 3572.21 2061.17 -11431.34 18129.32 3569.98 1216 26 -12257 59 228.15 1181.77 391 06 920 73 4.54 OSF 1.50 blaming 16840.00 3572.51 2076.05 -11444.69 18146.80 3569.88 1228.46 -12270.09 228 17 1183.09 392.08 921.38 4.53 OSF 1 50 Warning 16860.00 3572.81 2090.94 -11458.05 18164.26 3569.73 1240.63 -12282.62 228.19 1184.46 393.09 922.07 4.53 OSF 1 50 Warning 16880.00 3573.11 2105.82 -11471.40 18181.72 3569.54 1252.77 -12295 16 228.21 1185.87 394.11 922.80 4.52 OSF 1.50 Warning 16900.00 3573.41 2120.71 -11484.76 18199 16 3569 31 1264 88 -12307 72 225.23 1187.32 395 12 923 58 4 51 OSF 1 50 Warning 16920.00 3573.70 2135.59 -11498.11 18214.15 3569 08 1275.25 -12318 54 228.25 1188.82 396 39 924 23 4.51 OSF 1 50 Warning 16940 00 3574.00 2150.47 -11511.47 18226.55 3568 88 1283.78 -12327.54 228.27 1190.44 397 94 924.52 4.49 OSF 1 50 Warning 16960.00 3574.30 2165.36 -11524.83 18238.93 3568.67 1292.24 -1233658 228.29 1192.19 399.46 925.55 4.48 OSF 1 50 Warning 16980.00 3574.60 218024 -11538.18 18251.30 3568.47 1300.63 -12345.66 228.31 119406 400.98 926.41 4.47 OSF 1.50 Warning 17000.00 3574.90 2195.13 -11551.54 18263.66 356826 1308.96 -12354.79 228.33 1196.06 402.47 927.42 446 OSF 1.50 Warning 17020.00 3575 20 2210.01 -11564.89 18275 99 3568 05 1317.21 -12363 95 228.35 1198.18 403.95 928 55 446 OSF 1.50 Warning 17040.00 357550 2224.90 -11578.25 1828831 3567.83 132540 -1237316 228.37 1200.43 405.41 92983 445 OSF 1.50 Warning 17060.00 357579 2239.78 -1159160 1830062 3567.61 1333.52 -1238240 228.39 1202.80 40686 93124 4.44 OSF 150 Warning 17080.00 3576.09 2254.66 -1160496 18319 13 3567.30 1345.67 -12396 36 22841 1205.26 407.71 933.13 iia23 090 1.50 Warning 17100.00 357639 2269.55 -11618.32 18340.21 3567.01 1359.52 -12412.25 228.44 1207.71 408.33 93516 444 OSF 1.50 Warning 17120.00 3576.69 2284.43 -11631.67 18361.30 3566.81 1373.39 -12428.13 228.47 1210.14 408.95 93718 445 OSF 1.50 Warning 17140.00 3576.99 2299.32 -11645.03 1838239 356668 138729 -12444.00 228.49 1212.55 409.56 93918 445 OSF 1.50 Warning 17160 00 3577.29 2314.20 -11658.38 18402.49 3566 63 1400.54 -12459 11 228 50 1214.93 410.28 941 09 4 45 OSF 1 50 Warning 17180.00 3577.59 2329.08 -11671.74 18417.04 356660 1410.10 -12470.08 228.51 1217.37 411.50 942.71 444 OSF 1.50 Warning 17200.00 3577.89 2343.97 -11685.09 1843157 3566.54 1419.61 -12481.07 228.52 1219.89 41271 94443 444 0901.50 Warning 17220.00 3578.18 2358.85 -11698.45 18446.09 3566.45 1429.06 -12492.09 228.50 1222.50 413.91 946.23 4.44 OSF 1.50 Warning 17240.00 3578.41 2373.69 -11711.85 18460.59 3566 34 1438.45 -12503.14 228.29 1225.13 415.10 948.07 4.43 OSF 1 50 Warning 17260.00 3578.53 2388.47 -11725.33 18475.09 3566 20 1447 79 -12514.22 228.08 1227.76 416 29 949 91 4.43 OSF 1 50 Warning 17280.00 3578.54 2403.19 -11738.87 18489.58 3566 03 1457 08 -12525.34 227.85 1230 38 417 47 951 74 4.43 OSF 1 50 Warning 17284 34 3578.53 2406 38 -11741.82 18492 72 3565 99 1459 08 -12527 76 227.80 1230 95 417 72 952 14 NNIONEM OSF 1 50 Warning • ill Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 8 of 24 • Trajectory:S132-W2(P6b)Vs.SP33-W3 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North APm ,Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (8) (ft) (ft) (ft) (ft) (`) (ft) (8) (8) 17300.00 357849 2417.87 -11752.46 18514.18 3565.66 147281 -12544.26 227.82 1232.98 417.81 954.11 443 OSF 1.50 Warning 17320.00 3578 43 2432.54 -11766 05 18548 82 3564 90 1495 22 -12570 66 227.84 1235 38 417 31 956.84 4 45 OSF 1 50 Warning 17340.00 3578.37 2447.21 -11779.64 18583.54 356383 151799 -12596.85 227.89 123754 416.75 959.38 448 OSF 150 Warning 17360.00 3578 31 2461.89 -11793.23 18607.83 3562 95 1534.07 -12615.02 227.92 1239 53 417.10 961 13 446 OSF 1.50 Warning 17380.00 3578.26 2476.56 -11806.82 18628.28 3562.27 1547.63 -12630.32 227.95 1241 49 41779 962.64 446 OSF 1.50 Warning 17400.00 357820 2491.23 -11820.41 18648.73 3561.66 1561.21 -12645.61 227.98 124345 418.48 964.14 446 OSF 150 Warning 17420.00 3578.14 2505.91 -1183400 1866920 3561 11 1574.79 -12660.90 228.00 1245.40 419.17 965.63 4.46 OSF 1.50 Warning 17440.00 3578.08 2520.58 -11847.59 1868946 356063 1588.25 -12676.04 228.02 1247.34 419.88 967.10 4.46 OSF 1.50 Warning 17460.00 3578.02 2535.25 -11861.18 18702.95 3560.37 1597.19 -12686.15 228.02 1249.34 421 20 968.21 4.46 OSF 1.50 Warning 17480.00 3577.97 2549.92 -11874.77 1871644 3560 16 1606.07 -12896.29 228.03 1251 43 422.50 969.43 4.45 OSF 1.50 Warning 17500.00 3577.91 2584.60 -11888 36 18729.91 3560.01 1614.89 -12706.47 228.04 1253 62 423 80 970 76 4 44 OSF 1.50 Warning 17520.00 3577.85 2579.27 -1190195 18743.36 3559.92 1623.64 -12716.69 228.04 125592 42509 97220 444 OSF 150 Warning 17540.00 3577.79 2593.94 -11915 54 18756.80 3559.90 1632.34 -12726.93 228.04 1258 32 426.36 973.75 4 43 OSF 1.50 Warning 17560.00 3577 73 2608.62 -11929 13 18770.22 3559 92 1640 96 -12737 21 228 03 1260 82 427 63 975 41 4 43 OSF 1 50 Warning 17580.00 3577 68 2623.29 -11942 72 18783.62 3560.01 1649.53 -12747 52 228.02 1263 42 428 88 977 17 MIIIIIIIIIEICE OSF 1 50 Warning 17600.00 357782 2637.96 -11956.31 18809.86 3560.20 1666.28 -12787.72 228.01 1266.03 42915 97961 443 OSF 150 Warning 17620 00 3577 56 2652.64 -11969 90 18837.94 3560.26 1684.35 -12789.21 228.00 1268.52 429 26 982 02 4 44 OSF 1 50 Warning 17640.00 3577.50 2667.31 -11983.49 18866.07 356016 1702.59 -12810.82 228.00 1270.88 429.35 984.32 4.45 OSF 1 50 Warning 17660.00 3577.44 2681.98 -11997.08 18890.01 3559.99 1718.22 -12828.76 228.00 127112 429.77 986.28 445 OSF 1.50 Warning 1768000 3577.39 2696.66 -12010.67 18908.86 3559.89 1730.53 -12843.04 228.00 1275.36 43061 987.95 445 OSF 1.50 Warning 17700.00 3577.33 2711.33 -12024.26 18927.71 3559.87 1742.83 -12857.32 228.00 1277.61 43146 989.64 445 OSF 150 Warning 17720.00 3577.27 2726.00 -12037.85 18946.56 3559.93 1755.11 -12871.61 227.99 1279.88 43230 991.35 445 OSF 150 Warning 17740.00 3577.21 2740.67 -1205145 18965.40 3560.06 1767.38 -12885.91 227.98 1282.16 433.15 99307 445 OSF 1.50 Warning 17780.00 357715 275535 -1206504 18984.48 356025 1779.79 -12900.41 227.97 128446 43397 99482 445 OSF 150 Warning 17780.00 3577 10 2770 02 -12078 63 19004.03 3560 38 1792.50 -12915.26 227.96 1286 77 434.76 996.60 4.45 OSF 1.50 Warning 17791.69 3577 06 2778.60 -12086 57 19015.45 3560.41 1799.93 -12923.94 227.96 1288 12 435 22 997 6 MEMIER OSF 1 50 Warning 17800.00 357705 2784.69 -1209222 19023.57 356040 180521 -1293011 227.94 1289.08 43553 99840 445 OSF 150 Warning 17820.00 3577.12 2799.37 -12105 81 19043.12 3560.32 1817 91 -12944 96 227.90 1291 40 436.27 1000.23 4 45 OSF 1.50 Warning 17840.00 3577.33 2814.04 -12119.40 19062.66 3560.13 1830.61 -12959.81 227.88 1293.73 437.01 1002.06 445 OSF 1.50 Warning 17860.00 3577.58 2828.71 -12132.98 19082.93 3559.85 1843.78 -12975.22 227.90 1296.06 437.69 1003.94 445 OSF 150 Warning 17880.00 3577.82 2843.38 -12146.57 19104.17 3559.72 1857.59 -12991.35 227.92 1298.37 43829 1005.85 4.45 OSF 1.50 Warning 17900.00 3578.07 2858.06 -1216616 19125.42 3559.80 1871 43 -13007.48 227.92 1300.66 438.89 1007.74 4.45 OSF 1.50 Warning 17920.00 3578.32 2872.73 -12173.75 19146.68 3560.09 1885.28 -13023.60 227.92 1302.93 439.54 1009.58 4.45 OSF 1.50 Warning 17940.00 3578.57 288740 -12187.34 19167.94 3560.58 1899.15 -13039.71 227.91 130518 440.19 1011.39 445 OSF 1.50 Warning 17960.00 3578.82 2902.07 -1220093 19189.42 3561.24 191318 -13055.97 227.89 1307.40 440.81 101320 446 OSF 150 Warning 1798000 3579.07 2916.74 -1221452 19210.93 356197 1927.24 -13072.23 227.87 130961 44143 1014.99 446 OSF 1.50 Warning 18000 00 3579.32 2931 42 -12228 11 19232.45 3562 78 1941 33 -13088.47 227.84 1311 78 442.06 1016 75 4 46 OSF 1 50 Warning 18020 00 3579.57 2946.09 -12241 70 19253.96 3563.65 1955.43 -13104.69 227.82 131393 442.68 1018.49 446 OSF 1.50 Warning 18040 00 3579.82 2960.76 -12255 29 19280.03 3564 76 1972 56 -13124.32 227.78 1316 05 442 94 1020 42 4 46 OSF 1 50 Warning 18060.00 3580 07 2975.43 -12268 88 19312 13 3565 90 1993 84 -13148.31 227.75 1318 00 442 71 1022 54 4 47 OSF 1 50 Warning 18080.00 358032 2990.11 -1228246 19344.28 356675 201540 -1317216 227.73 131977 44243 102449 4.48 OSF 150 Warning 18100.00 3580.57 3004.78 -1229635 19373.66 3567.30 2035.28 -13193.78 227.72 1321.37 442.36 1026.13 4.49 OSF 1.50 Warning 18120.00 3580.82 3019.45 -12309.84 19399.40 356731 2052.80 -13212.62 227.71 1322.86 442.60 1027.46 4.49 OSF 1.50 Warning 18140.00 3581.07 3034.12 -12323.23 19425.14 3568.42 2070.41 -13231.40 227.69 1324.26 442.84 1028.71 4.49 OSF 1.50 Warning 18160.00 3581.32 3048.79 -12338.82 19450.90 3569.13 2088.10 -13250.10 227.68 1325.58 443.07 1029.87 449 OSF 1.50 Warning 18180.00 3581.56 3063.47 -12350.41 19480.18 3569.99 2108.33 -13271.25 227.66 1326.79 442.97 1031.15 4.50 OSF 1.50 Warning 18200.00 3581.81 3078.14 -12364.00 19501.56 3570.57 2123.17 -1328383 227.64 1327.90 447.97 1028.93 4.45 OSF 1.50 Warning 18220.00 3582.06 3092.81 -12377.59 19521.53 3571.12 2137.04 -13300.99 227.63 1329.02 453.85 1028.12 4.40 OSF 1.50 Warning 18240.00 3582.31 3107.48 -12391.18 19541 49 3571 87 2150.90 -13315.34 227.61 1330.13 476.23 1012.31 4.20 OSF 1.50 Warning 18280.00 3582.58 3122.16 -12404.77 1954430 357134 2152.84 -13317.15 227.61 1331.36 482.03 100367 415 OSF 1.50 Warning 18280.00 3582.81 3136.83 -12418.36 19544.00 3571.74 2152.64 -13317.15 227.61 133388 4843' 1008.8' 4.13 OSF 1.50 Warning 18300.00 3583.08 3151.50 -12431.95 19544.00 3571.74 2152.64 -13317.15 227.61 1334.70 48656 1010.00 412 OSF 1.50 Warning 18320.00 358331 3166.17 -12445.53 19544.00 3571.74 2152.64 -13317.15 227.61 1336.82 488.66 1010.71 4.11 OSF 1.50 Warning 18327.24 3583.40 3171.49 -12450.45 19544.00 3571.74 2152.64 -13317.15 227.61 133738 489.40 1011.061 4.111 OSF 1.50 Warning End of results Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 9 of 24 Field: Nikaitchuq Well: SP30-W1 Structure: Spy Island Borehole: SP3O-WIPBI Slot: SP30 Trajectory: SP3O-WIPB1 Client: EM Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08887938° Grid Scale Factor: 0.999900149 Magnetic Declination: 20.271° Magnetic Declination Dale: October 15,2012 Magnetic Model: BGGM 2012 Reference Point: Northing LULUS flevation Structure Unc. Slot Unc. 6053617.960(ftUS) 511465.870(ftUS) 53.920(ft)MSL 0.000(0)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prom Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 40.820 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 SP3O-W1PB1/SP3O-WIPB7 40.820 958.580 Act-Stns SLB_GYRO-MWD-No Global 18.000 SP3O-WIPB1/SP3O-WIPB1 956.580 2599.700 Act-Stns SLB MWD+GMAG-No Global 16.000 SP3O-W1PB1/SP3O-W1PB1 2599.700 9465.920 Act-Stns SLB_MWD+GMAG-No Global 12.250 SP3O-W1PB1/SP3O-W1PB1 9465.920 13788.700 Act-Stns SLB_MWD+GMAG-No Global 8.750 SP3O-W1PB1/SP3O-W1PB1 13788.700 13854.000 Act-Stns SLB BLIND+TREND-No Global 8.750 SP3O-WIPB1/SP3O-W1PB1 • 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 (8) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All 1oc01 minima indicated. Results filtered:Depth 9351.00 ft o MD<=18327.24 ft Results filtered:Ct-CI separation<=1500.00 ft Results highlighted:CI-Ct separation<=1320.00 ft 9340 00 3826.61 -2842.17 -5821 57 8716.53 3637.43 -2250.17 -5026.55 36 06 991.28 94.08 928 24 15 96 OSF 1.50 Pass 9360.00 3828 00 -2831.01 -5838 11 8727.50 3638.09 -2241 36 -5033.07 36 05 997 94 93.83 B35 06 16 11 OSF 1 50 Pass 9380.00 3629.40 -2819.85 -5854.65 8738.27 3638.71 -2232.67 -5039.39 3604 1004.76 93.58 94204 16.26 OSF 1.50 Pass 9400.00 3630.79 -2808.70 -5871.20 8748.97 3639.32 -2223.98 -5045.60 36.02 1011.72 93.34 949.16 16.42 OSF 1.50 Pass 9420.00 3632.19 -2797.54 -5887.74 8759.60 3639.92 -2215.29 -5051.71 36.01 1018.83 93.11 956.43 16.57 OSF 1.50 Pass 9440.00 3633.58 -2786.38 -5904.27 8770.17 3640.50 -2208.61 -5057 71 36 11 1026.08 92.90 963 82 16.73 OSF 1.50 Pass 9460.00 3634.90 -2775.11 -5920.74 8780.71 3641.06 -2197 91 -5063.62 36 40 1033.37 92.69 971 25 16 89 OSF 1.50 Pass 9480.00 3636.14 -2763.71 -5937.13 8791.21 3641.61 -2189.19 -506945 36.70 1040.66 92.49 97868 17.04 OSF 1.50 Pass 9500.00 3637.29 -2752.19 -5953.43 8801.67 3642.14 -2180.46 -5075 18 37.01 1047.96 92 30 986.10 17.20 OSF 1.50 Pass 9520.00 3638.36 -2740.54 -5969.65 8812.11 3642.67 -2171.70 -5080.84 37.32 1055.27 92.12 993.52 17.35 OSF 1.50 Pass 9540.00 3639.35 -2728.76 -5985.79 8827.89 3643.44 -2158.41 -5089.32 37.63 1062.53 92.41 1000.59 17.42 OSF 1.50 Pass 9560.00 3640.25 -2716.85 -6001.84 8843.82 3644.21 -2144 98 -5097.84 37 95 1069.70 92 71 1007 57 17 48 OSF 1 50 Pass 9580.00 3641 Of -2704.83 -6017.79 8859.75 3644.97 -2131.52 -5106 34 38 28 1076 78 83 00 1014 45 17.54 OSF 1.50 Pass 9600.00 3641.79 -2692.68 -6033.66 8875.71 3645.72 -2118.02 -5114.81 38.61 1083 76 93 29 1021.24 17.60 OSF 1.50 Pass 9620.00 3642.44 -2680.40 -6049.44 8891.67 3646.46 -2104 49 -5123.25 38.95 1090.65 93 59 1027.93 17.65 OSF 1 50 Pass 9640.00 3643.00 -2868.01 -6065.13 8908.43 3647.22 -2090.27 -5732.07 39.30 1097.45 93.94 1034.49 17.69 OSF 1.50 Pass 9660.00 3643.48 -2655.49 -6080.72 8929.01 3648.18 -2072.79 -514292 39.66 1104.10 94.57 1040.72 17.68 OSF 1.50 Pass 9680.00 3643.87 -2642 86 -6096.22 8949.68 3649.18 -2055 28 -5153.82 40.03 1110.58 95.20 1046.78 17.67 OSF 1 50 Pass 9700.00 3644 17 -2630.10 -6111.62 8970.41 3650.22 -2037.72 -5164 80 40.42 1116.89 95 83 1052.67 17.65 056 1 50 Pass 9720.00 3644.40 -2617.23 -6126.93 8991 20 3651.30 -2020 12 -5175 83 40.81 1123.02 96 48 1058 37 17 62 056 1 50 Pass 9740.00 3644.53 -2604.24 -6142.13 9019 98 3652.83 -1995.85 -5191 20 41.24 1128.93 97.74 1063.45 17.49 OSF 1 50 Pass 9760.00 3644.58 -2591.14 -6157.24 9052 93 3654.53 -1968.24 -5209 12 41.68 1134.48 99.35 1067.92 17.28 OSF 1 50 Pass 9780.00 364455 -2577.92 -6172.25 9086.18 3656.19 -1940.61 -522753 42.14 1139.65 101.02 1071.97 17.07 OSF 1.50 Pass 9800.00 3644.43 -256459 -8187.16 9108.44 3657.32 -1922.21 -524001 42.58 1144.51 101.78 1076.33 17.02 OSF 1.50 Pass 9820.00 3644.22 -255114 -6201.96 912850 3658.44 -190565 -525127 43.02 114921 10235 1080.65 16.99 OSF 150 Pass 9840.00 3643.94 -2537.58 -6216.66 9148.57 3659.68 -1889.08 -5262.54 43.48 1153 76 102.93 1084.81 16 96 OSF 1 50 Pass 9860.00 3643.56 -2523.92 -6231.26 9168.67 3661.02 -1872.51 -527383 43.96 1158.15 10349 1088.82 16.93 OSF 1 50 Pass 9880.00 3643.11 -2510.15 -6245.76 9188.78 3662.47 -1855 94 -5285 14 44.31 1162.39 104.06 1092.69 16.90 OSF 1.50 Pass 9900.00 3642.63 -2496.35 -6260.23 9208.94 3663.97 -1839.35 -5296.48 44.41 1166.59 104.65 1096.49 16.87 OSF 1 50 Pass 9920.00 3642.16 -2482.55 -6274.70 9229.10 3665.47 -1822 75 -5307 83 44.50 1170.78 105.25 1100.29 16.83 OSF 1 50 Pass 9940.00 3641 69 -2468 76 -6289.18 9249.26 3668.99 -1806 16 -5319 20 44.60 1174.96 105 84 1104.07 16.79 OSF 1 50 Pass 9960.00 3641.21 -2454.96 -6303.65 9269 43 3668.51 -1789.58 -5330.57 44.69 1179.14 106 43 1107.86 16.76 OSF 1 50 Pass 9980.00 3640.74 -2441.17 -6318.12 9288.75 3669.97 -1773 70 -5341.48 44.79 1183.31 106 96 1111.67 16 73 OSF 1 50 Pass 10000.00 3640.27 -2427.37 -6332.59 9307.39 3671.36 -1758.37 -5351 99 44.87 1187.49 107 46 1115 52 16.72 OSF 1 50 Pass 10020.00 3639.79 -2413.58 -6347.07 9326.03 3672 73 -1743.03 -5362.49 44.96 1191.69 107.96 1119.39 16.70 OSF 1.50 Pass 10040.00 3639.32 -2399.78 -6361.54 9344.66 3674.09 -1727.68 -5372.97 45.04 1195.90 108.46 1123.27 16.68 OSF 1.50 Pass 10060.00 3638.85 -2385.99 -6376.01 9363.30 3675 42 -1712.33 -5383 45 45.12 1200.14 108.95 1127 17 16.86 OSF 1 50 Pass 10080.00 3638.37 -2372.19 -6390.48 9382.24 367675 -1696.72 -539409 45.20 1204.38 109.50 113106 16.63 OSF 150 Pass 10100.00 3637.90 -2358.40 -6404.96 9401 44 3678 09 -1680.88 -5404 87 45.28 1208.64 110.08 1134 93 16.60 OSF 1 50 Pass 10120.00 3637.43 -2344.60 -6419.43 9420.65 367941 -1665.05 -541565 45.36 1212.90 11067 1138.79 16.57 OSF 1 50 Pass 10140.00 3636.95 -2330.80 -6433.90 9439.85 3680.71 -1649.21 -5426.43 45.44 1217.17 111.26 1142.67 16.54 OSF 1 50 Pass 10160.00 3636.48 -2317.01 -6448.38 9459.05 3682.00 -1633.36 -5437.20 45.52 1221.44 111.84 114658 18.51 OSF 1 50 Pass 10180.00 3636.01 -2303.21 -6462.85 9483 07 3683 57 -1613.56 -5450.70 45.61 1225 70 112.85 1150 14 16 42 OSF 1 50 Pass 10200 00 3635.53 -2289.42 -6477.32 9509.83 3685 18 -1591.56 -5465 86 45.71 1229.85 114.10 1153.46 16 30 OSF 1 50 Pass 1022000 3635.06 -2275.62 -6491.79 961491 368985 -1507.25 -5528.35 46.00 1233.53 122.95 15.17 OSF 150 Pass 1024000 3634.59 -2261.83 -6506.27 9655.70 369105 -1475.64 -5554.08 46.10 1236.10 12562 1152.02 14.86 OSF 150 Pass 10260.00 363417 -2248.03 -6520.74 9692.27 3692.39 -1447.66 -5577.61 46.20 1238.34 127.95 1152.71 14.62 OSF 1.50 Pass 10280.00 3633.64 -2234.24 -6535.21 9722.13 3693.33 -1425.02 -5597.04 46.27 1240.39 129.82 1153.65 14.45 OSF 1.50 Pass 10300.00 3633.17 -2220.44 -6549.69 9752.05 3694 06 -1402.47 -5616.70 46 33 1242 28 131 29 1154.43 14.29 OSF 1 50 Pass 10320 00 3632.69 -2206.65 -6564.16 9798.66 3694 99 -1367 73 -5647.75 46.41 1243 97 134 73 1153 82 13 94 OSF 1 50 Pass 10340.00 3632.22 -2192.85 -6578.63 9879.20 369818 -1309.88 -5703.69 46.64 1244.79 141 81 1149.93 13.25 OSF 1 50 Pass 10360.00 3631.79 -2179.08 -6593.13 9923 34 3700 46 -1279 25 -5735 39 46.54 1245 05 145.07 1148.00 12.95 OSF 1 50 Pass 10380.00 3631.49 -2165.38 -6607.70 9968.20 3702 82 -1248.76 -5768.20 46.39 1245.00 148.39 1145.75 12.66 OSF 1.50 Pass 10400.00 3631.31 -2151.75 -6622.33 10017.06 3705.09 -1216 32 -5804.66 46.23 1244.62 152.20 1142.82 12.34 OSF 1.50 Pass 10420.00 3631.25 -2138.19 -6637.04 10062 08 3706 71 -1187 14 -5838.91 46.02 1243.86 155 58 1139.81 12.06 OSF 1.50 Pass 10440.00 3631.32 -2124 70 -6651.80 10094 80 3707 72 -1166 30 -5864 11 45.80 1242 92 157 71 1137.45 11 89 OSF 1 50 Pass 10460.00 3831 52 -2111 28 -6666.62 10127 49 3708.67 .1145 72 -5889 50 45 57 1241 84 159 76 1135.01 11 72 OSF 1 50 Pass 10480.00 3631 85 -2097.92 -6681.50 10154 42 3709.39 -1128 96 -5910.56 45 31 1240.66 161 16 1132.89 11.61 OSF 1.50 Pass 10500.00 3632.31 -208463 -6696.44 10172.05 3709.72 -1117 99 -5924.36 45.04 1239.56 161.56 1131.52 11.57 OSF 1.50 Pass 10520.00 3632.89 -2071.40 -6711.43 10189.67 3709.89 -1106 98 -5938.13 44.77 1238.57 161.92 1130.29 11.53 OSF 1.50 Pass 10540 00 3833 61 -2058.25 -6726.48 10207 30 3709.89 -1095 94 -5951 87 44.48 1237.69 162.37 1129.12 11 49 OSF 1 50 Pass • Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 10 of 24 Trajectory:S132-W2(Rib)Vs.SP30-W 1 PBt 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) (°) (ft) (ft) (ft) 10560.00 3634.46 -2045.16 -6741.58 10224.91 370973 -108488 -5965.57 44.18 1236.94 162.90 112801 11.45 OSF 1.50 Pass 10580 00 363543 203214 -6756 73 10242.62 3709.40 -1073.72 -5979 32 43 99 1236.29 163.50 1126 96 11 40 OSF 1 50 Pass 10600 00 3636.42 -201913 -6771.89 10261.69 3708.95 -1061.69 -5994 10 43 92 1235.69 164.10 1125 96 11 35 OSF 1 50 Pass 10620 00 363741 -2006 12 -6787.05 10280 75 3708.46 -1049.65 -6008.87 4386 1235.10 164.71 1124 97 11 31 OSF 1.50 Pass 10640 00 3638.39 -199311 -6802 21 10299 80 3707 92 -1037.60 -6023 62 43 79 1234.53 165.32 1123 98 11 26 OSF 1 50 Pass 10660 00 3639 38 -1980 10 -6817.37 10318 85 3707 34 -1025.54 -6038 35 43 72 1233.97 165.95 1123 01 11 21 OSF 1 50 Pass 10680 00 3640.37 -1967.09 -6832.52 10338.06 3706 70 -1013 37 -605320 43.65 1233 43 166.59 1122 04 11.16 OSF 1.50 Pass 10700 00 3641 36 -1954.08 -6847.68 10358.26 3705.98 -1000.57 -6068.81 43.57 1232.88 167.32 1121 02 11 11 OSF 1.50 Pass 10720.00 3642.35 -1941.07 -6862.84 1037845 3705.21 -987.77 -6084.41 43.49 1232.35 188.06 1119.98 11 06 OSF 1.50 Pass 10740 00 3643.34 -1928 06 -6878.00 10398.63 3704 38 -974.99 -610000 43.41 1231.81 168.81 1118.95 11 00 OSF 1.50 Pass 10760 00 3644 32 -1915.06 -6893.16 10418 80 3703 49 -962.22 -6115.58 43.32 1231 27 169.56 1117.90 10 95 OSF 1.50 Pass 10780 00 3645 31 1902 05 -6908 32 10437 17 3702 64 -950.57 -6129 78 43 24 1230.73 170 10 1117.01 10 91 OSF 1.50 Pass 10800 00 3646.30 -1889 04 -6923.47 10454.10 3701 85 -939.82 -6142 82 43 16 1230 25 170 47 1116.27 10 88 OSF 1.50 Pass 10820 00 3647.25 -1876 02 -6938 63 10471 03 3701 05 -929 04 -615585 43 12 1229 80 170 85 1115 58 1085 OSF 1.50 Pass 10840 00 3648 06 -1862 99 -6953 78 10487 96 3700 25 -918 22 -6168.85 43.10 122941 171 23 1114 93 1082 OSF 1.50 Pass 10860 00 3648.73 -1849.95 -6968.93 10504.91 3699 45 -907 36 -6181.84 43.08 122906 171.61 1114.32 1080 OSF 1.50 Pass 10880.00 364927 -183690 -698408 10521 93 369863 -89642 -619435 43.06 1228.75 172.00 1113.75 1077 OSF 1.50 Pass 10900 00 364967 -1823.84 -6999.22 1054027 3697.75 -884.61 -6208.85 43.04 122847 17251 1113.13 10.73 OSF 1.50 Pass 10920 00 3649.92 -1810.76 -7014.35 10558.81 3696.86 -872.78 -6222.84 43.03 122821 173.03 1112.53 1070 OSF 1.50 Pass 10940 00 3650.04 -1797.67 -7029.47 10576 97 3695.96 -860 92 -6236 82 43.03 1227.97 173.55 1111.95 1067 OSF 1 50 Pass 1096000 3650.02 -178458 -7044.59 10595 32 3695.05 -849.04 -6250.79 43.02 1227.75 174.07 1111.38 1063 OSF 150 Pass 10980 00 3649 86 -1771 48 -7059 70 10613.69 3694 13 -837.14 -6264 74 43.01 1227.56 174.59 1110.84 10 60 OSF 1 50 Pass 11000 00 364959 -1758 37 -7074 80 10631 51 3693 23 -825.57 -627827 42.99 122740 175.04 1110.37 1057 OSF 1 50 Pass 11020 00 3649 31 -1745 27 -7089 91 10649.31 3692 35 -813.99 -6291 76 42.96 1227.27 175 50 1109.94 1054 OSF 1.50 Pass 11040.00 364902 -173216 -710502 1066711 3691.48 -802 38 -630523 42.93 1227.18 17596 110954 1051 OSF 1.50 Pass 11060 00 364874 -171906 -712012 10684.91 369062 -790.75 -6318.68 42.90 122712 176.41 110918 10.48 OSF 1.50 Pass 11080.00 364846 -170595 -7135.23 1070272 368977 -77910 -6332.11 42.87 122710 176.87 110886 1046 OSF 1.50 Pass 11100.00 364818 -169285 -7150.33 1072530 368870 -764.31 -634914 42.84 1227.09 17735 110819 1040 0561 50 Pass 11120.00 3647.90 -1679 74 -716544 1074934 3687.54 -748 30 -636770 42.80 122700 179.05 1107.31 1033 056 1.50 Pass 11140 00 364761 -1666 64 -718054 1077437 3686.38 -732 37 -6386 32 42.76 1226 85 18025 1106 35 1026 OSF 1 50 Pass 11160.00 364733 -165353 -719565 1080002 3685.16 -715.78 -6405 85 42.72 1226.62 181.58 110524 1018 OSF 1 50 Pass 11180 00 364705 -164043 -7210 76 10832.81 368379 -694 78 -6430 99 4268 1226.23 183.69 110345 10.06 OSF 1 50 Pass 11200 00 3646 77 -1627 32 -722586 10865.60 3682.70 -67404 -6456 36 4265 1225.64 18579 110145 9 94 OSF 1 50 Pass 1122000 3646.49 -161422 -724097 10901 14 3681.85 -65186 -648412 4264 1224.83 18819 109904 9.81 OSF 1.50 Pass 11240.00 3646.20 -1601 12 -7256 07 10956.70 3681 15 -61814 -652827 42.65 122338 192.69 1094.79 957 0901.50 Pass 11260.00 364592 -158801 -7271.18 10994.94 3681.08 -595.68 -655922 42.67 1221.82 19533 1091.27 942 OSF 1.50 Pass 11280 00 364564 -157491 -7286.28 11011 17 368094 -586 20 -8572.39 4268 1220.02 195.66 108925 9.39 OSF 1.50 Pass 11300.00 364536 -156180 -7301.39 11027.41 368082 -576.66 -658553 4268 121827 195.99 108729 9.36 OSF 1.50 Pass 11320 00 364508 -1548 70 -7316 49 11043.66 3680 13 -567.08 -659865 4267 121659 196.34 1085.37 933 OSF 1 50 Pass 11340 00 364479 -1535 59 -7331 60 11059.90 3679 47 -55747 -6611 72 4265 1214 97 196.68 108352 931 OSF 1 50 Pass 11360 00 364451 -1522 49 -7346 71 11076.15 3678 62 -547.81 -6624 76 4262 1213.41 197.02 1081 74 928 OSF 1 50 Pass 11380 00 364423 -1509 38 -7361 81 11092.45 3677 64 -538.08 -6637 81 42.59 1211 91 197.35 108001 925 OSF 1 50 Pass 11400 00 364395 -1496 28 -7376 92 1110879 3676.66 -528 30 -6650.85 42.55 121047 197.68 1078.35 9 22 OSF 1 50 Pass 11420 00 364367 -148317 -739202 1112513 367568 -51847 -6683 87 42.52 1209.08 19801 1076.75 920 OSF 1.50 Pass 11440.00 3643.38 -147007 -7407.13 11141.48 367471 -50839 -6676.87 4248 1207.76 198.35 107520 917 OSF 1.50 Pass 11460.00 3643.10 -1456 96 -7422.23 11157.84 3673 74 -498.68 -668984 42.45 120650 198.68 1073.72 915 OSF 1.50 Pass 11480.00 364282 -144384 -7437 33 1117420 3672 78 -488.72 -6702 79 4263 120528 19901 107228 912 050 1 50 Pass 11500 00 3642.52 -1430.68 -7452 38 11190.13 3671.83 -478.99 -6715 36 4260 1204.07 199.28 107088 910 OSF 1 50 Pass 11520 00 3642.23 -141752 -7467.44 11206.05 3670.88 -469 22 -6727 89 42 56 1202 93 199.57 106955 908 OSF 1 50 Pass 11540.00 3641.93 -1404 36 -7482 50 11221 97 3669 91 -45941 -674040 42.53 1201.85 199.85 1068.29 906 OSF 1.50 Pass 11560.00 364163 -1391 20 -749756 11237 90 3668 92 -449.55 -6752 87 4249 1200.84 20013 1067.09 9 04 OSF 1.50 Pass 11580.00 3641 34 .1378 04 -7512 62 11253.83 3667 91 -43965 -6765 31 4246 1199 90 20040 106597 9 02 OSF 1.50 Pass 11600.00 3641.04 1364.88 -752768 1126981 366689 -429.67 -6777.76 4242 1199.03 20068 106491 900 0501.50 Pass 11620.00 3640.75 -1351.73 -754273 11286.08 3665.84 -41948 -6790.39 42.38 119822 201.00 106389 898 0501 50 Pass 11640.00 3640.45 -1338 57 -7557 79 11302.34 3664 78 -409.25 -6802.99 42.34 119747 201.31 106294 896 0501 50 Pass 11660.00 364016 -132541 -7572.85 1131861 3663 71 -398.98 -681556 42.31 1196.79 20162 106205 894 050 1 50 Pass 11680.00 3639.86 -131225 -7587.91 1133488 366263 388.67 -682810 4227 1196.17 201.93 1081.22 892 050 1 50 Pass 11700 00 3639 57 -1299 09 -7602 97 11351 15 3661 55 -378 32 -684061 4223 119561 202.24 106046 890 OSF 1.50 Pass 11720 00 3639.27 -1285 93 -7618.02 11371 56 366019 -365 31 -6856.26 4218 119510 203.01 105943 887 OSF 1 50 Pass 11740.00 3638.98 -1272 77 -7633.08 11397.99 365865 -348.52 -6876 62 4212 1194 52 204.45 1057.89 880 OSF 1.50 Pass 11760.00 3838.68 -125961 -7648.14 1142444 365738 -331 82 -689710 42 08 1193.82 205.88 1056.24 873 OSF 1.50 Pass 11780.00 363839 -1246.45 -766320 11450.89 3656.36 -31524 -6917.68 42.05 119302 207.31 105448 8.67 0501 50 Pass 11800.00 3638.09 -1233.29 -7678.26 1147944 3655.57 -297.47 -6940.01 42.03 119209 208.97 105245 859 OSF 1.50 Pass 11820.00 3637.80 -122013 -7693.32 11508.27 3655.09 -279.70 -6962.70 4203. 119102 21066 105024 851 OSF 1.50 Pass 11840.00 3637.50 -1206 97 -7708.37 11537.07 3654 93 -262.11 -698551 4205. 1189.79 212.35 104790 844 050 1 50 Pass 11860 00 3637.21 -1193.82 -7723 43 1156454 3655 12 -24549 -7007.39 4208. 118843 213 88 1045 51 837 OSF 1.50 Pass 11880 00 3636.91 -118066 -7738.49 11591 23 3655 80 -22949 -7028.73 4213 1186 95 215 31 104308 8 30 OSF 1.50 Pass 11900 00 363661 -116751 -7753.56 1161784 3656 97 -21366 -7050 09 42.05 1185 37 216.74 1040 55 8 23 OSF 1.50 Pass 11920 00 3636.24 -1154 44 -7768.69 1164510 365867 -19760 -707205 41.82 1183 79 218 23 103797 817 OSF 1.50 Pass 11940.00 3635.80 -1141 46 -7783 90 1167717 366068 -178 93 -709804 4162 1182.15 220.22 1035 01 808 OSF 1.50 Pass 11960.00 3635.29 -1128 57 -7799.19 11709.25 3662 35 -160.50 -712425 4142 118044 222.20 1031.98 800 OSF 1.50 Pass 11980.00 363471 -1115.78 -7814.55 11744.67 3663 80 -14046 -715342 41 21 1178.64 224.51 102864 7 90 OSF 1.50 Pass 12000.00 3634.05 -1103.08 -7829.99 11792.04 3665 00 -114.38 -7192.94 41 02 1176.57 227.98 102425 7 77 OSF 1.50 Pass 12020 00 3633.32 .1090 48 -7845 50 1183419 3665 35 -91 92 -7228.61 40 77 1174.18 230.91 1019.91 765 OSF 1.50 Pass 12040 00 3632.54 .1077 97 -7861 09 1186049 3665 27 -7816 -7251.02 4047 1171 70 23228 1016.52 759 OSF 1.50 Pass 12060.00 3631.68 1065.56 -7876 75 11886 78 3664 99 -6452 -7273.49 4016 116924 23364 1013 15 753 OSF 1.50 Pass 12080.00 3630.77 -1053 26 -7892.49 11913 06 3664 52 -51 01 -7296.03 3985 1166 79 235 00 1009 80 747 OSF 1 50 Pass 12100.00 3629.79 -1041 05 -7908 30 11941 55 3663 88 -36 51 -732055 3954 1164 35 236 55 1006 32 741 OSF 1 50 Pass 12120 00 3628 75 -1028.94 -792419 11970 97 3663 32 -21 75 -734599 3924 1161 87 23819 1002 75 734 OSF 150 Pass 12140.00 362765 -1016.94 -794015 12000.35 3662 87 -722 -7371.52 3895 1159.36 239.81 999.16 728 OSF 1.50 Pass 12160.00 362649 -1005.04 -795618 12024.89 3662 59 4 77 -7392.93 3867 1156.83 240.98 995.85 722 OSF 1.50 Pass 1218000 362529 -99318 -7972.24 12044.97 3662.52 14.55 -741047 3873 1154 34 241 73 992.85 719 OSF 1.50 Pass 12200.00 3624.10 -981.32 -7988.30 12065.03 366260 24 31 -7427.99 3880 1151 84 24248 989.86 7 15 OSF 1.50 Pass 12220.00 362290 -969 47 -8004 36 1208506 3662 85 34 06 -7445.49 38 87 1149 34 24325 986.85 7 11 OSF 1.50 Pass 12240.00 3621 71 -95761 -802043 12105.07 3663 25 43 77 7462 98 38 96 1146 84 244 00 983 85 707 OSF 1 50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 11 of 24 Trajectory:SI32-W2(P6b)W.SP30-W1 PB1 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 (N) (N) (N) (N) (N) (ff) (N) (ff) (°) (ft) (N) (N) 12260 00 3620.51 -945.76 -8036.49 12130.69 366325 56.16 -748540 39.08 1144.30 24524 960.48 7.02 OSF 1.50 Pass 12280 00 3619.32 -933.90 -8052.55 12157 15 3664.83 6810 -750812 39.21 1141.64 246.54 976.96 6 97 OSF 1.50 Pass 12300 00 3618.13 -922 05 -8068.61 12183 54 3665.88 81.27 -7531.85 39.35 1138.88 247 80 973 35 6.92 OSF 1.50 Pass 12320 00 3616.93 -910.19 -8084.68 12206 86 3666.92 92.18 -7552.45 39.48 1136.00 248.91 969.74 6.87 OSF 1.50 Pass 12340.00 3615.74 -898.33 -8100.74 12224.17 366713 100.28 -7567.73 39.58 1133.14 24940 966.55 6.84 OSF 1.50 Pass 12360 00 3614.54 -886.48 -8116 80 12241 52 3668.22 108.43 -7583 02 39.67 1130.33 24980 963 47 6.81 OSF 1 50 Pass 12380 00 3613 35 -874.62 -813287 12258 90 3668.70 11614 -7598 34 39.75 1127.56 250.26 960 39 6 78 OSF 1 50 Pass 12400 00 3612.15 -862.77 -8148.93 12276.31 3669.06 124.90 -761316 39.83 1124.83 250.82 957 28 6.75 OSF 1 50 Pass 12420 00 3610.97 -850.93 -816520 1229375 3669.30 133.22 -7628.99 39.68 1122.16 251.32 954.29 6.72 OSF 1.50 Pass 12440 00 3609.87 -839.17 -8181.14 12317.53 366944 144.55 -7649.89 39.39 1119.59 25219 951.00 6.67 05E1.50 Pass 12460 00 3608.85 -827 49 -8197 35 12341 61 3669.36 155.96 -7671.10 39.09 1117.04 253.50 947.71 6.63 OSF 1 50 Pass 12480.00 3607 91 -815 91 -821363 12365.72 3669 05 167 30 -7692.37 38 77 111452 25412 944.45 6.59 OSF 1 50 Pass 12500 00 3607.06 -804 42 -8229.98 12388.99 3668.54 178.19 -7712.93 38 44 111204 255.68 941.26 6.54 OSF 1 50 Pass 12520.00 3606 28 -793.02 -8246.39 1240219 366820 184.57 -7724.94 38.09 110289 25516 938.79 812 OSF 1.50 Pass 1254010 3605 59 -781.71 -828217 12416.21 366719 191.03 -7736.93 37.74 110717 256.04 93615 6.51 OSF 1.50 Pass 12560 00 3604 99 -77049 -827941 12429.86 3667 60 197.57 -7748.90 37 39 1105.66 256 21 934.53 6.49 OSF 1.50 Pass 12580 00 3604.46 -759 36 -8296.02 12443.53 3667 33 204.18 -7760 86 37 04 1103.97 256.38 932.73 6.48 OSF 1.50 Pass 12600 00 3604 01 -748.32 -8312.70 12457 22 3867.09 210.87 -7772 80 36 70 110211 256.55 931.15 6.47 05E150 Pass 1262020 360365 -737.38 -8329.44 1247022 3666.88 217.64 -7784.72 36.36 1101.27 258.71 929.80 8.45 OSF 1.50 Pass 12640.00 3603.35 -726.51 -834622 12486.13 366617 22512 -7797.90 36.28 110021 25721 92814 6.44 OSF 1.50 Pass 12660 00 3603 04 -715.64 -8363.01 12505.99 3666.41 235.15 -7815.09 36.28 1099.19 257 75 927.03 6.42 OSF 1.50 Pass 12680 00 3602 74 -704 77 -8379.79 12525 84 3666 14 245 07 -7832.29 36 29 1098.17 258.49 925.52 6.39 OSF 1.50 Pass 12700 00 3602 44 -693.90 -8396.58 12545 70 3665.88 255 00 -7849.48 36 29 1097.16 259.23 924.01 6 37 OSF 1.50 Pass 12720.00 360213 -683.03 -8413.36 1256515 366511 264.93 -7866.67 36 30 1096.15 259.97 922.50 6.34 OSF 1.50 Pass 12740 00 3601.83 -672.16 -8430.15 1258349 368516 273.91 -788220 36.30 1095.14 260.53 921.13 6.32 OSF 1.50 Pass 12760 00 3801 53 -661.29 -8446.93 12599 83 366508 282.14 -7896.31 36.30 1094.20 260.94 919.91 6.31 OSF 1.50 Pass 12780 00 3801 22 -65042 -8463.72 12616 17 366474 29041 -791040 36 30 1093.33 261 36 91876 6 29 OSF 1 50 Pass 12800.00 360092 -639.55 -848050 12632.51 3664.35 298 74 -792445 36.29 1092.52 261 77 91768 6 28 OSF 1.50 Pass 12820.00 3600.62 -62868 -8497.29 1264886 3663.89 307.12 -7938.48 3628 1091.78 26218 91666 6.26 OSP 1.50 Pass 12840.00 3600.32 -617.81 -8514.07 12665.21 3663.38 315.54 -795249 3627 1091.10 262.58 915.72 6.25 OSP 1.50 Pass 12860 00 360001 -606.94 -8530.86 12681 89 366284 324.18 -7966.74 3626 109049 263.02 91482 6.24 OSF 1.50 Pass 12880 00 3599 71 -596.07 -854715 1269863 366235 332.90 -7981.03 36.25 1089.94 26346 91397 6.22 OSF 1.50 Pass 12900.00 359941 -585.20 -8564.43 12715 39 3661.92 34167 -7995.30 36 24 1089.45 263.91 913 18 6.21 05E1 50 Pass 12920.00 359910 -574.33 -8581.22 1273214 3661.54 35047 -800915 36.23 1089.02 26414 912.46 6.20 05E1 50 Pass 12940.00 3598.80 -563.46 -8598.00 12748.90 3661.22 35912 -802378 3623 108815 264.78 911.80 618 OSF 1.50 Pass 12960.00 359850 -55257 -8614.78 12765.80 366025 36828 -803811 36.43 1088.31 265.22 911 17 6.17 OSF 1 50 Pass 12980.00 359822 .541.59 -8631.49 1278315 3660.68 37752 -8052.78 36.83 1087.91 265 70 910.46 6 16 OSF 1.50 Pass 13000.00 359796 -530.49 -864812 1280049 366041 386.79 -8067.44 37.23 108742 26617 90965 6 15 OSF 1.50 Pass 13020.00 3597.72 -51927 -8664.68 12817.83 366014 396.09 -8082.07 37.62 1086.84 26664 908.76 6.13 OSF 1.50 Pass 13040.00 359750 -507.94 -8681.16 1283516 365916 40543 -8096.67 38.02 1086.17 267.10 907.78 6.12 OSF 1.50 Pass 13060.00 359730 -496.50 -869716 1285250 365917 41481 -8111.25 3841 108541 26756 906.71 610 OSF 1.50 Pass 13080.00 3597 12 -484.94 -8713.88 1288412 3659.19 43201 -813825 38.81 108444 26955 904.42 6 05 OSF 1.50 Pass 13100.00 3596 96 -47328 -8730.13 12918.70 365920 45000 -8167.32 39.23 1083.08 271.72 901 60 6.00 05E1 50 Pass 13120.00 3596 82 -461.49 -8746.29 1295060 365960 466.41 -819467 3967 1081.31 27363 898 56 594 OSP 1.50 Pass 1314000 359669 -449.60 -8762.37 12968.71 365985 47567 -821024 40.08 1079.33 27419 896.21 5.92 OSF 1.50 Pass 13160 00 3596.58 -437.66 -877841 12986.83 366021 48426 -822579 40.10 1077.32 274.75 893.83 590 OSF 1.50 Pass 13180.00 3596 46 -425.71 -879445 1300495 366027 49428 -8241.33 4011 1075.35 275 32 891.47 587 OSF 1.50 Pass 1320000 3596 34 -413 77 -8810.49 13023.09 3660.03 50364 -8256.86 4012 107340 27589 889 14 585 OSF 1.50 Pass 13220.00 3596.22 -401 82 -8826.53 13041 23 3659.90 51303 -8272.38 4013 107149 27648 686 85 583 OSF 1.50 Pass 13240.00 359611 -389.88 -884217 13059.90 385967 522.72 -8288.34 4012 106911 27711 88454 581 OSF 1.50 Pass 13280.00 3595.99 -377.94 -885812 1307818 3659.34 53244 -830429 40.12 1067.75 277.75 882.25 5.78 OSF 1.50 Pass 1328000 3595.87 -365.99 -887416 1309726 3658.91 542.19 -832022 40.11 1065.91 27839 879.99 576 OSF 1.50 Pass 13300 00 3595 75 -354 05 -8890 70 13115.95 3658 38 551 96 -833614 40.09 106410 27904 877.74 5 74 OSF 1 50 Pass 13320 00 3595.64 -342 10 -8906.74 13134.63 3657 76 561 75 -8352.04 4007 1062.30 27968 875.52 5.71 OSF 1.50 Pass 13340.00 359552 -33016 -8922.78 13158.55 3656.98 57425 -837242 4004 106049 28086 872.92 568 OSF 1.50 Pass 13360.00 359540 -318.22 -8938.82 1318214 3856.39 586.71 -839221 4002 100810 28224 87024 5.64 OSF 1.50 Pass 13380.00 3595.29 -306.27 -8954.86 13206.52 3655.98 59907 -841345 4001 105663 28321 86749 5.61 OSF 1.50 Pass 13400.00 359517 -294.33 -897090 13231.64 3655.74 61193 -843503 4002 105458 28449 864.59 557 OSF 150 Pass 13420 00 3595.05 -282 38 -8986 95 13268.59 3655 00 630.51 -846696 4000 1052.31 286 90 860.71 5.52 OSF 1.50 Pass 13440 00 3594 93 -270.44 -900299 13305.37 365341 648.52 -849829 3994 1049.72 28926 858.55 5.46 OSF 1.50 Pass 13480.00 3594.82 -258.50 -9019.03 1333373 3651.62 66208 -852383 39.86 1046.86 29082 85215 5.41 OSF 1.50 Pass 13480.00 3594.70 -246 55 -903507 1335543 3650.05 672.39 -854285 39.79 1043.93 29177 849.09 5.38 OSF 1.50 Pass 13500 00 3594.58 -234.61 -9051 11 13377 09 3648 33 682.65 -8561 86 39.71 104027 29273 84549 535 OSF 1 50 Pass 13520 00 359446 -222 66 -906715 13398.73 3646.47 692 86 -858084 3963 103727 29367 841.86 5.31 OSF 1.50 Pass 13540 00 3594.35 -210.72 -908319 13419.95 3644.50 702.85 -859947 39.53 103495 29459 838.23 5.28 OSF 1 50 Pass 13560.00 359413 -198.77 -9099.23 13440.00 364215 712.27 -861707 39.44 1031.90 29519 834.65 525 OSF 1.50 Pass 13580.00 359415 -186.82 -9115.27 1346026 3640.86 721.88 -8634.69 39.38 102815 29619 831.06 522 OSF 1.50 Pass 13600.00 3594.21 -174.85 -9131.29 1348011 363913 731.09 -8652 31 3928 1025.75 296.98 827.44 5.19 OSF 1 50 Pass 13620.00 359440 -162 86 -9147 30 13500 15 363746 740.49 -866994 3918 102263 29777 823.79 516 OSF 1.50 Pass 13640.00 359473 -150.86 -916329 1352160 363573 750.53 -868881 3906 1019.47 29869 820.02 513 OSF 150 Pass 13660.00 359520 -138.85 -9179.28 1354421 3833.92 760.97 -8708.56 3892 1016.24 29970 816.11 5.10 OSF 1.50 Pass 13680.00 359511 -126.82 -9195.24 13566.38 363211 771.34 -872810 38.77 1012.94 30071 81214 5.06 OSF 1.50 Pass 13700.00 3596.56 -114.78 -9211.20 13588.71 3630.30 781.64 -874822 3861 1009.57 301.72 808.10 5.03 05E1 50 Pass 13720.00 359742 -102.73 -9227.13 1361049 362811 79163 -876710 3845 100613 30268 80401 5.00 OSF 150 Warning 13740.00 3598.31 -9066 -9243.07 13631 51 3626.68 801.24 -878590 38.30 1002.66 303 59 799.94 4.97 OSF 1.50 Warning 13760.00 359920 -7862 -9259.01 1365248 362472 810.80 -880446 3814 999.17 30449 795.85 4.93 OSF 1.50 Warning 1378000 360008 -66.57 -927494 1367341 3622.64 820.31 -882299 37.96 995.66 305.38 791.74 420 OSF 1.50 Warning 13800.00 360097 -54.52 -929088 13694.29 362043 829.77 -8841 47 37.79 99213 306.28 78761 4 87 OSF 1 50 Warning 13820.00 360186 -4247 -9306.81 1370882 361813 836.37 -8854.32 3766 98814 30661 78390 485 05E1 50 Warning 13840.00 360274 -3041 -9322.75 13723 05 3617.24 842.90 -8866 85 37 53 985.26 306.91 78032 483 OSF 1.50 Warning 13860.00 360363 -18.36 -933869 13737.29 361511 84910 -887937 37.40 981.99 30720 776 86 481 OSF 1.50 Warning 1388000 3604.52 -6.31 -9354.62 1375154 361396 856.18 -8891.85 37.26 978.84 30748 773.52 4.79 OSF 1.50 Warning 13900 00 3605.40 574 -9370.56 13765 81 361227 862.92 -8904.31 37.12 975.80 307.76 77031 477 OSF 1.50 Warning I 13920 00 3606 29 17.79 -938650 13780.09 3610.55 86974 -8916 74 36.99 972.88 30802 767.21 475 OSF 1.50 Warning 13940 00 3607 18 29 85 -940243 13796 47 3608 55 87763 -8930 95 36.82 970.07 31243 761 45 467 OSF 1 50 Warning Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 12 of 24 Trajectory:SI32-W2(P6b)Vs.SP30-W1 PB1 • 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) 13960.00 3608.06 41.90 -9418 37 13815.99 3606.16 887.05 -8947 89 38.63 967.29 323.41 751.35 4.50 OSF 1 50 Warning 13980 00 3608.95 53 95 -9434 30 13835.52 3603 76 896 48 -8964 82 36.43 964.51 334.72 741 04 433 OSF 1 50 Warning 14000.00 3609.78 66 01 -945024 13854 00 3601.50 905.39 -8980.85 36.35 961.75 345.64 730.9•IiiiiiMrgr OSF 1.50 Warning 14020.00 3610.46 78.09 -9466 16 13854 00 3601.50 905.39 -8980.85 36.45 959.19 344.51 729.19 4.18 OSF 1.50 Warning 14040.00 3611.01 90 19 -9482.08 13854.00 3601 50 905.39 -8980 85 36.55 957.02 343.24 727.86 4.19 OSF 1.50 Warning 14060.00 3611 43 102 30 -9497.99 13854.00 3601.50 905.39 -8980.85 36.64 955.24 34184 7 7 4.20 OSF 1 50 Warning 14080.00 3611.70 114.43 -9513.89 13854.00 3601.50 905.39 -8980.85 36.72 953.86 340.31 778,66 421 OSF 1.50 Warning 14100.00 361183 126.58 -9529.78 13854.00 360150 905.39 -898085 36.79 952.88 338.65 728.78 423 OSF 150 Warning 14120.00 3611.83 138.74 -9545.65 13854.00 3601.50 905.39 -898085 36.85 9 0 336.86 727.39 425 OSF 150 Warning 14140.00 3611 71 150.91 -9561.52 13854 00 3601.50 905.39 -8980.85 36.8:�•. •�1 334.95 728.49 4.27 OSF 1.50 Warning 14160 00 3611 56 163.08 -9577.39 13854.00 3601 50 905.39 -8980.85 36 88 952 36 332 91 730.09 4 30 OSF 1.50 Warning 14180 00 3611 42 175.25 -9593.26 13854 00 3601 50 905 39 -8980 85 36 88 953 02 330.76 732 19 4 33 OSF 1 50 Warning 14200 00 3611 28 187 43 -9609.13 13854.00 3601.50 905 39 -8980.85 36.88 954.10 328.49 734.78 4 37 OSF 1 50 Warning 14220 00 3611 14 199 60 -9625.00 13854.00 3601 50 905 39 -8980 85 36.88 955 60 326 10 737 87 4 40 OSF 1 50 Warning 14240 00 3611 00 211 77 -9640.87 13854 00 3601 50 905 39 -8980 85 36.88 957 51 323.62 741 44 4 45 OSF 1 50 Warning 14260 00 3610 86 223.94 -9656.74 13854.00 3601.50 905.39 -8980.85 36.88 959.84 321 03 745.49 4.49 OSF 1.50 Warning 14280.00 361072 23612 -9672.80 13854.00 360150 905.39 -8980.85 36.88 962.57 318.35 750.01 4.54 OSF 1.50 Warning 14300.00 3610.57 24829 -9688.47 13854.00 3601 50 905.39 -8980.85 36 88 965 71 315.58 755.00 460 OSF 1.50 Warning 14320.00 3610.43 260.48 -9704.34 1385400 3601.50 905.39 -8980.85 36.88 969.26 312.72 760.45 466 OSF 1.50 Warning 14340.00 3610.29 272.63 -9720.21 13854.00 3601 50 905.39 -8980.85 36 88 973 20 309.79 766 34 4 72 OSF 1.50 Warning 14360.00 3610.15 284.81 -9736.08 13854.00 3801 50 905.39 -8980.85 36.88 977 54 306.79 772 68 4 79 OSF 1 50 Warning 14380.00 3610 01 296 98 -9751.95 13854 00 3601 50 905 39 -8980 85 36 88 982 26 303.73 779 45 4.86 OSF 1 50 Warning 14400.00 3609.87 309.15 -9767.82 13854.00 360150 905.39 -8980.85 36.88 98737 30061 78663 494 OSF 150 Warning 14420.00 3609 72 321.32 -9783.68 13854 00 3801 50 905 39 -8980 85 36 88 992 85 297 43 794 23 5 02 OSF 1 50 Pass 14440.00 3609 58 333.49 -9799.55 13854 00 3601 50 905.39 -8980.85 36 88 998 70 294 22 802.23 5 10 OSF 1.50 Pass 14460.00 3609 44 345 67 -9815.42 13854 00 3601 50 B05 39 -8980.85 36 88 1004 92 290 96 810 62 5 19 OSF 1 50 Pass 14480.00 3609 30 357.89 -9831.25 13854 00 3601 50 905 39 -8980 85 37.26 1011 44 287 66 819 34 5 29 OSF 1 50 Pass 14500.00 3609 16 370.22 -9847.00 13854.00 3601.50 905.39 -8980.85 37.66 1018 18 284.32 828.30 5.38 OSF 1.50 Pass 14520.00 3609.02 382.66 -9862.66 13854.00 360150 905.39 -8980.85 3807 1025.13 280.94 837.51 5.49 OSF 1.50 Pass 14540.00 3608.88 395.21 -9878.23 13854 00 3601 50 905.39 -8980.85 38 47 1032.29 277.54 846 94 5.59 OSF 1.50 Pass 14560.00 3608.74 407.87 -9893.71 1385400 3601.50 905.39 -8980.85 38.88 1039.66 274.11 856.60 5.70 OSF 1.50 Pass 14580.00 3608.60 420.64 -9909.11 13854.00 3601.50 905 39 -8980.85 39.28 1047 23 270.66 866 46 5.82 OSF 1.50 Pass 14600.00 3608.46 433.51 -9924.41 13854.00 360150 905.39 -8980.85 3969 105500 267.21 87654 5.94 OSF 1.50 Pass 14620.00 3608.32 446.49 -9939.63 13854 00 3601 50 905.39 -8980.85 40.09 1062.96 263.75 886 80 6.06 OSF 1.50 Pass 14640.00 3608.18 459.58 -9954.75 13854 00 3601 50 905.39 -8980.85 40.49 1071 11 260.28 897 26 6 19 OSF 1.50 Pass 14660.00 3608.03 472 77 -9969.78 13854.00 3601 50 905.39 -8980.85 40.89 1079 44 256 82 907 90 6.32 OSF 1 50 Pass 14680.00 3607.88 486 06 -9984.72 13854.00 3601 50 905 39 -8980.85 41 28 1087 95 253 36 918 72 646 OSF 1.50 Pass 14700.00 3607.72 499.46 -9999.57 13854.00 3601 50 905.39 -8980.85 41.68 1096.64 249 91 929 70 6 60 OSF 1.50 Pass 14720.00 3607 55 512.96 -10014 32 13854 00 3601 50 905 39 -8980 85 42 07 1105.49 246 48 940 84 6 75 OSF 1 50 Pass 14740.00 3607 38 526 57 -10028.B8 13854.00 3601 50 905 39 -8980.85 42.46 1114 51 243.06 952 14 6 90 OSF 1 50 Pass 14760.00 3607 19 540.28 -10043.54 13854.00 3601 50 905.39 -8980 85 42.88 1123 68 239 66 963 58 7.06 OSF 1.50 Pass 14780.00 3607.01 554.08 -10058.01 13854.00 3601.50 905.39 -8980.85 43.25 1133.02 236.28 975.17 7.22 OSF 1 50 Pass 14800.00 3606.81 567.99 -10072.38 13854.00 3601.50 905.39 -8980.85 4365 1142.50 232.92 986.89 7.38 OSF 1.50 Pass 14820.00 3606.60 582.00 -10086.66 13854.00 3601.50 905.39 -8980.85 44.04 1152.14 229.60 998.74 7.55 OSF 1.50 Pass 14840.00 3606.39 596.11 -10100.83 13854.00 3601.50 90639 -8980.85 44.43 1161.91 226.30 1010.72 7.73 OSF 1.50 Pass 14860.00 3606 17 610.31 -10114.91 13854.00 3601 50 905 39 -8980.85 44.83 1171 83 223 04 1022.81 7.91 OSF 1 50 Pass 14880 00 3605 94 624.82 -10128 88 13854.00 3601 50 905 39 -8980 85 45.22 1181 88 219 81 1035 01 8 09 OSF 1 50 Pass 14900 00 3605 71 639.02 -10142 76 13854 00 3601 50 905 39 -8980 85 45.62 1192 06 216.61 1047 33 8 29 OSF 1 50 Pass 14920 00 3605 47 653.52 -10156 54 13854.00 3601 50 905 39 -8980 85 46 01 1202 37 213.46 1059 74 8 48 OSF 1 50 Pass 1494000 360522 66811 -10170.21 13854.00 360150 905.39 -8980.85 46.41 1212.81 210.35 107225 868 OSF 150 Pass 14960 00 3604 96 682 79 -10183.79 13854.00 3601.50 905.39 -8980.85 46.66 1223.37 207.29 1084 85 8 89 OSF 1 50 Pass 14980 00 3604 70 697 49 -10197 35 13854.00 3601 50 905.39 -8980 85 46.66 1234 14 204.30 1097 61 9 10 OSF 1 50 Pass 15000.00 360444 71219 -1021090 13854.00 3601.50 905.39 -898085 46.66 1245.14 201.38 111056 9.31 OSF 150 Pass 15020.00 360419 726.89 10224.46 13854.00 3601.50 905.39 -8980.85 46.66 1256.36 198.54 112367 9.53 OSF 1 50 Pass 15040.00 360393 74160 -10238.02 13854.00 3601.50 905.39 -8980.85 46.66 1267.80 195.77 113695 9.76 OSF 1.50 Pass 15060.00 360367 756.30 -10251.57 13854.00 3601.50 905.39 -8980.85 46.66 1279.44 193.07 115041 9.98 OSF 150 Pass 15080.00 3603 41 771 00 -10265 13 13854.00 3601.50 905.39 -8980 85 46.66 1291.30 190.43 1164 02 10.22 OSF 1 50 Pass 15100.00 3603 15 785 70 -10278 69 13854.00 3601 50 905.39 -8980.85 46.66 1303 35 187 86 1177 78 10.45 OSF 1 50 Pass 15120 00 3602 89 800 40 -10292 25 13854.00 3601 50 905 39 -8980 85 46 54 1315.60 185.35 1191 70 10 70 057 1 50 Pass 15140.00 3602.55 815.06 -10305.85 13854.00 3801.50 905.39 -8980.85 48.03 132108 182.91 1205.81 10.94 OSF 1.50 Pass 15180.00 3602.11 829.65 -10319.52 13854.00 3601.50 905.39 -8980.85 45.51 134881 180.53 1220.13 11.19 OSF 1.50 Pass 1518800 3801.55 84418 -1033125 1385400 380150 905.39 -898085 4498 135179 178.22 123464 11.45 OSF 150 Pass 15200.00 3600.89 858.65 -10347.04 1385480 3601.50 905.39 -8980.85 44.44 1367.00 175.98 1249.35 11.71 OSF 1.50 Pass 15220.00 3800.13 873.05 -10360.90 1385400 3801.50 905.39 -8980.85 44.07 138043 173.83 1284.22 11.97 OSF 1.50 Pass 15240.00 359835 887.44 -10374.77 1385400 3801.50 905.39 -8980.85 4407 139404 171.76 127920 1224 OSF 1.50 Pass 15260.00 359857 901.83 -10388.84 1385400 3601.50 905.39 -8980.85 4407 1407.80 169.76 129429 12.50 OSF 1.50 Pass 15280.00 3597.78 916.22 -10402.51 13854.00 3601.50 905.39 -8980.85 4407 1421.71 167.83 1309.49 12.77 OSF 1.50 Pass 15300.00 3597.00 930.61 -10416.38 1385400 3601.50 90519 -8980.85 44.07 1435.76 165.97 132478 13.04 OSF 1.50 Pass 15320.00 359621 945.00 -10430.25 13854.00 3601.50 905.39 -8980.85 44.07 1449.95 164.20 134(116 13.32 OSF 1.50 Pass 15340.00 3595.43 95918 -1044412 13854.00 360150 905.39 -898085 44.07 146428 162.49 1355.62 1159 OSF 150 Pass 1536800 359465 973.77 -10457.99 1385400 360150 905.39 -8980.85 44.07 147873 180.85 1371.17 1187 OSF 150 Pass 1538080 359186 988.16 -10471.85 13854.00 3601.50 905.39 -8980.85 44.07 1493.32 159.28 1388.81 14.14 OSF 1.50 Pass End of results Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 13 of 24 Field: Nika,t huq Well: SP3O-W1 Structure: Spy Island Borehole: SP3O-W1 Slot: SP30 Trajectory: SP3O-W1 Client: Eni Petroleum Type: De/Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08887938° Grid Seale Factor: 0.999900149 Magnetic Declination: 20.271° Magnetic Declination Date: October 15,2012 Magnetic Model: BGGM 2012 Reference Point: Northing Latina glevation Structure Unc. Slot Unc, 6053617.960(NUS) 511465.870(fIUS) 53.920(ft)MSL 0.000(ft)(1 sigma) 0.000(9)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surwvina Proc: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole/Survey 0.000 40.820 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 SP30-WIPB1/SP30-WIPB7 40.820 956.580 Act-Stns SLB_GYRO-MWD-No Globs 16.000 SP30-W1PB1/SP30-W1PB1 956.580 2599.700 Act-Stns SLB_MWD+GMAG-No Globe 16.000 SP30-WIPB1/SP30-W1PB1 2599.700 9465.920 Act-Stns SLB_MWD+GMAG-No Globe 12.250 SP30-WIP131/SP30-WIPB1 9465.920 12948.130 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP30-WIPB1/SP30-WIPB1 12948.130 17879.520 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP3O-W1/SP3O-W1 17879.520 17945.000 Act-Stns SLB BLIND+TREND-No Globe 8.750 SP3O-W1/SP3O-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 Acim Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (9) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9351.00 ft Os MD 0=18327.24 ft Results filtered:Ct-Cl separation 0=1500.00 ft Results highlighted:Cl-Ct separation 0=1320.00 ft 934000 362661 -2842.17 -5821.57 8716 53 3637.43 -2250 17 -502655 36 06 091 28 9408 928.24 15 96 OSF 1 50 Pass 936000 3628.00 -2831.01 -5838.11 8727.50 3638.09 -2241.36 -5033.07 36.05 997.94 93.83 93506 16.11 OSF 1.50 Pass 9380.00 3629.40 -2819.85 -5854.65 8738.27 3638.71 -223267 -5039.39 36.04 1004.76 93.58 942.04 16.26 OSF 1.50 Pass 9400.00 3630.79 -2808.70 -5871.20 8748.97 3639.32 -222398 -504560 36.02 1011.72 93.34 949.16 1642 OSF 1.50 Pass 9420.00 363219 -2797.54 -588774 875960 3639.92 -2215.29 -5051 71 36.01 1018.83 9311 956.43 16.57 OSF 1.50 Pass 9440.00 3633.58 -2786 38 -590427 8770 17 364050 -2206 61 -5057 71 36.11 1026 08 9290 983.82 16.73 OSF 1 50 Pass 9460.00 3634.90 -2775.11 -5920 74 8780 71 3641 06 -2197.91 -506362 36 40 103337 9269 971.25 16.89 OSF 1.50 Pass 9480.00 3636.14 -276371 -5937.13 8791 21 3641.61 -2189 19 -506945 36.70 1040.66 92.49 978.68 17.04 058 150 Pass 9500.00 363729 -2752.19 -5953.43 8801.67 3642.14 -2180.46 -5075 18 37.01 1047.96 9230 986.10 17.20 OSF 1.50 Pass 9520.00 3638.36 -2740.54 -5969.65 8812.11 364267 -2171.70 -5080.84 37.32 1055.27 92.12 99352 17.35 OSF 1.50 Pass 954000 3639.35 -2728.76 -5985.79 8827 89 364344 -2158.41 -5089 32 3763 106253 9241 100059 17.42 OSF 1 50 Pass 9560.00 3640.25 -2716.85 -6001.84 884382 3644.21 -2144.98 -5097 84 37 95 1069 70 9271 100757 17.48 088 1 50 Pass 958000 3641.06 -270483 -6017.79 8859 75 3644.97 -2131 52 -5106 34 38.28 1076 78 9300 101445 17.54 OSF 1.50 Pass 9600.00 3641.79 -2892.68 -6033.66 8875.71 3645.72 -2118.02 -5114.81 38.61 1083.78 93.29 1021.24 1760 OSF 1.50 Pass 9620.00 3642.44 -2680.40 -6049.44 8891.67 364646 -210449 -5123.25 38.95 1090.65 9359 102793 17.65 OSF 150 Pass 9640.00 3643.00 -2668.01 -6065.13 890843 3647.22 -2090.27 -513207 39.30 1097.45 9394 103449 17.69 OSF 1.50 Pass 9660.00 364348 -2655.49 -608072 892901 3648.18 -2072.79 -514292 39.66 1104.10 9457 1040.72 17.68 056 150 Pass 968000 3643.87 -2642.86 -6096.22 8949.68 3649.18 -2055 28 -515382 4003 1110.58 9520 1046 78 1767 OSF 1 50 Pass 970000 364417 -2830.10 -6111.62 8970.41 365022 -2037.72 -516480 4042 1116.89 9583 105267 1765 OSF 150 Pass 9720.00 3644.40 -2617.23 -6126.93 8991.20 3651.30 -2020.12 -517583 4081 1123.02 96 48 1058 37 17.62 OSF 1.50 Pass 9740.00 364453 -2604.24 -6142.13 9019.98 365283 -1995.85 -519120 41.24 112893 97.74 1063.45 1749 OSF 1.50 Pass 9760.00 3644.58 -2591.14 -6157.24 9052.93 365453 -1968.24 -5209.12 41.68 1134.48 99.35 1067.92 17.28 OSF 150 Pass 9780.00 364455 -2577.92 -6172.25 908618 365619 -194061 -5227.53 4214 1139.65 101.02 1071 97 17 07 OSF 150 Pass 980000 364443 -2564.59 -6187.16 9108 44 3857 32 -1922 21 -524001 42.58 1144.51 101 78 1076 33 17 02 OSF 150 Pass 9820.00 384422 -2551.14 -8201 96 9128.50 365844 -1905.65 -525127 4302 114921 10235 108065 16.99 OSF 1 50 Pass 9840.00 364394 -2537.58 -6218.66 9148.57 365968 -1889.08 -526254 43.48 1153.76 102.93 108481 16.96 OSF 1 50 Pass 986000 3643.56 -2523.92 -623126 9168.67 3661 02 -1872.51 -5273.83 43.96 1158.15 10349 108882 16.93 OSF 1.50 Pass 9880.00 3643.11 -2510.15 -6245.76 9188.78 366247 -1855.94 -5285.14 4431 116239 10406 109269 16.90 056 150 Pass 9900.00 3642.63 -2496.35 -6260.23 9208.94 366397 -1839.35 -5296.48 4441 1168.59 10465 1096.49 16.87 OSF 1.50 Pass 992000 3642.16 -2482.55 -627470 922910 366547 -1822 75 -530783 4450 117078 10525 110029 16 83 OSF 1 50 Pass 994000 3641 69 -2468.76 -628918 9249.26 3666 99 -1806.16 -531920 4460 1174.96 105.84 110407 16.79 056 1 50 Pass 9960.00 3641.21 -2454.96 -6303.65 926943 366851 -1789.58 -5330.57 44.69 117914 10643 110786 16.76 OSF 1 50 Pass 9980.00 3640.74 -2441.17 -6318.12 9288.75 366997 -1773.70 -5341.48 44.79 1183.31 106 96 1111.67 16.73 OSF 1.50 Pass 10000.00 3640.27 -2427.37 -6332.59 9307.39 3671.36 -1758.37 -5351.99 44.87 118749 10746 1115.52 16.72 056 1.50 Pass 10020.00 3639.79 -2413.58 -6347.07 9326.03 367273 -1743.03 -536249 44.96 1191.69 107.96 1119 39 16.70 OSF 1.50 Pass 1004000 363932 -2399.78 -6361.54 934466 367409 -1727.68 -537297 45.04 1195.90 10846 112317 18.68 OSF 1 50 Pass 10060.00 363885 -2385.99 -8376.01 936330 3675.42 -1712.33 -538345 4512 120014 108.95 1127.17 16.66 OSF 150 Pass 10080.00 3638 37 -237219 -6390.48 938224 3676.75 -1696 72 -539409 45.20 1204.38 10950 1131.06 16.63 OSF 1.50 Pass 10100.00 3637.90 -235840 -6404.96 9401.44 367809 -168088 -540487 45.28 1208.64 11008 113493 16.60 OSF 1.50 Pass 10120.00 3637.43 -2344.60 -641943 9420.65 367941 -166505 -5415.65 45.36 1212.90 110.67 1138.79 18.57 OSF 1.50 Pass 1014000 3636 95 -2330.80 -6433.90 9439.85 368071 -164921 -542643 4544 121717 11126 114267 16.54 OSF 1 50 Pass 10160.00 3636.48 -2317.01 -6448.38 9459.05 3682.00 -1633.36 -543720 45.52 122144 111 84 1146.56 16.51 OSF 1 50 Pass 10180 00 3636.01 -230321 -6462.85 948307 368357 -161356 -545070 4561 1225.70 11285 115014 16 42 OSF 1 50 Pass 10200 00 3635.53 -228942 -6477.32 9509.83 3685.18 -1591.56 -5465 86 45.71 1229.85 11410 115346 16 30 OSF 1.50 Pass 10220.00 3635.06 -2275.62 -6491.79 961491 368965 -150725 -5528 35 46.00 1233.53 122.9. . 1517 OSF 1.50 Pass 10240.00 3634.59 -2261.83 -6506.27 9655.70 3691.05 -147564 -5554.08 4610 1236.10 125.62 1152.02 1486 OSF 150 Pass 10260.00 363411 -2248.03 -652074 969227 3692.39 -144766 -5577.61 4620 1238.34 12795 1152.71 1462 OSF 1.50 Pass 10280.00 363364 -223424 -653521 072213 369333 -142502 -559704 46.27 1240.39 12962 115365 1445 OSF 150 Pass 10300 00 363317 -222044 -6549.69 975205 3694 06 -1402.47 -5616 70 46.33 124228 13129 1154 43 1429 OSF 150 Pass 10320.00 3632.69 -2206.65 -656416 979866 3694 99 -1367.73 -564775 46.41 1243.97 13473 1153 82 13.94 OSF 1.50 Pass 10340.00 3632.22 -219285 -657863 987920 369818 -1309.88 -570369 46.64 1244.79 14181 114993 13.25 OSF 150 Pass 10360.00 3631.79 -2179.08 -6593.13 9923.34 370046 -1279.25 -5735.39 46.54 1245.05 145.07 1148.00 12.95 OSF 1.50 Pass 10380.00 363149 -2165.38 -6607.70 996820 3702 82 -1248.76 -576820 46.39 1245.00 14839 1145 75 12.66 058 1.50 Pass 10400.00 3631.31 -2151 75 -662233 10017.06 3705 09 -1216 32 -580466 46.23 1244.62 15220 1142 82 12.34 OSF 150 Pass 10420.00 3631.25 -2138.19 -663704 10062 08 3706 71 -1187 14 -583891 46 02 124386 15558 1139.81 12.06 OSF 150 Pass 10440.00 3631.32 -212470 -6651 80 1009480 3707.72 -1166 30 -586411 45 80 124292 15771 113745 11 89 OSF 1 50 Pass 10460.00 3631.52 -2111.28 -6666.62 10127.49 370867 -114572 -588950 4557 1241.84 15976 113501 11.72 OSF 150 Pass 1048000 3631.85 -2097.92 -6681.50 1015442 3709.39 -1128.96 -5910.56 45.31 1240.66 161.16 1132.89 1161 OSF 1.50 Pass 10500.00 3632.31 -2084.63 -669644 10172.05 3709.72 -1117 99 -592436 45.04 1239.56 161.56 1131.52 1157 OSF 1 50 Pass 10520.00 3632.89 -2071.40 -6711.43 1018967 370989 -110698 -5938.13 44.77 1238.57 16192 113029 1153 OSF 150 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 14 of 24 Trajectory:SI32-W2(P6b)W.SRN-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 Anm Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (") (fl) (ft) (ft) 1054060 3633.61 -2058.25 -6726.48 10207.30 3709.89 -1095.94 -5951.87 41.48 123769 162.37 1129.12 11.49 OSF 1.50 Pass 10560 00 3634 46 -2045.16 -6741 58 10224 91 3709 73 -1084.88 696557 44.18 1236 94 162 90 112801 11 45 OSF 1 50 Pass 10580 00 3635.43 -2032.14 -6756.73 10242 82 3709 40 -1073 72 -5979 32 43.99 1236 29 163.50 1126.96 11 40 OSF 1 50 Pass 10600.00 3636.42 -2019.13 -6771.89 10261 69 3708 95 -106169 -5994.10 43.92 1235.69 16410 1125.96 11.35 OSF 1 50 Pass 10620 00 3637.41 -2006.12 -6787.05 10280 75 3708 46 -104965 -6008.87 43.86 1235 10 164.71 1124.97 11.31 OSF 1 50 Pass 10640.00 3638.39 -1993.11 -6802.21 10299.80 3707.92 -103760 -602382 43.79 123453 165.32 1123.98 11.26 OSF 1.50 Pass 10660.00 3639.38 -1980.10 -6817.37 10318.85 3707.34 -1025.54 -6038.35 43.72 1233.97 165.95 1123.01 11.21 OSF 1.50 Pass 10680.00 364037 -1967.09 -6832.52 10338.06 3706.70 -1013.37 -6053.20 43.85 123343 186.59 1122.04 11 16 OSF 1.50 Pass 10700 00 3641 36 -1954.08 -6847.68 10358.26 3705 98 -1000.57 -6068 81 43.57 1232.89 167.32 1121.02 11 11 OSF 1 50 Pass 10720 00 3642 35 -1941.07 -6862 84 10378.45 3705 21 -987.77 -6084 41 43.49 1232.35 168.06 1119.98 11.06 OSF 1 50 Pass 10740 00 3643 34 -1928 06 -6878 00 1039863 3704.38 -974.99 -6100 00 43.41 1231.81 168.81 1118 95 11.00 OSF 1 50 Pass 10760 00 3644 32 -1915.06 -6893 16 10418 80 3703.49 -962.22 -6115 58 43.32 1231 27 16956 1117 90 10.95 OSF 150 Pass 10780 00 3645 31 -190205 -6908 32 10437.17 3702.64 -950.57 -6129 78 43.24 1230.73 170.10 1117 01 10 91 OSP 1.50 Pass 10800 00 3646 30 -188904 -6923 47 10454 10 3701 85 -939.82 -6142.82 43.16 1230.25 170.47 1116 27 10 88 OSF 1 50 Pass 10820 00 3647 25 -1876 02 -6938.63 10471 03 3701.05 -929.04 -6155 85 43 12 1229 80 170.85 1115 58 10 85 OSF 1.50 Pass 10840.00 3648 06 -186269 -6953 78 1048766 3700.25 -918.22 -6168.85 43.10 1229.41 171 23 1114.93 10.82 OSF 150 Pass 10860.00 3648 73 -184965 -6968 93 10504.91 3699.45 -907.36 -6181 84 43.08 1229.06 171.61 1114.32 10.80 OSF 1 50 Pass 10880.00 364927 -1836.90 -6984.08 10521.93 369863 -896.42 -6194.85 43.06 1228.75 172.00 1113.75 10.77 OSF 1.50 Pass 10900.00 3649.67 -1823.84 -6999.22 1054027 3697.75 -884.61 -620865 43.04 1228.47 17261 1113.13 10.73 OSF 1.50 Pass 10920.00 3649.92 -1810.76 -7014.35 1055861 3696.86 -87278 -622264 43.03 1228.21 17363 1112.53 10.70 OSF 1.50 Pass 10940.00 3650.04 -179767 -7029.47 10576 97 3695.96 -860.92 -6236.82 43.03 122797 17355 1111.95 10.67 OSF 1.50 Pass 10960 00 3650.02 -1784.58 -7044.59 10595.32 3695.05 -849 04 -6250 79 43.02 1227 75 174 07 1111.38 10.63 OSF 1 50 Pass 10980 00 3649.86 -1771.48 -7059.70 10613.69 3694.13 -837.14 -6264.74 43.01 122756 17459 1110.84 1060 OSF 1.50 Pass 11000 00 3649.59 -1758.37 -7074.80 10631.51 3693.23 -825.57 -6278.27 4299 122740 175.04 1110.37 1057 OSF 150 Pass 11020 00 3649.31 -174527 -7089.91 10649.31 3692.35 -813 99 -6291 76 42.96 122727 17550 1109.94 1054 OSF 1 50 Pass 11040 00 3649 02 -1732.16 -7105.02 1066711 3691 48 -802 38 -630523 42.93 1227 18 175 96 110954 1051 OSF 1 50 Pass 11060.00 3648 74 -1719.06 -712012 1088461 369062 -790 75 -6318.68 42 90 1227 12 17641 1109.18 1048 OSF 1 50 Pass 11080.00 3648.46 -1705.95 -7135.23 10702.72 3689.77 -77910 -6332.11 42.87 1227 10 176 87 110886 1046 OSF 1.50 Pass 11100.00 364818 -1692.85 -7150.33 10725.30 3688.70 -764.31 -634914 42.84 122709 177.85 1108.19 10.40 OSF 1 50 Pass 1112060 3647.90 -1679.74 -716544 10749.84 368754 -748.30 -6367.70 4280 122700 179.05 1107.31 10 33 OSF 1.50 Pass 11140.00 364761 -166664 -718054 10774.37 3686.38 -732.37 -6386.32 42.76 1226.85 180.25 1106.35 1026 OSF 1.50 Pass 11160.00 3647.33 -165363 -719565 10800.02 368516 -715.78 -6405.85 42.72 1226.62 181.58 110524 1018 OSF 1.50 Pass 1118060 3647.05 -1640.43 -7210.76 10832.81 3683.79 -694.78 -6430.99 4268 1226.23 18369 110345 1006 OSF 1.50 Pass 11200.00 3646.77 -1627.32 -7225.86 1086560 3682.70 -674.04 -6456.36 4265 122564 185 79 1101.45 994 OSP 1 50 Pass 1122000 364649 -1614.22 -7240.97 1090114 368185 -851.86 -648412 4264 122483 18819 109904 981 OSP 150 Pass 11240.00 3646.20 -1601.12 -7256.07 10956 70 3681 15 -61814 -6528 27 4265 122358 19269 109479 957 OSP 1 50 Pass 11260.00 3645.92 -1588.01 -7271 18 10994 94 3681 08 -59568 -6559 22 4267 1221 82 195 33 1091 27 942 OSF 1 50 Pass 11280.00 364564 -1574.91 -7286.28 1101117 3680.94 -58620 -6572.39 4268 1220.02 19566 108925 9.39 OSF I 50 Pass 11300.00 3645.36 -1561.80 -7301 39 1102741 368062 -57666 -6585 53 4268 1218 27 195 99 108729 9 36 OSF 1 50 Pass 11320.00 3645.08 -1548.70 -731649 1104366 368013 -567.08 -659865 4267 1216.59 196 34 1085.37 9 33 OSP 1 50 Pass 11340.00 364479 -1535.59 -7331.80 11059.90 367947 -557.47 -6611 72 4265 1214.97 19668 108352 9.31 OSF 1 50 Pass 11360.00 3644.51 -1522.49 -7346.71 11076.15 367862 -547.81 -6624 76 4262 121341 197.02 1081.74 928 OSP 1.50 Pass 11380.00 3644.23 -1509.38 -7361.81 11092.45 367764 -538.08 -6637.81 4259 121191 197.35 108001 925 OSF 1.50 Pass 11400.00 3643.95 -1496.28 -7376.92 11108.79 367666 -528.30 -6650.85 4265 1210.47 19768 1078.35 9.22 OSF 1 50 Pass 11420.00 364367 -1483.17 -7392.02 11125.13 367568 -51847 -6663.87 4252 120908 198.01 1076.75 9.20 OSF 1 50 Pass 11440.00 3643.38 -1470.07 -740713 11141 48 3674 71 -50859 -6676 87 42.48 1207 76 198 35 107520 917 OSF 1.50 Pass 1146060 3643.10 -1456.96 -7422.23 11157.84 3673 74 -49868 -6689 84 4245 1206 50 19868 1073.72 915 OSF 1 50 Pass 11480.00 3642.82 -1443.84 -7437.33 1117420 3672 78 -488 72 -6702 79 4263 120528 199 01 1072.28 912 OSF 1 50 Pass 11500.00 3642 52 -1430.68 -7452.38 1119013 3671 83 -478.99 -6715 36 4260 120407 199 28 107088 910 OSF 1 50 Pass 11520.00 3642 23 -1417.52 -746744 11206 05 3670 88 -469.22 -6727.89 42.56 120293 199 57 1069.55 9.08 OSF 1 50 Pass 11540.00 3641 93 -1404.36 -7482 50 11221 97 3669 91 -45941 -674040 42.53 1201 85 199 85 1068.29 906 OSF 1 50 Pass 11560 00 364163 -1391.20 -7497.56 11237 90 3668 92 -449.55 -6752.87 4249 1200 84 20013 106709 9 04 OSF 1 50 Pass 11580.00 3641 34 -1378.04 -751262 11253.83 3667.91 -43965 -6765 31 42.46 1199.90 20040 106597 9.02 OSP 1.50 Pass 11600.00 3641.04 -1364.88 -752768 11269.81 3666.89 -42967 -6777.76 4242 1199.03 20068 1064.91 900 OSF 150 Pass 11820.00 3640.75 -1351.73 -7542.73 11286.08 3665.84 -419.48 -6790.39 42.38 119822 201.00 106389 898 OSF 1.50 Pass 11640.00 364045 -1338.57 -7557.79 11302.34 3664.78 -40925 -8802 99 42.34 119747 201.31 106294 896 OSP 1.50 Pass 1166000 364016 -1325.41 -7572.85 11318.61 3663 71 -398.98 -681556 42.31 1196.79 20162 106205 8.94 OSF 1 50 Pass 11680.00 3639 86 -131225 -7587 91 11334 88 3862.63 -38867 -6828.10 4227 1196.17 201.93 1081.22 892 OSF 1 50 Pass 11700.00 363957 -1299.09 -7602.97 1135115 366155 -378.32 -684061 42.23 1195.61 202.24 106046 8.90 OSF 150 Pass 11720.00 3639 27 -1285.93 -7618 02 1137156 366019 -365.31 -6856.26 42.18 119510 203 01 1059.43 887 OSF 1 50 Pass 11740.00 3638 98 1272.77 -7633.08 11397 99 365865 -348.52 -687662 4212 1194 52 204 45 105789 880 OSF 1 50 Pass 11760.00 3638.68 -125961 -764814 1142444 3657 38 -331.82 -689710 42.08 1193 82 205 88 1056.24 873 OSF 1 50 Pass 11780.00 3638.39 -124645 -7663.20 11450.89 3656 36 -31524 -691768 42 05 1193 02 207.31 1054.48 8.67 OSF 1 50 Pass 11800.00 3638.09 -1233.20 -7678.26 1147944 3655 57 -29747 -6940 01 42.03 1192 09 208.97 105245 859 OSF 1 50 Pass 11820.00 3637.80 -122013 -7693.32 11508 27 3655 09 -279.70 -6962 70 42.03 1191 02 210.66 105024 851 OSF 1 50 Pass 11840.00 3637.50 -1206.97 -7708.37 11537.07 3654.93 -262.11 -698551 42.05 1189.79 212.35 104790 844 OSF 1 50 Pass 11860.00 3637.21 -1193.82 -772643 11564.54 365512 -245.49 -7007.39 42.08 118843 213.88 1045.51 8.37 OSF 1 50 Pass 11880.00 3636.91 -118666 -7738.49 1159123 3655 80 -22949 -7028.73 4213 1186.95 215.31 104308 8.30 OSF 1 50 Pass 11900.00 363661 -116761 -7753.56 1161784 365697 -21366 -705009 4205. 1185.37 216.74 104055 823 OSF 1 50 Pass 11920.00 3636 24 -1154.44 -776869 1164510 365867 -19760 -707205 41.82 1183 79 218.23 103797 817 OSF 1 50 Pass 11940.00 363580 -114146 -7783.90 1167717 366068 -178.93 -709804 4162 118215 22022 103501 808 OSF 150 Pass 11960.00 3635.29 -1128.57 -7799.19 1170925 3662 35 -16050 -712425 4142 118044 222 20 1031 98 800 OSF 1 50 Pass 11980.00 3634 71 -1115.78 -7814.55 1174467 3663 80 -14046 -715342 41 21 117864 224 51 1028.64 790 OSF 1 50 Pass 12000.00 3634 05 -1103.08 -7829.99 11792.04 3665 00 -114 38 -7192 94 41 02 1176 57 227 98 1024 25 7 77 OSP 1 50 Pass 12020.00 3633.32 -1090.48 -7845.50 1183419 3665.35 -91.92 -722861 40.77 117418 230 91 1019.91 765 OSF 1 50 Pass 12040.00 3632.54 -1077.97 -7861.09 1186049 3665 27 -7816 -7251 02 4047 1171 70 232 28 1016.52 759 OSF 1 50 Pass 12060.00 363168 -1065.56 -7876.75 11886.78 3664 99 -6452 -727349 4016 116924 23364 101315 753 0001 50 Pass 12080.00 3630.77 -1053.26 -7892.49 11913.06 3664.52 -5101 -7296.03 39.85 1166 79 235.00 1009.80 747 OSF 1 50 Pass 12100.00 3629 79 -1041.05 -7908 30 1194155 3663 88 -3651 -7320.55 39.54 1164.35 236.55 1006.32 741 OSF 1 50 Pass 1212000 3628.75 -1028.94 -792419 1197067 3663.32 -21.75 -7345.99 39.24 1161 87 23819 100275 764 0001 50 Pass 12140.00 362765 -101664 -794015 12000.35 366287 -7.22 -737152 3895 1159.36 23981 99916 728 OSF 150 Pass 12160.00 3626 49 -1005.04 -7956.18 1202489 366259 4.77 -7392.93 3867 1156 83 240 98 995 85 722 OSF 1 50 Pass 12180 00 3625.29 -993.18 -797224 1204497 366252 14.55 -741047 38 73 1154 34 241 73 992 85 7 19 OSF 1 50 Pass 12200.00 3624 10 -981 32 -7988 30 1206503 366260 24 31 -7427.99 3880 1151 84 24248 989 86 7 15 OSF 1.50 Pass 12220 00 3622 90 -969 47 -8004 36 12085.06 366285 34 06 -7445 49 3887 1149 34 243 25 986 85 7 11 OSF 1 50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 15 of 24 Trajectory:S132-W2(P6b)Vs.SP30-W1 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North APm Ct-Cl Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) 12240.00 3621.71 -957.61 -802043 12105.07 3663.25 43.77 -7462.98 38.96 1146.84 244.00 983.85 7.07 OSF 1.50 Pass 12260.00 362081 -945.76 -8036.49 12130.69 3663.95 56.16 -7485.40 3928 1144.30 24524 98048 7.02 OSF 1.50 Pass 12280 00 3619.32 -933.90 -8052.55 12157.15 3664.83 68.80 -7508.62 39.21 1141.64 246.54 976.96 6 97 OSF 1 50 Pass 12300 00 3618.13 -922.05 -8068.61 12183 54 366588 81 27 -7531 85 39.35 1138.88 247 80 973.35 6 92 OSF 1.50 Pass 12320 00 3616.93 -910.19 -8084.68 12206 86 3666 92 92.18 -755245 39.48 1136.00 248.91 969.74 6 87 OSF 1.50 Pass 12340 00 3615.74 -898.33 -8100.74 12224.17 3667.63 100.28 -7567.73 39.58 1133.14 24940 966.55 6 84 OSF 1.50 Pass 12360.00 361484 -886.48 -8116.80 12241 52 3668.22 108.43 -7583.02 3987 1130.33 249.80 963.47 6.81 OSF 1 50 Pass 12380.00 3613.35 -874.62 -8132.87 12258 90 366810 11684 -7598.34 39.75 112786 25026 960.39 6.78 OSF 1.50 Pass 12400.00 3612 15 -862.77 -8148.93 12276 31 3669.06 124 90 -7613.66 39.83 1124.83 250.82 957 28 6.75 OSF 1.50 Pass 12420 00 3610.97 -850.93 -8165.00 12293 75 3669 30 133.22 -7628 99 3988 1122.16 251.32 954.29 6.72 OSF 1 50 Pass 12440.00 3609.87 -839 17 -8181.14 12317 53 3669.44 144 55 -7649 89 39.39 1119.59 252.39 951 00 6.67 OSF 1 50 Pass 12460 00 3608.85 -827.49 -8197.35 12341.61 3669 36 155.96 -7671 10 39.09 1117.04 253.50 947 71 6.63 OSF 1 50 Pass 12480.00 3607.91 -815.91 -8213.63 1236572 366905 167.30 -7692 37 38.77 1114.52 25462 94445 6.59 OSF 1 50 Pass 12500.00 3607.06 -804.42 -8229.98 1238829 386884 178.19 -7712.93 3844 1112.04 25568 941.26 6.54 OSF 1.50 Pass 12520.00 360628 -793.02 -8246.39 1240259 366820 18457 -7724 94 38.09 1109.69 25586 93879 652 OSF 1 50 Pass 12540 00 3605.59 -781 71 -8262.87 12416.21 3667 89 191 03 -7736 93 37.74 1107.57 256.04 936 55 6.51 OSF 1 50 Pass 12560 00 3604.99 -770.49 -8279.41 12429.86 366760 197 57 -7748 90 37.39 110566 256 21 93453 6.49 OSF 1 50 Pass 12580.00 360448 -759.36 -8296.02 1244353 3667 33 20418 -7760 86 37.04 1103.97 256.38 932 73 648 OSF 1 50 Pass 12600.00 360401 -748.32 -8312.70 12457.22 366709 21087 -7772.80 36.70 1102.51 256.55 931.15 647 OSF 1 50 Pass 12620.00 360365 -737.38 -8329.44 1247022 3666.88 217.64 -7784.72 3636 1101.27 256.71 929.80 645 056 1.50 Pass 12640.00 360335 -726.51 -8346.22 12486.13 366667 22522 -7797 90 38.28 1100.21 25701 92854 644 OSF 1 50 Pass 12660.00 3603.04 -715.64 -836301 1250529 366641 23515 -7815 09 36 28 109919 25775 92703 642 OSF 1 50 Pass 12680 00 3602.74 -704.77 -8379.79 12525.84 3666 14 24507 -7832 29 36.29 1098.17 258.49 92552 6.39 OSF 1 50 Pass 12700 00 3602.44 -893.90 -8396.58 1254570 3665 88 255 00 -7849.48 36 29 1097.16 25923 92401 6.37 OSF 1 50 Pass 12720.00 360213 -683.03 -8413.36 1256555 366561 26493 -786667 36.30 1096.15 25997 92250 6.34 OSF 150 Pass 12740.00 3601.83 -672.16 -8430.15 1258349 3665.36 27391 -7882.20 36.30 1095.14 260.53 921.13 6.32 OSF 1.50 Pass 12760.00 3601.53 -661.29 -8446.93 1259983 3665.08 282 14 -7896 31 36.30 1094.20 26094 91991 6.31 OSF 1 50 Pass 12780.00 3601.22 -650.42 -8463.72 1261617 3664 74 29041 -7910 40 36.30 109333 261 36 918.76 6.29 OSF 150 Pass 12800 00 3600.92 -639.55 -848050 1263251 3664 35 298 74 -7924.45 36 29 1092.52 261.77 91768 6.28 OSF 1.50 Pass 12820.00 360062 -628.68 -8497.29 12648.86 3663 89 307 12 -7938.48 36 28 1091.78 26218 916.66 8.26 OSF 1.50 Pass 12840.00 3600.32 -617.81 -851407 12665 21 3863 38 31554 -7952.49 36.27 1091.10 26258 915.72 8.25 OSF 1 50 Pass 12860.00 3600.01 -606.94 -8530.86 12681.89 3862.84 324.18 -7966.74 36.26 1090.49 26322 914.82 6.24 OSF 1.50 Pass 12880.00 3599.71 -596.07 -8547.65 1269883 3662 35 33290 -7981 03 36.25 1089.94 26346 91397 6.22 OSF 1.50 Pass 12900.00 3599.41 -565.20 -8564.43 1271539 3661 92 341 67 -7995 30 36.24 108945 26391 913.18 6.21 OSF 1 50 Pass 12920.00 359910 -574.33 -8581 22 1273214 366154 35047 -800955 36.23 1089.02 26434 912.46 6.20 OSF 1 50 Pass 12940.00 3598.80 -563.46 -8598.00 12748.90 366122 359 32 -8023 78 36 23 108865 284.78 911.80 6.18 OSF 1 50 Pass 72960.00 359850 -552.57 -8614.78 12765.80 366095 368.28 -8038.11 36.43 1088.31 28522 911.17 617 OSF 1.50 Pass 12980.00 359822 -541.59 -8631.49 1278315 366088 377.52 -8052.78 36.83 1087.91 26570 91046 6.16 OSF 1.50 Pass 13000.00 3597.96 -53049 -8648.12 1280049 366041 386.79 -806744 37.23 1087.42 26617 90985 6.15 OSF 1.50 Pass 13020.00 3597 72 -519.27 -8664.68 12817.83 366014 396 09 -8082 07 3762 1086.84 266.64 908 76 613 OSF 1 50 Pass 13040.00 3597.50 -507 94 -8681.16 12835.16 3659 86 40543 -809667 38 02 108617 26710 907 78 612 OSF 1 50 Pass 13060.00 3597.30 -496.50 -8697.56 12852.50 365957 41481 -8111 25 38.41 1085.41 26756 906 71 610 OSF 1 50 Pass 13080.00 359712 -484.94 -8713.88 12884.52 365919 432.01 -813825 38.81 108444 28985 90442 6.05 OSF 1.50 Pass 13100.00 359696 -47328 -8730.13 12918.70 3659.20 450.00 -8167.32 39.23 1083.08 271.72 901.60 6.00 OSF 1.50 Pass 13120.00 3596.82 461.49 -8746.29 12950.23 365989 466.22 -8194.35 3987 1081.31 27359 898.59 5.94 OSF 1.50 Pass 13140.00 359689 -44960 -8762.37 12965.59 3659.87 474.09 -820754 4008 1079.37 27388 896.45 5.93 OSF 1 50 Pass 13160.00 3596.58 -43786 -8778.41 12980 96 366015 482.02 -822071 4010 107744 27416 894 34 5.91 OSF 1 50 Pass 13180.00 3596.46 -425.71 -879445 12996 35 3660.46 490.00 -823385 4013 107560 274.44 892 31 5.89 OSF 1 50 Pass 13200.00 3596.34 -413.77 -881049 13011 74 3660.77 498 05 -8246.97 4015 1073.84 27472 89036 5.88 OSF 1.50 Pass 13220.00 3596.22 -401.82 -8826.53 13027 14 3661 11 506.16 -826026 4018 1072.16 27500 888.50 5.86 OSF 1.50 Pass 1324020 3596.11 -389.88 -8842.57 1304282 3661.45 514.36 -8273.19 4021 107087 27529 886.72 585 OSF 1.50 Pass 13260.00 359599 -377.94 -885862 1306780 366215 52752 -829428 4026 1068.98 27654 884.29 5.81 OSF 1.50 Pass 13280.00 359587 -365.99 -887486 13092 33 366308 540.55 -8315.40 40.32 1067.29 277 77 881 78 5 78 OSF 1.50 Pass 1330000 3595 75 -35425 -8890.70 1311712 3664.27 55344 -8336.55 4040 106581 278.99 87919 5 74 OSF 1 50 Pass 13320.00 3595.64 -342.10 -8906.74 13140.80 3665.62 565.64 -8356.79 4049 1063.65 28008 87680 5.71 OSF 1.50 Pass 1334000 3595.52 -330.16 -8922.78 13161.72 3666.88 576.38 -837470 4258 1061.75 28090 874.15 588 OSF 1.50 Pass 1338020 3595.40 -31822 -893882 1318284 3668.18 58710 -839262 4086 1059.83 281.72 87168 566 0961.50 Pass 13380.00 3595.29 -306.27 -8954.86 1320355 3669.50 597 80 -841054 40.75 1057.89 28284 869 20 563 0961 50 Pass 13400.00 359517 -294.33 -8970.90 13224.45 3670 84 60846 -842846 40.83 1055.94 283 36 866.70 560 0961 50 Pass 13420 00 359505 -282.38 -8986.95 13242.74 3672.00 617.80 -8444.15 40.91 1053.99 28392 864.38 558 OSF 1.50 Pass 13440.00 359493 -270.44 -900229 13260.46 3673.03 626.89 -845933 4098 105208 28443 86213 556 OSF 1.50 Pass 13460.00 359482 -258.50 -9019.03 1327820 3873.96 63602 -847480 41.04 1050.21 28494 859.92 554 OSF 150 Pass 13480.00 3594.70 -246.55 -903507 1329526 367479 64521 -848988 41.10 1048.38 28546 857.75 5.52 OSF 1.50 Pass 13500.00 359458 -23481 -9051.11 1331374 3675.52 65444 -8504.85 41.15 104680 28598 85562 5.50 OSF 1.50 Pass 13520.00 359446 -222.66 -9067.15 1333191 367616 66392 -852034 41.20 104485 28653 85350 548 OSF 1.50 Pass 13540 00 359435 -210 72 -908319 1335040 367665 67360 -8536 08 41 24 104313 28713 851 38 546 OSF 1.50 Pass 13560.00 3594.23 -198 77 -9099.23 13368.90 3676.98 683 33 -8551 83 41 27 1041.44 28773 849.29 5.44 OSF 150 Pass 13580.00 359415 -186 82 -9115.27 13387.42 367713 69309 -856756 41.34 103977 28833 84722 542 OSF 1 50 Pass 13600.00 359421 -174.85 -9131.29 1340524 3677.12 702.89 -8583.28 41.37 1038.09 28823 845.14 540 OSF 1.50 Pass 13620.00 3594.40 -162.86 -9147.30 13422.87 3676 98 711 88 -859762 41 38 1036.41 28235 84318 5 39 OSF 1.50 Pass 13640.00 3594.73 -150.86 -9163.29 1343826 367680 72011 -861062 4138 1034.78 28982 84137 5.37 OSF 150 Pass 13660.00 359520 -138.85 -9179.28 1345365 3676 57 72840 -862359 41 37 103321 28989 839.62 5 36 OSF 1 50 Pass 13680.00 3595.81 -126.82 -9195.24 13469.04 3676.31 736.74 -8636 52 41 36 1031 70 29015 83793 5.35 OSF 1 50 Pass ■ 13700.00 3596.56 -114.78 -9211.20 1348443 3676.01 74515 -864941 41.34 1030.24 29042 836.30 5.33 OSF 1.50 Pass 13720.00 359742 -102.73 -9227.13 13499.82 367568 75362 -8662.26 41.30 1028.85 29069 834.73 5.32 OSF 1.50 Pass 13740.00 3598.31 -9088 -9243.07 13515.04 3675.31 762.05 -867492 41.25 1027.55 29095 83326 5.31 OSF 1 50 Pass 13760.00 359920 -7862 -9259.01 13530 05 3674.94 770.42 -8687.38 41.20 1026.34 291 17 831 90 5.30 OSF 1 50 Pass 13780.00 360008 -66.57 -9274.94 13545 07 3674.59 778 86 -869979 41.14 1025.23 291 38 83064 529 OSF 1 50 Pass 13800.00 360097 -5482 -9290.88 13560.10 3674.24 787.36 -871218 41.09 102421 291.60 829.49 528 OSF 1.50 Pass 1382020 3601.86 -42.47 -9306.81 1357513 3673.89 795.92 -872453 41.03 1023.30 29182 828.43 5 27 056 1.50 Pass 1384020 3602.74 -3041 -9322.75 1359017 367386 804.55 -8736.84 40.98 102248 292.03 82746 5.26 OSF 1.50 Pass 13860.00 3603.63 -18.36 -9338.69 13605.39 3673.22 813.34 -874927 40.92 1021.75 29226 826.58 526 OSF 1 50 Pass 13880.00 3604.52 -6.31 -935482 13621.24 3672.85 82254 -876216 40 87 1021.12 29257 825.75 525 OSF 1.50 Pass 13900 00 360540 5.74 -937056 13637.09 3672.43 831 80 -8775 01 40 80 102056 29286 824.99 5.24 OSF 1 50 Pass 13920 00 3606 29 17.79 -9386.50 13652 93 3671 97 841 12 -878782 40 74 1020.09 29316 824 32 5 23 OSF 1 50 Pass ■ ■ Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 16 of 24 Trajectory:SI32-W2(P6b)Vs.SP3O-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 Anm Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (6) ON (ft) (ft) ON (ft) (°) (ft) (ft) (6) 1394000 3807.18 29.85 -9402.43 1366877 3671.46 850.48 -880069 40.87 1019.70 293.45 823.74 5.22 OSF 1.50 Pass 13960 00 360866 41 90 -9418.37 13684.60 3670 91 859.89 -8813.31 40.60 1019 39 293.74 823.24 5.22 OSF 1.50 Pass 13980 00 3608.95 53.95 -9434.30 13699 86 3670 35 86961 -8825.52 40.53 1019 17 293 95 822.87 5.21 OSF 1 50 Pass 14000 00 3609.78 66 01 -9450.24 13713 90 3669 79 877.46 -8836.72 40 52 1019.s 294 00 822.72 5.21 OSF 1 50 Pass 14020 00 3610.46 78 09 -9466.16 13727 94 3669 21 885.99 8847 87 40.5 iniEn, 294 04 822.6 521 OSF 1 50 Pass 14040 00 3611 01 90 19 -9482.08 13741 99 3668 59 894 58 8858.97 40 51 1019 13 294 06 822.76 5.211 OSF 1 50 Pass 14060 00 3611.43 102.30 -9497.99 13756 04 3667 94 903.23 -8870.01 40.51 1019.33 294.08 822 95 5.21 OSF 1.50 Pass 14080 00 3611 70 114.43 -9513.89 13770 08 3667 26 911.95 -8881.01 40.50 1019.64 294.09 823.25 5.21 OSF 1 50 Pass 14100 00 3611.83 126.58 -9529.78 13784.13 3666.55 920.73 -8891.94 40.50 1020.05 294.09 82366 522 OSF 1 50 Pass 14120.00 3611 83 138.74 -954565 13802.00 366561 931.97 -8905.81 4049 1020.55 29459 823.83 521 OSF 1.50 Pass 14140.00 3611.71 15091 -9561.52 13821 73 3864.52 944.38 -892110 4045 1021.04 295.33 82383 520 OSF 1 50 Pass 14160 00 3611 56 16308 -9577 39 13841 45 3663.38 956.79 -8936 38 40.39 1021.55 296.07 823.84 5.19 OSF 1 50 Pass 14180 00 3611 42 175 25 -9593 26 13861 16 3662.20 969.21 -895165 40.33 1022.06 296.81 823.86 15 OSF 1 50 Pass 14200 00 3611 28 18743 -9609 13 13880.87 3660.97 981 62 -8966 91 40.27 1022 57 297.56 823.8:iMENEME OSF 1 50 Pass 14220 00 3611 14 199 60 -9625.00 1389527 3660.07 990 72 -8978 04 40 22 102315 297.58 824.43 5.17 OSF 1 50 Pass 14240 00 3611 00 211 77 -9640.87 13909.32 3659.22 999.66 -8988 84 4018 1023.83 297.55 825.14 5.17 OSF 1.50 Pass 14260 00 3610.86 223 94 -9656.74 1392336 3658.41 1008.66 -8999.59 40.14 1024.64 297.52 825.96 5.18 OSF 1.50 Pass 14280 00 3610.72 236 12 -967260 1393739 365764 1017.71 -9010.28 40.10 1025.56 297.47 826.91 5.18 OSF 1.50 Pass 14300 00 3610.57 248.29 -9888.47 13951.43 3656.91 1026.83 -9020.93 40.06 1026.59 297.42 827.98 5.19 OSF 1.50 Pass 14320.00 3610.43 260 46 -9704.34 13965.45 3656.21 1036 00 -9031.51 40.02 1027.74 29736 829.17 5.20 OSF 1.50 Pass 14340 00 361029 272 63 -9720.21 1398670 3655 49 1046.04 -9042.97 39 99 1029.01 297.47 830.37 5 20 OSF 1 50 Pass 14360 00 3610.15 284 81 -9736.08 13999.06 3654 65 1058 16 -9056.73 39 94 1030.32 298.00 831.33 5.20 OSF 1 50 Pass 14380 00 361001 296 98 -9751.95 14017.41 3653 82 1070.29 -9070.47 39 90 103167 298.53 832 32 5.20 OSF 1.50 Pass 14400 00 3609 87 309 15 -9767 82 14035 76 3653.00 1082 45 -9084.19 3986 1033 05 29907 833.35 519 OSF 1 50 Pass 14420.00 3609.72 321.32 -978368 1405410 365220 109463 -9097.89 3982 103446 29960 83440 5.19 OSF 150 Pass 14440.00 3609.58 33349 -9799.55 14071.73 365144 1106.34 -9111 03 39 78 103591 300.03 835.56 OIRIE OSF 150 Pass 14460.00 3609.44 34567 -9815.42 14086.32 3650 82 1116.09 -9121.88 39.75 1037.43 30063 837.08 5.20 OSF 1.50 Pass 14480 00 3609.30 357.89 -9831.25 1410090 3650.19 112588 -913266 4010 103899 30060 838.66 5.21 OSF 1.50 Pass 14500 00 3609.16 37022 -9847.00 1411548 364957 1135.72 -914339 4047 104052 299.98 840.21 522 OSF 150 Pass 14520 00 360902 382.66 -986266 1413005 3648 95 114562 -915407 4084 1042 02 29992 841.74 522 OSF 150 Pass 14540.00 3608.88 395.21 -9878.23 14144.62 3648 33 115557 -9164.70 41 21 104347 299.86 843.23 523 OSF 1.50 Pass 14560 00 3608.74 40787 -9893.71 1415919 3647 71 116558 -917527 41 58 104489 299.80 844.70 524 OSF 1.50 Pass 14580 00 3608.60 42064 -9909.11 1417618 3647 02 1177.30 -918755 41 95 1046 26 300.09 845.87 524 OSF 1.50 Pass 1460000 360846 43351 -992441 14193.83 364640 118950 -920029 42 32 104753 30047 846 89 524 OSF 1 50 Pass 1462000 3608.32 446.49 -993963 14211.49 3645 89 1201.74 -921301 42.70 1048.71 300.85 847.82 524 OSP 1.50 Pass 1464000 3608.18 459.58 -9954.75 1422916 364549 1214.01 -922571 4309 1049 79 30122 848.65 524 OSF 1.50 Pass 1466000 3608.03 472 77 -9969.78 14246.83 364519 1226.31 -923840 4348 1050.78 30169 849.39 524 OSF 1.50 Pass 14680.00 3607.88 486.06 -9984.72 1426566 3645.00 1239.37 -9251.82 4387 1051.66 302.12 84992 523 OSF 1.50 Pass 14700.00 3607.72 49946 -9999.57 14285 35 3645 00 125317 -9266.00 4428 105242 302 79 850 23 523 OSF 1.50 Pass 14720.00 3607.55 512 96 -10014.32 1430514 3645 20 1266 97 -928019 44 70 105304 30346 85040 522 OSF 1.50 Pass 14740.00 3607.38 526 57 -10028.98 14324.92 364561 1280 76 -9294 37 4513 105353 30413 85045 521 OSP 1.50 Pass 14760.00 360719 54028 -10043.54 1434469 3646 22 1294 53 -930854 45 58 105388 304 78 85036 520 OSP 1.50 Pass 14780.00 3607.01 55408 -10058.01 14364 96 3646 96 130864 -932306 46.03 105409 30552 850.09 519 OSP 1.50 Pass 1480060 3606.81 567.99 -10072.38 14385.38 3647 57 1322.87 -9337.70 46.48 105416 30628 84965 517 OSP 1.50 Pass 1482060 360660 58200 -1008666 14405.81 3648 05 1337.10 -9352.36 46.92 1054.08 307.04 84906 5.16 OSF 1.50 Pass 1484000 3606.39 59611 -10100.83 1442625 3648 38 1351.33 -936702 47.36 1053.85 30780 84832 5.15 OSF 1 50 Pass 14860.00 3606.17 610 31 -10114.91 14445 33 364856 136463 -9380.71 47.78 105348 308 37 847.57® OSF 150 Pass 14880.00 3605.94 624.62 -10128.88 14459.20 364864 1374.32 -939062 4820 105305 30815 847.28 514 OSP 150 Pass 14900 00 3605.71 639.02 -10142.76 14473 06 364869 1384.08 -940048 4862 105259 307 93 846 98 5 14 OSF 1 50 Pass 14920 00 3605.47 65352 -10156.54 14486.93 3648 71 1393.90 -941027 4903 1052 11 307 70 84665 514 OSP 1.50 Pass 1494000 3605.22 66811 -10170.21 14500.80 3648 70 1403.77 -942001 4945 1051 61 30746 846 31 514 OSF 1.50 Pass 14960.00 360496 682 79 -10183.79 1451468 364866 1413 71 -9429.70 49 72 1051 10 30721 845 96 514 OSF 1 50 Pass 14980.00 3604.70 697.49 -10197.35 1452856 364859 1423.70 -9439.33 49.73 105067 306.97 845.69 515 OSF 1.50 Pass 1500060 3604.44 71219 -10210.90 14542.82 364849 143463 -944916 49.73 105035 306.78 845.51 515 OSF 1.50 Pass 1502000 3604.19 726.89 -10224.46 1455761 3648.34 1444.72 -945923 49.74 105014 30667 845.37 515 OSF 1.50 Pass 1504000 3603.93 74160 -10238.02 1457220 364816 1455.47 -9469.25 49.74 1050.03 3065 :EgM 515 OSF 1.50 Pass 1506000 360367 756 30 -10251.57 14586 89 3647 95 1466.26 -947921 49 74 1050.0 30643 845.41 515 OSF 150 Pass 15080.00 360341 771 00 -1026513 14601.58 3647 70 147711 -9489.11 49 73 105012 306 30 845.59 515 OSP 1.50 Pass 15100 00 360315 785 70 -1027869 1461626 364742 1488 00 -949896 49.73 1050 31 306 17 845.87 516 OSF 1.50 Pass 15120 00 3602 89 80040 -10292.25 1463065 364711 1498.72 -950855 4966 105061 305.98 846.30 516 OSF 1.50 Pass 15140 00 3602.55 81506 -10305.85 14642.88 3846 83 1507.89 -9516.64 49 39 1051.11 30541 84717 517 OSP 1.50 Pass 15160.00 360211 82965 -10319.52 14655.11 3646 56 151711 -952466 4912 1051 84 30483 848.29 519 OSF 1.50 Pass 15180.00 3601.55 844.18 -10333.25 14667.33 3646.28 1526.39 -9532.61 48.84 105282 30423 849.67 5.20 OSF 1 50 Pass 1520000 3600.89 85865 -10347.04 1467963 3646 01 1535.71 -9540.48 4855 105404 303.62 851.29 522 OSF 1 50 Pass 15220.00 3600.13 873.05 -10360.90 14691 72 3645 75 154508 -954827 48.36 105549 303.00 85316 524 OSF 1 50 Pass 15240.00 3599.35 88744 -10374.77 14703.90 364548 155450 -955599 48.37 1057.12 302.37 855.21 526 OSP 1.50 Pass 15260 00 3598.57 901 83 -10388.64 14716 05 3645 22 1563.96 -956362 48.38 105889 301 73 857.40 528 OSF 1.50 Pass 15280.00 3597.78 916 22 -10402.51 14729.13 3644 94 157418 -9571 75 48 39 1060 80 30124 859.64 5 29 OSF 1.50 Pass 15300 00 3597.00 93061 -10416.38 1474325 364464 158529 -9580.48 4840 1062 82 300 93 861.88 531 OSF 1.50 Pass 15320 00 3596.21 945 00 -10430.25 14757.36 3644 32 1596.43 -958914 48.41 1064 96 300.62 86422 533 OSF 1.50 Pass 15340.00 3595.43 95938 -1044412 1477146 3643 99 160760 -9597.72 4842 1067.20 300 30 866.67 534 OSF 1.50 Pass 1536060 359465 97377 -10457.99 14785.53 364366 161880 -9606.24 4843 106955 299.98 869.23 5.36 OSF 1.50 Pass 15380 00 3593.86 98816 -10471.85 1479969 3643 32 163064 -961468 4844 1072.01 299.66 871.91 538 OSF 1.50 Pass 15400.00 3593.08 1002.55 -10485.72 14813.63 3642 97 1641 31 -962365 4844 107457 299.33 874.69 540 OSF 1.50 Pass 15420 00 3592.30 1016 94 -10499.59 14833.25 364253 165709 -9634.70 4845 1077.20 300 00 876.87 5 40 OSF 1.50 Pass 15440 00 3591.51 1031 33 -1051346 14853 97 364218 1673 74 -9647 01 4847 1079 81 300.86 878 91 5 40 OSF 1.50 Pass 15460 00 3590.73 1045 71 -10527.33 1487468 3641 97 1690 38 -9659 35 48 50 1082 41 301 72 880.94 5 39 OSF 1 50 Pass 15480 00 3589.95 1060 10 -10541.20 14895 39 3641 89 170700 -9671.70 4853 1084 99 302.58 882.95 5 39 OSF 1.50 Pass 15500.00 358916 1074 49 -10555 07 14916 79 3641 96 172417 -968449 4857 108756 30355 884 86 5 39 OSF 1 50 Pass 15520.00 3588.38 108888 -10568.94 1493961 364223 1742.42 -9698.17 4863 109007 304.76 886.58 5.38 OSF 150 Pass 15540.00 358760 1103.27 -1058281 14962.41 3642.72 1760.62 -9711.90 48.69 109254 305.96 888.24 5.37 OSF 1.50 Pass 15560.00 358681 1117.66 -10596.68 1498521 3643.44 177877 -972568 4877 109495 307.14 889.86 5.36 OSF 1.50 Pass 15580 00 3586.03 1132 05 -1061055 15007.47 3644.35 1796.44 -9739.79 48.86 1097.31 308.23 891 50 5.35 OSF 150 Pass 15600 00 358525 1146 43 -1062442 15028.01 364524 1812 73 -975167 48 94 1099.65 30902 893.31 5 35 OSF 1.50 Pass 15620 00 358446 1160 82 -10638.29 15048.56 3646 10 182901 -976417 4902 1101 98 309.81 89511 5.35 OSF 1 50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 17 of 24 Trajectory:SI32-W2(P6b)Vs.SP3O-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 Abim Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) 15640 00 3583.71 1175.24 -10652.13 15069.12 3646.95 1845.30 -977689 49.41 1104.25 310.57 896.88 5.35 05F1.50 Pass 15680.00 358392 1189.74 -10665.89 15089.71 3647.77 1861.60 -9789.24 49.85 1106.39 311.32 898.52 5.34 OSF 1.50 Pass 15680.00 358242 120432 -10679.56 15115 97 3648.83 1882.36 -9805.30 50.30 1108.37 313.05 899.34 5.32 OSF 1.50 Pass 15700 00 3581.89 121898 -10693.15 15144 83 3650 12 1905.02 -982312 50.76 1110.07 315.19 899.62 5.29 OSF 1.50 Pass 15720 00 3581.45 1233.72 -10706.67 15173 73 3651.55 1927 56 -9841.15 51 19 1111.50 317 29 899.65 5.27 OSF 1 50 Pass 1574000 3581.09 1248.54 -10720.10 15198 03 3652.85 1946.39 -9856.45 5161 1112.67 318.61 89994 5.25 OSF 150 Pass 15760 00 3580.82 1263.42 -10733.45 15216 76 3653 72 1960.92 -9868.25 5200. 1113.73 319 03 900.72 5 25 OSF 150 Pass 15780 00 3580.63 1278.39 -10746.72 15235 52 3654.45 1975.49 -9880.04 52.37 1114.69 319.45 901.40 5.25 OSF 1.50 Pass 15800.00 3580,53 129342 -10759.91 15254.29 3655.03 1990.09 -9891.82 52.70 1115.56 319.89 901.97 5.24 OSF 1.50 Pass 15820.00 358047 1308.49 -10773.06 15273.08 3655.46 2004.72 -9903.59 52.72 1116.40 320.39 902.48 5.24 OSF 1.50 Pass 15840 00 3580.41 1323.55 -10786.22 15291 70 3655.74 2019.26 -9915.24 52.74 1117.27 320.88 903.02 5.23 OSF 1.50 Pass 15860 00 3580.35 1338.62 -10799 37 15310.15 3655 89 2033.67 -9926.75 52.74 1118.16 321 35 903.60 523 OSF 1.50 Pass 15880 00 3580.29 1353.68 -1081253 15328.60 365593 204811 -993824 52.75 1119.08 32182 904.20 5.23 OSF 1.50 Pass 15900 00 3580.23 1368.75 -10825.68 15347.05 3655.86 2062.57 -9949.70 52.74 1120.02 322.30 904.83 5.22 OSF 1.50 Pass 15920.00 3580.17 1383.81 -10838.83 1536549 3655.66 2077.04 -9961.13 52.73 1121.00 322.78 905.49 OSF 1.50 Pass 15940 00 3580.10 1398.88 -10851.99 15383.15 3655 38 2090.91 -9972.04 52.72 1122.00 323.12 906 26 OSF 1.50 Pass 15960 00 3580.04 1413.94 -10865.14 15399 70 3655 11 2103.95 -998224 52.70 1123.06 323.27 907.22 5.22 OSF 1 50 Pass 15980 00 357998 1429 01 -10878 30 15416.24 3654 85 2117 01 -9992.39 52.69 1124.18 323.42 908 24 5.23 OSF 1.50 Pass 16000.00 3579.92 1444.07 -10891.45 15432 78 365461 213010 -1000250 52.68 1125.36 323.57 909 32 5.23 OSF 1 50 Pass 16020.00 3579.86 1459.14 -10904.61 15449.32 3654 38 214321 -1001257 52.66 112680 32371 910.47 523 OSF 1.50 Pass 16040.00 3579.80 1474.20 -10917.76 15465.85 3654 16 2156.35 -10022.60 52.65 1127.91 323.85 911.68 524 OSF 1.50 Pass 16060.00 3579.73 1489.27 -1093092 1548244 3653 94 2169.57 -10032.62 52.64 1129.27 324.00 912.94 5.24 05F 1.50 Pass 16080.00 3579.67 1504.33 -1094497 15499 05 3653 71 2182.83 -10042.62 52.62 1130.69 324.16 914.26 5.24 OSF 1.50 Pass 16100 00 3579.61 1519.40 -1095722 15515.66 365347 219612 -10052.57 52.61 113217 324.31 91564 5.25 OSF 1.50 Pass 16120.00 3579.55 1534.46 -10970.38 15532 25 3653 21 2209.44 -10062.48 52.60 1133 71 324.46 917.08 5.25 OSF 1.50 Pass 16140 00 3579.49 1549.53 -10983.53 15548 84 3652 95 2222.77 -10072.34 52.58 1135.31 324.60 918.58 5.26 OSF 1.50 Pass 16160.00 3579.43 156459 -1099669 15565.83 365266 2236.46 -1008240 5258 1136.97 32482 92009 5.26 OSF 150 Pass 16180.00 3579.36 1579.86 -11009.84 1558526 365242 225213 -10093.89 5255 1138.65 32545 921.35 5.26 OSF 1.50 Pass 16200.00 3579.30 159472 -11023.00 1560469 3652.34 2267.80 -10105.38 5254 1140.34 32609 922.63 5.26 OSF 1.50 Pass 16220.00 3579.19 160979 -1103615 1562412 3652.41 228346 -10116.87 5253 114295 32671 923.91 525 OSF 1.50 Pass 16240.00 3578.94 162486 -11049 30 15643 55 365264 229912 -10128.36 52 53 1143.76 327 33 925.22 525 OSF 1.50 Pass 16260.00 3578.62 163993 -1106244 15863 26 3653.01 231501 -10140.02 5256 114549 327 99 926.50 525 OSF 1.50 Pass 16280.00 3578.31 165590 -11075.59 15683.54 3653.44 2331.36 -10152.02 5260 1147.21 32873 927.73 5.25 OSF 1.50 Pass 16300.00 3578.00 167007 -11088.73 15703 83 3653.87 2347.70 -10164.03 5263 1148.92 32948 928.94 5.24 OSF 1.50 Pass 16320.00 357769 1685.14 -11101.88 1572411 365431 2364.04 -10176.04 5286 115063 330.23 93015 5.24 OSF 1.50 Pass 16340.00 357738 170021 -11115.02 1574440 3654 76 2380.38 -10188.06 52.89 1152.34 330 97 931.36 523 OSF 1.50 Pass 16360.00 357707 1715.28 -11128.17 1576710 3655.26 239864 -10201.53 52.73 115402 33213 932.27 522 OSF 1.50 Pass 16380.00 3576.76 173035 -11141.31 1579066 3655.76 241756 -10215.57 52 76 1155.64 33342 933.03 521 OSF 1.50 Pass 16400.00 3576.45 1745.42 -11154.46 1581423 3656.26 243644 -1022968 52.80 115720 334 72 933.72 5.20 OSF 1.50 Pass 16420.00 3576.13 176049 -1116760 15837.81 3656.75 245528 -10243.85 52.84 1158.69 336 D2 934.35 5.18 OSF 1.50 Pass 16440.00 3575.82 1775.56 -11180.75 15860.83 385720 2473.63 -10257.73 52.87 116013 337.21 934.99 517 OSF 1.50 Pass 16460.00 357551 1790.63 -11193.90 1588368 365756 2491.82 -10271.55 52.90 116152 338 39 93560 516 OSF 1.50 Pass 16480.00 357520 180570 -11207.04 15906 55 365785 2510.00 -1028543 52.93 1162.86 339 56 93615 515 05E1.50 Pass 16500 00 3574.89 1820.77 -11220.19 15929 43 3658 05 252815 -10299.36 52.95 116414 340 74 936.66 5.14 OSF 1.50 Pass 16520.00 357458 1835.84 -11233.33 15948.35 3658.16 254315 -1031089 52.97 116540 34127 937.56■ 4 OSF 1.50 Pass 16540.00 357427 1850.91 -1124648 15965.56 3658.23 2556.81 -10321.35 52.98 1166.71 341.53 93869 5.13 OSF 1.50 Pass 16580.00 357395 186598 -11259.62 15982.76 365828 2570.50 -10331.77 52.99 1168.06 34179 939.87 5.14 OSF 1.50 Pass 16580.00 357364 1881.05 -11272.77 15999 95 365825 258421 -1034215 53.00 116946 34205 941.10 514 OSF 1.50 Pass 16600.00 3573.33 1896.12 -11285.91 1601714 3658 21 2597.94 -1035250 53.01 1170.90 342 31 942.37 514 OSF 1.50 Pass 16620.00 357302 1911 19 -11299.06 16035 35 3658.14 261251 -1036342 53.01 1172.39 34274 943.57 514 OSF 1.50 Pass 16640.00 3572.71 1926.26 -11312.20 1605637 365804 2629.32 -1037603 53.02 1173.88 34363 94446 513 OSF 1.50 Pass 18680.00 357240 1941.33 -11325.35 16077 38 365796 264612 -1038865 53.02 1175.35 34453 945 34 513 OSF 1.50 Pass 16680.00 3572.09 1956.40 -1133849 1609840 3657.88 2662.91 -1040129 5393 1176.81 34543 94619 512 OSF 1.50 Pass 16700.00 357178 1971.47 -11351.64 1611942 365782 2679.70 -1041395 53.01 117824 346 32 947.03 5.11 OSF 1.50 Pass 16720.00 357155 1986.51 -11364.82 16151 74 3657 74 270540 -1043354 52.85 117962 34897 94664 508 OSF 1.50 Pass 16740.00 3571.46 200151 -11378.04 1618654 3657.73 2732.81 -1045498 5269 1180.80 35199 945.81 504 OSF 1.50 Pass 16780 00 3571 48 2016.47 -11391.32 16219 32 3657.78 2758 38 -1047549 5255 1181.79 354 6 ®r6 r 5 01 OSF 1.50 Pass 16780.00 3571.64 2031.40 -1140463 16239 29 365788 277389 -1048807 5241 1182.72 355.29 945.54 500 OSF 1.50 Pass 16800.00 3571.91 2048.29 -1141798 16259.27 3658.06 278941 -10500.65 52.32 1183.70 35594 946.08 5.00 OSF 1.50 Warning 16820.00 357221 206117 -11431.34 16279.24 365832 2804.91 -1051324 52.31 1184.68 35666 946.58 4.99 OSF 1.50 Warning 16840.00 357251 2076.05 -1144469 1629922 365866 282042 -10525.83 52.31 118567 357 38 947 09 4.99 OSF 1.50 Warning 16860.00 357281 209094 -11458.05 16317 34 365904 2834.48 -1053725 52.31 118666 35781 947.79 OSF 1.50 Warning 16880.00 357311 2105.82 -1147140 1633331 3659.38 2846.91 -1054728 5232 1187.71 35790 948.78 499 OSF 1.50 Warning 16900.00 357341 212071 -11484.76 1634928 3659.71 2859.36 -1055726 52.32 118883 35799 948.83 499 OSF 1.50 Warning 16920.00 3573.70 213559 -11498.11 1636524 3660 04 2871.85 -1056720 52.32 1190.01 35808 950 96 4.99 OSF 1.50 Warning 16940.00 3574.00 215047 -1151147 16381.20 366036 2884.36 -1057710 52.32 119126 35817 95215 500 OSF 1.50 Warning 16960.00 3574.30 216536 -11524.83 1639715 366067 2896.90 -1058694 52.32 119258 35825 95342 5.00 OSF 1.50 Pass 16980 00 357460 218014 -1153818 16413 34 366098 290967 -1059690 52 32 1193 96 358 38 954.72 5.01 OSF 1.50 Pass 17000.00 357490 219513 -11551 54 1642968 3661 25 292259 -1060690 52.32 119541 35853 956.06 5 01 OSF 1.50 Pass 17020.00 357520 2210.01 -11564.89 16446 02 3661 46 293554 -10616 86 52.31 1196.91 35869 95746 5 02 OSF 1.50 Pass 17040.00 3575.50 2224.90 -1157825 16462.35 366163 294851 -1062677 52.30 1198.48 35884 958.92 5.02 OSF 1.50 Pass 17060.00 3575.79 2239.78 -11591.60 16478.66 3661.75 296151 -1063664 5229 1200.10 358.99 96045 5.02 OSF 1.50 Pass 17080.00 3576.09 2254.66 -11804.96 16494.97 3661.83 2974.53 -1064646 5228 1201.79 35914 962.03 5.03 OSF 150 Pass 17100.00 3576.39 226955 -11618.32 1651055 3661.79 298701 -1065579 5226 120354 359.18 963.76 504 OSF 150 Pass 17120 00 3576 69 2284 43 -1163167 16526 02 3661 55 299944 -1066500 5223 1205.36 35920 96557 5.04 OSP 150 Pass 17140.00 3576 99 2299.32 -1164503 1654147 3661 13 3011 88 -1067413 5220 120726 35921 96746 5.05 OSF 1.50 Pass 17160.00 3577.29 2314.20 -11658.38 16556.87 3660 50 3024 34 -1068318 5215 120923 35923 96942 5.06 OSF 150 Pass 17180.00 3577.59 2329 08 -11671.74 1657225 3659.69 3036 80 -10692.15 5210 1211.28 35924 97146 5.07 OSP 150 Pass 17200 00 3577.89 2343.97 -11685.09 16587.57 3658.68 3049.25 -10701.03 5203. 1213.40 35924 97358 5.08 OSF 1.50 Pass 1722000 357818 2358 85 -1169845 1660950 3657 03 3087.08 -1071368 51 87 1215.56 36035 974.99 5.07 OSF 150 Pass 17240.00 357841 237369 -11711.85 16632.74 365519 3085.94 -1072714 5148 1217.73 36167 97628 5.06 OSF 1.50 Pass 17260.00 357853 2388 47 -11725.33 10655.98 3653 27 310476 -10740.64 51 08 121994 362.99 97762 5.05 OSF 150 Pass 17280 00 3578.54 240319 -1173887 1667922 3651 25 3123.53 -1075418 5067 1222.20 36429 97901 5.04 OSF 1 50 Pass 17300.00 3578.49 2417.87 -11752.46 16701 20 3649.31 3141.26 -10767.04 5051 1224.49 365.38 98057 5.04 OSF 1.50 Pass 17320.00 3578.43 243254 -11786.05 1672292 364751 315876 -10779.78 5042 1226.74 36642 98213 5.03 OSP 1.50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 18 of 24 Trajectory:SI32-W2(P6b)Vs.SP3O-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 Arim Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (It) (ft) (ft) (ft) (R) (ft) (8) (°) (6) (ft) (ft) _ 17340 00 3578.37 2447.21 -11779.64 1674467 3645.81 3176.27 -10792.57 50.34 1228.97 367.47 983.66 03 OSF 1.50 Pass 17360.00 357831 246189 -1179323 16766.45 364423 319378 -10805.41 5026 123117 368.52 98516 .02 OSF 150 Pass 1738000 357826 2476.56 -11806.82 16786.12 3642.88 3209.59 -10817.05 5020 1233.35 369.22 986.8 .8. OSF 1.50 Pass 17400.00 357820 2491 23 -11820.41 16803.84 3641 72 3223.84 -10827.51 50.14 1235.56 369.60 988.83 02 OSF 1.50 Pass 17420.00 3578.14 2505.91 -11834.00 16821.55 3640.61 323810 -10837.94 50.09 1237.80 369.98 990.82 03 OSF 1.50 Pass 17440.00 3578.08 2520.58 -11847.59 16839.26 3639.54 3252.39 -10848.36 50.03 1240.07 370.36 992.84 03 OSF 1 50 Pass 17460.00 3578.02 2535.25 -11861.18 16856.96 363852 3266.69 -10858.75 49.98 1242.39 370.73 994.90 04 OSF 1.50 Pass 17480.00 3577.97 2549.92 -11874.77 16873.15 363762 3279.78 -10868.23 49.94 1244.74 370.86 997.17 04 OSF 1.50 Pass 17500.00 3577.91 2564.60 -11888.36 16884.65 3637 00 3289.12 -1087492 49.91 1247.19 370.21 1000.06 06 OSF 1.50 Pass 17520.00 3577.85 2579.27 -11901.95 16896.14 3636 38 3298.49 -10881 53 49.88 1249.78 369.55 1003.08 08 OSF 1 50 Pass 17540.00 3577 79 2593.94 -11915.54 16907.61 3635 77 3307.88 -10888 07 49.85 1252.50 368 88 1006.25 10 OSF 1.50 Pass 17560.00 3577 73 2608.62 -11929.13 16919.05 3635 17 3317.31 -10894 54 49.82 1255 36 368.20 1009.56 12 OSF 1 50 Pass 17580.00 3577 68 2623.29 -11942.72 16930.48 3634 58 3326.76 -10900.94 49.79 1258 34 367.51 1013.01 15 OSF 1.50 Pass 17600.00 3577 62 2637.96 -11956 31 16941.88 3633 99 3336.23 -10907 25 49 76 1261 46 366 80 1016 60 17 OSF 1.50 Pass 17620.00 3577 56 2652.64 -11969.90 16953.25 3633 41 3345.72 -10913 50 49.73 1264 71 366.08 1020 32 19 OSF 1 50 Pass 17640.00 3577 50 2667.31 -11983.49 16965.80 3632 78 3356.24 -10920.31 49.70 1268 08 365 56 1024.05 21 OSF 1.50 Pass 17680.00 3577 44 2681.98 -11997.08 16993.91 3631.36 3379.78 -10935.60 49.63 1271.45 367 73 1025.96 20 OSF 1 50 Pass 17680.00 3577.39 2696.66 -12010.67 17022.09 3629 92 3403.28 -10951 09 49.56 1274.68 369.89 1027.75 18 OSF 1 50 Pass 17700.00 3577.33 2711.33 -12024.26 17050.32 3628.46 3426.72 -10966 76 49.49 1277.78 372.04 1029.42 16 OSF 1.50 Pass 17720.00 3577.27 2726.00 -12037.85 17118.92 3624.94 3482.83 -11006 04 49.32 1280.51 380.72 1 r 6.7 .05 OSF 1 50 Pass 17740.00 3577 21 2740.67 -12051 45 17160.65 3622.90 3516.21 -11031 02 49.23 1282 50 384 86' 10JEIRIEE OSF 1 50 Pass 17760.00 3577 15 2755 35 -12065.04 17177.09 3622.17 3529.31 -11040 92 49.20 1284 47 385 08 1027.44 01 OSF 1 50 Pass 17780.00 357710 2770.02 -12078.83 17193.53 362150 3542.44 -1105078 49.16 1286.49 38525 1029.34 02 OSF 150 Pass 17800.00 357705 2784.69 -12092.22 17209.96 3620.89 3555.59 -1106061 49.16 128857 38541 103130 02 OSF 150 Pass 17820.00 3577 12 2799 37 -12105.81 17226.38 3620.34 3568.77 -11070 41 49.17 1290.70 385 55 1033.34 03 OSF 1 50 Pass 17840.00 3577 33 2814.04 -12119.40 17242 80 3619.85 3581.96 -11080 16 49 17 1292.87 385 68 1035.42 04 OSF 1 50 Pass 17860.00 3577.58 2828.71 -12132.98 17259.97 3619 39 3595.79 -11090 34 49.14 1295.09 385 93 1037.48 04 OSF 1 50 Pass 17880.00 357782 2843.38 -12146.57 1727720 3618.94 3609.68 -11100.52 49.11 1297.36 38619 1039.56 05 OSF 1.50 Pass 17900.00 3578.07 2858.06 -12160.16 17294.41 3618.52 3623.58 -11110.66 49.07 1299.66 386.45 1041.70 05 OSF 1.50 Pass 17920.00 3578.32 2872.73 -12173.75 1731162 3618.11 3637.49 -1112078 49.04 1302.00 38676 104383 D6 OSF 150 Pass 17940.00 3578.57 288740 -12187.34 17328.82 3617.73 3651.43 -11130.86 49.01 1304.39 387.07 1046.01 06 OSF 1.50 Pass 17960.00 3578.82 2902.07 -12200.93 17348.45 3617.32 3667.34 -11142 34 48.98 1308.80 387.76 1047.97 06 OSF 1.50 Pass 17980.00 357907 2916.74 -12214.52 1737041 3617.00 3685.13 -1115521 48.95 1309.20 388.82 1049.65 06 OSF 1.50 Pass 18000.00 3579 32 2931 42 -12228.11 17392 39 3616.81 3702.92 -11168 13 48.93 1311.56 389.88 1051.31 05 OSF 1 50 Pass 18020.00 3579 57 2946 09 -12241.70 17414 39 3616.76 3720.69 -11181 08 48.91 1313.88 390.94 1052.93 05 OSF 1 50 Pass 18040.00 3579 82 2960.76 -12255.29 17435 57 3616.84 3737.78 -11193 59 48.90 1316.18 391 87 1054.61 OSF 1.50 Pass 18060.00 3580 07 2975.43 -12268.88 17454 37 3617 02 3752 95 -11204 69 48.89 1318 48 392 42 1056.54 05 OSF 1 50 Pass 18080.00 358132 299111 -12282.48 1747116 381729 3788.13 -11215.78 48.89 132180 39217 105849 .05 OSF 150 Pass 18100.00 3580.57 3004.78 -12296.05 17491.95 381757 3783.31 -11228.85 48.90 1323.13 393.52 1060.48 .05 OSF 1.50 Pass 18120.00 3580.82 3019.45 -12301644 17510.74 3818.13 3798.49 -11237.91 48.90 1325.48 394.07 1082.44 .05 OSF 150 Pass 18140.00 3581.07 3034.12 -12323.23 17530.11 3618.71 3814.14 -11249.30 48.92 1327.85 394.71 1084.38 .06 OSF 1.50 Pass 18180.00 3581.32 3048.79 -12338.82 17550.96 3619.24 3830.99 -11261.57 48.92 1330.20 395.58 1066.16 .05 OSF 1.50 Pass 18180.00 3581.56 3063.47 -12350.41 17571.82 3619.63 3847.85 -11273.85 48.93 1332.55 396.45 1067.92 .05 OSF 1.50 Pass 18200.00 3581.81 3078.14 -12364.00 1759218 3619.87 3864.70 -11286.15 48.92 1334.87 397,33 1069.66 OSF 1.50 Pass 18220.00 3582.06 3092.81 -12377.59 17613.54 3619.96 3881.54 -1129845 48.91 1337.19 398.21 1071.3. P OSF 1.50 Pass 18240.00 3582.31 310748 -12391.18 1763217 381915 3896.50 -11309.38 48.90 133150 398.73 107135 .05 OSF 150 Pass 18280.00 3582.56 3122.16 -12404.77 17650.01 3819.96 3911.01 -1131194 48.89 1341.84 399.17 1075.40 .05 OSF 1.50 Pass 18280.00 3582.81 3136.83 -12418.38 17667.95 3619.98 3925.52 -11330.48 48.88 134421 399.60 1077.48 .05 OSF 1.50 Pass 18300.00 3583.06 3151.50 -12431.95 17885.88 362011 3940.05 -11341.00 48.87 1348.60 400.03 1079.59 .06 OSF 150 Pass 18320.00 358131 3186.17 -12445.53 1770181 3620.06 3954.58 -11351.49 48.86 1349.03 400.46 1081.72 .06 OSF 1.50 Pass 18327.24 358140 3171.49 -1245145 17710.30 3620.08 3959.85 -11355.29 48.85 1349.91 400.82 1082.50 .06 OSF 150 Pass End of results • Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 19 of 24 Field: Nikeitchuq Well: Tuvaaq ST 1 Structure: Nikaitohuq Exploration Borehole: Tuvaaq ST 1 Slot: Tuvaaq ST 1 Trajectory: Tuvaaq ST 1 Client: ENI Type: Def Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.05867531° Grid Scale Factor: 0.999955561 Magnetic Declination: 24.151° Magnetic Declination Date: February 15,2005 Magnetic Model: BGGM 2009 Reference Point: Mating Luling J;levatlon Structure Unc. Slot Unc. 6050899.000(ftUS) 507330.900(ftUS) 35.030(ft)MSL 0.000(ft)(1 sigma) 0.000(6)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 32.690 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 32.690 2949.020 Act-Stns SLB_MWD+GMAG-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 2949.020 8882.810 Act-Stns SLB_MWD+GMAG""2-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 8862.810 17630.000 Act-Stns SLB_MWD+GMAG^^3-No Global 30.000 Tuvaaq ST 1/Tuvaaq ST 1 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 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 9351.00 ft<=MD<=18327.24 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation r_1320.00 ft 9340.00 3626.61 -2842.17 -5821.57 3811.54 3256 86 -1946.79 -5590.89 9.86 995.81 130.09 908 49 11 62 OSF 1 50 Pass 9360.00 3628.00 -2831.01 -5838.11 3827.19 3264.92 -1940.40 -5602.69 10.22 990.17 130.29 90273 11.54 OSF 1 50 Pass 9380.00 3629.40 -2819.85 -5854.65 3842.99 3272.93 -1933.95 -561468 10.58 984.63 130.49 89704 11.45 OSF 150 Pass 9400.00 3630.79 -2808.70 -5871.20 3858.93 3280.88 -1927.43 -5626.87 10.93 979.17 130.71 891 44 11.37 OSF 1 50 Pass 9420.00 3632.19 -2797.54 -5887.74 3877.65 3290.04 -1919.78 -5641.29 11.34 973.79 131.18 88575 11.27 OSF 1.50 Pass 9440.00 3633.58 -2786.38 -590427 3902.29 3301.91 -1909.86 -5660.47 12.02 968.36 132.02 879.81 11.12 0571.50 Pass 9460.00 3634.90 -2775.11 -5920.74 3927.02 3313.60 -1900.12 -5679.96 12.97 962.72 133.01 873.50 10.97 OSF 1 50 Pass 9480.00 3636.14 -2763.71 -5937.13 3951.80 3325 09 -1890.55 -5699.72 13 91 956.83 134.02 866 95 10.82 OSF 1 50 Pass 9500.00 3637.29 -2752.19 -5953.43 3973.48 333497 -188235 -571718 14.79 950.70 134.75 86033 10.69 OSF 150 Pass 9520.00 3638.36 -2740.54 -5969.65 3991.29 334298 -1875.64 -5731 61 15.59 944.44 135.14 853.81 10.59 OSF 1 50 Pass 9540.00 3639.35 -2728.76 -5985.79 4009.12 3350.92 -1868.94 -5746.10 16.39 938.04 135.52 84716 10.49 OSF 1.50 Pass 9560.00 3640.25 -2716.85 -6001.84 4026 96 3358.77 -1862.25 -5760.66 17.20 931.53 135.91 840.39 10.39 OSF 1 50 Pass 9580.00 3641.06 -2704.83 -6017.79 4044.80 3366.54 -1855.57 -5775.26 18.01 924.90 136.31 833.49 10.28 OSF 1.50 Pass 9600.00 3641 79 -2692.68 -6033.66 4062.65 3374 22 -1848 89 -5789.93 18.83 918.14 136.71 826.46 10 18 OSF 1.50 Pass 9620.00 3642 44 -2680.40 -6049.44 4080.49 3381 82 -1842.24 -5804.62 19.86 911.25 137 11 819 30 10 07 057 1 50 Pass 9640.00 3643 00 -2668.01 -6065.13 4098.30 3389 35 -1835 60 -5819.34 20.49 904.24 137.52 812.03 9.96 OSF 1 50 Pass 9660.00 3643.48 -2655.49 -6080.72 4116.10 3396 80 -1828.97 -5834.09 21.33 897.11 137.93 804.62 9.85 OSF 1.50 Pass 9680.00 364187 -2642.86 -8096.22 4133.88 3404.18 -1822.36 -5848.85 22.17 889.86 138.34 797.09 9.74 OSF 1.50 Pass 9700.00 3644.17 -2630.10 -6111.82 4151.64 3411.49 -1815.77 -5863.64 23.02 882.48 138.75 789.44 9.63 OSF 1.50 Pass 9720.00 3644 40 -2617.23 -6126.93 4168.09 3418 20 -1809.67 -5877.36 23.86 874.99 139.04 781.75 9.53 OSF 1.50 Pass 9740 00 3644 53 -2604.24 -6142.13 4184.10 3424 68 -1803 71 -5890.73 24 69 867.41 139 30 774.01 9 43 OSF 1.50 Pass 9760 00 3644 58 -2591 14 -6157.24 4200.09 3431 11 -1797.73 -5904 09 25.53 859.74 139.55 766.17 9 33 OSF 1 50 Pass 9780.00 3644.55 -2577.92 -6172.25 4216.07 3437 48 -1791.73 -5917.46 26.38 851.99 139.80 758.25 9.23 OSF 1.50 Pass 9800.00 3644.43 -256459 -6187.16 4232.04 3443.81 -1785.72 -5930.83 27.25 844.15 140.05 750.24 9.13 OSF 1.50 Pass 982900 3644.22 -2551.14 -6201.96 4247.99 3450.08 -1779.69 -5944.20 28.12 836.23 140.30 742.16 9.03 OSF 1.50 Pass 9840.00 3643.94 -2537.58 -6216.66 4263.73 3456.23 -1773.71 -5957 40 29.00 828.22 140.53 734.00 8.93 OSF 1.50 Pass 9860.00 3643 56 -2523 92 -6231 26 4279 40 3462 32 -1767.74 -5970.55 29 89 820 14 140 75 725 77 8 82 OSF 1 50 Pass 9880.00 364311 -2510.15 -6245.76 429506 3468.37 -1761 74 -5983.69 3062 81199 14097 717.47 8.72 OSF 150 Pass 9900.00 3642.63 -2496.35 -6260.23 4310 75 3474.39 -1755.71 -5996.85 31 02 803.88 141 19 709.21 8.62 OSF 1.50 Pass 9920.00 3642.16 -2482.55 -6274.70 4326.48 3480.40 -1749.63 -601007 31.42 795.85 141.42 70103 8.52 OSF 1.50 Pass 9940.00 3841.69 -2468.76 -6289.18 4342.27 3486.40 -1743.50 -6023.32 31.83 787.90 14164 692.94 8.42 OSF 1.50 Pass 9960.00 3641.21 -245496 -6303.65 4363.71 3494.54 -1735.20 -6041.34 32.40 779.99 14243 684.50 8.29 OSF 1.50 Pass 9980.00 3640.74 -2441 17 -6318.12 4386 63 3503 32 -1726 47 -6060 63 33 02 772.00 143 35 675.89 8.15 OSF 1.50 Pass 10000.00 3640.27 -2427.37 -6332.59 4409.35 3512 11 -1717 97 -6079 78 33 66 763 93 144.25 667.23 8 02 OSF 1.50 Pass 10020.00 3639.79 -2413.58 -6347.07 4431.88 3520 91 -1709.69 -6098 79 34.32 755.80 145.13 658.50 7.88 OSF 1 50 Pass 10040.00 3639.32 -2399.78 -6361.54 4450.48 3528.21 -1702.95 -6114.51 34.87 747.62 145.61 850.01 7.77 OSF 1.50 Pass 10060.00 3638.85 -2385.99 -6376.01 4466.35 3534.39 -1697.19 -6127.95 3535 739.52 145.81 641.77 7.68 OSF 1.50 Pass 10080.00 3638.37 -2372.19 -6390.48 4482.31 3540 53 -1691.37 -6141 48 35 83 731.50 146.01 633.62 7.58 OSF 1.50 Pass 10100 00 3637.90 -2358.40 -6404.96 4498.34 3546 63 -1685.50 -6155 09 36 32 723.57 146.21 625.56 7.49 OSF 1 50 Pass 10120.00 3637.43 -2344.60 -6419.43 4514.45 3552 70 -1679.58 -6168 79 36.82 715.72 146.41 617 57 7.40 OSF 1 50 Pass 10140.00 3636.95 -2330.80 -6433.90 453064 3558.72 -167360 -6182.58 37.32 707.95 146.61 80967 7.31 OSF 150 Pass 10160.00 3636.48 -2317.01 -6448.38 4547.28 3564 84 -1867 44 -6196 78 37.83 700.27 146.87 601 82 7.21 057 1.50 Pass 10180.00 3636.01 -2303.21 -6462.85 4564.36 3571.07 -1661.10 -6211.36 38.37 692.66 147.17 594.01 7.12 OSF 1 50 Pass 10200.00 3635.53 -2289.42 -6477.32 458148 3577.29 -1654.74 -6225.99 38.91 685.12 14746 586.27 7.03 OSF 1.50 Pass 10220.00 3635.06 -2275.62 -6491.79 4598.64 3583.47 -1648.35 -6240.66 39.47 677.64 14776 57860 6.94 OSF 150 Pass 10240 00 3634.59 -2261.83 -6506.27 4615 83 3589.63 -1641 95 -6255.38 40.03 670.23 148 05 571 00 6.85 OSF 1.50 Pass 10260.00 3634 11 -2248.03 -6520.74 4633 05 3595 76 -1635 53 -6270 14 40.60 602.89 148 33 563 47 6 76 OSF 1.50 Pass 10280.00 3633.64 -2234.24 -6535.21 4649.14 3601.48 -1629.52 -6283.92 41.14 855.64 14845 556.14 6.68 OSF 1.50 Pass 10300.00 363117 -2220.44 -6549.69 4665.22 3607.22 -1623.48 -6297.67 41.69 848.49 148.55 548.92 6.60 OSF 1 50 Pass 10320.00 3632.69 -2206.65 -6564.16 4681.31 3612.98 -1617 41 -6311.42 42.25 641.46 148.65 541.82 6 53 OSF 1.50 Pass 10340.00 3632 22 -2192.85 -6578.63 4697 40 3618 76 -1611 31 -6325 14 42 83 634.53 148 72 534.84 6 45 057 1.50 Pass 10360.00 3631 79 -2179 08 -6593.13 4713.53 3624 58 -1605 17 -6338 87 43 06 627 75 148 80 528.01 6 38 OSF 1 50 Pass 10380.00 3631 49 -2165 38 -6607.70 4729.88 3630 50 -1598.92 -6352 78 43.24 621.18 148 89 521.38 6 31 OSF 1.50 Pass 10400.00 3831 31 -2151 75 -6622.33 4747.25 3636.83 -1592.27 -6367 52 43.48 614.80 149.06 514 89 6 24 OSF 1.50 Pass 10420.00 3631.25 -2138.19 -6637.04 4764.66 3843.22 -1585.61 -638228 43.72 608.60 149.23 508.57 6.17 OSF 1.50 Pass 10440.00 3631.32 -2124.70 -6651.80 4782.10 3649 67 -1578.94 -6397 05 44.00 602.57 149.39 502.44 8.10 OSF 1.50 Pass ■ 10460.00 3631.52 -211128 -6666.62 4799.58 365618 -1572.25 -641183 4429 596.72 149.53 496.50 6.03 OSF 1.50 Pass 10480.00 363185 -2097.92 -6681.50 4817.09 366275 -1565.56 -642662 4458 59104 149.64 49074 5.97 OSF 150 Pass 10500 00 3632.31 -2084.63 -6696 44 4834.90 3669 47 -1558.75 -6441 64 44.90 585.53 149 76 485.15 5 91 OSF 1 50 Pass 10520.00 3632.89 -2071.40 -6711 43 4852.88 3676 29 -1551.89 -6456.80 45.22 580.19 149 89 479.72 5.85 OSF 1 50 Pass 10540.00 3633.61 -2058.25 -6726.48 4870.91 3683.15 -1545.02 -6471.98 45.55 575.00 150.00 474.46 5.80 OSF 1.50 Pass 10560.00 3634.46 -2045.16 -6741.58 4888.98 3690.05 -153815 -6487.20 45.89 569.97 15009 469.38 5.74 OSF 1 50 Pass 10580 00 3635.43 -2032.14 -6756.73 4907 08 3696 99 -1531 26 -650244 46.38 565.10 150 14 464 47 5 69 OSF 1 50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 21 of 24 Trajectory:SI32-W2(P6b)W.Tuvaaq ST 1 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 nr Ct-Ct Distance Separation Clearance OSF Rule Status (5) (5) (n) (n) (ft) (ft) (n) (n) (°) (ft) (5) (0) 10600 00 3636.42 -2019.13 -6771.89 4924.94 3703.86 -152448 -6517.47 47.07 560.33 150.14 459.69 564 OSF 1.50 Pass 10620 00 3637 41 2006 12 -6787.05 4942 30 3710 48 -1517 85 -6532 08 47 74 555 66 150.07 455.08 5.60 OSF 1 50 Pass 10640 00 3638 39 -1993.11 -6802.21 4959 75 3717 03 -1511 13 -6546 79 4841 551 11 149.98 45059 5.56 OSF 1 50 Pass 10660 00 3639.38 -1980 10 -6817.37 4977.29 3723 52 -1504 33 -6561 60 49 08 546.68 149.89 446 21 5.51 OSF 150 Pass 10680 00 3640.37 -1967 09 -6832.52 4994.92 3729 96 -1497.45 -6576 50 49 76 542 35 149.79 441 95 5.47 OSF 1 50 Pass 10700 00 3641 36 -1954 08 -6847.68 5012.65 3736 32 -149047 -6591 50 50 43 538 13 149.68 437 81 5 44 OSF 1 50 Pass 10720 00 3642.35 -194107 -6862.84 5030.54 374269 -148340 -6606.65 51.12 534.01 149.58 433.75 5.40 OSF 1.50 Pass 10740 00 3643.34 -1928.06 -6878.00 5048.44 3749.08 -1476.31 -6621.80 51.81 530.00 149.46 429 82 5.36 OSF 1.50 Pass 10760.00 3644.32 -1915.06 -6893.16 5066.34 3755.47 -1469.21 -6636 94 52.52 526.10 149.31 426.02 5.33 OSF 1.50 Pass 10780.00 3645.31 -1902.05 -6908.32 5084.23 3761.89 -1462.11 -6652.06 5323 522.30 149.12 422.35 5.29 OSF 1.50 Pass 1080000 3646.30 -1889.04 -6923.47 5102.13 376831 -1455.00 -6667.17 53.96 518.61 148.91 418.81 5.27 OSF 1.50 Pass 10820 00 3647.25 -1876.02 -693863 5119.99 377474 -1447.90 -6682.25 5478 51505 14865 415.41 5.24 OSF 1.50 Pass 10840 00 3648.06 -1862.99 -6953.78 5137.80 3781.15 -1440.80 -6697.27 55.64 511 62 148.34 412.19 5.21 OSF 1.50 Pass 10860 00 3648.73 -1849.95 -6968.93 5155.57 3787.55 -1433.71 -671225 5652 50835 14798 409.15 519 OSF 150 Pass 10880 00 3649 27 -1836 90 -6984 08 5173 30 3793.94 -1426.62 -6727 19 57.41 505 23 147 58 406.30 518 OSF 1 50 Pass 10900 00 3649 67 -1823.84 -6999 22 5190.98 3800.32 -1419 53 -6742 09 58.32 502 27 147 12 403.65 5 16 OSF 1 50 Pass 10920 00 3649 92 -1810 76 -7014 35 5208 36 3806.59 -1412 55 -6756 72 59 23 499 49 146 58 401.23 5.15 OSF 1 50 Pass 10940 00 3650 04 .179767 -7029 47 5224 48 3812.42 -1406 04 -6770 26 60.09 496 92 145 85 399.15® OSF 1 50 Pass 10960 00 365002 -1784.58 -7044.59 5240.58 3818.24 -139948 -678376 60.95 49460 145.07 397.35 5.15 OSF 150 Pass 10980 00 3649 86 -1771 48 -7059.70 5256 66 3824.07 -1392 88 -6797 22 61 82 492 53 14424 395.83 5 16 OSF 1 50 Pass 11000 00 3649 59 -1758 37 -7074.80 5272 74 3829.90 -1386 22 -6810 63 62.66 490 71 143 37 394.59 5.18 OSF 1 50 Pass 11020 00 3649 31 -1745 27 -7089.91 5288.83 3835.75 -1379 49 -6824.04 63.48 489 12 142 48 393.59 5.19 OSF 1 50 Pass 11040 00 3649.02 -1732.16 -7105.02 530524 3841.72 -137259 -683767 64.32 487.75 141.60 392.81 5.21 OSF 150 Pass 11060.00 3648 74 -1719.06 -7120.12 5322 97 384816 -1365.09 -6852.39 65.23 486.56 140.86 39211 522 OSF 1 50 Pass 11080.00 364846 -1705.85 -7135.23 5340.72 385460 -1357.57 -686713 6614 48554 14009 39160 524 OSF 150 Pass 11100.00 3648.18 -1692.85 -7150.33 535850 386103 -1350.02 -6881.87 6705 484.67 13929 391.28 526 OSF 1.50 Pass 11120.00 364790 -1679.74 -716544 537629 386746 -134244 -689663 67 97 483.98 138481 391121 529 OSF 1 50 Pass 11140.00 364761 -166664 -718054 539410 3873.88 -1334.84 -6911.41 6888 48344 137.64 391.14 5.31 OSF 1 50 Pass 11160.00 3647.33 -1653.53 -7195.65 5411 79 388023 -1327.27 -6926 08 6979 483 07 136.78 391 35 5.34 OSF 1 50 Pass 11180.00 364705 -1640.43 -7210.76 5429 50 3886 55 -131964 -6940 75 7069 482.87 135 91 391 73 5.38 OSF 1 50 Pass 11200 00 3646.77 -1627.32 -7225.86 544727 3892 84 -1311.94 -6955.48 71 581 482.831 13502 392 28 5.41 OSF 1 50 Pass 11220.00 364649 -1614.22 -7240.97 546510 389911 -130415 -6970.25 7248 482.96 13415 392.98 5.45 OSF 150 Pass 11240.00 3646 20 -1601.12 -7256.07 5482 99 3905 35 -1296 29 -6985 07 73 37 483.24 133.28 39384 549 OSF 1 50 Pass 11260.00 3645 92 -1588.01 -7271.18 5503 14 3912 31 -1287 40 -7001.75 74 36 48365 13264 38468 5.52 OSF 1 50 Pass 11280 00 364564 -157491 -7286.28 5525 95 3920 04 -127741 -702074 7547 484.06 13227 395 34 5.54 OSF 150 Pass 11300 00 3645 36 -1561.80 -7301.39 5548 82 3927.63 -1267.49 -703989 76.58 48443 131.87 39598 5.56 OSF 150 Pass 11320.00 3645.08 -1548.70 -7316.49 5571 73 3935.08 -125765 -705921 7768 484.77 131 46 396 59 5.58 OSF 150 Pass 11340.00 3644.79 -1535.59 -733160 5593.26 3941.92 -1248.50 -7077.45 78.71 485.07 130.88 397.28 5.61 OSF 150 Pass 11360.00 364451 -152249 -7346.71 5610.89 394753 -1241.05 -709241 79.56 48549 129.88 398.36 5.66 OSF 1.50 Pass 11380.00 364423 -1509.38 -7361.81 562846 395319 -1233.65 -7107.31 8041 486.06 12885 399.62 5.71 OSF 150 Pass 11400.00 3643.95 -1496.28 -7376.92 5645 97 3958.88 -1226.31 -7122.15 81.26 486.80 12779 401.06 5.77 OSF 1.50 Pass 11420.00 364367 -1483.17 -7392.02 5863 43 3964.62 -1219.02 -7136 94 8211 487.70 126.73 402.68 5.83 OSF 1 50 Pass 11440.00 3643.38 -1470.07 -740713 5680 82 3970 39 -1211.79 -715167 8296 488 77 12564 40448 5.89 OSF 1 50 Pass 11460 00 364310 -1456.96 -7422.23 5698 85 3976 43 -1204.33 -7166.93 8385 490.01 12458 406 41 5.96 OSF 1.50 Pass 11480 00 3642.82 -1443.84 -7437 33 5716 97 398254 -1196.88 -7182 28 8495 491.37 12351 40849 6.03 OSF 1.50 Pass 11500 00 3642.52 -143068 -7452.38 5735 01 398866 -1189.52 -7197.5] 85 85 492.85 122.41 41071 610 OSF 1.50 Pass 11520 00 3642.23 -1417 52 -7467.44 5753 00 3994 81 -1182 23 -7212.82 86 75 494 48 121.33 41306 618 OSF 1 50 Pass 11540.00 3641 93 -1404.36 -7482.50 5770 91 4000.97 -1175 01 -722802 8765 496 26 12024 41556 6.25 OSF 1 50 Pass 11560.00 364163 -1391.20 -7497 56 5789 53 400742 -1167 58 -724382 8858 49818 11919 41819 6 34 OSF 1 50 Pass 11580.00 3641 34 -1378.04 -751262 5808 85 401413 -1159.97 -7260.26 8955 500 21 118.17 42089 642 OSF 150 Pass ' 11600.00 3641.04 -1364.88 -7527.68 5828 07 4020.83 -1152.51 -727665 9053 502.34 117.14 42371 6.50 OSF 150 Pass 11620.00 3640.75 -1351 73 -7542.73 584719 402751 -1145.20 -7293.01 91.50 504 58 116 12 426.63 6.59 OSF 1 50 Pass 11640.00 364045 -1338.57 -7557.79 5866.22 4034.19 -1138.03 -730932 9247 506.93 115.08 429.67 6.68 OSF 1.50 Pass 11660.00 364016 -1325.41 -7572.85 5883 85 404040 -113148 -732446 93.37 50941 11398 43288 6.78 OSF 1.50 Pass 11680.00 3639.86 -1312.25 -7587.91 590055 4046.31 -1125.28 -7338.80 94.22 512.07 112.87 436.28 6.88 057150 Pass 11700 00 363957 -1299.09 -7602.97 5917 22 405225 -1119.09 -735310 9507 514.91 111.80 43984 6.99 OSF 1.50 Pass 11720.00 363927 -1285.93 -7618.02 5933.87 405822 -1112.92 -7367.37 9590 51795 11077 443.57 710 OSF 150 Pass 11740.00 363898 -1272.77 -7633.08 595049 406421 -1106.76 -7381 59 96 73 521 18 10979 44745 7.20 OSF 1 50 Pass 11760 00 363868 -125961 -764814 596708 4070 22 -110062 -7395 78 9756 524 58 10885 451 48 732 OSF 1 50 Pass 11780.00 3638 39 -1246.45 -7663.20 5984 14 4076 43 -1094.30 -7410 36 98 39 52816 107.97 455 65 7.43 OSF 1 50 Pass 11800 00 3638 09 -1233.29 -7678.26 6001 30 408269 -1087 94 -7425 02 9923 531 91 107.14 459 94 754 OSF 1 50 Pass 11820.00 3637.80 -122013 -7693.32 6018 46 4088 97 -1081 59 -7439.67 10005 535.80 106.37 464 35 765 OSF 1 50 Pass 1184000 363750 -1206.97 -7708.37 603561 409525 -1075.23 -7454.31 10087 539.85 10565 46888 7.76 OSF 150 Pass 11860 00 363721 -1193.82 -7723.43 6052 75 4101 55 -1068.88 -7468.93 101.67 544 05 10498 47353 7.87 OSF 1 50 Pass 11880.00 3636.91 -118066 -773849 6069.73 4107.80 -1062 59 -748341 10246 54840 104.37 47829 798 OSF 150 Pass 11900.00 3636.61 1167.51 -775356 6086.26 4113 92 -1056.49 -749750 10307 552.92 10379 483.19 8.09 OSF 1 50 Pass 11920.00 3636.24 -115444 -7768.69 6102 73 4120.07 -105045 -7511.54 10352 557.70 10324 488.34 821 OSF 1 50 Pass 11940.00 363580 -114146 -7783.90 611914 412623 -104446 -7525.52 103.97 56275 10275 493.71 8.32 OSF 150 Pass 11960.00 363529 -1128.57 -779919 6135 50 413242 -1038.53 -753945 104.40 568.07 10232 499.32 844 OSF 1 50 Pass 11980.00 3634.71 -1115.78 -7814.55 615179 413862 -103266 -7553.33 104.82 57365 101.95 50515 8.55 OSF 150 Pass 12000.00 363405 -1103.08 -7829.99 6168 33 4144 96 -1026.74 -7567 40 10524 57949 101.63 511 20 867 OSF 1 50 Pass 12020.00 3633.32 -109048 -784550 6185 28 4151 47 -102064 -7581.82 10565 585.56 101.38 51743 8.78 05F 1 50 Pass 12040.00 363254 -1077.97 -7861 09 6202 25 4157 99 -1014 52 -7596.24 106.05 591 84 101.18 52384 8 89 OSF 1 50 Pass 12060.00 3631 68 -1065.56 -7876.75 6219 23 4164 52 -1008 36 -761066 106.43 598 32 101.03 530 43 9.00 OSF 1 50 Pass 12080.00 363077 -1053.26 -7892.49 6236 24 4171 06 -100217 -7625 08 106.80 605.01 100.93 537 18 911 OSF 1 50 Pass 12100.00 362979 -1041 05 -7908 30 6253 25 417762 -995 95 -7639 50 107 15 611 88 10087 544 10 9.22 OSF 1 50 Pass 12120.00 362875 -1028.94 -792419 6269 87 4184 03 -989.85 .7653 56 107 46 618 95 100.86 551 17 9.33 OSF 1 50 Pass 12140.00 362765 -1016.94 .794015 6286 37 4190.42 -983.80 -7667 52 107 76 626 21 10088 558.41 944 OSF 1 50 Pass 12160.00 3626 49 -1005 04 -7956 18 6302 85 4196 83 -977.75 -7681 45 108.05 63365 100.94 565.82 954 OSF 1 50 Pass 12180.00 362529 -99318 -797224 631931 420325 -971.71 -7695.35 108.58 64122 10105 573.32 965 OSF 150 Pass 12200.00 362410 -981 32 -7988.30 6335 75 420968 -965.67 -7709.22 109.11 64888 101.19 580.88 9.75 OSF 1 50 Pass 12220.00 3622.90 -96947 -8004.36 635216 421613 -959.65 -7723.05 10962 656.62 101.37 588.50 9.85 OSF 1.50 Pass 12240.00 3621 71 -95761 -802043 6368.36 422251 -953.86 -773669 110 11 664 45 101.58 59619 9.95 OSF 1.50 Pass 12260.00 362051 -945 76 -8036.49 638458 422892 -94761 -7750 31 110.59 672 36 101.82 603.94 10.04 OSF 1 50 Pass 12280.00 3619 32 -933 90 -805255 640082 4235.35 -941 50 -7763 90 111 05 680 35 102 07 611.76 1013 OSF 1 50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 22 of 24 J Trajectory:5132-W2(Mb)Vs.Tuvaaq ST 1 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 Ct-Ct Distance Separa ion Clearance OSF Rule Status (ft) (ft) (5) (0) (ft) • (8) (ft) (8) (°) (5) (ff) (ft) 12300.00 3618.13 -922.05 -8068.61 6417.07 4241.80 -935.32 -777748 111.50 688.41 02.34 619.64 1023 OSF1.50 Pass 12320 00 3616 93 -910 19 -8084.68 6433.33 4248 28 -929 08 -7791 03 111.93 696.55 02.63 627.60 10.32 OSF 1 50 Pass 12340 00 3615 74 -898 33 -8100 74 6449.35 425467 -922 89 -7804 35 112.34 704.76 02.93 635 60 10.41 OSF 1 50 Pass 12360 00 3614 54 -886.48 -8116 80 6464.38 4260 72 -917 11 -7816 84 112.73 713.06 03.29 64367 10.50 OSF 1 50 Pass 12380 00 3613.35 -874 62 -8132.87 6479.31 4266.78 -911.47 -7829.26 113.11 721.46 0366 651.82 10.58 OSF 1.50 Pass 12400 00 3612 15 -862 77 -8148.93 6494.13 4272.85 -905.95 -7841 60 11349 729.96 0483 660 06 10.67 OSF 1.50 Pass 12420 00 3610 97 -850 93 -8165 00 6508.85 4278 94 -900 56 -7853 87 113.77 738.54 0441 668 40 10.75 OSF 1.50 Pass 12440 00 3609 87 -839 17 -8181 14 6523.51 4285 06 -895 27 -7866 10 113.97 747.18 04.78 676 79 10.84 OSF 1 50 Pass 12460 00 3608 85 -827 49 -8197.35 6538.13 4291 21 -890 09 -7878 30 114.17 755.86 05.17 685 21 10.93 OSF 1 50 Pass 12480.00 3607 91 -815.91 -8213.63 6556.80 4299 10 -883 50 -7893.90 114.45 764.55 0546 693.70 11.02 OSF 1.50 Pass 12500.00 3607.06 -804.42 -8229.98 6576.53 4307.37 -876.44 -7910.35 11472 773.16 0573 702.14 11.12 OSF 1.50 Pass 12520.00 3606.28 -793.02 .8246 39 6596.44 431565 -86920 -7926.95 11496 78169 05.96 710.52 11.21 OSF 1.50 Pass 12540.00 3605 59 -781 71 -8262 87 6616.53 4323 94 -861 79 -7943E8 115.18 790.14 06.17 718 82 11.31 OSF 150 Pass 12560.00 3604 99 -770.49 -827941 6636.86 4332 27 -85417 -7960.59 115.37 798.50 06.39 727 04 11.41 OSF 1.50 Pass 12580.00 3804 46 -759 36 -8296.02 666071 4341 92 -845 20 -7980.47 115.59 806.72 06.51 73517 11.51 OSF 150 Pass 1260080 3604.01 -748 32 -8312.70 6684 76 4351.49 -836.20 -800061 115.79 814.76 06.63 743.14 11.61 OSF 1.50 Pass 12620.00 360365 -737.38 -8329.44 670981 4360.97 -827.19 -8021.03 115.98 822.63 06.76 750.92 11.71 OSF 1.50 Pass 12640.00 3803 35 -726 51 -8346 22 6732 78 4370 11 -818.40 -8041.14 116.29 830.33 06.93 758.50 11 80 OSF 1.50 Pass 12660.00 3603 04 -715 64 .8363.01 6747 86 4375 89 -81283 -8053.91 116 51 838.02 07.33 765 93 11.87 OSF 1.50 Pass 12680.00 3602.74 -704 77 .8379.79 6762.90 4381 70 -807.26 -8065.62 116.72 845.79 07.73 773.43 11.93 OSF 1.50 Pass 1270080 3602.44 -693 90 -8396 58 677791 4387 55 -801.69 -8079.27 116.93 85364 08.13 781.01 12.00 OSF 1 50 Pass 1272080 3602.13 -683.03 -8413.36 670288 439343 -796.11 -8091.85 117.13 861.57 08.58 788.65 12.06 OSF 1.50 Pass 12740.00 3601 83 -672 16 -8430.15 680781 4399.34 -790 52 -8104.37 117.32 869.58 0983 796 36 12.12 OSF 1 50 Pass 12760.00 3601 53 -661.29 -8446 93 6822.71 4405 29 -78494 -8116.83 117.51 877.66 0947 80414 12.18 OSF 1.50 Pass 12780.00 3601 22 -650 42 -8463 72 6845.66 4414 46 -776 29 -8136.02 117.80 885.76 0972 81208 12.27 OSF 1.50 Pass 1280080 3600.92 -639 55 -848050 6872 52 4424 97 -766.07 -8158.53 118.12 893.71 0987 819.93 12.36 OSF 1.50 Pass 1282080 360062 -628.68 -8497.29 689984 4435 33 -755.66 -8181.33 118.44 901.49 1081 827.61 1245 OSF 1 50 Pass 12840.00 360032 -617 81 -8514.07 692506 4444.81 -74582 -8202 75 11872 909.11 1020 83510 12.54 OSF 1.50 Pass 12860.00 360001 -606 94 -853086 694095 4450 71 -73967 -821617 11889 916.69 1083 842.41 12.59 OSF 1.50 Pass 12880.00 3599 71 -596 07 -854765 6956.80 445663 -73357 -8229 54 11986 92434 11.05 849.77 1265 OSF 1.50 Pass 12900.00 3599 41 -585 20 -856443 697260 4462 57 -72753 -8242.88 11924 932.04 11 48 85719 12.70 OSF 1.50 Pass 12920.00 3599.10 -574 33 -8581.22 698835 446853 -721.54 -825617 11941 939.80 11.91 86486 12.76 OSF 150 Pass 12940 00 3598.80 -563.46 -859880 700406 447452 -715.60 -8269.43 119.58 94762 12.34 872.19 12.82 OSF 1.50 Pass 1296000 3598.50 -552.57 -8614.78 7019.71 448052 -709 72 -828264 11987 955.49 1277 879.77 12.87 OSF 1.50 Pass 12980 00 3598.22 -541 59 -8631 49 703524 4486 50 -70389 -8295 72 12027 963.40 13.19 88740 12.93 OSF 1.50 Pass 13000 00 3597 96 -530.49 -864812 7050 72 4492 51 -698 07 -8308 75 12068 971.33 1382 89505 12.99 OSF 150 Pass 13020 00 3597 72 -519.27 -866468 706616 4498 55 -692 25 -8321 72 121.09 979.30 1483 902 75 13.05 OSF 1.50 Pass 13040.00 359750 -50794 -8681.16 7081.57 450460 -686.43 -833463 121.50 987.31 1445 910.47 13.10 OSF 1.50 Pass 13060.00 3597.30 -496.50 -8697.56 7096.93 451068 -680.62 -834749 121.91 995.34 1487 91812 1316 OSP 1.50 Pass 13080.00 3597.12 -484.94 -871388 7112.25 4516.78 -674.81 -836029 122.33 100342 15.31 926 01 1322 OSF 1 50 Pass 13100 00 3596 96 -473.28 -873013 7138 01 4526.98 -665.02 .838181 122.88 1011.44 1553 93389 13.30 OSF 1 50 Pass 13120.00 3596.82 -461.49 -8746 29 7165 38 453760 -65460 -840479 123.45 1019.30 15.72 941 61 13.38 OSF 1 50 Pass 13140.00 3596.69 -44960 -8762.37 7192 93 454804 -64410 -8428.02 12404 102688 15.93 94916 1345 OSF 1 50 Pass 13160.00 3596.58 -43766 -877841 721540 4556.42 -635.51 -844708 124.33 1034.51 1628 956.46 1351 OSF 1.50 Pass 13180.00 3596 46 -425 71 -879445 7230.89 456216 -629.63 -846014 124.53 104288 16.78 963.68 1355 OSF 1.50 Pass 13200 00 3596 34 -413 77 -881049 724628 456793 -623.79 -847317 124 72 1049.70 1729 97097 1359 OSF 1.50 Pass 13220 00 3596 22 -401 82 -8826.53 7261.64 4573.71 -617.98 -8486 16 124 91 1057.38 17 82 978 30 1363 OSF 1.50 Pass 13240.00 3596 11 -389 88 -8842.57 7276.96 4579.52 -612.20 -849910 125.11 1065.13 18.36 98568 1366 OSF 1.50 Pass 13260.00 3595.99 -377.94 -885862 729224 458535 -606.45 -8512.01 12529 1072.93 1889 99313 13.70 OSP 1.50 Pass 13280.00 3595.87 -36599 -887466 7308.75 459168 -80026 -852594 125.50 108019 1941. 100085 13.74 OSF 1.50 Pass 13300 00 359575 -354 05 -8890.70 733001 459981 -59225 -854388 125.75 108865 1982 1008.23 13.79 OSF 1 50 Pass 13320 00 3595.64 -342 10 -8906 74 7351.36 460792 -584.14 -8561 88 126.00 1096.46 2023. 1015 77 1385 OSF 1.50 Pass 13340 00 3595 52 -330 16 -8922 78 7372 79 4616 00 -575 92 -857994 126 24 1104.23 2063 1023.26 1390 OSF 1 50 Pass 13360.00 3595.40 -318.22 -893882 7394.30 4624 06 -567.60 -8598 07 126.48 1111 95 2103 1030 72 1395 OSF 1.50 Pass 1338080 3595.29 -306 27 -895486 741589 4632.09 -55918 -861626 126.71 1119.83 21.43 1038.14 1400 OSF 1.50 Pass 1340000 359517 -294 33 -8970.90 7436.50 4639 70 -551 07 -863361 126.92 1127.27 21.84 1045.50 1404 OSF 1.50 Pass 1342000 359505 -282 38 -8986 95 745072 464-497 -54547 -864557 127.06 1134.93 22.39 1052 80 14.08 OSF 1.50 Pass 13440 00 3594 93 -270 44 .900299 746489 4650 26 -53990 -865748 127.20 114267 2283 1060.18 1411 OSF 1.50 Pass 13480.00 3594 82 -258 50 -901903 7479.03 4655 59 -534 35 -8669 34 127.34 115048 2348 106763 1414 OSF 1.50 Pass 13480.00 359470 -246.55 -903507 749312 4660.94 -52883 -868115 127.48 1158.37 2482 107515 1418 OSF 1.50 Pass 13500.00 3594.58 -23461 -9051.11 750717 4666.33 -523.33 -869291 12762 1166.32 2456 1082.74 14.21 OSF 1.50 Pass 13520.00 359446 -222.66 -9067.15 7521 18 4671 74 -517 87 -870462 127.75 1174.35 25.10 109041 14.24 OSF 1.50 Pass 13540.00 3594 35 -210 72 -908319 753720 4677 97 -511 64 -871800 127.90 1182.44 2561 109817 14.29 OSF 1 50 Pass 13560 00 3594.23 -198 77 -9099.23 7556 29 4685 39 -504.24 -873395 128.08 1190.54 26 05 110597 14.33 OSF 150 Pass 13580.00 359415 -186.82 -9115 27 7575.39 4692.80 -496.89 -874995 128.30 1198.59 2646 1113.75 1438 OSF 1.50 Pass 13600.00 359421 -174.85 -9131.29 759453 470020 -489.56 -876601 128.51 1206.52 26.84 1121.42 1443 OSF 1.50 Pass 13620.00 359440 -162.86 -9147.30 7613 72 4707.59 -482.26 -878214 128.72 1214.31 27.22 112896 1448 OSF 1.50 Pass 13640.00 3594 73 -150 86 -9163.29 7633 23 4715.09 -474.87 -879887 128.94 1221.97 2761 1136.36 14.53 OSF 1.50 Pass 13660.00 3595.20 -138.85 -9179.28 7653.11 472271 -467.28 -881528 12915 1229.49 27 99 114362 1457 OSF 1 50 Pass 13680.00 359581 -126.82 -9195 24 7673 08 4730.35 -45960 -883206 129.36 1236.86 28.37 115074 1462 OSP 1 50 Pass 13700.00 3596 56 -114.78 -9211.20 769315 473801 -451.81 -8848.89 129.56 124489 28.75 1157.72 1466 OSP 1.50 Pass 13720.00 359742 -102.73 -922713 7713.31 474569 -443.92 -8865.78 129.75 1251.19 2915 116456 14.70 OSP 1.50 Pass 13740.00 3598 31 -9068 -9243.07 773302 4753 17 -43617 -888229 129.92 125826 29.57 1171.34 14.73 05E1.50 Pass 13760 00 359920 -7862 -925901 775246 4760 53 -42859 -889861 130.09 1265.33 3081 117811 1476 OSF 1 50 Pass 13780.00 360008 -66 57 -9274.94 7771.88 4767 85 -421 08 -8914 96 13026 1272.38 3045 1184.87 1479 OSF 1 50 Pass 13800.00 3600 97 -54 52 -929088 7791.29 477515 -41366 -8931 33 13043 1279.43 3081 119162 1482 OSF 1.50 Pass 13820.00 3601.86 -4247 -9306.81 781067 478241 -406.31 -8947 74 13060 1286.48 31.41 1198.33 1485 OSF 1.50 Pass 13840.00 3602.74 -3041 -9322.75 7827.86 4788 84 -39985 -896231 130.76 1293.53 31.95 1205.02 1487 OSF 1.50 Pass 13860 00 3603.83 -18 36 -9338.69 7844.30 4795 01 -393 70 -897626 13091 1300.62 3251 1211 74 1489 OSF 1.50 Pass 13880 00 3604 52 -6 31 -935462 786072 4801 18 -38758 -899019 131.06 1307.74 3306 1218.50 14.90 OSF 1.50 Pass 13900 00 360540 5 74 -937056 7877 11 4807 37 -381 50 -900409 131.20 1314.91 3382 122529 14.92 OSF 1 50 Pass 13920.00 3808.29 17.79 -9386.50 7893.47 4813.58 -375.47 -9017.98 131.35 1322.10 34.18 1232.11 14.94 OSF 1.50 Pass 13940.00 3807.18 29.85 -9402.43 7909.81 4819.78 -389.47 -9031.85 131.50 1329.34 34.74 1238.98 14.96 OSF 1.50 Pass 13980.00 3808.06 41.90 -9418.37 7929.24 4827.14 -382.35 -9048.36 131.87 1338.59 35.28 1245.88 14.98 OSF 1.50 Pass 13980.00 3808.95 53.95 -9434.30 7948.81 4834.58 -355.19 -9085.00 131.84 1343.84 35.78 1252.78 15.01 OSF 1.50 Pass Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 23 of 24 Trajectory:S132-W2(P6b)Vs.Tuvaaq ST 1 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) (0) (ft) (ff) (ft) (ff) (ft) (`) (IQ (If) (ff) _ 14000.00 3609.78 68.01 -9450.24 7988.37 4841.95 -348.05 -9081.84 132.06 1351.13 136.30 1259.72 15.03 OSF 1.50 Pass 14020.00 3810.46 78.00 -9466.16 7987.88 4849.30 -340.83 -9098.25 132.27 1358.54 136.83 1266.79 15.05 OSF 1.50 Pass 14040.00 3611.01 90.19 -8482.08 8007.25 4856.58 -333.87 -9114.78 132.49 1366.08 137.35 1273.97 15.08 OSF 1.50 Pass 14060.00 3611.43 102.30 -9497.99 8026.09 4863.64 -327.02 -9130.81 132.70 1373.74 137.89 1281.28 15.10 OSF 1.50 Pass 14080.00 3611.70 114.43 -9513.89 8044.87 4870.68 -320.18 -9146.83 132.91 1381.53 138.43 1288.71 15.13 OSF 1.50 Pass 14100.00 3611.83 126.58 -9529.78 8063.60 4877.68 -313.38 -9162.81 133.12 1389.45 138.96 1286.27 15.16 OSF 1.50 Pass 14120.00 3811.83 138.74 -9545.65 8082.29 4884.66 -306.55 -9178.75 133.32 1397.50 139.50 1303.96 15.19 OSF 1.50 Pass 14140.00 3611.71 150.91 -9561.52 8100.93 4891.82 -299.77 -9194.85 13150 1405.66 140.03 1311.77 15.22 OSF 1.50 Pass 14180.00 3611.56 163.08 -9577.39 8118.22 4897.34 -294.18 -9207.69 133.83 1413.85 140.59 1319.58 15.24 OSF 1.50 Pass 14180.00 3611.42 175.25 -9593.26 8131.42 4903.06 -288.59 -9220.61 133.75 1422.09 141.15 1327.45 15.27 OSF 1.50 Pass 14200.00 3611.28 187.43 -9609.13 8146.61 4908.81 -282,95 -9233.50 133.87 1430.37 141.70 1335.36 15.30 OSF 1.50 Pass 14220.00 3611.14 199.60 -9625.00 8161.80 4914.81 -277.28 -9248.34 133.99 1438.68 142.25 1343.31 15.33 OSF 1.50 Pass 14240,00 3611.00 211.77 -9640,87 8176.99 4920.43 -271.57 -9259.15 134.10 1447.04 142.79 1351.31 15,36 OSF 1.50 Pass 14280.00 3610.88 223.94 -9656.74 8192.16 4828.29 -265.82 -8271.91 134.21 1455.44 143.32 1359.36 15.39 OSF 1.50 Pass 14280.00 3610.72 238.12 -9672.60 8207.72 4832.33 -259.88 -8284.96 134.31 1483.88 143.84 1387.45 15.42 OSF 1.50 Pass 14300.00 3610.57 248.29 -9688.47 8223.41 4938.46 -253.82 -8298.07 134.42 1472.35 144.34 1375.58 15.46 OSF 1.50 Pass 14320.00 3610.43 260.46 -9704.34 8239.10 4944.63 -247.71 -9311.14 134.52 1480.85 144.84 1383.75 15.49 OSF 1.50 Pass 14340.00 3610.29 272.63 -9720.21 8254.79 4950.84 -241.52 -9324.16 134.81 1489.39 145.33 1391.96 15.53 OSF 1.50 Pass 14380.00 3610.15 284.81 -9738.08 8270.48 4957.08 -235.28 -9337.13 134.70 1497.95 145.81 1400.21 15.57 OSF 1.50 Pass End of results Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SI32-W2\SI32-W2\SI32-W2(P6b) 12/11/2012 8:05 AM Page 24 of 24 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. En' E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = P x 10 + 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 E111 E&P Division REVISION STAP-P-1-M-6140 0 1 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. S P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 11 I I 1 l 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. S P E O IDENTIFICATION CODE PAG 209 OF 338 ENI S.p.A. Enn E&P Division REVISION STAP-P-1-M-6140 0 1 I I fillit LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE: I CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 MudT}pe: FWGELS Rig twe: J.UPs Hole Clameter(in): 121/4 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Vscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter On): 13'7/8 P.V.(cps): 19 Pumps: 12.P-160 Grade: J.55 Y.P.(lb/1001P): 5 Liners On): 6.5' Weight Obit): 61 Gelstb/100 t°): 2/8 Flow Fate(bp!): 0.25 Max.Burst pres(psi): 3103 W.L(cc.60 min): 10.5 Litholog y Shale Expected EMW t68 Kg/cm2/1 0 m Time Vol une Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (Psi) (min) fbbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 100 300 10.5 2 463 5 125 400 11 2 465 8 150 500 11.5 2 450 7 1.75 570 12 2 445 8 200 600 13 2 440 8 2D0 550 14 2 437 8.5 200 505 15 2 435 — Nde: Pumped with a constant tow rate of(bbl): \,blume pumped(bbl): bblume reamed(bbl): (psi) 1000 . 900 - - . _ ._. 800 stop pump r 700 • ` e 600 - S • / (shut in curve 500 ---•—•_.S - •—•—•--• • • • • U 400 r 18 minutes e 300 - 200 . 100 • 0 . . - . . - . • . • . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbfj 4 ♦ Time mins 1 RESULTS: (Press.,,,,,+Press.,-o.)x10,D epth=[(1.3 x 797110)+(430 x 0.07)]x10/797=1.68(Kg/cm2/10 m) Note: Company Representative 0 Figure 15-1 - Leak-Off Test Report t, 122222. p t,p d 9 d ti fo t h •R d p A 3 9l p 1444444444 w4$144.4.4ggg r--. #i ti R k k h k 11 t1's t1$1 k k h B it tf 1'W/'1' I N r,nr..�4;4� 0 0 • 4""Ei===i.,sgglUt.;I gW-iia€,.3s F's' pp;p�;yp;ggpp�;;p;•BBH9P b ;` 6 I R ~ I sas sa � t79� 8�� �� 9 R����� t N -� s yppyppp E 5, � u, 1 1 r� j g 8= F F g F oac7' U U .. 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Wu' w W ix i -15 A,5 C h.A1.53, :e4 ,V, 3i i. 3i S2 ce 1 ri 4N TI4N I 1 - TUN . . 1124K 1 F . a_bsrb•c pc0,-P AD It/1.6 I 3 7 .-- 0 ---* ct.„-L- k, , _. Is I .e 9 , IC, 'pi \ 1 - 7 . ,., t 6. ' I lik ) NN ■ •''''1, .,,,, .11 . 1.5 1, ,,,! 7 ill .."N• . 0,,,,. Ds-30 D I ......„.,...:II r) k—i 1, •-____, , Ill -3 .. it.. .., to... tlp,,,,ob, it Cr i 21 0 , MirS 11 $ C ‘tici DS-3M S a vo i . s-L3N , ,-, -,,,,, ' . Ci0 --'' r , r "en sv,II •21/1P' IF - DRAWING NOTES: 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 SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH. RANGE 9 EAST. UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L, DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCEC IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 OR COORDINATE VALUES IN NAD27, voisimmulkikli, 4fr.4tSV.-.......... 4Pc-) .- '-‘,.• # a i ' . SURVEYOR'S CERTIFICATE 4 ail ,..7 * : 49th I\ . *0 r HERESY CERTIFY THAT I AM PROPERLY REGISTERED AND • T— '1 • el, LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 01.1-.-.:-1sid-ace:— .'.L.A7roat ....; ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY f.?`: FRANCIS J. CORNING I E i DONE BY ME OR UNDER MY DIRECT SUPERVISION AND #, _„:. Y. u....".. LS-106,95 i THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 01. 2070 # 47.6\ 10/4-itatfe. Jr # T.- '... ..•........ . 0 410. 411 -u, q,S.SONP,0",ls 4. "Illikillnal0126. 13* ell'' lee' 01 I SPY ISLAND DRILL SITE - WELL CONDUCTORS AS—BUILT LOCATIONS • _ . , @IN 11 •IN"pi CAD FICE:E1413543DB US operafing DATE DRAWING NO. PART: REV: io/rx/20'c Eni-3543—d9 1 OF 3 0 REV DATE BY GK APP DCSCRIP'DON -REV- DATE BY CK APP DESCRIPTION 0 10/0'/3C DHS CC CC iri is i)'cw • t 1V 1 r' a Q �v i , t7 S \'' , Sec W — -. -.7:1 CJ W 0000 � 0) o. VA N (CI ,,, (n to Tel LA wlt(% f y)`?N•X�` cP 0' 00 ' O G9 DETAIL A. SCALE: 1„.ao' sAsrvx lc' 0044. „oapER 1 S fib' ti +� v.�;Yew° ti •�•°_ •i 1 g�NV?o0N LT. Y r)'r x rYa DETA'L A c -a SPY ISLAND DRILL SITE (SID) i 1 CAIN L 5�atytq<' I \ c--------------____.---- 1 1 SCALE LEGEND L 201111111111L_f�_____ �o�o 0 = WELL CONDUCTOR AS—BUILT THIS SURVEY 1'' = 200' I Vil* ���ar&arc SPY ISLAND DRILL SITE �� WELL CONDUCTORS • . �` AS—BUILT LOCATIONS•2n n (@ 'to n'� CAD FILE.EN 354309 us ®peratong DAT;:c/o,fza10 DRA41NC NO Eni-3543—d9 IPA2 of 3 1 REVo: REV' DAIL BY l CK APP ___DC'SCAIPMN REV DATE 1 BY ' CK APP DESCRIPTION_. .. 0 111/C P: D. S CC CC .. c Drc MV.n j Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. A '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 6053421.65 1651761.87 70°33'27.194" 149'54'25.000" 798 1179 12.4 3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 12,4 4 6053418.56 1651746.17 70'33'27.164" 149'54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70°33'27.149" 149°54'25.692" 803 1202 12,4 6 6053415.54 1651730.54 70°33'27.134" 149°54'25.925" 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°33'27.089" 149°54'26.622" 809 1234 12.4 .y 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 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 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°33'26.823" 149°54'30.773" 836 1374 12.4 24 6053382.12 1651558.61 70°33'26.808" 149°54'31.003" 837 1382 12.4 25 6053377.65 1651535.94 70°33'26.764" 149°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 28 6053373.11 1651512.46 70°33126.7201' 149°54'32.366" , 846 1428 12.4 29 6053371.56 1651304.49 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°33'26.601" 149°54'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149'54'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70°33'26.555" 149°54'34.941" 1, 863 1516 12.4 38 6053354.74 1651417.32 70°33'26.541" 149°54'35.177" 864 1524 12.4 liesios Osi.,- SPY ISLAND DRILL SITE WELL CONDUCTORS '�4� ,l ' AS-BUILT LOCATIONS c i 1111 • �sr w am CAD riLE:Eh135a3C9 U opera i>frig oATI'o�olL2oto DRAWING NO: En1-3543-d9 'PART: 3 IRE: • rao- NO -- 0 % = 0 > 0 0 = °J • -o > a a a a a a a a a a a a a a a v a a a a c a a a v v a a •n y u co 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 Q Z D 0 W ei N N N ei N N N rl el ei N N ei H N ei N ei rr N N + N ei Ca i z. w 7 .0 C v J + ei 01 t0 a N 0 t0 Cr ei 01 N 01 CO t0 4, ei 01 N m ei CO lD a N in m ei 00 C N n CO M O r! N M a a u1 l0 CO M eI eI N aa M M LO N 00 O ei N N 7 ... 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M M M M M M M M m M M M M m M M M m M M M M M M M M M M 3 O O O O O O O O O O O O O O O O O O O O O O O O O O O O N N N N N N N N N N N N N N N N N N N N N N N N N N N N ti L N a p p LLI 13 C:Q Fc o o Om m t0 n N (0 en In 0 tC0 0 .m-I pm a 000 n ..-I N v IMn NN0 oNO in M N Cl) Z U N N N N NN (M0 t(0 (00 (0 l0 b � I0 t(0 l0 in in in IMn INn M Ian Imn i1 i1 .7 a a V/ n X WO N J 4444444444444444444444444444 .— a ei eeei ei eei eeeeee-I eeee eeee4 reee _I z DD z M M M M M M M M M M M M M M M M M M M M M M M M M M M M — m O a; 1 Q C in Q Z v CO M M v M M M 00 0 N Om 0 N ONO N N N I� N l^0 uN1 O a O M O Ian O a 0 N L d y .-i M N l0 O a N 00a0 la0 u1 aM N a Oa N t0 a M ei O M a N N O Z R } l^O t0 l0 l0 l0 t0 t0 (M0 l0 t0 l0 l0 tD l0 (0 l0 la0 t0 t0 t0 t0 'M0 lD lD t0 (N0 t0 t0 ei II Q ua inIMOOLnOOLI10 inininininininininininininini 1 0000000000000000000000000000 J = �; a t0 t0 l0 tD t0 l0 t0 l0 t0 t0' t0' t0' t0 t0 t0 t0' l0 t0 t0 t0 t0' t0 t0 t0 l0 l0' t0 tD Cn O CU ■ U 00pp Oppppp po n O N tM0 ON1 M l0 OMO O M tun N a tD M eai M m O M t!1 N 0 l^O OOi .m-1 M CO 03 -0 a In In M In In t0 t0 t0 N N N 00 00 00 00 M M M 0 O O O ei N ei N N N N N N N N N N N N N N N N N N N N N M M M M M M M M en Q .0 +7-, V � a "v "aa ' avavvaa "avvvvavvvaa 'a a L .p0 p en en on en M m M M en Ien to M Ien Ien M M M tn M M M M e 1 M M M an Q CO M M M M M a M Ol O1 M M M Ol M M 01 Ol Ol O) Ol Ol 01 Ol M Ol Ol 01 M J a a a . a a a a a a a a a a a a a a a a a a a a a a a ei ei ei ei ei ei ei ei ei ei ei ei ei ei ei rt ei r1 ei ei ei ei e1 r1 r1 ei ei ei 0 W — aa p 1 Z 0 M N l0 MV M 0 CO N l0 N 00 N IMO a N .N-I CO t^0 INn CO M N 0 tD M M N a — N ei e I ei ei ei rl O O O O M M M M M M DO co ao t10 co W N N N N Z ar N N N N N N n N N N N N t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 t0 -o 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 7 M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M '.7,.6' 0 e e o o e o 0 0 o e o o e e o 0 0 0 M O O O O O O O O O O O O O O O O O O O O O O O O O O O O O N N- O N a N t0 ei ei M ei 0 M N l0 N 00 O O a M r1 ei a M M tD 2 00 00 N N M N M ei M M M 00 M r1 N a M M O N M a t0 M ei N a .xi1 U• M N a l0 00 O a t0 M N M ei M N 0p N a t0 00 M 00 O N x (0 (0 M a M e N 0 M M 00 N In M N N N M M t10 N t0 M M N N N M (0 X N N N N N N N- N 1/40 00 00 t0 t0 (0 t0 t0 b M in M M M M In M M u1 00 W 4444444444444444444444444444 0 0 In In In In In In In In M M In In In In In M In In In In In In In M In in M M < a tD l0 tO t0 t0 lD t0 t0 tO t0 tD t0 t0 l0 t0 t0 t0 t0 t0 t0 t0 t0 tO t0 tO t0 l0 t0 z z ri ri ri ri 4 .-i .-i ei e i ri eti ei ea ri ei ei ei 4 ri 4 ei ei e i ei ri ei ri .- I a C N m 0 EL a O M N l0 M a .-I M a N O M M ei N N W M N O M N M a M N Z ,�v, N tO O M O M v M M M M 00 M 00 M 00 M N t0 r♦ lO ei ei lD N M ei a5 M N O 00 N M N O M N t0 00 N M a N M 00 t0 M M N N t0 a M - v, N N N N N - N - 0 0 0 0 0 M M M M M Do 00 00 00 Do Do I� N N N 7 • > a a a a a a a a a et a a a M M M M M M M M M M M M M M M o Y M M M M ee M m M m M M M m m M M m m ee M M M M M M M m er Q' @ M M M M M M M M M M M M M M M M M M M M M M M M M M M M _ 0000000000000000000000000000 LO a t0 t0 t0 l0' tD t0 t0' t0' t0 t0' t0' t0 l0 t0 t0' l0' l0' t0 t0 t0' *0 t0' lD t0 t0 l0' t0 t0 u M 7 U 0x0 -0 T 0 ,,, -. 5.: m O 0 0 U N O Y O N r1 N M a M l0 N 00 M - N N - eai eMi --I - N e-•1 N N N N N N N N N CO fl u 3 u C (0 a1 ice+ 0 CO U CO U 0 o n W O 0 ''-',0 .c 5 Q 5 0 0YII' � -o 5 d• aaavd ad d• d; el Q Z Q 0 O ,N-1 e-I .N. .Ni (Ni N N N N N Li e�-1 *Si w 0 N C _1 to O 00 to m N m t0 d' O to tu L,: 74 -, 74747474 ,74 ,-, ..4 .-4 O N C J — C O J In L.. 00 00 00 00 0O 00 00 00 00 00 rm1 In l a N ..1 M N n m N 'o 01 N M t0 00 O IA N N ,1 .-I '-I N N N N en M m 13 N N N N N N N N N N L 00 u1 u1 vA u1 I In U1 M In In o C m m m al m m m 01 01,01 40 J N a-I N aa-I ri eI ri N t--1 0 N N • N OO 00 M 00 M W M N 00 a Z N N t0 tO tO to to t0 M I(1 Z cu n n n N N r- r n'I r n 73 N N N N N N N N N N ' m in in i+'1 in in M in m rn '7, m m m M M M m m m m ▪ 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N ti N W I . 0 O 0 N N N M corn en r-i ct = Q fY I- 00 N M d' IA Is 00 In In Cl) Z ^ X N lb ILA N M N CO a 00 N d 'Cr s d' d' .Cr d' M m J °� 0 ra rP ri M < ai '-I ,1 .-I a-1 .l - ,-1 r1 ,-1 J M CO z IA IA In IA In In IA IA IA I.f1 COO Wm < �- N f6 Q Q Z m to m n m M ,1 m m l y N y0,, V m m M 00 M m N O t0 C C 0 of IN v m ri 0 oD N v N 0 +„I e-1 N H 1 ,1 rl 0 0 0 0 N Z (0 } t0 tO tO tO to to t0 t0 t0 � a InInInInIn � 0001u1 'a d its 0 0 0 0 0 0 0 0 0 0 C }I Q t6 to to to l6 to t0" to to IO CO v . cV in i0 1� cV M M m '-I N CL -1C 3 (LO 0m0 N INA N Om1 N a 001 r, in V/ en 73 M en M M M M M M M to u v a a v cr a ar a a V LE 'ED of Ion on on Ion Ion en In Ion in 0 CO m m m m m m m m m 01 00 J N N ,"1 N r♦ N N N N N 0 0 — 0 en p 00 0 01 8 4 :1 io 0 00 In -i a• ? N to to too to to to n in,IIn. v o to to to to to to to to tD N N N N N N N N N N 7 m M M M M M in M M,m m m m m m M m M m m 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N:t` O• Q to al N N M INl1 t0 Lm en N x 4 tO O M IA N m ,1 I/ N x 7 M j< Ln d• v d• a s v d• V rri 00 ri rl N N N N ay N N .-1 0 0 ttMwM .0tM a t0 110 1/0 to t0 t0 t0 to tO t0 Z Z Z ri ri a-I a-i ,-I' ri ri .•' rii r-i ai I N C — 0 10 0 a Q ✓ sr z ,,,, tun o o a OMl sr Oml m ,m-1 r m ,;, N N LO ID ttOO INO to OOl IO In 7 , 5- en en en m m en m 1.) en m Y M m m M M m M M m m QN VI tninintntntnmtnoLn f0 0 0 0 0 0 0 0 0 0 0 0 a to t0 to t0 t0 m to to to',to u o N = uomo -o >, e\-1 ■ o 0 m L m L N y 0 .0 O z m 0 ei N m Q In t0■N CO ri O) r1 N N en fn M M fM M M m en CO G Y w 0/ u • N y Y O m L m 0 V O V 0 . _ 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 joi m y p �o n N o =w 3s N¢ ° °p sip r Not € a O.; . G w w � m Y U m m � Q CL N M V- In CO I, H Q ig CD (:,1 hlo . 7., ce 1 g ri 0 0 0 0 Y 1 w o a S F L) �.�� N z Z o N il H 0a w on. °°NLL _ _ on I. Ek 0 13 Z O.<_, Eivy, i Y u7 Z (7 u oo _�a N © y I a_di: a0 " z� a_`4 z 31 g ! P k m 4 P HtR ig 'Co' ' , -.4- 6 ° � 5 e --NMI I Afr ' j = 45 Z " I 1_iiEl !r a • -fir-,= "—I 1_11_-- w j -b _I ii _—_ _ - (_____Q �,,o, 1 r Y q F V► a A� I A ° m st ' ..- I A I I � I �P o li I 7.16 6I j I e F z I I j p lI i 1I __ .astsi I j j ce I I s / W to cc 6 2 m E )NA NIoN NI,NO NIA t0� cDM)0)4 � c0co coO ONOhONO V) _ S N M Mut0�I■r 000J0)0)OO7�NNMMa 4 LO N(0 h I-co 000)M00.7�NNMMat V NN ES . 16 c0 tO 66 tD CD co,6 6 V)tD cO cc;r---:r N.r.:r r r r r r n r r rr r r n r N.:OO OO co OS ao OO OO 6 N Oo CO CO C Zm O b YOB 3 22 ° 0 11 al 0) —NMd c0 N CO CD ,-NMd L O —NMd cONCO 0) ,-NMd On CO 0) �NM a; j Qg NMMMMM th MM MMa4a a 7 V 4d'ni d'_N N N ui 6 N ui N M tD O t0 tDO m cO CO O O h'r r r ,,,,,k- N ON pr X3 a i o 8 IT c 7''' oi N m 0 m m N K ... 0 o 2 E 0OlOOU)O O a 0)a CO 4 0)V 0) 0)70)C 0)V 0)a CO CO M CO MNM CO MN CO MN MI.NI,N 8N ,-NNMMa 4.66 to E r r 00 co 30)00--N N M r.-4 7666 O N.r co co p,0)O O—,-NNM L O w d a a a 44 a V a a a 7444 V a V 4 M6 6 66 6 6 6 N N M M 6 M N 6666 u-i 6666606 o- O h • O 2 E € ggg m 7NMd NtOh000) 7NMa u)Or C°.CD NMd NtDhOD 3 0 _ In t0r�0) �NMa in co 000000000 NNNNNNNN sf f N 000]00 CONm 070)070)0)rn0)0)01 `; 3� R as N a 0 F. _____,_______,„,___,„.7._y_,_ _.____, .\__7__\_/____\_7_______ a +a o Lo z WW W 0 u.m Z U Nm \ W C O^ _n 5 a O N Li 3 03 3 0 1 I Z O Illri 5 .<..... J• W [II W . N • co II m to a C0 • t cu w > C ARIL Milk i5 J l'a 6 IF . v• so— lib- 516.... 9 ,, V ate, vs • o a I 3 0 Li m to ca Ink© I- u, ` .,...,r: ,.., ,,,,i �� 4 d -44.1 04 e 0 v411P ' V- Q � r� a, i„......1114 p • r- 4:- : .....k., o > � a� ° to . iLlaiim. • •r — rim , 0 ... .... .......... \ . .. . . d ' ' >C > G t d d w � v r o 7€ O O V V a� V > = fe d a� -1 .mE � -- � � = O U •- 2 c A 'c I W CCC >, c >■N s 'o g R 2 — co _ 01 id 0ou 2 u, 2 F °� E = E gi Li z 7 : s C1 t O 0 `' to W � � ig 6 W � Z XZ ci.(.,..,. QC^'1 2 C'7 N c"� 0 2 E a� 6 Ili - - - CemCAD E*well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : SI-32-W2 Country : USA Field State : Alaska Prepared for : Mr.Luca Borri Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 12/18/2012 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (9071273-1765 E-Mail Address : slauper©slb.com ` 14UATE Disclaimer Notice: Schlumoerper submits this document with the benefit o`its judgment,experience,and good oilfield practices This information is provided in accordance with generally accepted industry practice,retying on facts or'formetion provided by others,limnations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictors are opinions only ND WARRANTY IS GMFN CONCERNING ACCUMCY OR COMP1 TENFSS OF DATA.INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPI IFS.RECOMMENDATIONS MADE,OR RESUITS OF THE SERVICES RFNDFRFD Freedom from infringement of any intellectual property rights of Sclslumberger or others is not to be inferred and no imelleaual property rights we granted hereby *Mark of Schlumberger Page 1 S132-W2 vl.cfw;12-18-2112;Version wcs-cesn472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumhurgcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2761.0 ft BHST : 40 degF Bit Size : 16 in ft (x 1000)psi < 0 1 2 Frac SV 4 =xe 2 xe SV-4 , 1. SV-3 SV-2 B Permafrost • 1 • Ugnu Top (UG4; ti TD 1 • o l__-- 0 Well Lithology Formation Press Page 2 S132-W2 vl.ctw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Stalin r String : 133/6 Surface Casing District : Prudhoe Bay !� Country : USA Loadcase : Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2681.0 ft Casing/liner Shoe MD : 2761.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2761.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 144.7 Mean OH Equivalent Diameter: 19.171 in Total OH Volume : 928.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 2000.0 16.000 190.0 20.063 2761.0 16.000 35.0 16.822 Max. Deviation Angle : 51 deg Max. DLS : 3.666 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (Ib/gal) (Ib/gal) 160.0 11.70 8.40 SV-4 Siltstone 773.0 11.50 8.40 SV-4 Siltstone 1141.0 11.50 8.40 SV-3 Sandstone 1430.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2084.0 12.00 8.40 SV-1 Sandstone 2488.0 12.50 8.40 Ugnu Top(UG4) Shale 2761.0 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 1858.4 32 0.6 3766.0 3057.2 50 1.0 Page 3 S132-W2 vl.cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 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 401.4 bbl Total Volume 1014.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Surface Lead Slurry 450.0 2256.4 10.70 k:2.08E-1 Ibf.s^n/ft2 n:0.187 Ty:16.36 Ibf/100ft2 12.5ppg DeepCRETE 63.0 504.6 2256.4 12.50 k:1.68E-1 Ibf.s^n/ft2 n:0.301 Ty:0.44 lbf/100ft2 Surface Tail Mud 401.4 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 2009 psi at 2681.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 177 psi ft (x 1000) psi _ ( 0 2 — Hydrostatic —Frac —Pore r— C'J Fluid Sequence Static Well Security Page 4 SI32-W2 v1 cfw;12-18-2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 3: pumping schedule - Spacer/Cement Max Rate is 8-BPM - (No significant amount of time to be spent outside of+/- 0.2ppg Density Range) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 8-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Maintain returns during cement job if possible - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from highlighted Rates in Job Report 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(2-8 BPM) 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 5.0 450.0 90.0 450.0 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 03:08 1014.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 1 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2008 psi at 2681.0 ft Burst 4719 psi at 0.0 ft Temperature Results BHCT 60 degF Simulated Max HCT 71 degF Simulated BHCT 70 degF Max HCT Depth 2761.0 ft CT at TOC 61 degF Max HCT Time 02:50:45 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 60 degF 20 degF Bottom Hole (degF) 70 degF 40 degF Page 5 S132-W2 vi.cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 MEM String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl;2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time<30 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Top Plug is not Bumped at calculated Volume a) Pump Y2 shoe track volume MAX b) If Bump not seen,shut in and hold pressure 4) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time<10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume =volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Page 6 SI32-W2 v1 cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated ECDs at Surface Shoe o Depth= 2761 ft ri Frac — Fore rr) Hydrostatic N- Nemo Dynamic _ 1111111111111111111111111111. -ate iw ww w w ° - � -- - rwwww w ■ i_a_..a • t111111111111111111101111111111111111111111111111111111111111011111111111111111111111111111 rwwwawwwwwawaw ,_< aaaar a j �E- a _a aaaa . i■tEilaaaliwwwww�ww ; ww�r■ww� swww wwwww� wwwwwwww■II ,1, ' 1111111111111111111111111111 ww ,wwww w www a =: _• i!I1I111JPE!%t _I�=J=I a aaak_ at w- wwww -w wwww l 1111111111111111111111111111111111111111111111•111111111111111 1l1wwwwmrw 1111111111111111111111111111111111111111111.11111111111 2 L, 1 wwwwwwwwwwww 11111111111111111 c _ _ � �_o _ _ wi www . a N N ! wwww _,�aaaaaaaa �a a1111111111111111111111111111111111111111111110111111111 } s��wm 0 wwwwwww 1 1111 ww 111111111111111111101.11111 Q U � w wwwww . a , Wm_i_awa=_ wa2nllu _ _ wwwwwwa-1 Ian - - o wwwrrw wwwwwwwwwwwww Inilli � a -? s_ ::: a . . Lo cd- o wwwwwwww- . oci 1 ' - r I — 0 20 40 60 80 100 120 140 160 180 200 Time(min) ICI Page 7 S132-W2 vl.cfw;12-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumburgcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated ECDs at Conductor Shoe o_ Depth= 160 ft Fbre • �_ - Hydrostatic 11111 Dynamic M .. . _ I _, •UU.•.� ■.....�I — N . . N. M ■ .. ....U....... _. .........U... ..�__.. ........_ ....:�... . Vii.... �mur�� �si. _. to .mu.. t. �ls... .....��.. . — .. � ■ .. .. ........ S■ C = C Ems i MOM.UM EM EM U W= U UUUU�:• o- ....................a.. .......- . ...... ..... . ..._....... 1111111111111111101111111111111111- U.;... �:_;...;:UU:�- N o . NM 1111111111111111111111 a. Q M N_ .... ..... . .. ...0-5 11111110111111101111 11111111 111.111111.11111111_...=s_..s_.. . 1 .1 .1M1 a.. �UUUUUU.1.=a U.0 g _ ■111111 1 iui• II II III ..l co F l r I .I I is rt i_ is I I i I I r Li _i_=I1j.ISir i j t 0 co l . . I 1 I I I I 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 8 5132-W2 v1 cfw:12-18-2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumdurgcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Surface Pressures o_ _ p — cat.CernHP 1 i � I Calc.Pump Press. O r j//' O O 1 — F CO 1 O v) I N O co a cn o co ,i 0,.......6..... n . i G I p 1 1I O—I r r r , 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 SI32-W2 v1 cfw:12-18-2012:Version wcs-cem472 05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Slurry Temperatures during placement 07, _o ......... Last Sack Temp. — First S. k Temp. I 10 API BHC _N t•-- 11111111111.1111111111111111111 i M- cD _ �� {`f O 111 in ME _ _. -O O III 11101111111111 Ell - N N MI. �----.�-. u7 MOM 11111111111111111111111 ---"—•••211 ° 0 0 INN NI M__ �� _ �� to(COO' _ MO ., _1111111111111 0 Mal d — 111001.1111 � --_ -- . -O 0 co N N o_ 01111 `r`� /�� N N r— i O r ■ r r r i 1 M 0 30 60 90 120 150 180 210 Time(min) 1 Page 10 SI32-W2 v1 cfw:12-18-2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Slurry Temperatures up to 24hrs after Placement u o co Last Sack Temp. — First Sack Temp. ! !!!!! mar!I♦! !! !!� _N rw........1 •AR BI-ICT _!�!! !!!!!� !!!�!!! !!! co- giumm____Irm o /!!! !!!!!� !!! U!!!!!! o _r°n -.am __ . .... ......... mi. i L,_)_ !l. �12.=:�. =...! i o,, _--11---..................1------.. O O _!_!! ! !�.!!! !!!!!!.. _O r- - *---...._ !l/�..� �.!!.!!�!!.!! !I♦!.. tl '!!!!!! 1M��'�!!�!!!!! ���!!!11. I e- a !!!!!!�!!!lIIImwi.—''MIIIIIIIII!!IIII!!!!!!!r!III I to O E U, III■lIUIIIIIIII�:!!UIII■I _ o Ito- !!!!!�!!!!!!!!!�!!l�11.=�!! , x_ . Ls ..=o � !!!!! !! lusrum ! i !! Cl.)cfl_ V ..r....iirmirir rww..r...wwrmmiwrww.r..w.mme. Lo LU 1 eL � --- _ !!!! !!�!!!!!! !!!!!I ! !! � � �m�sl�s�rIIMMMIIIIII,= — • !!! ! ! I m a Ln_ ' - •viii ll�i!! !!!! !!!� ; _o In !� ! !�� ��!!��!!! !!! !IN } N ! !! !OM! MI IM!!!�!!!!� �! I=l1� !_!!_!!__!!_�_!'!!!! !!_!!!1. 1 In 1111111111111111111111 �! !!ll��r!!!!!!!! H!! 4 _N o_ !!!!!! !! ! !l�I�!!!!!!! !!!!IR ■ N rianimmuus Ismimi�IIi �ilCi�ii■lmmum � iamm� 1111 NUN= c) o !!! !!!!1•!!!a►-� ! MI., -U) �!!!�� ! (�ill!!I!!!!!!•■lllw�-r�!llllI c•i L- I<II<IIIIII11IIIIIIIIII I !. to (V O O 0 Nr I I I I I 1 I M 0 250 500 750 1000 1250 1500 1750 Time (min) Page 11 SI32-W2 v1.cfw;12-18-2012;Version wcs-cem47235 1 Client : Eni Petroleum Well : SI-32-W2 Scliderier String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 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 :401.4 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo.Model : HERSCHEL_B. k :2.54E-2 lbf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl 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 Ibf/100ft2 DESIGN BLEND SLURRY Name :ASL(0.79) Mix Fluid : 11.075 gal/sk Job volume :450.0 bbl Dry Density : 108.69 Ib/ft3 Yield :2.40 ft3/sk Quantity : 1052.50 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 Page 12 SI32-W2 v1 cfw:12-1&2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 ie String : 13 3/8 Surface Casing District : Prudhoe Bay �j Country : USA Loadcase 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 :0.441bf/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 Page 13 S132-W2 vl.cfw;12-1B-2012:Version wcs-cern472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumbergcr String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2741.0 ft Casing Shoe :2761.0 ft NB of Cent. Used :25 NB of Floating Cent. :16 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint ()/a) (ft) 2121.0 17 1/3 NW-ST-13 3/8-8-ST A3B W131 0.0 2068.8 2761.0 8 1/2 NW-ST-13 3/8-8-ST A3B W131 33.3 2701.0 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) (Ibf) (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 ft 0 20 0 60 80 100 -—Betaeer Oert I + -1At Cent ++ - -f-+ ' - - o i I I ++ -t-f- =- I. ++ : ++I f +i • ,2,— Cl ■I 1 It O O , Pipe Standoff Page 14 SI32-W2vl.ctw;12.1&2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SI-32-W2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 6: WELLCLEAN II Simulator % ft 0 25 50 75 100 0 20 40 60 80 100 -Std Betw.Cen �a t. Mud CContamination 1 I —Cement Coverage '/ —Uncontaminated Slurry �� 1 C.-7' ""' o J • -'.--t r_.. . 0 0 0— N O O- co Cement Coverage Uncontaminated Slurry (.1 3 z 3 0 :41-- 0 0 0 500- 500 500 500 1000- 1000 ,. 1000 1000 w _ L L L a 1500- 1500 5_ a 1500 1500 a a) a) a) a) o - 0 0 0 2000- I I, 2000 2000 2000 2500 a 2500 2500 2500 a) 3 al a) 3 a) -o o v 2 o -o 3 3 3 L 3 0 0 z z •r07.oO1FLF Sulam, la M071211'. •Mta. .fit% Page 15 SI32-W2 vt.cfw;12-18-2012;Version wcs-cenr472_05 Client : Eni Petroleum Well : SI-32-W2 SW String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 7: 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 :450.0 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 ASL(0.79) 105249.492 Fresh water 277.530 bbl 10.001 bbl lb 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 16 S132-W2 vl.cfw;12-18-2012:Version wcs-cem472_05 CemCADE*well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : SI32-W2 Country : USA Field State : Alaska Prepared for : Mr.Luca Borri Location : Spy Island Proposal No. : v2 Service Point : Prudhoe Bay Date Prepared : 1/30/13 Business Phone : (907)659 2434 Prepared by : Stephen Lauper Phone : (907)273-1765 E-Mail Address : slauper@slb.com 4 a 4UAT E Disclaimer Notice: Schlumberger submits this document with the benefit of its Judgment experience,and good oilfield practices. This information is provided in accodanca w th generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are net infallible. Calcuhtons are estimates based on provided information.All proposals,recommendations,or predictions are opinions only, NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED.EFFECTNENESS OF MATERIAL,PRODUCTS OR SUPPI IFS,RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED Freedom from infringement of any intellectual pmpeny rights of Schlumberger or mhers is not to be inferred any no Wellectual property rights are granted hereby Mark of Schlumberger Page 1 SI32-W2 vi.ctw;12-18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 Schlumbcrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 9377.0 ft BHST : 90 degF Bit Size : 12 1/4 in ft (x 1000)psi Frac —Siltstone— ao�e i Shale ■ i t. - Shale II _ 1 • 4 Shale - 1 ,r, _ — i Shale II I I ■ • • • 'Sandstone. • - • ■ I 1.._. o - Ell 0 Well Lithology Formation Press. Page 2 SI32-W2 v1.cfw;12-18-2012: LoadCase Intermediate Casing lal:Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 ohrie1 String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2761.0 13 3/8 68.0 12.415 Landing Collar MD : 9283.0 ft Casing/liner Shoe MD : 9363.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 9377.0 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 : 1146.5 bbl (including excess) Max. Deviation Angle : 86 deg Max. DLS : 3.676 deg/100ft Formation Data MD Frac. Pore Name Lithology _ (ft) (lb/gal) (lb/gal) 773.0 11.50 8.40 SV-4 Siltstone 1141.0 11.50 8.40 SV-3 Sandstone 1430.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2084.0 12.00 8.40 SV-1 Sandstone 2488.0 12.50 8.40 Ugnu Top(UG4) Shale 3364.0 12.50 8.40 UG-2 Coal Bed Shale Marke 6375.0 12.50 8.40 Lower Ugnu Shale 7464.0 12.50 8.40 Schrader Bluff Top Shale 7829.0 12.50 8.40 N Sequence Top Sandstone 8119.0 12.50 8.40 N Top Sandstone 8299.0 12.50 8.40 N Bottom Sandstone 8971.0 12.50 8.40 N Sequence Base Sandstone 9377.0 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 1858.4 32 0.6 2761.0 2424.1 50 1.2 9377.0 3628.3 90 1.9 Page 3 SI32-W2 v1.cfw;12-18-2012; LoadCase Intermediate Casing(a):Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 SGhiberger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 7119'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k: 5.97E-3 lbf.s^n/ft2 n : 0.616 Ty:8.86 lbf/100ft2 Displacement Volume 703.9 bbl Total Volume 1002.9 bbl TOC 7057.2 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 5923.9 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 lbf/100ft2 12.5ppg DeepCRETE 195.0 2258.0 7119 12.50 k:4.89E-3 Ibf.s^n/ft2 n:0.960 Ty:15.95 lbf/100ft2 Mud 705.0 0.0 9.50 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 378 psi at 2761.0 ft Pore 139 psi at 2761.0 ft Collapse 2740 psi at 9283.0 ft Burst 5376 psi at 0.0 ft Csg.Pump out 61 ton Check Valve Diff Press 48 psi ft (x 1000) psi 0 2.5 —F --I— -Pete G— _a G G Fluid Sequence Static Well Security Page 4 SI32-W2 vi cfw;12-18-2012; LoadCase Intermediate Casing la 1:Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 Schlumherger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 3: pumping schedule - Spacer/Cement Max Rate is 8-BPM - (No significant amount of time to be spent outside of+/- 0.2ppg Density Range) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 8-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Maintain returns during cement job if possible - Attempt to follow highlighted flow rates as close as possible and within ranges specified 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(2-8 BPM) 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 6.0 195.0 32.5 195.0 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 8.0 705.0 88.1 705.0 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 02:36 1000.0 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 243 psi at 9377.0 ft Pore 139 psi at 2761.0 ft Collapse 2740 psi at 238.3 ft Burst 5376 psi at 0.0 ft Temperature Results BHCT 85 degF Simulated Max HCT 90 degF Simulated BHCT 75 degF Max HCT Depth 9377.0 ft CT at TOC 75 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 75 degF 82 degF Bottom Hole (degF) 75 degF 90 degF Page 5 SI32-W2 vl.cfw;12-1B-2012; LoadCase Intermediate Casing(a):Version wcs-cemd72_05 Client : Eni Petroleum Well : SI32-W2 S p String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA loadcase : Intermediate Casing(a) Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl;2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time <30 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time <10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume =volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Page 6 SI32-W2 v1 cfw:1218-2012: LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 Schlumderger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(al Simulated ECDs at INT Shoe o De th= 9377 ft r) — Frac r +� Fore f $ l -�-- t __.. _' ����� _- �i�11•�1�i� Hydrostatic - . 11■■■ Dynamic 11111111111111111111111111111111111 ' O I r�=r ._ _ L �I•�M NW 11111 - ioniammum )rm1s1•rmw To 0 _ n�1•�1•��11.01_11.11111111. ' t — tno- rn,— L - LL 0 LI • C Q �� , _T-3. _ 1 _ co . 0 si-1- co r r r r r 0 25 50 75 100 125 150 175 Time (min) Page 7 SI32-W2 vt.cfw;1218-2012; LoadCase Intermediate Casing Ial;Version wcs-cem47Z_05 Client : Eni Petroleum Well : S132-W2 ScIMmerger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated ECDs at Surface Shoe 0 Depth= 2761 ft cYi —Frac � - _ r ; —Fore .-�- -- — in •ttttt� •1. . -• rirrr• - - Dynamic - - {N- --------------- -r-� -------- . ELi,• _�����.5�A��1�MOM M ����M�i � r � � � i��� i � i1� �wii� - - i= �=I �A■� �� i� � i � l f� �i � �� � i �i � ��� i ��rn° mim � iw� MI�� � � � lii� �� s.- ■ ••iiu•u.uuu•mu•uiauiusuuiuiiu -f � ����E t� ��� ��i !� ��� ��� »11111111111=111 =o_ _1111�����._ _— --_ -------- ---�1--- Ic,.,— - 1i 0 ll...............--,1■4—\Nr■—• IIIII _i a rn" MIS �IIIIIIIIr --• �IIt1I�II11`IIIIIrIIIIINIII 1-11111 111111 IIIIIIIIIIIIIIIIIIII -1.---- i to_ 111111 -— AM - 11111111111111111 00 0 CC t . 1 1 1 1 1 t 0 25 50 75 100 125 150 175 Time(min) Page 8 S132-W2 v1 ctw:12-18-2012: LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated Surface Pressures during Placement o_ . N — Calc.CemHP Calc.Pump Press. ag_a.lna - M M I MO -VMI o_ t = I♦Ir-_ III- -EM EN MIN Ma MINI MAIM NM - _. ._ ■_i- - _ - �� --.r _- . _. - .. . - -•-- -� iii= ii . -mil__ .... —moo N - -ii- Ep► --_ f �, _- m-- mu =i -_omm-� a o- -� - I—. i •E IMIE MI c)0 �� - y I_� _ M W `o_ - di ' , , ~� � i � . - o t r , 1 i 0 25 50 75 100 125 150 175 Time(min) Page 9 SI32-W2 vi,cfw;12-18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : Sl32-W2 Schlumbcrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated Slurry Temperatuers during Placement 1 I -o 00 — Last Sack Temp T __ f ' _._� .,__....L: a Lc) API BHCT f I MMHr.M..MH....E....M.. O .. _-$...asp......= ....■'■u_ . o _� �_ _ su . s ... • co II. _ .•. .••.. ••M.. • _o a. i ■ ■ •aauu - •..•.•.•. O, . : . '--- '-‘ "2 Ma ' rimi.- . :II - ' -‘P N NEON II _ .. ■ .. %Pt %•.•.. .... ■ ' ..■ .ua■ NM Lo.0 rc))0, I Mr _ 11101 _ • Yu' 1 II , __• i , , , Ali I __ -� Q ■ .. ' ..■■ - i a...•....w.._ -N C) .�•• I ••.. ..•..■....■a N S O_ _ : ■ .. -_ • _.-._._I . _. -.. - --- - - .-- N in r r i I 106 0 25 50 75 100 125 150 175 Time(min) Page 10 SI32-W2 vl cfw;12-18-2012; LoadCase Intermediate Casing(al;Version wcs-cem472_05 Client : Eni Petroleum Well : Sl32-W2 Schiumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated Slurry Temperatures up to 24hours after Placement ch6 1— Last Sack Temp. 1 1__-I t-_. _. +_ i = Lo �_ API BHCT � -- _N .M.M� ui=iiiuiu:iii. Lo i i hilV. 1•1uu 511! ..�.�.M.-M... � N° N_ r- _::::_:: Client : Eni Petroleum Well : S132-W2 Sibielierier String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) 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 :8.86 lbf/100ft2 Gel Strength :32.02 lbf/100ft2 MUD Mud Type :WBM Job volume :703.9 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 Ibf.s^n/ft2 At temp. :80 degF n :0.324 Ty : 12.92 lbf/100ft2 Gel Strength :(Ibf/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 : 15.951bf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid :5.471 gal/sk Job volume : 195.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk ✓ Quantity :714.03 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 12 S132-W2 vl.ctw;12-18-2012; loadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : S132-W2 S hlumbaler String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :9343.0 ft Casing Shoe :9363.0 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) 7083.0 0 0/0 0.0 7101.6 9377.0 57 1/1 HYDROFORM HFD 50.0 9363.0 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) (Ibf) (Ibf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford('1 N.A. N.A. N.A. o;o ft 0 20 60 80 100 I + -1A.t Oe-t '" I - 1 . ■ O . O ' C ' ' IINI i J i r. Pipe Standoff Page 13 SI32-W2 vi,cfw;12-1&2012: tuadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : SI32-W2 Scili merger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 6: WELLCLEAN II Simulator Q 0,0 °%U 11 0 25 50 75 100 0 20 40 60 80 100 o_ O —Std Betw.Cent. —Mud Contamination CO —Cement Coverage —Uncontaminated Slurry —_- 1 O O- OD � ' --- 1-- ---H oO O O Cement Coverage Uncontaminated Slurry Fuck C,K.b.o. 11.k �.w1 3 U 3 3 z 7000 7000 7000 7000 7200— X 7200 7200 7200 7400— 7400 7400 7400 7600— 7600 7600 7600 7800— 7800 7800 7800 8000 8000 8000 8000 .' . -c 8200— 8200 ' -c 8200 ‘, 8200 a _ a a 0. 0 8400— 8400 0 0 8400 u r 8400 0 8600— 8600 8600 8600 8800— 8800 8800 8800 9000- 9000 9000 • 9000 9200— 9200 9200 9200 m ; S m ; m v o a -o o -o 0 3 3 0,- z z Nio�w.cnErE •M� rte. UDPUSMA Page 14 SI32-W2 vl.cfw:12-18-2012: LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : SI32-W2 SiIimlirger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) 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: 195.0 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 71402.977 lb Fresh water 93.007 bbl 10.001 bbl D046 142.806 lb 0.200%BWOB D065 178.507 lb 0.250%BWOB D167 178.507 lb 0.250%BWOB D153 71.403 lb 0.100%BWOB II Page 15 SI32-W2 v1 cfw:12-1&2012: LoadCase Intermediate Casing(a);Version wcs-cem472_05 String Summary String OD/Weight/Grade i,onnection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Surface Casing 13 3/8",68.000 ppf,L-80 BTC,L-80 32.0-2761.0 12.259 2.31 L 2.15 3.77 Burst Design(13 3/8"Surface Casing) Collapse Design(13 3/8"Surface Casing) Axial Design(13 3/8"Surface Casing) 650 650 650 F F F N N u) 7 m 7 L 1300 t 1300 L 1300 a a a a) a) 0) 0 0 0 -t3 0 a m m d h 1950 y 1950 h 1950 as as as a) a) a) 2600 2600 2600 - Design Load Line - Design Load Line - Design Load Line Pi.e Ratin. - Pi.e Ratin. Pi.e Ratin. 0 1500 3000 4500 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) Burst Load Data(13 3/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Drilling Load: Pressure Test Test Pressure: 2000.00 psi 32 13 3/8",68.000 ppf,L-80 BTC,L-80 2.46 B5 L + 100.00 Cl 5.24 AS 3.18 B5 Mud Weight: 9.40 ppg 41 2.46 B5 L +100.00 C1 5.25 AS 3.18 B5 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 160 2.45 B5 L 32.60 C1 5.40 A5 3.17 B5 200 2.45 B5 L 26.08 C1 5.45 AS 3.16 B5 Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 200 2.45 B5 L 26.08 C1 4.19 AS 3.12 135 Surface Pressure(1/3'BHP): 529.80 psi 600 2.43 B5 L 8.72 C1 3.88 AS 3.00 B5 Shoe Depth,MD: 2761.0 usft 600 2.43 B5 L 8.72 C1 3.88 AS 2.99 B5 Fracture Pressure at Shoe: 1578.22 psi 800 2.41 B5 L 6.57 C1 4.00 AS 2.96 B5 Fracture Margin of Error: 0.00 ppg 800 2.41 B5 L 6.57 C1 4.01 AS 2.96 B5 1000 2.40 B5 L 5.29 C1 4.15 AS 2.92 B5 External Pressure: Fluid Gradients(w/Pore Pressure) 1200 2.39 B5 L 4.45 C1 4.29 AS 2.89 B5 TOC,MD: 32.0 usft 1200 2.39 B5 L 4.45 C1 4.31 A5 2.89 B5 Prior Shoe,MD: 160.0 usft 1300 2.38 B5 L 4.13 C1 3.77 AS 2.77 B5 Mud Weight Above TOC: 8.33 ppg 1363 2.38 85 L 3.96 C1 4.38 A4 2.84 85 Fluid Gradient Below TOC: 8.33 ppg 1500 2.37 B5 L 3.63 C1 4.45 A4 3.00 B5 Pore Pressure In Open Hole: No 1900 2.35 B5 L 2.94 C1 4.69 A4 2.95 B5 ---- - 2040 2.34 B5 L 2.76 C1 4.78 A4 2.71 BS 2100 2.34 B5 L 2.69 C1 4.14 AS 2.62 B5 Axial Load Data(13 3/8"Surface Casing) 2100 2.34 85 L 2.69 C1 4.15 AS 2.62 B5 2200 2.33 B5 L 2.58 Cl 4.21 AS 2.61 B5 Running in Hole-Avg.Speed: 0.7 ft/s 2300 2.33 B5 L 2.49 C1 4.27 AS 2.59 B5 2400 2.33 B5 L 2.40 Cl 4.33 AS 2.58 B5 Overpull Force: 100000 lbf 2500 2.32 B5 L 2.32 Cl 4.44 AS 2.58 B5 2500 2.32 85 L 2.32 Cl 4.40 AS 2.57 B5 Green Cement Pressure Test: 1500.00 psi 2600 2.32 B5 L 2.25 Cl 4.46 AS 2.56 135 2750 2.31 B5 L 2.16 C1 4.55 AS 2.54 B5 Collapse Load Data(13 3/8"Surface Casing) 2750 2.31 B5 L 2.16 C1 5.32 A4 2.88 B5 2760 2.31 B5 L 2.15 C1 5.33 A4 2.88 B5 Drilling Load: Full/Partial Evacuation 2761 2.31 B5 L 2.15 C1 5.33 A4 2.88 B5 Mud Weight: 9.40 ppg Mud Level,MD: 2761.0 usft B5 Pressure Test Assigned External Pressurefluid Gradients(w/Pore Pressure) C1 Full/Partial Evacuation External Pressure Fluid Gradients(w/Pore Pressure) A4 Overpull Force TOC,MD: 32.0 usft AS Green Cement Pressure Test(Axial) Prior Shoe,MD: 160.0 usft - Fluid Gradient Above TOC: 8.33 ppg Fluid Gradient Below TOC: 8.33 ppg Pore Pressure In Open Hole Below TOC: No String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Production Casing 9 5/8",40.000 ppt,L-80 Series 500 Type 563(TC) 32.0-9377.0 8.750 A 3.91 1.74 3.41 Burst Design(9 5/8"Production Casing) Collapse Design(9 5/8"Production Casing) Axial Design(9 5/8"Production Casing) 2500 2500 2500 F 7 7 3 - -c -c a a a 5000 5000 tj 5000 V V V m m m U U U) /8 N 0 2 7500 2 7500 2 7500 - Design Load Line - Design Load Line Design Load Line 10000 Pi.e Ratin. 10000 10000 - Pi.e Ratin. - Pi.e Ratin. 0 2500 5000 7500 0 950 1900 2850 200000 400000 600000 800000 Burst Rating (psi) Collapse Rating (psi) Axial Force (lbf) Minimum Safety Factors(9 5/8"Production Casing) Burst Load Data(9 5/8"Production Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Production Load: Tubing Leak Packer Fluid Density: 8.60 ppg 32 9 5/8",40.000 ppf,L-80 4.00 B6 +100.00 C5 3.98 A5 3.55 A5 Packer Depth,MD: 18327.0 usft 41 4.00 B6 +100.00 C5 3.98 A5 3.55 AS Perforation Depth,MD: 18327.2 usft 200 Series 500 Type 563(TC) 4.02 B6 31.11 C5 4.04 A4 3.58 A5 Gas Gravity: 0.70 200 4.02 66 31.10 C5 3.52 A5 3.37 A5 Reservoir Pressure: 1569.25 psi 600 4.07 86 10.44 C5 3.42 A5 3.31 A5 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 600 4.07 86 10.44 C5 3.41 A5 3.31 A5 724 4.08 B6 8.69 C5 3.47 A4 3.34 A5 External Pressure: Fluid Gradients(w/Pore Pressure) 800 4.09 B6 7.88 C5 3.48 A4 3.35 A5 TOC,MD: 7119.0 usft 1000 4.12 86 6.35 C5 3.48 A4 3.40 A5 Prior Shoe,MD: 2761.0 usft 1200 4.14 86 5.35 C5 3.49 A4 3.40 A4 Mud Weight Above TOC: 9.40 ppg 1284 4.15 B6 5.02 C5 3.49 A4 3.33 AS Fluid Gradient Below TOC: 8.33 ppg 1300 4.15 B6 4.96 05 3.45 A5 3.31 A5 Pore Pressure In Open Hole: Yes 1309 4.15 B6 4.93 C5 3.49 A4 3.32 A5 1500 4.17 86 4.36 C5 3.50 A4 3.40 A4 1900 4.22 B6 3.53 C5 3.52 A4 3.39 A4 Axial Load Data(9 5/8"Production Casing) 2100 4.24 B6 3.23 C5 3.53 A4 3.39 A4 2200 4.25 B6 3.10 C5 3.54 A4 3.39 A4 Running in Hole-Avg.Speed: 0.7 ft/s 2300 4.26 B6 2.98 C5 3.54 A4 3.38 A4 2400 4.27 B6 2.88 C5 3.55 A4 3.38 A4 Overpull Force: 100000 lbf 2500 4.28 86 2.79 C5 3.55 A4 3.38 A4 2600 4.29 B6 2.70 C5 3.56 A4 3.38 A4 Green Cement Pressure Test: 1800.00 psi 2750 4.30 B6 2.59 C5 3.57 A4 3.39 A4 2761 4.31 136 2.58 C5 3.57 A4 3.39 A4 2869 4.31 86 2.51 C5 3.57 A4 3.39 A4 2900 4.32 86 2.50 C5 3.57 A4 3.39 A4 3000 4.33 136 2.44 C5 3.58 A4 3.39 A4 Collapse Load Data(9 5/8"Production Casing) 3100 4.33 B6 2.39 C5 3.59 A4 3.39 A4 3200 4.34 B6 2.34 C5 3.59 A4 3.39 A4 Production Load: Full Evacuation 3300 4.35 136 2.30 C5 3.60 A4 3.40 A4 Assigned External Pressure:Fluid Gradients(w/Pore Pressure) 3400 4.35 B6 2.27 C5 3.61 A4 3.40 A4 3500 4.36 B6 2.23 C5 3.62 A4 3.40 A4 External Pressurefluid Gradients(w/Pore Pressure) 3600 4.36 B6 2.21 C5 3.62 A4 3.41 A4 TOC,MD: 7119.0 usft 3700 4.37 B6 2.19 C5 3.63 A4 3.41 A4 Prior Shoe,MD: 2761.0 usft 3800 4.37 B6 2.17 C5 3.64 A4 3.42 A4 Fluid Gradient Above TOC: 9.40 ppg 3905 4.37 B6 2.16 C5 3.65 A4 3.42 A4 Fluid Gradient Below TOC: 8.33 ppg 7119 4.44 B6 1.85 C5 3.92 A4 3.62 A4 Pore Pressure In Open Hole Below TOC: No 7119 3.91 B6 1.85 C5 3.92 A4 3.62 A4 7500 3.91 B6 1.83 C5 4.02 A4 3.70 A4 7900 3.91 B6 1.80 C5 4.16 A4 3.69 C5 8200 3.91 B6 1.78 C5 4.30 A4 3.66 C5 8500 3.91 B6 1.77 C5 4.47 A4 3.63 C5 8800 3.91 B6 1.76 C5 4.66 A4 3.61 C5 8800 3.91 B6 1.76 C5 4.66 A4 3.60 C5 8900 3.91 B6 1.75 C5 4.73 A4 4.02 C5 9376 3.91 B6 1.74 C5 5.10 A4 3.99 C5 9377 3.91 136 1.74 C5 5.11 A4 3.99 C5 B6 Tubing Leak C5 Full Evacuation Production A4 Overpull Force AS Green Cement Pressure Test(Axial) TRANSMITTAL LETTER CHECKLIST WELL NAME 1\iiKe.i'lc.A SI3�-wz y PTD# Q 13t/3 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: i Kai Eck POOL: itkikcjc-k_l £ r k r 13) O) 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 5 a To n N 7 a I N N a) 0 L N 4 m o j .- C U N C a 0 = CL h 00 o) O 0 d C ai m C U) U co o O - c co O co Y a `E a) (9 m — m 7 Cl) ° N N E L O a C U a (O p' >` CC C c 7 c0 7 n 1] w m 3 Y n E a) a o (n 0 r a c o cn • m (o 0 c m n u E of F-ui c ° ° m F N 7 (n E 0) 0 p E O CO X -0 o 0 C) m C co g CO m 0 a) m 6 = — O o co o)ai co d C N >co 3 C_ CO a 7 C j N 0 U C F- m D7 M 6 N - C "o Q 3 :C a U) C L a N 7 O O•o c N O ° U) m a 3 3 m a a) a 0 o V V a) .LO.� D- N Y N L — 0 a) N m •C tO > 3 7 Z U ° ° Li 7 C -0 U) . co D7 O LU_. 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N CO ,rt (() (O 1- CO 0 '- N (N N N N N N N N N 2 CO CO CO CO CO CO CO CO CO U co co co r O w 0 w O C O C N N U CO Ce o p co a) M O N W O co ,_ C N O E• d co N J N -5 d a) 0 C C O 3 1.- E a s 0) a � 00 a cc) U Q Q w Q 0 Q • Weil History File A P EN *IX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to 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 information. HALLIBURTON - 0 \ 3 Sperry Drilling • 0 Surface Data Logging End of Well Report S132-W2 Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: May 25, 2013 fps a • • `KFM*41.9, HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 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 I 1 HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Doyon 15 Well: SI32-W2 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23483-00-00 Sperry Job Number: AK-AM-0009957284 Job Start Date: 05 Mar 2013 Spud Date: 07 Mar 2013 Total Depth Date: 11 May 2013 Total Depth: 18,350 MD, 3,607' TVD North Reference: True Declination: 20.036° Dip Angle: 81.073° Total Field Strength: 57614.091 nT Date Of Magnetic Data: 15 Mar 2013 Wellhead Coordinates N: North 70° 33' 27.68273" Wellhead Coordinates W: West 149° 54' 22.14323" Drill Floor Elevation: 53.62' Ground Elevation: 13.1' Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Leigh Ann Rasher Kori Jo Plowman, Clifton Posey Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 HALLIBURTON I Sperry Drilling DAILY SUMMARY 03/05/2013 Move rig. Mudloggers on standby. 03/06/2013 Move rig. Mudloggers on standby. 03/07/2013 Rig up mudlogging unit. Continue rig up operations. Rig up suitcases and test. Perform 13 3/8"dummy hanger run. Rig up knife valve, diverter and function. Rack back HWDP,jars, and NMDFC. Fill conductor with spud mud. Pressure test pumps and surface equipment. Pick up clean out BHA#1 and wash conductor to 160' MD. Drill ahead to 311' MD and pull out of hole to pick up BHA#2. 03/08/2013 Continue to pick up BHA#2. Drill ahead from 311' MD to 2100' MD. Max gas observed was 444 units at 1681' MD. 03/09/2013 Continue to drill ahead from 2100' MD to surface TD of 2821' MD. Back ream out of hole per K&M rep. Lay down BHA#2 and rig up casing equipment. Max gas observed was 730 units at 2100' MD. 03/10/2013 Continue to rip up casing equipment. Run in hole with 13 3/8"casing to 834' MD. Lay down 4 casing joints and replace 2 connection collars due to problem with pin and box thread. Continue to run in hole with casing to 2767' MD. Pick up and make up hanger and landing joint, set hanger and land casing at 2806' MD. Circulate and condition mud for cement job. Test cement lines and pump cement. 03/11/2013 Finished cement job. Rig down mudlogging unit to prepare for rig move to SD37-DSP1 RWO. 04/25/2013 Mudloggers rig up unit. Continue to test BOPE. Rig down testing equipment and retrieve test plug from tubing hangar. Pick up and make up landing joint and screw into tubing hangar. Displace well from OBM to LSND mud. Lay down two singles to 2618' MD, pull out of hole on elevators and lay down crossover and mule shoe. Pick up 5" drill pipe and lay down mouse hole. Make up bushing running tool and set wear bushing. 04/26/2013 Slip and cut drill line. Test casing for 30 minutes at 2500 psi. Pick up BHA#3 and run in hole to 1373' MD. Circulate and shallow hole test tools. Continue to run in hole and drill shoe track from 2717' MD to casing shoe at 2806' MD. Drill ahead to 2842' MD, circulate and perform formation integrity test to 13.0 ppg EMW.Wash and ream to 2835' MD. Drill ahead to 3470' MD. Max gas observed was 100 units at 3121' MD. 04/27/2013 Drill ahead from 3470' MD to 5805' MD. Max gas observed was 30 units at 5664' MD. 04/28/2013 Drill ahead from 5805' MD to 7350' MD. Max gas observed was 919 units at 7002' MD. 04/29/2013 Drill ahead from 7350' MD to 9304' MD. Max gas observed was 970 units at 8289' MD. HALLIBURTON I Sperry Drilling 04/30/2013 Drill ahead from 9304' MD to intermediate TD of 9407' MD. Circulate bottoms up twice then back ream out of hole. Max gas observed was 152 units at 9356' MD. 05/01/2013 Continue to back ream out of hole. Lay down bottom hole assembly#3. Make up and pick up bottom hole assembly#4 and run in hole. Shallow test on measurement while drilling tools @ 1000' MD. Continue to run in hole filling every 20 stands. Ream from 9214'to bottom. Circulate bottoms up at bottom, then begin to back ream out of hole. Begin made after drilling logging pass at 9022' MD. 05/02/2013 Continue MAD pass to 7931' MD. Pull out of hole. Lay down bottom hole assembly#4. Change rams and test. Rig up for casing run and run in hole with 9 5/8"casing. 05/03/2013 Continue to float in 9 5/8"casing to bottom. Rig down casing equipment. Rig up and pump cement. 05/04/2013 Cement casing. Rig down cementing equipment. Nipple down blow out preventers. Change rams. Freeze protect outer annulus with diesel. Pick up 5"drill pipe. Pick up 4.5" drill pipe. 05/05/2013 Pick up stands of 4.5"drill pipe and rack back. Slip and cut. Test blow out preventers. Sperry tested total hydrocarbon analyzer and gas chromatograph. 05/06/2013 Finish testing blow out preventers. Casing test to 3000 psi for 30 min. Pick up bottom hole assembly#5 and run in hole. Cement Bond Log/Sonic Log from 660'to 9300' MD. Tag plug at 9300' MD. Displace low solids non-dispersed mud to PrimoFaze oil based mud. 05/07/2013 Drill out cement and 20'of new formation to 9427' MD. Circulate and condition mud. Pick up to 9280' MD. Perform Formation integrity test to 13.0 ppg effective mud weight. Drill ahead in production section. Cuttings consist primarily of unconsolidated to calcareously cemented sandstone, with lesser amounts of siltstone which also varies between silty sandstone and sandy siltstone. 05/08/2013 Continue to drill ahead in OA Sands. Cuttings consist primarily of unconsolidated to calcareously cemented sandstone. There are lesser amounts of siltstone,which can also vary between silty sandstone and sandy siltstone.. 05/09/2013 Continue to drill ahead in OA Sands. Well has been ballooning sporadically throughout the day, more noticeably just around midnight; report cut off time. The erratic taking and giving fluids by the hole has directly affected the calculated lag, and therefore the cuttings samples and cuttings gas cannot be as accurately calculated during these periods. Samples consist primarily of unconsolidated to occasional cuttings of calcareously cemented sandstone. There are lesser amounts of siltstone, which also vary between silty sandstone and sandy siltstone. 05/10/2013 Continue to drill ahead in OA Sands. Well has been ballooning. The erratic taking and giving fluids by the hole has directly affected the calculated lag therefore the cuttings samples and cuttings gas cannot be as accurately attributed/assigned to specific depths during these periods. Samples consist primarily of unconsolidated to occasional cuttings of calcareously cemented sandstone. There are small amounts of siltstone, silty sandstone and sandy siltstone. 1 HALLIEt URTON Operry Orilleng Days vs. Depth . WELL NAME: S132-W2 LOCATION: Spy Island OPERATOR: ENI Petroleum AREA: North Slope MUD CO: MI Swaco STATE: Alaska RIG: Doyon 15 SPUD: 7-Mar-2013 SPERRY JOB: AK-AM-0009957284 TD: 11-May-2013 0 t�I Commenced 16"Surface i I I i I l i i ��� ���� 07 March 2013 ,mmiii Hole Section somminsommENNEMIIIMI1111111 1000 ul On On Bot:19:30 07 March 2013 wwmuill. Sperry SDL rig up unit and — ���w� :��w� gas equipment MIN 1 1 1 1 1 II 1 1 ! I m��1•�■ TD Surface Hole Section Pro nosed 2000 K`v.wmwc 2821'MD,2423'TVD 11111111111111111111111111111111111111111111111 -- ��■www� Off Bot: 10:03 09 March 2013�w�w Actual -_\www■ wsimm maw w■■ . .20■21•••w■1l0tIrr www 3000 ns. ..v I �• Commenced 12.25"Intermediate — — mw WIwwna111■■■■ Hole Section MIMIr`wwII TIM 1•1111111111111 w Landed 13 3/8"Casing •a gm _ On Bot: 17:45 26 April 2013 -4000 — 2806'MD,2413'TVD ��►,-� - 10 10 March 2013 �����nrwm��m�>•w -- 1 . 1 1 1 LL 5000 I RIH-Perform FIT to 13.0 w ppg EMW lim 26 April 2013 _ 6000 1 Ell - 111•11111M11111=11111•111111111111111111111111111 111111111111111111111111111111111111111111111111111111111111111MININONI MN= ' 7000 1M — TD Intermediate Hole Section..... == mMaINI r 9407'MD,3625'TVD Niommionomm mom ___________________;� Off Bot:01:30 30 April 2013 www ww }, 8000 ' —O. CD --_-- --_— Commenced 8.75"Production 9000 ,1� ' Hole Section On Bot: 10:00 07 May 2013 I CD 1. . L. 10000 ,! U) —�_. �_='_= RIH-Perform FIT to 13.0 Landed 9 5/8"Casing ..la,w� 07 ppg y^2013 11000 _■■■ ---- 9387'MD,3624'TVD MEN NE U11•11 03 May 2013 , , 12000 — =ELIU* N --- 13000 1 1‘ 14000 15000 — 16000 1 TD Production Hole Section 18350'MD,3608'TVD 17000 Off Bot:02:40 11 May 2013 , 18000 _ �/ i 19000 20000 , - 0 5 10 15 20 25 30 35 Rig Days "AL.LIBURT©PJ Surface Data eporry ctrtei.r,r After Action Review WELL NAME: S132-W2 LOCATION: Spy Island OPERATOR: ENI Petroleum AREA: North Slope SPERRY JOB: AK-AM-0009957284 STATE: Alaska RIG: Doyon 15 HOLE SECTION: Surface EMPLOYEE NAME: Leigh Ann Rasher DATE: 10-Mar-2013 What went as, or better than, planned: Rig down and rig up went smoothly. All data transfers (WITS, DX, Petrolink) worked as expected. No problems with INISTE were experienced. Difficulties experienced: Gas equipment was reading a little high (30-40 units) right after spudding 5132-W2. The gas would stay at 20-30 units even when the pumps were turned off. Gas equipment was calibrated twice during a connection and all pressures on the THC were checked. Gas still remained above normal readings. After a day or so they dropped down to normal. We think the genie filter got wet and possible caused the higher than normal gas readings. Recommendations: Genie filters should be replaced on a regular basis. Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v 3.0 1-11"LL1BLIRT®1S1 Surface Data Logging parry C?rillCnel After Action Review WELL NAME: S132-W2 LOCATION: Spy Island OPERATOR: ENI Petroleum AREA: North Slope SPERRY JOB: AK-AM-0009957284 STATE: Alaska RIG: Doyon 15 HOLE SECTION: Intermediate EMPLOYEE NAME: Leigh Ann Rasher DATE: 30-Apr-2013 What went as, or better than, planned: No major issues were encountered with the gas equipment and overall INSITE ran well. Succesfully completed the GORE sample program which included 10' samples throughout the N-sand formation. Difficulties experienced: The ADI computer froze while drilling resulting in 60' of missed data from 5010' MD to 5070' MD. Recommendations: Back up the ADI twice a day, once per tour, Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v 3.0 1-4"1.-L.1 BUR-MINI Surface Data Logging Spsrry C3rtiling After Action Review WELL NAME: S132-W2 LOCATION: Spy Island OPERATOR: ENI Petroleum AREA: North Slope SPERRY JOB: AK-AM-0009957284 STATE: Alaska RIG: Doyon 15 HOLE SECTION: Production EMPLOYEE NAME: Emil Opitz DATE: 13-May-2013 What went as, or better than, planned: The Vortex Cooler and its components were reconditioned and successfully repaired to their proper working order. Difficulties experienced: The Vortex Cooler was unable to reach the desired temperatures, 30-40 degrees Fahrenheit. This was due to the warmth of the compressed air being supplied by the rig. There is no viable solution for us to solve this matter at this time. INSITE pits stopped calculating properly and we were unable to access them from the IRIS machine. This problem was solved by deleting the pits configuration file and reconfiguring the pits. Recommendations: N/A Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v3.0 HALLIBURTON o�-y o�;,,,,,4 Formation Tops WELL NAME: SI32-W2 LOCATION: Spy Island OPERATOR: ENI Petroleum AREA: North Slope MUD CO: MI Swaco STATE: Alaska RIG: Doyon 15 SPUD: 3/7/2013 0:00 SPERRY JOB: AK-AM-0009957284 TD: 11-May-2013 Marker MD INC AZ TVD TVDSS 16"Surface Borehole 20"Conductor Shoe 160.0 0.4 296.7 160.0 106.4- SV-4 770.0 15.0 183.2 765.2 711.4 SV-3 1,145.0 25.1 182.9 1,115.6 1,062.0 SV-2 1,435.0 29.8 183.4 1,372.4 1,318.8 Permafrost Base 1,878.0 32.5 182.5 1,748.3 1,694.7 SV-1 2,086.0 27.3 183.2 1,920.1 1,866.5 Ugnu Top(UG4) 2,536.0 50.5 202.1 2,240.8 2,187.2 13 3/8"Surface Casing Shoe 2,806.0 50.0 217.6 2,413.7 2,360.1 TD 16"Borehole 2,821.0 50.0 218.5 2,423.3 2,369.7 12 1/4"Intermediate Borehole UG-2 Coal Bed Marker 3,379.0 60.9 238.7 2,744.4 2,690.8 Lower Ugnu 6,288.0 81.4 241.3 3,259.6 3,206.0 Schrader Bluff Top 7,506.0 81.6 256.3 3,442.7 3,389.1 N Sequence Top 7,839.0 83.4 265.2 3,486.4 3,432.8 Fault 1 8,032.0 82.9 273.4 3,509.2 3,455.6 N Sand Top 8,115.0 82.9 276.1 3,519.5 3,465.9 N-2 Top 8,166.0 82.9 276.1 3,525.7 3,472.1 N-3 Top 8,218.0 82.9 276.1 3,532.0 3,478.4 N Sand Bottom 8,381.0 83.0 283.4 3,552.5 3,498.9 Fault 2 8,780.0 84.9 297.2 3,591.3 3,537.7 N Sequence Base Faulted Out n/a n/a n/a 9 5/8"Intermediate Casing 9,387.0 87.9 310.0 3,624.2 3,570.6 TD 12 1/4"Borehole 9,407.0 88.0 310.0 3,624.9 3,571.3 8 3/4"Lateral Borehole OA Sand Top 9,419.0 88.0 309.7 3,625.3 3,571.7 OA-2 10,250.0 89.5 314.9 3,627.1 3,573.5 OA-2 10,465.0 90.8 312.5 3,625.1 3,571.5 _ OA-2 10,592.0 88.5 312.0 3,625.6 3,572.0 _ OA-3 10,818.0 88.0 307.0 3,633.3 3,579.7 OA-3 11,950.0 93.1 307.3 3,621.4 3,567.8 OA-2 12,090.0 93.2 308.8 3,613.2 3,55, OA-2 12,596.0 89.4 304.7 3,612.8 3 5' OA-2 12,830.0 93.2 305.5 3,607.4 Fault A 13,776.0 88.2 310.1 3,607.8 3,554.2 _ OA-3 15,171.0 91.8 315.8 3,600.7 3,547.1 OA-2 15,278.0 93.1 318.7 3,596.1 3,542.5 _ OA Sand Top 15,855.0 90.6 314.7 3,586.4 3,532.8 OA Sand Top 15,901.0 89.9 313.7 3,586.3 3,532.7 Fault B 15,931.0 89.5 313.1 3,586.2 3,532.6 OA-2 16,024.0 89.5 312.8 3,587.1 3,533.5 OA-2 16,126.0 91.0 313.1 3,586.6 3,533.0 OA-2 17,135.0 87.8 320.0 3,592.0 3,538.4 OA-3 17,205.0 88.7 319.4 3,594.0 3,540.4 TD 8 3/4"Borehole 18,350.0 89.6 319.3 3,607.9 3,554.3 , -- 11—I AIL.L.111181.11wArTC30m ��U� Report� Show n������m � Report# 2 Well Name: S|32-N2 Depth (MD) 9500 to 11500 ft Location: Spy Island (TVD) 3628 to 3926 ft Operator: ENI Petroluem Report Prepared By: Emil Opitz Formation: OA-Sand Report Delivered To: Andrew Buchanan Date: 7-May-2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected Depth 9847 ft Gas Units 995 Mud Chlorides(mg/L)= 127500 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 cs nnm »vm v»m Hydrocarbon Ratios 1000 Cl 222804 - 16330 = 206474 Cl/C2 = 100 C2 2383 - 321 = 2062 o1x:3 = 129 -- C3 1925 - 324 = 1601 n1/C4 = 143 ------ NPH -- ,� C4 1811 - 363 =_ 14*8 C1/C5 = /ws / C5 597 - 134 = 463 ~— Production �uo��~�--��` '_~ ——~ Analysis nsan nod —11Water kiwon'pmuucimvHydrocarbons _~-- � ��W ___ Depth 10157 ft Gas Units 1122 Mud Chlorides(mg/L)= 110000 Gas Flowline Background Show / ________ »»m ovm »nm _______ Hydrocarbon Ratios 10 C1 233725 - 30716 = 20300e c1m2 = 105_ C2 2621 - 683 = 1938 o1/o3 = 140 C3 2187 - 734 = 1453 C1/C4 = 940 Oil • . C4 1072 - 856 = 216 o1/u5 = 263 C5 1102 - 331 = 771 NPH . � Production 1 — Analysis Dmm foil nWate, Fimcn-Producible Hydmcarbons M Hydrocarbon Ratios Depth 11001 ft Gas Units 10*3 Mud Chlorides(mg/L)= 105000 Cl Cl Cl C1 Flowline Background Show C2 C3 C4 C5 npm »»m ppm 1000 Hydrocarbon Ratios :st,Cl 123988 - 129*9 = 111038 C1/C2 = 162 C2 870 - 183 = 687 C1/C3 = 259 -- %I C3 657 229 = 428 C1/C4 = 5844 NPH C4 408 - 389 = 19 C1/C5 = 467 n5 449 - 211 = 238 __ __ _ Production �«« ~_~~~ Analysis []naa []on 11 Water [�won'pvmuc/u/envumc Hydrocarbons �_ ~ 11 Depth 11377 ft Gas Units 962 Mud Chlorides(mg/L)= 115000 G=^ Flowline Background Show _____ __ —�— � nnm »»m vvm _ _ Hydrocarbon Ratios 10 C1 111732 - 8460 = 103272 o1/u2 = 171 | C2 766 - 163 = 003 o1v:3 = 259 Oil C3 597 - 1e9 = 398 C1/C4 = 6075 C4 387 - 370 = 17 Cl/C5 = 465 NPH C5 428 - 206 = 222 1 � Production Analysis fsa, fOil FIVVater pi Non-Producible Hydrocarbons . d ts .,,cuwilsomp Show Report ,.';Report Well Name: S132-W2 Depth (MD) 11500 to 13400 ft Location: Spy Island (TVD) 3629 to 3600 ft Operator: ENI Petroluem Report Prepared By: Emil Opitz Formation: OA-Sand Report Delivered To: Andrew Buchanan Date: 8-May-2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. ...� . .......:................... ....._.................,............... ., Hydrocarbon Ratios Depth 11565 ft Gas Units 1676 Mud Chlorides(mg/L)= 115000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 190014 - 8943 = 181071 C1/C2 = 219 1000 w— C2 978 - 152 = 826 C1/C3 = 325 - ■ C3 754 - 196 = 558 C1/C4 = 325 4 ■ C4 938 - 380 = 558 C1/C5 = 1000 NPH C5 410 - 229 = 181 _ Production - Analysis nGas foil Water nNon-Producible Hydrocarbons r -- - Depth 12132 ft Gas Units 1195 Mud Chlorides(mg/L)= 100000 Gas Flowline Background Show PPm PPm PPm ___ ___ _ __ ____ _- Hydrocarbon Ratios 10 - ____ - Cl 134387 - 13133 = 121254 C1/C2 = 126 C2 1157 - 198 = 959 C1/C3 = 177 -C3 931 - 246 = 685 C1/C4 = 1250 Oil - — C4 524 - 427 = 97 C1/C5 = 390 • -—- 05 562 - 251 = 311 NPH Production 1 Analysis nGas f Oil nWater nNon-Producible Hydrocarbons ■ M Hydrocarbon Ratios Depth 12441 ft Gas Units 997 Mud Chlorides(mg/L)= 90000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 Cl 109385 - 8265 = 101120 C1/C2 = 110 7_ C2 1082 - 165 = 917 C1/C3 = 154 — C3 875 217 = 658 C1/C4 = 1124 NPH C4 468 - 378 = 90 C1/C5 = 366 C5 500 - 224 = 276 e �— , --——Production 100 ,— Analysis nGas f oil nWater pi Non-Producible Hydrocarbons i--�— - - Depth 13335 ft Gas Units 899 Mud Chlorides(mg/L)= 91000 Gas _ _ Flowline Background Show - ___ - PPm PPm PPm Hydrocarbon Ratios 10 L _ 11733 85854 C1/C2 = 91 Cl 97587 = C2 1200 - 261 = 939 C1/C3 = 118 Oil C3 1057 - 330 = 727 C1/C4 = 1506 —- C4 538 - 481 = 57 C1/C5 = 277 Y C5 5.80 - 270 = 310 NPH Production 1 Analysis f Gas f Oil nWater nNon-Producible Hydrocarbons . i-Loa-s-usursorraora 'W' :' Eltpierry Clirl Ilene Show Report R Well Name: S132-W2 Depth (MD) 13400 to 15800 ft Location: Spy Island (TVD) 3600 to 3587 ft Operator: ENI Petroluem Report Prepared By: Emil Opitz Formation: OA-Sand Report Delivered To: Andrew Buchanan Date: 9-May-2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. I .... ...:.:.:.............:.:.....:.:.........:.......:...:.........:.........:...:.........................:.......:.:.:.:...........:...........:.......:...................:.•.•.•.•.•.Hydrocarbon Ratios...... Depth 13824 ft Gas Units 684 Mud Chlorides(mg/L)= 91000 Cl C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 76867 - 2241 = 74626 C1/C2 = 85 1000 C2 938 - 65 = 873 C1/C3 = 111 = C3 790 - 118 = 672 C1/C4 = 121 C4 862 - 247 = 615 C1/C5 = 381 NPH -- 05 378 - 182 = 196 ------• Production 100 i Analysis nGas nOil Water fx1Non-Producible Hydrocarbons _ Depth 14226 ft Gas Units 753 Mud Chlorides(mg/L)= 85000 Gas Flowline Background Show ___ PPm PPm PPm --------------- ______---- Hydrocarbon Ratios 10 _ C1 82776 - 4290 = 78486 C1/C2 = 91 -- C2 985 - 126 = 859 C1/C3 = 125 C3 800 - 172 = 628 C1/C4 = 545 Oil C4 431 - 287 = 144 C1/C5 = 280 — — — C5 464 - 184 = 280 NPH Production 1 Analysis nGas nOil nWater f1Non-Producible Hydrocarbons • Hydrocarbon Ratios Depth 14951 ft Gas Units 878 Mud Chlorides(mg/L)= 78000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 PPm PPm PPm Hydrocarbon Ratios 1000 Cl 96594 - 6118 = 90476 C1/C2 = 95 C2 1086 - 132 = 954 C1/C3 = 139 - C3 837 184 = 653 C1/C4 = 748 NPH C4 446 - 325 = 121 C1/C5 = 334 C5 479 - 208 = 271 _,_ Production 100 —— _ — - —_ Analysis nGas foil nWater fz�Non-Producible Hydrocarbons _ —— —— - - II Depth 15680 ft Gas Units 894 Mud Chlorides(mg/L)= 78000 Gas Flowline Background Show - - ------ PPm PPm PPm — — — - - Hydrocarbon Ratios 10 - -- C1 99617 - 2718 = 96899 C1/C2 = 95 C2 1099 - 79 = 1020 _ C1/C3 = 137 Oil T C3 825 - 116 = 709 C1/C4 = 477 C4 426 - 223 = 203 C1/C5 = 334 C5 451 - 161 = 290 NPH 1 Production Analysis []Gas f Oil []Water nNon-Producible Hydrocarbons I— J L 1111111J a F NU . _.____ B M.le :iMo., Show Report Report# 5 Well Name: S132-W2 Depth (MD) 16100 to 18650 ft Location: Spy Island (TVD) 3587 to 3607 ft Operator: p Report Prepared By: Emil Opitz Formation: OA-Sand Report Delivered To: Andrew Buchanan Date: 10-May-2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 16936 ft Gas Units 851 Mud Chlorides(mg/L)=_ 85000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 96662 - 8575 = 88087 C1/C2 = 94 1000 C2 1078 - 143 = 935 c1/C3 = 132 C3 832 - 164 = 668 C1/04 = 153 C4 812 - 237 = 575 01/05 = 487 NPH C5 315 - 134 = 181 Production 100 _ —— Analysis []Gas []Oil 711Nater [Non-Producible Hydrocarbons —— 121 Depth 17354 ft Gas Units 874 Mud Chlorides(mg/L)= 90000 Gas Flowline Background Show ———— PPm PPm PPm Hydrocarbon Ratios 10 .- C1 98553 - 24942 = 73611 C1/02 = 100 C2 1003 - 270 = 733 01/03 = 144 C3 743 - 231 = 512 C1/C4 = 1207 Oil C4 343 - 282 = 61 C1/C5 = 356 ——— - 05 360 - 153 = 207 NPH Production 1 Analysis []Gas []Oil nWater [Non-Producible Hydrocarbons M Hydrocarbon Ratios Depth 17859 ft Gas Units 840 Mud Chlorides(mg/L)= 105000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 92338 - 21868 = 70470 C1/02 = 95 ''IN C2 1021 - 280 = 741 C1/03 = 133 — - C3 803 273 = 530 01/04 = 1355 NPH C4 379 - 327 = 52 C1/C5 = 295 C5 403 - 164 = 239 ..- _ Production 100 -__——— Analysis nGas foil nWater [Non-Producible Hydrocarbons — — 4 I Depth 18327 ft Gas Units 665 Mud Chlorides(mg/L)= 105000 Gas Flowline Background Show --- PPm PPm PPm Hydrocarbon Ratios 10 --- Cl 74653 - 7861 = 66792 01/02 = 96 C2 829 - 134 = 695 C1/03 = 138 Oil C3 659 - 174 = 485 01/04 = 1363 C4 320 - _ 271 = 49 01/C5 = 365 C5 348 - 165 = 183 NPH 1 Production Analysis nGas MOH []Water [Non-Producible Hydrocarbons • 1 HALLIBURTON Sperry Drilling Water and Oil Based Mud Record 2 co • O = a m CO m o O E.` c a' C c 0 E m U -op -0 -8 J t -O 9 II -0 0 U 80- !0 -(0 -a "p m (0 U 222 a, 0 - a) a) 0 (a = 0 m - 0 d Ti C0 0 0) m -7k -E. Om p - - O N N a) a) Q o E QQQ aC) 0.. « 0 Ln mvm E if, r om uM v m 00000 > 0 0 0 0` m� 3 � a. m < 0 0` 0 0` m a . 0 co x N m 2 m H K v o m 3 - p x U cr (0 0 0 0 0 . i O D 0 0 0 0 0 0 O O O N N O O O O 0 0 (0000 (0 (00 (0 0 (0 Q Q O O O O co O O 0 0 0 0 0 0 0 0 0 0 o ` 0 0 0 ' ' $0 0 0 0 0 0 0 O N O ¢V 0000 U E 800 N N N N m N 0 N N CO m M N N J (00) 0) 0000) 00 (00) 0 0 0 0 0 0 0 0 0 0 0 0 N N V N N V V V '9(9 (0o 0 0 0 0 0 M N N N ' ' N O N 00 N co V V M M co. .428 ° C)O N O N N N n M D a 0 0 0 0 c- o 0 0 0 0 0 0 0 0 3 a N o m m o 0 0 0 C O p N .- e- O , N T N V O N m tD r r r N L Y N O H W(00U) O N O N N N N O O N N m O r V .E N N N MV , ,.- Lt '/2.1 - O N n N oN N ' O N V V V. . . ,- ,- V G O N ai M 0 M M M M co•W Z r.- n Q W D O A Z O WfnI- x rCOmr o NNM (O0 V M ,- N M "moNN m mMmM QCG a o) 0) 0) NOai00) aiaioioio( O i o 6 O 6 d 0 0 0 O O N a N N N N N N _ _ _ N _ _ 043 ,L0000 00000 ' E ..,-. 0...0. ..0. N M o. 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V V K CC E c2 2 2 W N R N if)(O N p b o 0 N N N ,- m co r M N N co m 9 N N $(O O V m O N N N QV N N N O c V V N N N co co co co N N 00,0 O m Q O co V E m co m N N M N M N 00 0 N M N N N M (Y N m CO M co M M M M NNU) mMvMvvMM m v Co m O 0 cO V 0 oM m N N m M V(O N ,4-4-4. O M N M C N(0000 (0 Co °o O roror MvNVNNVV raOm N 28r-° a a N a a', a Q s E a E N C O T o o V - i i C O O N N C O O N N < 00 x N N ,- co (O m i m — o N N N (O N N N V O N N N N Ui 2 E c7 M M M M M_ w Q E W a O U' O E N CO V m CO V CO N CO r 00 N (O V 2 OU—O Q .. CO V V 00 � ,- NN NMM M '"�^ E - - - - . co co co a ~D�, o o �; -N0NCCNNNQNNNN "° 0U) Nm � mm� o> JQ � n V N ap N N o o M N M m m CO - CT) n v v N m 1--- 1,-- n n w a� w Ct (n v 0 o 0n 0 d °° c> j ° °'rn to o f a - N O CO N N M v m r r co v N CO CO(O a a ° (O m 0 n (o r N S� j d a N M N N N N N N N N N a) O T n M M N N ,- ,- N N O N(G a M W N .r- m 0 m M .- M M ,- O N N N V > NN .- .-NN- 0 V V V NN -0 °-2 (� -E > N c, ry co co co o(p m co co 0 o O m c0 O O d M M ro N r m O V N M co co m V V O V N V N N V V v V V >_H N m V v V v v ��11pA, CO ^` N C V a Z m 0 O N N O N 0 0 0 0 0 O O 000 W O m 0 0 0 (O 00000 O 0 0 0 O cC O) y. m Z 3 a 0) (0 (0 (0 co co co co 000 (n N V N co v V 0 V V U•c7 c 5 J c co of ai of co ai ai of of ai of Oi of ai of of CD E °of of of ai of M M M Oi 7 Co w m a. CO C 0 n m co oo r r r r r r.--.. L, O r N m N ON O o o O c\e cs, N V W W W N N N aryl V V R OV N V r m r CO CO CO CO CZ U M°� D xN � NNNNMNraOmmm mmm 0 O ,� m °,- .- ,- .- OMO 0 CV >, >, C a a a a a a m > >> N m c m m 0 0 .. 22225551 % 522 2 2 2 m 2222 2 2 2 2 2 2 2 2 O r .5l0 -N N N N N O ,L N SV ( 0 N r 06O 0` -CV .M- HALLIBURTON Sperry Orillincg Bit Record ❑ N ❑ F ❑ C F' O C N 0 O E N O 3 N 3 o v E a ❑ ❑ ❑ F F F 6 o F m w C7 a a m m ' N r r r 2 a C7 x E00 00 O 0 co rn U) J LL M II d M C O O N co Co a O O O X N T CD O O O O N (J) E N In Z Q p W ~ 07 6 m o 0 H d' C a E ") co 0 a ¢ iI `/) O O 0 u-) N o 0 a CO 0) O <d' CO N O N tO 0 U- m m ~ O o 0 0 0 m O _ Ln N V E?) DC m cO CO o 0 CO v O CO u) m N 0 CO 5 c`.7, Q0 co i N E s o o � o � CO CO v 0 0 Ln O ❑ N N _ N a in T¢ N cD N r w G m N- U) & O CO- U EOURO = ❑a a z $ o x CG a ij a W 0 ° co O a ui F = x X ❑ m L N E O L u U � N CO OJ Z O O O O O O N CO Q I N CO -a- on H^1.,.1-1113tJF11-CJF *awe-.=y�cm-013.6 � ...�. Morning Report Report#1 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 160' Well: S132-W2 Daily Charges: Current Depth: 311' Area: Spy Island Total Charges: 24 Hour Progress: 151' Location: North Slope Rig Activity: M/U BHA#2 Date: 7-Mar-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) 0.0 230.5 693.4 182' Flow In ..m 0 SPP 'Si 0 ---- Flow In(spm) 0 Gallons/stroke 4.23 @ 0.96 I MWD Summary Depth Tools ECD (ppg) . Mm Max 160' to 311' SP Motor 1.83,GyroPulse,PowerPulse 825,ARC 825 10.91 10.66 11.12 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 m•/I % 242' Gel Spud Mud 8.80 120 22.5 33 22 6.0 9.7 900 2.5 ' - --- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+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 47 268' 0 0 0 0 0 0 0 Minimum 5 305' 0 0 0 0 0 0 0 Average 35 0 0 0 0 0 0 0 ■ Background - Trip - Connection - * 10,000 Units = 100% Gas In Air I (current) (max) lmaxt 24 hr Recap: Continue rig up operations. Rig up suitcases and test. Perform 13 3/8"dummy hanger run. Rig up knife valve, diverter,and function. Rack back heavy weight drill pipe,jars,and NMDFC. Fill conductor with spud mud. Pressure test pumps and surface equipment. Pick up clean out BHA#1. Wash out conductor to 160'MD. Drill ahead to 311'MD. Pull out of the hole to pick up BHA#2. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 Morning Report Report#2 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 311' Well: SI32-W2 Daily Charges: Current Depth: 2100' Area: Spy Island Total Charges: 24 Hour Progress: 1789' Location: North Slope Rig Activity: Drill 16"Hole Date: 8-Mar-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) 148.9 228.5 1469.1 478' Flow In(s pm) 729 SPP 'Si 1269 ---- Flow In(spm) 172 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg)Mr. Min Max 311' to 2100' SP Motor 1.83,GyroPulse,PowerPulse 825,ARC 825 11.15 9.45 11.56 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) m1/30min m./I % 1767' Gel Spud Mud 9.40 124 20.0 28 30 5.4 9.6 1800 6.0 ■ Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 - 160' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary s 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 444 1681' 0 0 0 0 0 0 0 Minimum 3 940' 0 0 0 0 0 0 0 Average 68 0 0 0 0 0 0 0 Background 48 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) lmax) 24 hr Recap: Continue picking up BHA#2. Drill ahead from 311'MD to 2100'MD. Max gas observed was 444 units at 1681'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 i' Morning Report Report#3 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 2100' Well: S132-W2 Daily Charges: Current Depth: 2821' Area: Spy Island Total Charges: 24 Hour Progress: 721' Location: North Slope Rig Activity: R/U Casing Equip Date: 9-Mar-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: 1 ROP(ft/hr) 216.3 576.9 2711' Flow In(6.m) SPP (psi) ---- Flow In (spm) Gallons/stroke 4.23 @ 0.96 ( Depth Tools �� Min Max MWD Summary 2100' to 2821' SP Motor 1.83,GyroPulse,PowerPulse 825,ARC 825 ECD (ppg) 10.07 9.89 10.49 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (pub Eq) cP (Ib/100ftz) ml/30min m./I % 2821' Gel Spud Mud 9.35 85 22.5 23 28 5.1 9.9 1400 5.0 �. [ ,... .. .. � , .I.." 1.'_" :::::::"..7.-"" "._um 1 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD f 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 730 2100' 98702 0 0 0 0 0 0 Minimum 11 2785' 334 0 0 0 0 0 0 Average 111 15134 0 0 0 0 0 0 Background - Trip 366 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) . .__ 24 hr Recap: Continue to drill ahead from 2100'MD to surface TD of 2821.1'MD. Back ream out of the hole per K&M. Lay down BHA#2. Rig up casing equipment. Max gas observed was 730 units at 2100'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HA4.E,.LIE3 JR"TC 1 �� Morning R - h Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 2821' Well: S132-W2 Daily Charges: Current Depth: 2821' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: Cement Date: 10-Mar-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Current Pump & Flow Data: ROP(ft/hr) Flow In(gpm) 148 _ SPP(psi) 315 Flow In(spm) 35 Gallons/stroke 4.23 @ 0.96 Depth Tools Avg Max MWD Summary to ECD (ppg) : , M Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (lb/100ft2) ml/30min mg/I 2821' Gel Spud Mud 9.35 43 17 15 7.7 _ .._.. Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD . " sue., :'.. " _` Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 l II� Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary � �� �1 1�� �1 7 :: .: 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 11 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to rig up casing equipment. Run in the hole with casing to 834'MD. Laid down four joints of casing and replaced two connection collars due to problem with pin and box thread. Continue to run in the hole with casing to 2767'MD. Pick up and make up hanger and landing joint. Set hanger and land casing at 2806'MD. Circulate and condition mud for cement job. Test cement lines and pump cement. I Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 i Morning Report Report#5 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 2821' Well: SI32-W2 Daily Charges: Current Depth: 2821' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: Set Wear Bushing Date: 25-Apr-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr ---- Flow In (.pm) 148 SPP .si 315 ---- Flow In (spm) 35 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max to ammosirnimi Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec,/qt) ..b Eq) cP (Ib/100ft2) ml/30min me/1 % 2821' LSND 9.25 46 8 23 6.6 9.5 600 4.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 Y - 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: Continue to test BOPs. Rig down test equipment. Retrieve test plug from hanger. Pick up and make up landing joint and screw into hanger. Displace OBM to LSND. Lay down singles to 2618'MD. Pull out of the hole on elevators to surface and lay down crossover and mule shoe. Pick up 5"drill pipe. Lay down mouse hole. Make up bushing running tool and set wear bushing. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 11-11"11-11-111E311-11 -ream `', �':. ce i, t r W a°r a k, r';r 1 Hornung 1 i ( ;,r Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 2821' Well: S132-W2 Daily Charges: Current Depth: 3470' Area: Spy Island Total Charges: 24 Hour Progress: 649' Location: North Slope Rig Activity: Drill 12.25"Hole Date: 26-Apr-2013 Rig: Doyon 15 Report For: Keener/Simonson/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr) 24.6 270.3 684.5 3324' Flow In(••m) 914 SPP(•si) 1230 ---- Flow In(spm) 216 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) 31. Min Max 2821' to 3470' Xceed 900, TeleScope 825,ARC 825 9.88 8.60 10.05 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 % 3236' LSND 9.30 49 2.7 9 24 6.0 9.5 2100 4.0 .° Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 - 2821' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 80 -- 20 ---_---- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 100 3121' 22478 0 0 0 0 0 0 Minimum 2 2863' 38 0 0 0 0 0 0 Average 50 7990 0 0 0 0 0 0 Background 27 Trip Connection 10,000 Units = 100%Gas In Air (current) (max) (max) „_. ..._ 24 hr Recap: Slip and cut drill line. Test casing for 30 minutes at 2500 psi. Pick up BHA#3. Ran in the hole to 1373'MD, circulate and shallow hole test. Continue to run in the hole. Drill shoe track from 2717'MD to casing shoe at 2806'MD. Drill to 2842'MD. Circulate and perfomr LOT to 13.0 ppg EMW. Wash and ream to 2835'MD. Drill ahead to 3470'MD. Max gas observed was 100 units at 3121'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 Morning Report Report#7 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 3470' Well: S132-W2 Daily Charges: Current Depth: 5805' Area: Spy Island Total Charges: 24 Hour Progress: 2335' Location: North Slope Rig Activity: Drill 12.25" Hole Date: 27-Apr-2013 Rig: Doyon 15 Report For: Keener/Simonson/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr) 0.0 318.3 583.3 5410' Flow In •.m 905 SPP • 1586 ---- Flow In (spm) 214 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools �'] Min Max 3470' to 5805' ECD (ppg)Xceed 900, TeleScope 825,ARC 825 10.01 9.61 10.28 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) ..b Eq) cP (Ib/100ft2) ml/30min mg/I C5566' LSND 9.30 - 53 14.0 13 29 5.2 9.3 2600 4.6 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 - 2821' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 80 -- 20 -------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 30 5664' 4830 0 0 0 0 0 0 Minimum 3 5457' 52 0 0 0 0 0 0 Average 8 1240 0 0 0 0 0 0 Background 6 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 3470'MD to 5805'MD. Max gas observed was 30 units at 5664'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 I II-11"L.11 rC3II rC Mop nin _._. .,_. _..... P y„, 4 9B ' `lent�,{ S p�l3rry or�H lYfFj 9 4 �` t} Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 5805' Well: S132-W2 Daily Charges: Current Depth: 7350' Area: Spy Island Total Charges: 24 Hour Progress: 1545' Location: North Slope Rig Activity: Drill 12.25"Hole Date: 28-Apr-2013 Rig: Doyon 15 Report For: Keener/Simonson/Buchanan Time: 12:00 AM _ .,• �...r �.,�.�� _ __ _„ _ �_ _._�..s._.���, � ,�. • �� �_ . ._, _ ., . Win . . , . ROP Current Avg 24 hr Max Max®ft Current Pump & Flow Data: ROP ft/hr 333.7 335.9 812.3 6552' Flow In ••m 734 SPP (psi) 1190 ate, , m ---- Flow In (spm) 173 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max 2805' to 7350' Xceed 900, TeleScope 825,ARC 825 10.00 9.68 10.25 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (ppb E.) cP (Ib/100ft2) m1/30min mg/I % 7158' LSND 9.20 48 14.5 11 27 5.2 9.6 2300 4.5 „:.1.:a n .a Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 2821' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 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 919 7002' 240202 0 0 0 0 0 0 Minimum 3 5849' 23 0 0 0 0 0 0 Average 64 14625 0 0 0 0 0 0 Background 3 Trip - Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 5805'MD to 7350'MD. Max gas observed was 919 units at 7002'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 1-1 Morning Report ' Report#9 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 7350' Well: S132-W2 Daily Charges: Current Depth: 9304' Area: Spy Island Total Charges: 24 Hour Progress: 1954' Location: North Slope Rig Activity: Drill 12.25" Hole Date: 29-Apr-2013 Rig: Doyon 15 Report For: Keener/Simonson/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) 0.0 244.5 570.1 9225' Flow In(gpm) 749 SPP(psi) 1627 Flow In (spm) 177 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max 7350' to 9304' Xceed 900, TeleScope 825,ARC 825 10.23 9.79 10.84 n 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 % 8927' LSND 9.40 50 14.0 13 27 4.6 9.6 1900 6.1 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKH1716D-E4C PDC 12.25" 0.969 2821' Size Set At Type Weight rade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 50 50 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 970 8289' 228125 2548 726 488 208 224 9 Minimum 11 7516' 1732 0 0 0 0 0 0 Average 125 24633 356 267 244 164 266 25 Background 64 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 7350'MD to 9304'MD. Max gas observed was 970 units at 8289'MD. I I Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 111-11A.L-L-11ZSLJIFI-rica PJ 'ri�"1PfH��/ CSt`Ql�itl� Morning Report Report#10 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 9304' Well: S132-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 103' Location: North Slope Rig Activity: BROOH Date: 30-Apr-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) 220.0 441.1 9304' Flow In ..m) 897 SPP(•Si) 1187 ---- Flow In(spm) 212 Gallons/stroke 4.23 @ 0.96 L:17.-,....-7...7.7...72,---.11 MWD Summary Depth Tools ECD (ppg) Min Max 9304' to 9407' Xceed 900, TeleScope 825,ARC 825 10.65 10.57 10.84 _ ,�,.. � :..;.. mot.: �.,.�.��..� .:,._.__7�� f �.b1 _. :2....7,, �,.�_�: _-,.�.,a ,,,:._� �.��. ....mow; . , 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./I % 940T LSND 9.40 50 17.5 13 28 4.6 9.6 1800 6.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 2821' ---- _. S. «..; Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 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 152 9356' 28816 404 446 306 390 298 141 Minimum 32 9407' 4320 57 67 58 71 89 27 Average 112 19366 285 324 226 287 228 104 Background 37 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 9304'MD to intermediate TD of 9407'MD. Circulate bottoms up two times and back ream out of the hole. Max gas observed was 152 units at 9356'MD. I Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 ' lM Morning Report Report#11 . Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 9407' Well: SI32-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: MAD Pass Date: 1-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr ---- Flow In (•.m 912 SPP •si 1847 ---- Flow In (spm) 215 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Min Max 9407' to 9407' TeleScope 825,ARC 825, SADN 825 --- n Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/gt) •.b Eq) cP (Ib/100ft2) ml/30min m./1 9407' LSND 9.40 46 17.5 11 24 5.2 9.3 1200 6.2 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD gym; - Size Set At Type Weight rade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 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 18 Trip 98 Connection 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to back ream out of the hole. Lay down BHA#3. Make up and pick up BHA#4 and run in the hole. Shallow test MWD at 1000'MD. Continue to run in the hole filling every 20 stands. Ream from 9214'MD to bottom. Circulate bottoms up at bottom,then begin back reaming out of the hole. MAD Pass starting at 9022'MD. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 I Morning Report Report# 12 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 9407' Well: S132-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: RIH w/9 5/8"Casing Date: 2-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM 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) Avg Min Max to � , =U Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (••b Es) cP (Ib/100ft2) m1/30min m./I 9407' LSND 9.40 48 17.5 10 25 5.2 9.3 1200 6.2 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 k 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 118 Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue MAD Pass to 7931'MD. Pulled out of the hole and laid down BHA#4. Change Rams and test. Rig up for casing run and run in the hole with 9 5/8"casing. 6 Y I Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLISLJRTON �tF,�Rw•v c3.-aia.r+ Morning Report Report# 13 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 9407' Well: S132-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: Cementing Date: 3-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM :... ... . . :. .r:,. . .° .., 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) • 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 Eq) cP (Ib/100ft2) m1/30min mill 9407' LSND 9.40 46 17.5 12 16 5.4 9.1 1200 6.4 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 � Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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 62 Connection - * 10,000 Units = 100%Gas In Air (current) (max) tmax) 24 hr Recap: Continue to float in 9 5/8"casing to 9387'MD. Rig down casing requipment. Rig up and pump cement. 1, Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 id ,� h (x i P I Yr""'ig't£dY"W�(•�'Yl"aP.3 e!%1.�<,.,._ WV....uPo.,..n �t�l`11r��� r.:7":.:7:3§��� i Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 9407' Well: S132-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: P/U 4.5" DP Date: 4-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In •.m SPP • ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max to 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 m./I % 9407' LSND 9.40 46 15.0 12 16 5.6 9.1 1200 6.4 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 L-80 Lithology(%) Ss Cht Silt Siltst CIy 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) tmax/ 24 hr Recap: Cement casing. Rig down cementing equipment. Nipple down BOPs. Change Rams. Freeze protect out annulus with diesel. Pick up 5"drill pipe and 4.5"drill pipe. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 1 I-#ALLIBLiP TAIV Morning Report Report#15 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 9407' Well: SI32-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: Test BOPs Date: 5-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM 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 tat Tools ECD (ppg)=== Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out (sec/qt) (.•b Es) cP (Ib/100ft2) ml/30min m./I % 9407' LSND 9.40 46 15.0 12 16 5.6 9.2 1200 6.4 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Smith XR+Milltooth 16" 1.117 15.70 160' 2821' 2661' 25.0 50.0 1-1-WT-A-E-I-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------_----- mm 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: Pick up stands of 4.5"drill pipe and rack back. Slip and cut drill line. Test BOPs. Sperry tested and calibrated Total Hydrocarbon Analyzer and Gas Chromatograph. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 Morning Report Report# 16 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 9407' Well: S132-W2 Daily Charges: Current Depth: 9407' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: Displace to OBM Date: 6-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr ---- Flow In (.pm SPP (psi) ---- Flow In (spm) Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) • 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/10oft2) m1/30min m./1 % 9407' LSND 9.40 46 12 16 ---- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 9407' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806 LTC 68.0 L-80 9 5/8" 9387 HYDRIL 10.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement ) (current) ------------ :_._ :-.7 .e _�71 = 7_ : , mow_ -`- --.2.:::- _. . ..,_ ::_: °` -7._-..7- T r_.7, 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: Finish testing BOPs. Casing test to 3000 psi for 30 minutes. Pick up BHA#5 and run in the hole. CBL and sonic from 6600'MD to 9300'MD. Tag plug at 9300'MD. Displace LSND to PrimoFaze OBM. I Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 f.- r,,,,,,y :_:,,;,.s, Morning Report Report# 17 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 9407' Well: S132-W2 Daily Charges: Current Depth: 11052' Area: Spy Island Total Charges: 24 Hour Progress: 1645' Location: North Slope Rig Activity: Drilling Ahead Date: 7-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr 250.0 277.4 439.4 10115' Flow In •.m 554 SPP .si) 2968 ---- Flow In(spm) 132 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max 9407' to 11052' Xceed 675,EcoScope 675,Telescope 675,sonicVision 675 11.76 11.04 12.18 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (Ib/bbl) % 10722' PrimoFaze 9.40 9.45 63 57/43 23 36 3.1 1.00 1.3 6.5 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 - 9407' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 90 -- 10 -------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1122 10156' 233725 2621 2187 1072 1102 498 248 Minimum 33 9411' 7223 64 44 20 19 1 0 Average 508 77660 881 779 416 442 217 112 Background 138 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) max 24 hr Recap: Drill out cement and 20'of new formation to 9427'MD. Circulate and condition mud. Pick up to 9280'MD. Perform FIT to 13.0 ppg EMW. Drill ahead in production section. Cuttings consist primarily of unconsolidated to calcareously cemented sandstone,with lesser amounts of siltstone,which also varies between silty sandstone and sandy siltstone. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBLJRTQPJ d ,.Morning a Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 11052' Well: S132-W2 Daily Charges: Current Depth: 13573' Area: Spy Island Total Charges: 24 Hour Progress: 2521' Location: North Slope Rig Activity: Drilling Ahead Date: 8-May-2013 Rig: Doyon 15 Report For: Keener/Amend/Buchanan Time: 12:00 AM u ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) 265.0 315.5 630.0 12430' Flow In ••m 550 SPP •si 3142 ---- Flow In s•m 130 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Av. Min Max 11052' to 13573' Xceed 675,EcoScope 675,TeleScope 675,sonicVision 675 11.95 10.81 12.59 Mud Data Density Viscosity Oil� • /Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (1b/bbl) % 13199' PrimoFaze 9.50 9.55 56 64/36 17 29 3.3 1.50 2.0 8.8 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 - 9407' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) 90 -- 10 -------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1796 11765' 200687 1125 887 514 552 299 155 Minimum 133 12283' 11443 157 194 155 191 135 74 Average 611 58045 541 483 293 329 193 103 Background 208 Trip - Connection - * 10,000 Units = 100% Gas In Air (current) (max) (max) -M m.__. w� 24 hr Recap: Continue to drill ahead in the OA sands. Cuttings consist primarily of unconsolidated to calcareously cemented sandstone. There are lesser amounts of siltstone,which can also vary between silty sandstone and sandy siltstone. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBL.�11 '-dN11 ' ', ` .'� Morning, Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 13573' Well: S132-W2 Daily Charges: Current Depth: 15955' Area: Spy Island Total Charges: 24 Hour Progress: 2382' Location: North Slope Rig Activity: Drilling Ahead Date: 9-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr . 280.0 281.3 475.2 15645' Flow In ••m 495 SPP (•si) 2752 ---- Flow In (spm) 116 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg)MTN Min Max 13573' to 15955' Xceed 675,EcoScope 675,TeleScope 675,sonicVision 675 12.05 11.47 12.37 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 13199' PrimoFaze 9.35 9.65 48 67/33 14 20 3.5 1.50 2.0 9.2 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 HycalogSKHl716D-E4CPDC 12.25' 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 - 9407' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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 896 15709' 98303 1093 820 425 451 244 128 Minimum 46 15920' 1839 44 65 58 83 73 45 Average 420 37315 470 407 235 264 160 87 Background 70 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to drill ahead in OA sands. Well has been ballooning sporadically throughout the day,more noticably just around midnight. The erratic taking and giving of fluids by the hole has directly affected the calculated lag,and therefore the cutting samples and cuttings gas cannot be accurately calculated during these periods. Samples consist primarily of unconsolidated to occasional cuttings of calcareoulsy cemented sandstone. There are lesser amounts of siltstone,which also vary between silty sandstone and sandy siltstone. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 MALL1BtJR1 I Morning Report Report#20 k, Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 15955' Well: S132-W2 Daily Charges: Current Depth: 18130' Area: Spy Island Total Charges: 24 Hour Progress: 2175' Location: North Slope Rig Activity: Drilling Ahead Date: 10-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 231.0 253.0 432.6 16301' Flow In •.m 445 SPP .si) 2537 ---- Flow In (spm) 105 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) . Min Max 15955' to 18130' Xceed 675,EcoScope 675,TeleScope 675,sonicVision 675 11.68 11.36 12.44 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 17761' PrimoFaze 9.40 9.40 45 66/34 14 17 3.6 1.20 1.6 6.5 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 - 9407' ---- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 L-80 Lithology(%) Ss Cht Silt Siltst CIy 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 874 17534' 98553 1003 743 343 360 181 95 Minimum 86 16122' 7332 63 71 57 75 62 38 Average 396 40479 480 396 204 224 125 68 Background 84 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to drill ahead in OA sands. Well continues to balloon sporadically. The erratic taking and giving of fluids by the hole has directly affected calculated lag,and therefore the cuttings samples and cuttings gas cannot be as accurately attributed/assigned to specific depths during these periods. Samples consist primarily of unconsolidated to occasional cuttings of calcareously cemeneted sandstone. There are small amounts of siltstone,silty sandstone,and sandy siltstone. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 il-11^1-1-11113LJ k _ Morning Report Report#2 lapoevy t3roHtrrg, Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 18130' Well: S132-W2 Daily Charges: Current Depth: 18350' Area: Spy Island Total Charges: 24 Hour Progress: 220' Location: North Slope Rig Activity: BROOH Date: 11-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM _ _ ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr) 215.6 303.3 18247' Flow In ..m) 459 SPP •si) 2088 ---- Flow In(spm) 108 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg)ZEE Min Max 18130' to 18350' Xceed 675,EcoScope 675,TeleScope 675,sonicVision 675 11.75 11.44 11.91 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T pe in out (sec/gt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 18350' PrimoFaze 9.40 9.40 47 67/33 14 16 - 1.30 1.7 5.2 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 - 9407' -_-- _.,,w Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L 80 9 5/8" 9387' HYDRIL 10.0 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 671 18304' 74955 883 720 345 375 196 105 Minimum 182 18149' 16990 282 302 174 202 124 67 Average 479 49751 623 531 266 294 159 86 Background - Trip 454 Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to drill ahead in OA sands to final TD of 18350'MD. Back ream out of the hole per K&M. Samples consist primarily of unconsolidated to occasional cuttings of calcareously cemented sandstone. There are small amounts of siltstone,silty sandstone,and sandy siltstone. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 ""35: HALl.�ISI.lRTC31V �; Morning R . fl i Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 18350' Well: S132-W2 Daily Charges: Current Depth: 18350' I Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: RIH to spot breaker Date: 12-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In(•im) SPP is') ---- Flow In(spm) Gallons/stroke 4.23 @ 0.96 ..::ww —.-:::::::=7::::::_77------:._, . . . 11 ., ..�Y_ _.:, _i.: ..- � __ . MWD Summary Depth Tools ECD (ppg) Min Max to Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 18350' PrimoFaze 9.40 9.40 47 67/33 14 17 3.8 1.10 1.43 5.93 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 44.30 9407' 18350' 8943' 10 160 1-2-BT-X-1-WT-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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 17 Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to back ream out of the hole per K&M. Lay down BHA#5. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 HALILiBLIFtTClN Morning Report Report#23 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 18350' Well: SI32-W2 Daily Charges: Current Depth: 18350' Area: Spy Island Total Charges: 24 Hour Progress: 0' ! Location: North Slope Rig Activity: Prep to spot breaker Date: 13-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr ---- Flow In (..m) 165 SPP (psi 605 ---- How In s•m) 39 Gallons/stroke 4.23 @ 0.96 MWD Summary Depth Tools ECD (ppg) Avg Min Max to Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) m1/30min (lb/bbl) % 18350' PrimoFaze 9.40 9.40 46 67/33 12 21 - 1.30 1.69 5.93 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 44.30 9407' 18350' 8943' 10 160 1-2-BT-X-1-WT-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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: Make up BHA#6. Run in the hole,filling every 20 stands. Circulate and condtion mud once on bottom on preparation for spotting the breaker. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 Morning Report Report#2': Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 18350' Well: SI32-W2 Daily Charges: Current Depth: 18350' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: Prepare to POOH Date: 14-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM 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) Avg Min Max to Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 18350' PrimoFaze 9.40 9.40 46 67/33 12 22 - 1.10 1.43 6.47 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 44.30 9407' 18350' 8943' 10 160 1-2-BT-X-1-WT-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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: Spot breaker on bottom. Pull out of the hole on elevators to 9137'MD. Circulate and condition mud prior to displacing to KCI/NaCI brine. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 i"1"1..L.,1E3L.l1RTC.INI Morning Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterday's Depth: 18350' Well: Sl32-W2 Daily Charges: Current Depth: 18350' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: RIH w/4.5"injection liner Date: 15-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM 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 to Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 18350' KCI/NaCI Brine 9.15 -- ------ Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 44.30 9407' 18350' 8943' 10 160 1-2-BT-X-1-WT-TD _,.. _- Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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: Pull out of the hole and lay down 4.5"drill pipe singles. Lay down BHA#5. Rig up casing. Run in the hole with 4.5" injection liner. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 Morning Report Report#26 Customer: ENI Petroluem Job No.: AK-AM-0009957248 Yesterdays Depth: 18350' Well: S132-W2 Daily Charges: Current Depth: 18350' Area: Spy Island Total Charges: 24 Hour Progress: 0' Location: North Slope Rig Activity: POOH Date: 16-May-2013 Rig: Doyon 15 Report For: Ross/Amend/Buchanan Time: 12:00 AM 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 to Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T pe in out (sec/gt) Ratio cP (Ib/100ft2) ml/30min (Ib/bbl) % 18350' KCI/NaCI Brine 9.20 27 ------ Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 52.80 2821' 9407' 6586' 12 160 1-1-BT-A-X-1-NO-TD 3 Smith MDSi616 BPX PDC 8.75" 0.902 44.30 9407' 18350' 8943' 10 160 1-2-BT-X-1-WT-TD Size Set At Type Weight Grade Comments Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 2806' LTC 68.0 L-80 9 5/8" 9387' HYDRIL 10.0 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) I 24 hr Recap: Continue to run in the hole with 4.5"injection liner. Set liner at 18327'MD. Pull out of the hole. Logging Engineers: Emil Opitz/Clifton Posey Report By: Emil Opitz Unit Phone: 907-685-0772 i HALLIBURTON ( Sperry Drilling WELL INFORMATION Customer : Eni Petroleum Survey Report Well Name : SI32-W2 Job Number : AK-XX-0009957284 Rig Name : Doyon 15 Field Name : Nikaitchuq Country : USA DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E t Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 40.52 0.00 0.00 40.52 0.00 N 0.00 E 0.00 0.00 138.75 0.39 306.00 138.75 0.20 N 0.27 W 0.16 0.40 169.59 0.34 291.84 169.59 0.29 N 0.44 W 0.28 0.33 203.96 0.39 226.50 203.96 0.25 N 0.62 W 0.46 1.15 235.33 0.84 188.61 235.33 0.05 S 0.73 W 0.68 1.86 264.02 1.20 185.34 264.01 0.56 S 0.79 W 0.95 1.27 298.66 1.93 181.38 298.64 1.50 S 0.84 W 1.40 2.13 329.62 2.74 173.50 329.57 2.76 S 0.77 W 1.86 2.81 356.72 3.15 174.63 356.64 4.14 S 0.62 W 2.32 1.53 387.50 4.18 173.98 387.35 6.10 S 0.43 W 2.97 3.35 418.73 4.13 172.97 418.50 8.35 S 0.17 W 3.68 0.28 449.54 5.04 169.84 449.21 10.78 S 0.20 E 4.37 3.06 480.49 5.76 168.07 480.03 13.64 S 0.76 E 5.07 2.39 511.59 6.26 171.08 510.95 16.84 S 1.35 E 5.89 1.90 542.37 6.44 172.54 541.55 20.21 S 1.83 E 6.88 0.79 569.64 6.76 173.90 568.63 23.32 S 2.20 E 7.86 1.31 600.40 7.47 177.07 599.16 27.12 S 2.50 E 9.20 2.64 635.21 8.53 179.60 633.63 31.96 S 2.63 E 11.12 3.21 664.51 10.06 178.56 662.54 36.69 S 2.71 E 13.05 5.25 728.60 13.25 181.58 725.30 49.64 S 2.65 E 18.58 5.07 821.88 17.20 184.71 815.29 74.08 S 1.22E 30.20 4.32 879.28 19.51 185.40 869.77 92.08 S 0.38 W 39.26 4.04 972.66 21.66 184.44 957.18 124.79 S 3.18 W 55.62 2.33 1066.05 22.91 183.20 1,043.60 160.12 S 5.53 W 72.68 1.43 1159.38 25.44 182.88 1,128.73 198.29 S 7.55 W 90.64 2.71 1252.74 28.23 182.34 1,212.03 240.38 S 9.46 W 110.16 3.00 1346.01 27.64 184.93 1,294.44 283.98 S 12.22 W 131.09 1.45 1439.33 29.93 183.36 1,376.22 328.80 S 15.44 W 152.95 2.58 1532.66 32.60 181.83 1,455.99 377.18 S 17.61 W 175.36 2.98 1626.05 31.90 182.26 1,534.97 426.98 S 19.39 W 198.02 0.79 1719.42 32.07 182.95 1,614.17 476.38 S 21.64 W 220.94 0.43 Job No: AK-XX-0009957284 Well Name: SI32-W2 Survey Report INSITE V7.4.20 Page 1 i t__ HALLIBURTON I Sperry Drilling ''''` DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 1812.84 32.22 182.45 1,693.27 526.03 S 23.98 W 244.04 0.33 1906.20 32.56 182.54 1,772.10 576.00 S 26.16 W 267.13 0.37 1999.61 34.42 182.27 1,850.00 627.49 S 28.32 W 290.85 2.00 2092.96 37.46 183.24 1,925.57 682.21 S 30.97 W 316.38 3.31 2186.42 39.08 184.72 1,998.95 739.95 S 35.00 W 344.43 1.99 2279.82 43.56 186.38 2,069.08 801.31 S 41.00 W 375.80 4.94 2373.19 47.16 190.62 2,134.69 866.96 S 50.89 W 412.51 5.03 2466.59 49.73 197.74 2,196.69 934.62 S 68.07 W 456.68 6.33 2559.96 50.83 203.47 2,256.38 1,001.78 S 93.35 W 507.98 4.86 2653.39 50.44 209.67 2,315.67 1,066.33 S 125.62 W 564.50 5.15 2737.12 49.87 213.90 2,369.33 1,120.96 S 159.46 W 618.26 3.94 2819.19 49.67 218.07 2,422.35 1,171.64 S 196.26 W 673.03 3.89 2912.52 51.60 223.98 2,481.58 1,226.00 S 243.62 W 738.92 5.31 3005.85 52.50 229.10 2,539.00 1,276.57 S 297.02 W 808.70 4.43 3099.14 53.74 232.34 2,594.99 1,323.79 S 354.78 W 881.00 3.08 3192.40 56.69 235.48 2,648.20 1,368.87 S 416.68 W 956.15 4.20 3285.85 59.08 237.55 2,697.88 1,412.51 S 482.69 W 1034.42 3.17 3380.10 60.94 238.73 2,744.99 1,455.59 S 552.02 W 1115.46 2.25 3472.41 62.84 239.16 2,788.48 1,497.59 S 621.77 W 1196.43 2.10 3565.71 64.54 239.29 2,829.83 1,540.38 S 693.63 W 1279.64 1.83 3659.50 67.38 238.89 2,868.04 1,584.38 S 767.11 W 1364.83 3.05 3752.43 71.08 238.97 2,900.99 1,629.21 S 841.52 W 1451.21 3.98 3845.74 75.16 239.04 2,928.07 1,675.18 S 918.05 W 1540.00 4.37 3939.16 78.07 239.17 2,949.70 1,721.84 S 996.02 W 1630.39 3.12 4032.51 80.60 239.27 2,966.97 1,768.79 S 1,074.83 W 1721.65 2.71 4125.82 82.66 238.62 2,980.56 1,816.41 S 1,153.91 W 1813.45 2.31 4219.46 82.82 239.34 2,992.39 1,864.27 S 1,233.52 W 1905.82 0.78 4312.77 83.24 239.93 3,003.71 1,911.09 S 1,313.43 W 1998.04 0.77 4406.06 83.32 240.46 3,014.63 1,957.15 S 1,393.83 W 2090.36 0.57 4499.34 83.22 241.32 3,025.56 2,002.21 S 1,474.76 W 2182.76 0.92 4592.59 83.44 242.52 3,036.39 2,045.81 S 1,556.48 W 2275.24 1.30 4685.91 83.52 243.42 3,046.99 2,087.94 S 1,639.06 W 2367.90 0.96 4779.29 83.40 243.98 3,057.62 2,129.05 S 1,722.23 W 2460.65 0.61 4872.61 83.29 243.93 3,068.44 2,169.75 S 1,805.51 W 2553.32 0.13 4965.93 83.12 244.14 3,079.48 2,210.32 S 1,888.82 W 2645.98 0.29 5059.32 83.81 244.29 3,090.11 2,250.68 S 1,972.37 W 2738.75 0.76 5152.67 83.33 243.34 3,100.56 2,291.61 S 2,055.61 W 2831.49 1.13 5246.01 83.35 243.24 3,111.39 2,333.28 S 2,138.43 W 2924.16 0.11 5339.28 82.40 242.35 3,122.96 2,375.59 S 2,220.74 W 3016.64 1.39 5432.51 82.17 242.18 3,135.47 2,418.58 S 2,302.51 W 3108.92 0.31 5525.95 81.75 241.94 3,148.54 2,461.94 S 2,384.24 W 3201.32 0.52 5619.26 81.66 242.11 3,162.00 2,505.25 S 2,465.79 W 3293.53 0.20 5712.57 82.04 241.98 3,175.23 2,548.55 S 2,547.38 W 3385.77 0.43 5806.15 81.69 242.13 3,188.47 2,591.96 S 2,629.21 W 3478.29 0.41 5899.22 81.61 241.90 3,201.99 2,635.17 S 2,710.53 W 3570.25 0.26 Job No AK-XX-0009957284 Well Name: S132-W2 Survey Report INSITE V7.4.20 Page 2 F HALLIBURTON I Sperry oruu.,g ; DIRECTIONAL SURVEY DATA W-• Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°I100') 5992.44 81.71 241.88 3,215.51 2,678.63 S 2,791.89 W 3662.35 0.11 6085.73 81.44 241.66 3,229.18 2,722.28 S 2,873.19 W 3754.48 0.37 6178.99 81.32 240.50 3,243.16 2,766.87 S 2,953.90 W 3846.47 1.24 6272.29 81.35 241.41 3,257.22 2,811.65 S 3,034.53 W 3938.48 0.96 6365.33 81.58 240.92 3,271.02 2,856.02 S 3,115.13 W 4030.28 0.58 6458.88 81.16 240.79 3,285.06 2,901.07 S 3,195.91 W 4122.53 0.47 6552.28 81.51 240.90 3,299.13 2,946.05 S 3,276.55 W 4214.62 0.39 6645.66 81.43 240.70 3,312.98 2,991.10 S 3,357.16 W 4306.72 0.23 6739.00 81.75 240.39 3,326.63 3,036.51 S 3,437.56 W 4398.77 0.47 6832.43 81.54 240.29 3,340.21 3,082.25 S 3,517.89 W 4490.91 0.25 6925.76 81.89 241.69 3,353.66 3,127.04 S 3,598.66 W 4583.03 1.53 7019.03 81.05 242.82 3,367.49 3,169.98 S 3,680.29 W 4675.16 1.50 7112.30 80.78 243.97 3,382.22 3,211.22 S 3,762.63 W 4767.23 1.25 7205.71 80.26 245.10 3,397.61 3,250.84 S 3,845.81 W 4859.36 1.32 7299.10 81.32 248.58 3,412.56 3,287.08 S 3,930.56 W 4951.48 3.85 7392.38 81.69 252.09 3,426.34 3,318.12 S 4,017.42 W 5043.32 3.74 7485.73 81.68 254.88 3,439.85 3,344.38 S 4,105.97 W 5134.67 2.96 7579.11 81.53 257.44 3,453.48 3,366.48 S 4,195.66 W 5225.29 2.72 7672.50 82.33 259.98 3,466.59 3,384.57 S 4,286.33 W 5315.11 2.83 7765.83 83.44 264.14 3,478.16 3,397.36 S 4,378.03 W 5403.63 4.58 7859.19 83.44 266.63 3,488.83 3,404.82 S 4,470.47 W 5490.56 2.65 7952.46 83.27 271.14 3,499.62 3,406.62 S 4,563.07 W 5575.25 4.81 8045.83 82.87 273.75 3,510.89 3,402.67 S 4,655.66 W 5657.50 2.81 8139.17 82.87 276.64 3,522.48 3,394.29 S 4,747.89 W 5737.54 3.07 8232.50 83.28 280.18 3,533.74 3,380.74 S 4,839.53 W 5814.87 3.79 8325.87 82.11 281.82 3,545.61 3,363.07 S 4,930.44 W 5889.79 2.15 8419.29 83.60 284.30 3,557.23 3,342.12 S 5,020.72 W 5962.76 3.08 8512.65 84.37 288.13 3,567.02 3,316.20 S 5,109.86 W 6032.59 4.16 8606.06 84.73 290.75 3,575.89 3,285.25 S 5,197.54 W 6098.98 2.82 8699.41 85.00 294.83 3,584.25 3,249.25 S 5,283.23 W 6161.43 4.36 8792.87 84.89 297.62 3,592.49 3,208.11 S 5,366.74 W 6219.72 2.98 8886.27 85.82 300.87 3,600.05 3,162.64 S 5,447.95 W 6274.11 3.61 8979.64 86.61 304.38 3,606.22 3,112.41 S 5,526.41 W 6323.99 3.85 9073.04 87.63 308.24 3,610.91 3,057.19 S 5,601.56 W 6368.76 4.27 9166.41 87.31 309.66 3,615.03 2,998.55 S 5,674.10 W 6409.72 1.56 9259.75 87.66 308.55 3,619.13 2,939.73 S 5,746.46 W 6450.45 1.25 9353.49 87.72 308.47 3,622.91 2,881.41 S 5,819.75 W 6492.23 0.11 9363.17 87.81 308.58 3,623.28 2,875.39 S 5,827.32 W 6496.54 1.47 9398.40 87.87 310.08 3,624.61 2,853.08 S 5,854.55 W 6511.79 4.26 9491.70 88.23 308.43 3,627.79 2,794.08 S 5,926.75 W 6552.29 1.81 9585.01 88.70 308.49 3,630.29 2,736.06 S 5,999.79 W 6593.97 0.51 9678.26 90.63 308.95 3,630.83 2,677.74 S 6,072.54 W 6635.25 2.13 9771.56 91.05 311.42 3,629.46 2,617.54 S 6,143.81 W 6674.40 2.69 9864.97 90.90 312.93 3,627.87 2,554.84 S 6,213.02 W 6710.63 1.62 9958.26 90.50 313.75 3,626.73 2,490.82 S 6,280.86 W 6745.06 0.98 Job No: AK-XX-0009957284 Well Name: S132-W2 Survey Report INSITE V7.4.20 Page 3 HALLIBURTON I Sperry oh'rw.,g >; DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 10051.71 89.98 314.04 3,626.34 2,426.03 S 6,348.20 W 6778.71 0.64 10144.97 89.87 315.17 3,626.47 2,360.54 S 6,414.60 W 6811.21 1.22 l 10238.39 89.29 315.01 3,627.15 2,294.38 S 6,480.55 W 6843.02 0.64 10331.78 90.67 313.70 3,627.18 2,229.09 S 6,547.32 W 6875.95 2.04 10425.11 91.24 312.31 3,625.63 2,165.45 S 6,615.56 W 6910.90 1.61 10518.48 90.15 312.63 3,624.49 2,102.41 S 6,684.43 W 6946.67 1.22 10611.78 88.10 311.83 3,625.92 2,039.71 S 6,753.50 W 6982.77 2.36 10705.06 87.80 311.42 3,629.26 1,977.79 S 6,823.19 W 7019.76 0.54 10798.34 88.00 307.07 3,632.68 1,918.83 S 6,895.36 W 7060.25 4.67 10891.78 88.14 306.66 3,635.82 1,862.81 S 6,970.07 W 7104.29 _ 0.46 10985.15 90.44 307.33 3,636.98 1,806.63 S 7,044.64 W 7148.12 2.57 11078.42 88.87 307.59 3,637.54 1,749.91 S 7,118.67 W 7191.25 1.71 11171.77 90.57 307.55 3,638.00 1,692.99 S 7,192.66 W 7234.25 1.82 11265.10 90.81 310.33 3,636.87 1,634.34 S 7,265.24 W 7275.24 2.99 11358.40 92.32 311.56 3,634.33 1,573.23 S 7,335.68 W 7313.26 2.09 11451.76 92.01 311.22 3,630.80 1,511.54 S 7,405.67 W 7350.62 0.49 11543.80 90.41 310.19 3,628.86 1,451.53 S 7,475.43 W 7388.48 2.07 11638.33 90.70 308.28 3,627.94 1,391.75 S 7,548.64 W 7429.57 2.04 11731.66 90.33 307.27 3,627.10 1,334.58 S 7,622.40 W 7472.26 1.15 11825.04 91.11 307.60 3,625.93 1,277.82 S 7,696.55 W 7515.47 0.91 11918.50 92.22 306.70 3,623.21 1,221.41 S 7,771.00 W 7559.11 1.53 12011.84 94.02 308.04 3,618.13 1,164.84 S 7,845.07 W 7602.33 2.40 12105.13 93.03 308.92 3,612.40 1,106.90 S 7,917.96 W 7643.91 1.42 12198.41 91.42 309.62 3,608.77 1,047.91 S 7,990.12 W 7684.37 1.88 12291.81 89.51 308.31 3,608.02 989.18 S 8,062.73 W 7725.36 2.48 12385.14 89.09 306.95 3,609.16 932.20 S 8,136.64 W 7768.26 1.52 12478.47 88.86 306.28 3,610.83 876.55 S 8,211.54 W 7812.63 0.76 12571.76 89.11 304.91 3,612.48 822.26 S 8,287.38 W 7858.42 1.49 12665.02 90.09 304.24 3,613.13 769.33 S 8,364.17 W 7905.65 1.27 12758.47 92.57 304.53 3,610.96 716.58 S 8,441.26 W 7953.22 2.67 12851.81 93.40 305.73 3,606.10 662.94 S 8,517.50 W 7999.64 1.56 12945.03 91.16 305.11 3,602.39 608.96 S 8,593.40 W 8045.62 2.49 13038.33 88.99 304.97 3,602.27 555.40 S 8,669.78 W 8092.21 2.33 13131.70 89.95 305.91 3,603.13 501.26 S 8,745.85 W 8138.27 1.44 13225.05 90.96 308.62 3,602.39 444.74 S 8,820.13 W 8181.71 3.10 13318.36 91.24 310.68 3,600.60 385.22 S 8,891.96 W 8221.65 2.23 13411.73 89.48 310.69 3,600.01 324.35 S 8,962.76 W 8260.09 1.88 13505.13 89.24 309.94 3,601.06 263.93 S 9,033.97 W 8299.10 0.84 13598.44 88.99 311.72 3,602.50 202.93 S 9,104.56 W 8337.30 1.93 13692.08 87.93 311.39 3,605.02 140.84 S 9,174.61 W 8374.54 1.19 13785.39 88.21 309.96 3,608.16 80.06 S 9,245.33 W 8412.95 1.56 13878.68 88.17 311.05 3,611.10 19.50 S 9,316.23 W 8451.61 1.17 13971.96 88.50 310.46 3,613.81 41.37 N 9,386.86 W 8489.90 0.72 14065.21 89.84 310.41 3,615.17 101.85 N 9,457.83 W 8528.66 1.44 14158.53 90.64 310.52 3,614.77 162.41 N 9,528.83 W 8567.41 0.87 Job No AK-XX-0009957284 Well Name: S132-W2 Survey Report INSITE V7.4.20 Page 4 HALLIBURTON ( Sperry❑rmng i DIRECTIONAL SURVEY DATA Il' Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg 1 (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°1100') u, 14251.91 91.13 311.49 3,613.33 223.67 N 9,599.29 W 8605.38 1.16 14345.23 91.24 311.68 3,611.40 285.59 N 9,669.07 W 8642.46 0.24 14438.55 91.30 313.07 3,609.33 348.47 N 9,737.99 W 8678.35 1.49 14531.81 91.09 315.08 3,607.39 413.33 N 9,804.98 W 8711.64 2.17 14625.29 91.25 314.99 3,605.48 479.45 N 9,871.02 W 8743.56 0.20 14718.63 90.44 314.04 3,604.10 544.89 N 9,937.57 W 8776.22 1.34 14811.90 90.00 313.46 3,603.75 609.38 N 10,004.95 W 8810.02 0.78 14905.13 90.18 313.04 3,603.60 673.26 N 10,072.85 W 8844.57 0.49 14998.57 90.32 314.24 3,603.19 737.74 N 10,140.47 W 8878.60 1.29 15091.88 90.56 315.26 3,602.48 803.43 N 10,206.74 W 8910.90 1.12 15185.19 92.04 315.88 3,600.36 870.05 N 10,272.04 W 8941.93 1.72 15278.50 93.20 318.87 3,596.09 938.62 N 10,335.15 W 8970.15 3.43 15371.84 91.17 319.44 3,592.53 1,009.18 N 10,396.15 W 8995.61 2.26 15465.06 90.22 318.40 3,591.40 1,079.44 N 10,457.40 W 9021.43 1.51 15558.35 90.28 317.96 3,591.00 1,148.96 N 10,519.61 W 9048.42 0.48 15651.61 91.20 318.41 3,589.79 1,218.46 N 10,581.78 W 9075.40 1.10 15744.91 90.98 317.00 3,588.02 1,287.46 N 10,644.55 W 9103.13 1.53 15838.17 90.89 315.05 3,586.49 1,354.56 N 10,709.29 W 9133.45 2.09 15932.11 89.45 313.06 3,586.22 1,419.88 N 10,776.80 W 9167.03 2.61 16024.90 89.47 312.83 3,587.09 1,483.09 N 10,844.72 W 9201.87 0.25 16118.28 90.91 312.93 3,586.78 1,546.63 N 10,913.15 W 9237.03 1.55 16211.62 91.33 314.46 3,584.96 1,611.10 N 10,980.62 W 9270.94 1.70 16305.05 91.07 313.98 3,583.00 1,676.24 N 11,047.56 W 9304.08 0.58 16398.82 90.50 315.24 3,581.71 1,742.09 N 11,114.31 W 9336.74 1.47 16491.65 89.88 313.44 3,581.41 1,806.97 N 11,180.70 W 9369.49 2.05 16584.92 90.23 313.60 3,581.32 1,871.19 N 11,248.33 W 9403.65 0.41 16678.33 89.08 313.76 3,581.88 1,935.70 N 11,315.88 W 9437.61 1.24 16771.72 89.14 314.36 3,583.33 2,000.64 N 11,382.99 W 9470.98 0.65 16865.00 88.05 315.85 3,585.62 2,066.69 N 11,448.80 W 9502.71 1.98 16958.35 88.33 317.16 3,588.57 2,134.38 N 11,513.02 W 9532.31 1.43 17051.73 89.66 317.09 3,590.20 2,202.80 N 11,576.55 W 9560.97 1.43 17145.12 87.60 320.34 3,592.44 2,272.94 N 11,638.14 W 9587.14 4.12 17238.45 89.27 318.88 3,594.99 2,344.00 N 11,698.59 W 9611.90 2.38 17331.81 88.97 317.93 3,596.42 2,413.81 N 11,760.56 W 9638.56 1.07 17425.08 89.18 316.98 3,597.93 2,482.51 N 11,823.61 W 9666.67 1.04 17518.40 89.53 317.05 3,598.98 2,550.77 N 11,887.24 W 9695.49 0.38 17611.73 89.55 317.34 3,599.73 2,619.25 N 11,950.65 W 9724.02 0.31 17705.12 89.45 316.80 3,600.54 2,687.62 N 12,014.26 W 9752.77 0.59 17798.49 90.19 317.23 3,600.83 2,755.92 N 12,077.92 W 9781.60 0.92 17891.91 88.79 317.36 3,601.67 2,824.57 N 12,141.27 W 9810.01 1.51 17985.27 89.10 316.56 3,603.39 2,892.79 N 12,204.98 W 9838.92 0.92 18078.68 88.85 316.30 3,605.06 2,960.46 N 12,269.35 W 9868.66 0.39 18171.85 89.57 316.96 3,606.34 3,028.18 N 12,333.33 W 9898.02 1.05 18265.49 89.29 319.22 3,607.27 3,097.86 N 12,395.87 W 9925.25 2.43 18282.74 89.62 319.34 3,607.44 3,110.93 N 12,407.12 W 9929.93 2.04 I Job No: AK-XX-0009957284 Well Name: S132-W2 Survey Report INSITE V7.4.20 Page 5
