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Home My WebLink About213-101MEMORANDUM 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 SI35-W4 NIKAITCHUQ SI35-W4 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 SI35-W4 50-629-23494-00-00 213-101-0 W SPT 3548 2131010 1500 57 52 57 56 80 210 220 220 4YRTST P Sully Sullivan 4/15/2025 Talked with operator about fluid packing wells 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 SI35-W4 Inspection Date: Tubing OA Packer Depth 14 1715 1678 1668IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250416121700 BBL Pumped:12.6 BBL Returned:7.6 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 12:45:21 -08'00' MEMORANDUM State of Alaska Packer Alaska Oil and Gas Conservation Commission TO: Jim Regg � ,� P.I. Supervisor �7�1¢I� DATE: Wednesday, May 5, 2021 SUBJECT: Mechanical Integrity Tests k+ -TVD Em US Operating Company Inc. 478 479 S135 -W4 FROM: Guy Cook NIKAITCHUQ 5135-W4 Petroleum Inspector 1c1)0 - IA 828 1727 Sre: Inspector BBL Pumped: Reviewed By; BIIL P.I. Supry pn NON -CONFIDENTIAL Comm Well Name NIKAITCHUQ S135 -W4 Insp Num: mi[ODC210501113720 Rel Insp Num: API Well Number 50-629-23494-00-00 Inspector Name: Guy Cook Permit Number: 213-101-0 Inspection Date: 4/30/2021 - Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer yo L1 Wednesday, May 5, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S135W4 'Typelnj k+ -TVD .54s Tubing 478 479 478 478 PTD 2131010 -ITypeTest s1'1 ,test psi 1c1)0 - IA 828 1727 1707 1702 BBL Pumped: 23 - BIIL Returned: OA 140 90 - vo - so - Interval avRTST IP/F 1' / Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer yo L1 Wednesday, May 5, 2021 Page I of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 03,2017 TO: pgg P.I.Supervisor ��1 SUBJECT: Mechanical Integrity Tests PI. 1��'�G�� J�'1' ENI US OPERATING CO INC SI35-W4 FROM: Adam Earl NIKAITCHUQ SI35-W4 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry�QR-- NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ S135-W4API Well Number 50-629-23494-00-00 Inspector Name: Adam Earl Permit Number: 213-101-0 Inspection Date: 9/27/2017 Insp Num: mitAGE170927190452 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI35-W4 - Type Inj W TVD 3548 " Tubing 382 - 382 - 382 • 382 - PTD 2131010 ' Type Test SPT Test psi 1500 IA 20 1654 - 1629 " 1618 - BBL Pumped: ; 4.6 - IBBL Returned: 4.1 OA 170 340 - 320 - 315 - Intervali 4YRTST P/F P ✓ — Notes: MIT-IA ,CANNES) ...,b N 4 `.[V Tuesday,October 03,2017 Page 1 of 1 1 lib .,.., • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 30,2013 TO: Jim Regg n I _-I P.I.Supervisor S ( 3 SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC SI35-W4 1 FROM: Bob Noble NIKAITCHUQ SI35-W4 Petroleum Inspector Src: Inspector Reviewed By: 1 P.I.Suprv. J �c NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ Sl35-W4 API Well Number 50-629-23494-00-00 Inspector Name: Bob Noble Permit Number: 213-101-0 Inspection Date: 10/25/2013 Insp Num: mitRCN131028135529 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T YP J w 3548 IA 1091 1655 1646 - i 1646 ' - . -- ell 2131010 Type In Test sty - — - -_ SPT I 1500 T OA ' 190 - 210 -I 210 205 H 1 PTD Type Test P 1 INITAL P 449 449 448 449 Interval P/F Tubing Notes: Wednesday,October 30,2013 Page 1 of 1 2"505 HALLIBURTOI\ RECEIVED OCT 282013 Sperry Drilling AOGCC To: Alaska Oil and Gas Conversation Commission DATA LOGGED / /2013 333 W 7t" Ave Suite 100 M K BENDER Anchorage, AK 99501 Attn: Howard Oakland From: Sperry Drilling - Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfielda.Halliburton.com Re: Eni Well — S135-W4 AFE # 6178 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 Sign Name IA/12-113 Date Please sign acknowledgement of receipt - email, fax, or mail back, Thank you. RECEIVED r ` STATE OF ALASKA OCT 11 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 466CC la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory U • GINJ ❑ WINJ❑., . WAG ❑ WDSPL❑ No.of Completions: .r Service 2Stratigraphic Test [112.Operator Name: 5.pate Comp.,Sus o,�r .� 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: - 7 tf 43•-• 213-101 • 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 8/28/2013 50-629-23494-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4427.3 FSL 1491.2 FEL S19 T14N R9E UM 9/21/2013 SI35-W4 • Top of Productive Horizon: 8.KB(ft above MSL): 53.8 • 15.Field/Pool(s): 43 FSL 3865 FEL 24 T14N R8EUMGL(ft above MSL): 13.1 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 387 FSL 5206 FEL 14 T14N R8EUM N/A ' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: • Surface: x- 511418.73 y- 6053608.81 Zone- 4 19932'MD/3621'TVD • ADL 0391283, 0388575, 0388574 TPI: x- 503968.45 y- 6049217.60 Zone- 4 • 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 497342.53 y- 6054839.35 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) N/A (ft MSL) 1990 MD/ 1751 TVD 21.Logs Obtained(List all logs herend submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic (13AnN/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 36.85 3160 36.85 2404 16 10.7 ppg ASL: 478 bbls N/A 12.5 DIMLiteCRETE:64 bbls 9.625 40 L-80 35.53 11232 35.53 3548 12.25 12.5 ppg DeepCrete:218 bbls '' N/A 4.5 11.6 L-80 11002 19928 • 3754 3621 • 8.75 Blank Liner with ICD's N/A 24.Open to production or injection? Yes No El 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 O N /Jr... 4- l•., aw' • o.-,_-- _. 4.5 11030 10868 MD/ 3548 TVD 1,07,7i i�.'.,C: •' 11232 - !1 ZV' AA 3 Sys' 34Z l , T%/() iJw ,o �?j-` 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED y ZZ•/l( _ 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A, _- Date of Test: Hours Tested: Production for Oil-Bbl: Gas MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period .- N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q . Sidewall Cores Acquired? Yes ❑ No Q - 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 OCT 2 5 13 ,\* Form 10-407 Revised 12/2009 4 liZSIlil CONTINUED ON REVERSE Submit original only G A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? H Yes I✓No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. SV4 763 760 SV3 1151 1116 SV2 1461 1365 Permafrost-Base 1990 1751 SV1 2221 1911 Ugnu Top 2770 2221 • UG-2 Coal Bed Marker 4375 2680 Lower Ugnu 8165 3171 Schrader Bluff Top 9267 3354 N Sequence Top 9588 3408 N top 9960 3451 N bottom 10072 3462 N sequence Base 10470 3505 OA sand top 11250 3550 Formation at total depth: OA sand / 19932 3621 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Printed Name: James Wright 1 J Title: Drilling and Completion Engineering Manager Signature: d--,,t.....„,,,„ ,j._ V Phone Contact: (907)865-3328 Date: 10/10/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 C = V Z ,0 N i. F>.. fct O 0 - M V U) I C — CO-)_ QN L1J13 QOV M C 0 E Q1 \ O ++ Q 00 V 4 — 00 N o N •� Q bacn45 a 0 CL r co N r CO N C)a) L 0 M CO r 0) V) r V tD M Cr; N O O C N O c _ •5 IIIMINI ` N N. o in'7 N M CO 2 ca a) G 0 J I -0 I= Q IMP'. r N M to CO a) 0) • o: o= or � or � N0 UI 3 J O 2 .;. I •- CO a) - Eoo0000 caccac C �- N p °� `° CO `° `° .� .0 U N L 0 -x O __ 0 0 0 0 0 0 N N N N N N Q N ,� O s_ a) z 2 Q m ns 0 .- _ � � � � � � 1 C) • o 4 . X _1 H I 0 CD NCD i : CE- \ 110......_1_ -0 et — Nntiv. `6 0 oM N �„� C j 0 O so co j M 2 O O r- 2 M 4 C') H 0 w V 0 t.) ti Cn w I > 2 co O 0- r M C r• IC) i co e O ao IA d _ CO C 0 p E- CD O 2 OM _ • tt01 C Nrcp Q av • �. .a- T- r- N •'� 1 c\ N 0. ' 4\4°' M at N. Q) M t0 tD �^,• CO N O) If) t0 0) to 0) c., to r tt) N. O In �' to f" In N N. N h N N. e V' M M N N w- 6'Q Toiri _ > O O e- N M I() 31 L• � E �t I# 4t it �t �tw ' . 4°' 0000000 � D EL C NIn0rCDo0tD ID O M O r In CO r co a Oa) N• QQ G) Q Zo c, m0N0) (OItCC) 00 : ..:> Q Q v Q) Q) M 0) M v O > V O .e 0) CO N. ti tD tD In u) \ CO ca = J w - Oo � o = c00o �('� r N M In CO h 00 co 00 CO O O - 00 at Nt• C.t 4t LIt Ct 4t 0t E Z = iiic ~ 0 ;; 0 0 0 0 0 0 0 0 M M N x- - 00000000 e ID 2t --(b( Enl Petroleum company I CASING&CEMENTING REPORT Lease&Well No. SID,SI35-W4 InterMediate Casing Date 14-Sep-13 County GPB State Alaska Supv. Chant CASING RECORD-Intermediate casino TD 11250/3550 Shoe Depth: 11232/3548 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt 10 5/8 40 HY563 Davis Linch 2.74 11,232.00 11,229.26 2 9 5/8 40 L-80 HY563 Tenaris 78.50 11,229.26 11,150.76 F.Collar/jt 10 5/8 40 HY563 Davis Linch 2.94 11,150.76 11,147.82 273 jts 9 5/8 40 1-80 HY563 Tenaris 11,118.88 11,147.82 28.94 L Hanger 28.94 28.94 0.00 Totals Csg Wt.On Hook: Type Float Collar: No.Hrs to Run: 14 Csg Wt.On Slips: Type of Shoe: Casing Crew: Fluid Description: 9.2 ppg LNSD mud Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: centralizers on every joint in shoe track,every other joint to 500'above N Sand CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLS) 100 Lead Slurry Type: Accelerated Crete Type1 Blend Yield(Ft3/sack): 1.57 Density(ppg) 12.5 Volume (BBLS/sacks): 218 bbls/780 sacks Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: N/A Yield(Ft3/sack): N/A Density(ppg) 12.5 ppg Volume (BBLs/sacks): N/A Mixing/Pumping Rate(bpm): N/A N Post Flush(Spacer) N Type: N/A Density(ppg) N/A Rate(bpm): N/A Volume: N/A � Displacement: Type: Mud Density(ppg) 9.5 ppg Rate(bpm): 5 bpm Volume(actual/calculated): 466/462 FCP(psi): 2581 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 3126 Casing Rotated? Yes X No Reciprocated? _Yes x No %Returns during job 100 Cement returns to surface? _Yes x No Spacer returns?_Yes x No Vol to Surf: 0 Cement In Place At: 20:37 Date: 10/14/2013 Estimated TOC: 8,705 Method Used To Determine TOC: Calculated Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLS) Lead Slurry II Type: Yield(Ft3/sack): Density(ppg) Volume (BBLS/sacks): Mixing/Pumping Rate(bpm): Tail Slurry w Type: Yield(Ft3/sack): a Density(ppg) Volume (BBLS/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: co Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes _No %Returns during job Cement returns to surface? _Yes _No Spacer returns?_Yes _No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: 1).F.0 . En!Petroleum company CASING&CEMENTING REPORT Lease&Well No. SID,SI35-W4 Surface Casing 13 3/8 Date 2-Sep-13 County GPB State Alaska Supv. Chant CASING RECORD-Surface casing TD 3175/2410 Shoe Depth: 3160/2404 PBTD: MD/ND Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt 14 3/8 BTC Weatherford 2.51 3,160.00 3,157.47 2 13 3/8 68 L-80 BTC Tenaris 79.41 3,157.47 3,078.06 F.Collar/jt 14 3/8 BTC Weatherford 1.46 3,078.06 3,076.60 77 jts 13 3/8 68 L-80 BTC Tenaris 3,039.30 3,076.60 37.30 Hanger 14 3/8 68 BTC _ 0.45 37.30 36.85 landing jt 153/8 68 Tenaris 36.85 36.85 0.00 Totals 3,159.98 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: 11.5 Csg Wt.On Slips: Type of Shoe: Casing Crew: Wfd Fluid Description: 9.5 ppg WBM/ Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: Centralizers 5'&8'above shoe;Centralizer 10'above FC;from 3rd joint through tail slurry(500'tail slurry),2 on 13 3/8"csg collars inside conductor @TD. CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.1 Volume pumped(BBLs) 100 Lead Slurry Type: Dispersed Type1 Blend Yield(Ft3/sack): 2.42 Density(ppg) 10.7 Volume (BBLs/sacks): 478 bbls/1109 sacks Mixing/Pumping Rate(bpm): 5.5 Tail Slurry Type: Crete Type 1 Blended Yield(Ft3/sack): 1.6 Density(ppg) 12.5 ppg Volume (BBLs/sacks): 64 bbls/230 sacks Mixing/Pumping Rate(bpm): 4.0 bpm N Post Flush(Spacer) y Type: Density(ppg) Rate(bpm): Volume: 0 .. Displacement: Type: Mud Density(ppg) 9.5 ppg Rate(bpm): 5 bpm Volume(actual/calculated): 466/462 FCP(psi): 480 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 980 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during job 100 Cement returns to surface? X Yes _No Spacer returns? X Yes _No Vol to Surf: 85 bbl cmt/100 bbl spacer Cement In Place At: 19:11 Date: 9/2/2012 Estimated TOC: Surface Method Used To Determine TOC: 10.5 ppg Cement sample taken&weighed @ surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 0) Post Flush(Spacer) o Type: Density(ppg) Rate(bpm): Volume: w Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? _Yes No %Returns during job Cement returns to surface? Yes _No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: 11. * Eni E&P Division [Well Name: SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • Date:8126/2013 - Report#: 1 e API/UWI:50 629-23494-00-00 i� Wellbore name: SI35-W4 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG • Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0135-W4 DRILLING 8/28/2013 6.069.18 1,100.21 6,074.97 166.72 36.4 -1.73 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 101.0 1.1 Mostly Cloudy WC E @ 12 MPH 26' Daily summary operation 24h Summary Install D/S suitcases.Install berming around the Rig.Plug Rockwasher into rig and remove jack stands to set on CH2Mhill truck for spotting.Replace circuit breakers in junction box for rear wheel steering controls on sub complex.Set Stompers and preload.Install diverter pipe on outside of Cellar to tie into the Rig with Zoom Boom.Fit up new brake parts for Drawworks.Spot sub complex over well Sl35- W4.Spot Pit complex.Cont.fitting up brake parts for Drawworks.Skid Rig Floor,install all hand rails and roof caps.Spot Rockwasher,begin hooking up interconnects.Cont.work on driller side suitcases. Standby while SID Production trouble shoot well SP36-W5.Work on rig maintenance.work on driller side suitcases.Move Rockwasher away from Prts and spot MP#3,move Rockwasher back.R/U interconnects.Cont.work on rebuilding Iron Roughneck.Cont.working on Caustic Hopper plumbing in Pits.Work on berming around Rig.Work on D/S suit cases.Load 90 Jnts 5"D.P.in Pipe Shed. Crane Well Head and Surface Dulling Riser into BOP landing.Put 13 3/8"Hanger in Pipe Shed.Crane Iron Roughneck to Rig Floor.Cont.work on Rig maintenance.N/U Starter Head,Drilling Riser and Diverter Tee W/Vetco Grey Rep onsite.Cont.loading 5"D.P.into Pipe Shed.Load 14 Jnts.5"HWDP into Pipe Shed.MPI new Brake Linkage.Work on Rockwasher Suit Cases.Cont.work on berming. Begin installing new Brake Linkage.Cont.working on Caustic Hopper.Cont.working on Rockwasher Suit Cases.Install section of Diverter pipe. Operation at 07.00 Cont.W/R/U 24h Forecast Cont.to rig up.Finish Diverter pipe connection.Test high Press.riser.Function test Diverter stack.P/U M/U 5"D.P.and 5"HWDP.Take on Spud mud.P/U M/U BHA#1. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 01:30 1.50 1.50 MOB A 20 P PJSA Install D/S suitcases.Install berming around the Rig.Plug Rockwasher into ng and remove jack stands to set on CH2Mhill truck for spotting.Replace circuit breakers in junction box for rear wheel steering controls on sub complex. 01:30 02:30 1.00 2.50 MOB B 2 P PJSA Spot sub complex over well SI35-W4. 02:30 03.30 1.00 3.50 MOB A 20 P PJSA Set Stompers and preload.Install diverter pipe on outside of Cellar to tie into the Rig with Zoom Boom.Fit up new brake parts for Drawworks. 03:30 06:00 2.50 6.00 MOB B 2 P PJSA Spot Pit complex.Cont.fitting up brake parts for Drawworks. 06:00 07:30 t.50 7.50 MOB B 2 P PJSA Skid Rig Floor,install all hand rails and roof caps. 07:30 09:00 t.50 9.00 MOB B 2 P PJSA Spot Rockwasher,begin hooking up interconnects.Cont.work on driller side suitcases. 09:00 12:00 3.00 12.00 MOB A 20 P PJSA Standby while SID Production trouble shoot well SP36-W5.Work on ng maintenance. 12:00 16:00 4.00 16.00 MOB A 2 P PJSA Move Rockwasher away from Pits and spot MP#3,move Rockwasher back.R/U interconnects.Cont.work on rebuilding Iron Roughneck.Cont.working on Caustic Hopper plumbing in Pits.Work on berming around Rig.Work on D/S suit cases.Load 90 Jnts 5"D.P.in Pipe Shed. 16:00 17:00 1.00 17.00 MOB A 20 P PJSA Crane Well Head and Surface Dulling Riser into BOP landing.Put 13 3/8"Hanger in Pipe Shed. 17:00 18:00 1.00 18.00 MOB A 20 P PJSA Crane Iron Roughneck to Rig Floor.Cont.work on Rig maintenance. 18:00 22:00 400 22.00 MOB A 20 P PJSA N/U Starter Head,Dulling Riser and Diverter Tee W/Vetco Grey Rep onsite.Cont.loading 5"D.P.into Pipe Shed. Load 14 Jnts.5"HWDP into Pipe Shed.MPI new Brake Linkage.Work on Rockwasher Suit Cases. 22:00 00.00 2.00 24.00 MOB A 20 P PJSA Cont.work on berming.Begin installing new Brake Linkage.Cont.working on Caustic Hopper.Cont.working on Rockwasher Suit Cases.Install section of Diverter pipe. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone ENI Project Manager Eni representative Nelson Carballo ENI Dilling Supenntenda Eni 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 Wein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rigt5@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(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kV/cm.) • 11* Eni E&P Division [Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report 'Well Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 2^g Date:8/27/2013 - Report#: 2 I' II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI35-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6.074.97 166.72 36.4 -0.73 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 99.0 2.8 Mostly Cloudy WC E©6 MPH 32" Daily summary operation 24h Summary Cont.installing suit cases on ODS.Cont.installing Brake Linkage.Cont.installing Caustic Hopper.Press.test DS suit cases.Install Cutting Box.Install slurry pump piping in RacImasher.Press.test Rockwasher suit case lines.Welding Centrifuge discharge line in Pits.Cont.work on Caustic Hopper.Install lids on suit cases.Adjust Brake Linkage.N/U Bell Nipple,flow line and turn buckles on BOPE. Install ST-80 into centering hole on the rig floor.Weld Diverter in Cellar.Cont.welding discharge in Pits.Cont.welding Diverter Pup in Cellar.Vetco Grey Rep test seals to 500 PSI for 10 Min.Install screens on Shakers.Check slurry pump function in Rockwasher.Remove all old 5"D.P.from Pipe Shed.Press.test cement lines to 1,000 PSI low and 4,500 PSI high.Install flow line.Perform Diverter test.Press.before function=2,900 PSI,after 1,650 PSI.200 PSI increase 36 Sec.total recharge time 148 Sec.Knife Valve open in 21 Sec.Annular closed in 32 Sec.Total Diverter line length 395'.Test waived by AOGCC Rep Bob Noble.Perform dummy run 13 3/8"Hanger as per Vetco Grey Rep onsite.RKB landing ring load shoulder 36.85'.Load 90 Jnts new 5"D.P.&14 Jnts 5"HWDP.Load BHA tools in Pipe Shed.Begin breaking in brakes on Drawworks.Took on 740 bbl 8.65 ppg Spud Mud from Mud Plant. Operation at 07.00 P/U M/U BHA#1. 24h Forecast P/U M/U 5"D.P.and HWDP.P/U M/U BHA#1 as per Sclumberger DD&MWD.Clean out 20"Conductor to 150'.POOH P/U M/U BHA#2 and drill 16"surface hole as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00'MOB A 20 P PJSA Cont.installing suit cases on ODS.Cont.installing Brake Linkage.Cont.installing Caustic Hopper.Press.test DS suit cases.Install Cutting Box.Install slurry pump piping in Rackwasher.Press.test Rockwasher suit case lines. 06:00 10:00 4.00 10.00 MOB A 20 P PJSA Welding Centrifuge discharge line in Pits.Cont.work on Caustic Hopper.Install lids on suit cases.Adjust Brake Linkage. 10:00 11:00 1.00 11.00 MOB A 20 P PJSA N/U Bell Nipple,flow line and turn buckles on BOPE. 11:00 12:00 1.00 12.00'MOB A 20 P PJSA Install ST-80 into centering hole on the ng floor.Weld Diverter in Cellar.Cont.welding discharge in Pits. 12:00 19:00 7.00 19.00 MOB A 20 P PJSA Cont.welding Diverter Pup in Cellar.Vetco Grey Rep test seals to 500 PSI for 10 Min.Install screens on Shakers. Check slurry pump function in Rockwasher.Remove all old 5"D.P.from Pipe Shed.Press.test cement lines to 1,000 PSI low and 4,500 PSI high.Install flow line. • 19:00 20:00 1.00 20.00 MOB C 12 P PJSA Perform Diverter test.Press.before function=2,900 PSI.after 1,650 PSI.200 PSI increase 36 Sec.total recharge time 148 Sec.Knife Valve open in 21 Sec.Annular closed in 32 Sec.Total Diverter line length 395'.Test waived by AOGCC Rep Bob Noble. 20:00 20:30 0.50 20.50 MOB C 20 P PJSA Perform dummy run 13 3/8"Hanger as per Vetco Grey Rep onsite.RKB landing ring load shoulder 36.85'. 20:30 00:00 3.50 24.00 MOB A 20 P PJSA Load 90 Jnts new 5"D.P.&14 Jnts 5"HWDP.Load BHA tools in Pipe Shed.Begin breaking in brakes on Drawworks.Took on 740 bbl 8.65 ppg Spud Mud from Mud Plant. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Torn 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 ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division `Well Name:SI35-W4 fa* ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq • API/1MA:50-6629-23494-00-00 2^n Date:8/28/2013 - Report#: 3 'I II II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6.074.97 166.72 36.4 0.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 99.0 3.9 Mostly Cloudy WC WNW @ 7 MPH 34" Daily summary operation 24h Summary Drift 5"D.P.P/U M/U 5"D.P.from Pipe Shed.Drift size 2.875".Check ST-80 gauge to ensure proper torque.Burn in and adjust brake on Drawworks.P/U M/U 5"HWDP.Dress and attempt to use Scorpion for M/U.After several attempts decision was made to use the Iron Roughneck.P/U M/U 14 Jnts 5"HWDP and Jars.Redress Scorpion for 9"pipe.P/U M/U NMFDC P/U M/U BHA#1 as per Schlumberger DD.Fill up Conductor and surface stack.Check for leaks and Press.test Mud Line to 3,000 PSI.Clean out 20"Conductor to 180'MD,490 GPM,320 PSI,40 RPM,TRQ 2K,WOB 2-8K, HST 82K,SLK 82K,ROT WT 82K.POOH rack back 5"HWDP.Pre spud meeting with all parties.Load floor W/BHA#2 components.Begin M/U BHA#2 as per Schlumberger DD and MWD Rep onsite. Trouble shoot Scorpion tool in attempt to reach make up torque for BHA.May not have enough Hydraulic Press.Dies appear to be slipping during make up. Operation at 07.00 Wait on Schlumberger Gyro tool. 24h Forecast • Work on Scorpion to make up torque for BHA#2.L/D BHA#2.Wait on Gyro sub from Deadhorse.Bring over MWD tool for OPP.Prep MWD and Gyro tools.P/U M/U 8"BHA#2.Drill to-280'MD.POOH P/U Jar stand and drill ahead as per well program. Lithology Shows MAASP(kgflcm") Mud Weight(gIL) • Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 12.00 12.00 12.00 MOB A 20 P PJSA Drift 5"D.P.P/U M/U 5"D.P.from Pipe Shed.Drift size 2.875".Check ST-80 gauge to ensure proper torque.Bum in and adjust brake on Drawworks. 12'00 1530 3.50 15.50 MOB A '20 P PJSA P/U M/U 5"HWDP.Dress and attempt to use Scorpion for M/U.After several attempts decision was made to use the Iron Roughneck.P/U M/U 14 Jnts 5"HWDP and Jars.Redress Scorpion for 9"pipe. 15.30 .16'.30 1.00 16.50 MOB A .20 P PJSA P/U M/U NMFDC P/U M/U BHA#1 as per Schlumberger DD. 16.30 .17.30 1.00 17.50 MOB A .20 P PJSA Fill up Conductor and surface stack.Check for leaks and Press.test Mud Line to 3,000 PSI. 17-.30 .19'.30 2.00 19.50 DRILL E '3 P PJSA Clean out 20"Conductor to 180'MD,490 GPM,320 PSI.40 RPM,TRQ 2K.WOB 2-8K,HST 82K,SLK 82K.ROT WT 82K.POOH rack back 5"HWDP:- 19:30 '22:00 2.50 22.00 DRILL E '20 P PJSM Pre spud meeting with all parties.Load floor W/BHA#2 components.Begin M/U BHA#2 as per Schlumberger DD and MWD Rep onsite. 2200 0000 2.00 24.00 DRILL E 20 P PJSA Trouble shoot Scorpion tool in attempt to reach make up torque for BHA.May not have enough Hydraulic Press.Dies appear to be slipping during make up. 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 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 Billy Petty ENI HSE 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(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 0.00 48.77 8/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm") Eq.Mud Weight(gIL) P LeakOff(kgflcm") Eni E&P Division Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq II* • API/UWI:50-629-23494-00-00 2^n Date:8/29/2013 - Report#: 4 I` II II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(in) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI35-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 1.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 220.68 219.88 220.68 3.61 61.1 100.0 2.8 Overcast WC 31' N @ 8 MPH Daily summary operation 24h Summary Cont.trouble shoot Scorpion,attempt to reach M/U torque.Decision was made to L/D 9"tools.L/D 9"Gyro collar,9"double pin and 9"bottle neck XO.Load Pipe Shed W/13 3/8"Csg.Wait on tools corning from Deadhorse.Load Pipe Shed and Rig floor W/BHA tools.P/U M/U BHA#2 as per Schlumberger DD and MWD Rep onsite.Wash down F/131'to 167'MD.Shallow hole test Schlumberger tools as per Rep.Slide&rotate F/167 to 406'MD(406'TVD)Monitor well.static.Shoot Gyro surveys as per DD dictates.BROOH F/406'to 131'MD.M/U DC,HWDP&Jar stand.Was down F/351'to 406'MD.Slide&rotate F/406'to 724'MD(721'TVD;750 GPM,1,200 PSI.40 RPM.4-5K TRN,2K TQF,WOB 20-30K,HST 120K,SLK 119K,ROT 119K,ECD 9.69 ppg W/9.05 ppg MW.Max Gas 3 units.ADT 3.61.Bit Hrs 3.61,Jar Hrs 3.61.Monitor well,static.Shoot Gyro surveys as per DD dictates. Operation at 07.00 Drill ahead 16"Surface @ 949'MD 24h Forecast Drill 16"Surface hole F/724'to-3.237'MD as per Schlumberger DD,MWD and Gyro. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1042.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 20P PJSA Cont.trouble shoot Scorpion,attempt to reach M/U torque.Decision was made to L/D 9"tools. 02:00 03:00 1.00 3.00 DRILL E 20 P PJSA UD 9"Gyro collar.9"double pin and 9"bottle neck XO. 03:00 06:00 3.00 6.00 DRILL E 20P PJSA Load Pipe Shed W/13 3/8"Csg.Wait on tools corning from Deadhorse. 06:00 09:00 3.00 9.00 DRILL E 20P PJSA Load Pipe Shed W/13 3/8"Csg.Wait on tools coming from Deadhorse. 09:00 09:30 0.50 9.50 DRILL E 20 P PJSA Load Pipe Shed and Rig floor W/BHA tools. 09:30 11:30 2.00 11.50 DRILL E 20P PJSA P/U M/U BHA#2 as per Schlumberger DD and MWD Rep onsite. 11:30 12,00 0.50 12.00 DRILL E 4 P PJSA Wash down F/131'to 167'MD 300 GPM,260 PSI.Shallow hole test Schlumberger tools as per Rep.630 GPM,720 PSI,HST 92K,SLK 92K. 12:00 16:00 4.00 16.00 DRILL E 3 P PJSA Slide&rotate F/167'to 406'MD(406'TVD)600 GPM,960 PSI,40 RPM,3-5K TRN,2K TQF,WOB 10-20K,HST 98K,SLK 98K,ROT 98K,ECD 9.2 ppg W/8.8 ppg MW.Max Gas 2 units.ADT 2.32,TST 1.64,TRT.68,Bit Hrs2.32,Jar Hrs 2.34.Monitor well,static.Shoot Gyro surveys as per DD dictates. 16:00 17:30 1.50 17.50 DRILL E 6 P PJSA BROOH F/406'to 131'MD 650 GPM,670 PSI,40 RPM,ECD 9.4 ppg,HST 92K,SLK 92K,ROT WT 92K,40 RPM. TRO 2K. 17.30 19:30 2.00 19.50 DRILL E 20P PJSA M/U DC,HWDP&Jar stand.Was down F/351'to 406'MD,600 GPM,690 PSI,108K HST,108K SLK,ROT 108K, 40 RPM,TRQ 2K. 19.30 00:00 4.50 24.00 DRILL E 3 P PJSA Slide&rotate F/406'to 724'MD(721'TVD)750 GPM.1,200 PSI.40 RPM,4-5K TRN.2K TOE,WOB 20-30K,HST 120K,SLK 119K,ROT 119K,ECD 9.69 ppg W/9.05 ppg MW.Max Gas 3 units.ADT 1.29.TOT 0.99,TRT 0.30,Bit Hrs 3.61,Jar Hrs 3.61.Monitor well.static.Shoot Gyro surveys as per DD dictates. 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 Tom Klein ENI Mutts Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Billy Petty ENI HSE Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@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(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 0.00 48.77 8/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') �� Eni E&P Division .,,} (well Name:SI35-W4 J ENI Petroleum Co.Inc. Daily Iy Report 1 l Well Code:27429 Field Name:Nikaitchuq • 2 n rl Date:8/30/2013 - Report#: 5 API/UWI:50-629-23494-00-00 'I II'I page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6,074.97 166.72 36.4 2.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 693.42 592.69 472.74 14.23 33.2 98.0 0.0 Mostly Cloudy WC WNW @ 12 MPH 23" Daily summary operation 24h Summary PJSA Slide&rotate F/724'to 2,275'MD(1,952'TVD)750 GPM,1,420 PSI,40 RPM,TRN 4-5K,TQF 5K,WOB 2-35K,HST 146K.SLK 122K,ROT 135K,ECD 10.16 ppg W/9.45 ppg MW.Max Gas 598 units.ADT 14.23,TST 11.11,TRT 3.12.Bit Hrs 17.75,Jar Hrs 17.75.Monitor well,static.Shoot Gyro surveys as per DD dictates.Started using MWD @—1,200'MD. Operation at 07.00 Doll ahead 16"Surface @ 2,624'MD 24h Forecast Drill 16"Surface hole F/2,275'to—3,237'MD as per Schlumberger DD,MWD and Gyro. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Slide&rotate F/724'to 1,103'MD(1,075'TVD)610 GPM,960 PSI,40 RPM,TRN 4-6K,TQF 4K,WOB 25-35K, HST 125K,SLK 120K,ROT 122K,ECD 9.7 ppg W/9.1 ppg MW.Max Gas 21 units.ADT 3.42,TST 3.2,TRT 0.22,Bit Hrs 7.03,Jar Hrs 7.03.Monitor well,static.Shoot Gyro surveys as per DD dictates. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Slide&rotate F/1,103'to 1,407'MD(1,326'TVD)700 GPM,1,160 PSI,40 RPM,TRN 6-8K,TQF 3K,WOB 20-25K, HST 130K,SLK 120K,ROT 124K,ECD 9.9 ppg W/9.1 ppg MW.Max Gas 1 units.ADT 3.11,TST 2.54,TRT 0.57,Bit Hrs 10.14,Jar Hrs 10.14.Monitor well,static.Shoot Gyro surveys as per DD dictates.Started using MWD @—1,200'MD. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Slide&rotate F/1,407'to 1,848'MD(1,646'TVD)630 GPM.1,320 PSI.40 RPM,TRN 5-7K,TQF 4K,WOB 2-35K. HST 141K,SLK 120K,ROT 130K,ECD 10.0 ppg W/9.2 ppg MW.Max Gas 300 units.ADT 4.35.TST 2.81,TRT 1.54,Bit Hrs 14.40.Jar Hrs 14.40.Monitor well,static. 18.00 00.00 6.00 24.00 DRILL E 3 P PJSA Slide&rotate F/1,848'10 2,275'MD(1,952'TVD)750 GPM,1,420 PSI,40 RPM,TRN 4-5K,TQF 5K,WOB 2-35K. HST 146K,SLK 122K,ROT 135K,ECD 10.16 ppg W/9.45 ppg MW.Max Gas 598 units.ADT 3.35,TST 2.56,TRT 0.79, Bit Hrs 17.75.Jar Hrs 17.75.Monitor well,static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative 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 Billy Petty ENI HSE Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@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(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 0.00 48.77 8/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') I`* En►E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • APIIt1Wl:50-629-23494-00-00 2^li Date:8/31/2013 - Report#: 6 II �I page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING _ DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 3.27 Daily Information End Depth(mKB) End TVD Depth p (TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 967.74 734.79 274.32 6.88 39.9 102.0 1.7 Cloudy WC 27` W @ 10 MPH Daily summary operation 24h Summary Slide&rotate F/2,275'to 3,175'MD(2,410'TVD)850 GPM,2,140 PSI,40 RPM,TRN 10K,TQF 8K,WOB 20-25K,HST 160K,SLK 120K,ROT 138K,ECD 10.04 ppg W/9.40 ppg MW.Max Gas 46 units.ADT 6.88,TST 4.70,TRT 2.18,Bit Hrs 24.63,Jar Hrs 24,63.Monitor well.static.Cycle Gyro tool to BROOH mode and take quad shot survey.BROOH as per K&M plan forward F/3,175'to 1,156' MD 850 GPM,1,860 PSI,80 RPM,TRQ 7K,ROT 143K,HST 138K,SLK 118,Max Gas 1,233 units.Hole unloaded at Shakers @ 1,800'and 1,400'MD.Slowed bumps to manage Shakers,resumed BROOH when 850 gpm flow rate was established. Operation at 07.00 L/D BHA#2 as per Schlumberger DD&MWD Rep onsite. 24h Forecast Cont.to BROOH F/1,156'MD to BHA#2.L/D BHA as per Schlumberger DD&MWD Rep onsite.Clean and clear rig floor.PJSM W/all essential personnel for casing run.R/U GBR Volant Equip.P/U M/U 13 3/8"Shoe Track and RIH to 3,160'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. • 00.00 06.00 6.00 6.00 DRILL E 3 P PJSA Slide&rotate F/2,275 to 2,741'MD(2.205'TVD)750 GPM,1,550 PSI,40 RPM,TRN 7-8K,TQF 5-8K,WOB 20- 30K,HST 152K,SLK 122K,ROT 136K,ECD 10.15 ppg W/9.40 ppg MW.Max Gas 293 units.ADT 3.32,TST 2.13,TRT 1.19.Bit Hrs 21.07,Jar Hrs 21.07.Monitor well.static. 06.00 1200 6.00 12.00 DRILL E 3 P 'PJSA Slide&rotate F/2,741'to 3,114'MD(2,390'TVD)850 GPM,2,180 PSI,40 RPM,TRN 8K,TQF 8-10K,WOB 5-20K, HST 156K,SLK 118K,ROT 136K,ECD 10.17 ppg W/9.40 ppg MW.Max Gas 98 units.ADT 2,98,TST 2.10,TRT 0.88.Bit Hrs 24.05.Jar Hrs 24.05.Monitor well,static. 12:00 13.30 1.50'. 13.50 DRILL E 3 P PJSA Slide&rotate F/3,114'to 3,175'MD(2,410'TVD)850 GPM,2,140 PSI,40 RPM,TRN 10K,TQF 8K,WOB 20-25K. HST 160K,SLK 120K,ROT 138K.ECD 10.04 ppg W/9.40 ppg MW.Max Gas 46 units.ADT 0.58,TST 0.47,TRT 0.11.Bit Hrs 24.63,Jar Hrs 24.63.Monitor well.static.Cycle Gyro tool to BROOH mode and take quad shot survey. 13:30 18.00 ' 4.50. 18.00 DRILL E 6 P 'PJSA BROOH as per K&M plan forward F/3,175'to 2,275'MD 850 GPM,2,130 PSI,80 RPM,TRO 9K,ROT 130K,10.2 ppg ECD,Max Gas 51 units. 18:00 00.00 6.00' 24.00 DRILL E 6 P PJSA BROOH as per K&M plan forward F/2,275'to 1,156'MD 850 GPM,1,860 PSI,80 RPM,TRQ 7K,ROT 143K,HST 138K,SLK 118,Max Gas 1,233 units.Hole unloaded at Shakers @ 1,800'and 1,400'MD.Slowed bumps to manage Shakers,resumed BROOH when 850 gpm flow rate was established. 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 Dolling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls 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 Eni representative Billy Petty ENI HSE Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 0.00 48.77 8/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division Well Name:SI35-W4 ffi* ENI Petroleum Co.Inc. Daily ReM Well Code:27429 Field Name:Nikaitchuq • APIIU1N1:50-629-23494-00-00 2^ Date:9/1/2013 - Report#: 7 I) II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLINGDOYON 15 LAND RIG __ Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI35-W4 DRILLING 8/28/2013 6.069.18 1,100.21 6,074.97 166.72 36.4 4.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 967.74 734.79 0.00 101.0 0.6 Overcast,Light Snow ENE @ 15 MPH WC 23" Daily summary operation 24h Summary BROOH as per hole dictates,Fl 1.156'to 693'MD,Monitor well at HWDP,static.BROOH as per hole dictates,Monitor well,static.Hole unloaded at Shakers @ 600'MD.Blow down Top Drive.Stand back Jar stand in Derrick,L/D BHA#2 as per Schlumberger DD&MWD Rep onsite.Clear and clean rig floor of BHA tools and handling Equip.Adjust brakes on Drawworks.PJSM with all essential personnel for running 13 3/8"Csg,Bring Csg.tools to rig floor Slips,C-Plate,Single Jnt Elevators,Link Extension&Volant Tool.Remove TDS 8 Bell Guide.M/U Volant to TDS 8.Install 4'Link Extension,Install 150 Ton Elevators.Install C-Plate and 350 Ton Slips on Rotary Table.Run 13 3/8"Csg.P/U M/U Baker Loc Shoe Track&install Centralizers to 161'MD.Check 13 3/8"Shoe Track @ 161'MD.RIH 13 3/8"Csg as per tally F/161'to 2,174'MD,SLK 140K.Filling Csg.during trip.RIH 13 3/8"Csg.as per Tally,filling Csg.F/2,174'to 3,120'MD SLK 160K.M/U Hanger and Landing Jnt as per Vetco Grey Rep onsite.Break Circ.@ 2 bpm,120 PSI,wash Landing Jnt&Hanger down to 3,160'MD,HST 280K.Total lost during trip 10 bbl.Circulate and condition mud for cement job as per MI Swaco plan forward to<20 YP.Stage up pumps F/2 bpm to 4.5 bpm,130 PSI. Operation at 07.00 Perform cement job as per Schlumberger plan forward. 24h Forecast Cont.to conditon mud to<20 YP as per MI Swaco plan forward.Perform cement job as per Schlumberger plan forward.Clean all surface Equip.of cement.N/D Diverter Stack and N/U BOPE.Test BOPE. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00' 1.00 DRILL E '5 P PJSA BROOH as per hole dictates,F/1,156'to 693'MD,850 GPM.1,780 PSI,80 RPM,TOF 3K.ECD 10.66 ppg W/9.4 ppg MW.HST 115K,SLK 110K,ROT 115K.Monitor well at HWDP,static. 01:00 03:00 2.00' 3.00 DRILL E 5 P PJSA BROOH as per hole dictates,F/693'to 415'MD,850 GPM,1,570 PSI,80 RPM,TQF 3K,ECD 9.67 ppg W/9.4 ppg MW.HST 108K.SLK 108K.ROT 108K,Monitor well.static.Hole unloaded at Shakers @ 600'MD.Blow down Top Drive. 03:00 06:30 3.50' 6.50 DRILL E 4 P PJSA Stand back Jar stand in Derrick.L/D BHA#2 as per Schlumberger DD&MWD Rep onsite. 06:30 07:30 1.00 7.50 DRILL E 20 P PJSA Clear and clean rig floor of BHA tools and handling Equip.Adjust brakes on Drawuorks. 07:30 09:00 1.50 9.00 DRILL G 20 P PJSM with all essential personnel for running 13 3/8"Csg.Bring Csg.tools to rig floor:Slips,C-Plate.Single Jnt Elevators, Link Extension&Volant Tool.Remove TDS 8 Bell Guide.M/U Volant to TDS 8.Install 4'Link Extension.Install 150 Ton Elevators.Install C-Plate and 350 Ton Slips on Rotary Table. 09:00 12:00 ' 3.00 12.00 DRILL G 4 P PJSA Run 13 3/8"Csg.P/U M/U Baker Loc Shoe Track 8 install Centralizers to 161'MD. 12:00 18:00 6.00' 18.00 DRILL G 4 P PJSM Check 13 3/8"Shoe Track @ 161'MD.RIH 13 3/8"Csg as per tally F/161'to 2,174'MD.SLK 140K.Filling Csg. during trip. 18.00 20:30 2,50 20.50 DRILL G 4 P PJSA RIH 13 3/8"Csg.as per Tally,filling Csg.F/2,174'to 3,120'MD SLK 160K.M/U Hanger and Landing Jnt as per Vetco Grey Rep onsite.Break Circ.@ 2 bpm,120 PSI,wash Landing Jnt&Hanger down to 3.160'MD.HST 280K.Total lost during trip 10 bbl. 20.30 00.00 3.50' 24.00 DRILL G 8 P PJSA Circulate and condition mud for cement job as per MI Swaco plan forward to<20 YP.Stage up pumps F/2 bpm to • 4.5 bpm 130 PSI. 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 Oliver Amend ENI Dolling 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 Eni representative Billy Petty ENI HSE Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') liff* Eni E&P Division IWeIIName:SI35-W4 EN!Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq • API/UWI:50-629-23494-00-00 enU n Date:9/2/2013 - Report#: 8 �� II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36. 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DES(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 5.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr( POB Temperature(°C) Weather Wind 967.74 734.79 0.00 99.0 1.4 Overcast WC 13` ENE @ 37 MPH W/ Gust to 45 MPH Daily summary operation 24h Summary Condition mud&circulate @ 4.5 bpm 80 PSI as per MI Swaco Plan forward to achieve<20 YP.Blow down TS-8,R/U Cement line to Volant tool.Cont.condition mud&circulate @ 4.5 bpm 140 PSI as per MI Swaco Plan forward,final YP 15.PJSM with a essential personnel involved in cement job.Pump 10 bbl water and test cement line to 1,000 PSI low and 3,000 PSI high.Pump 111 bbl 10.1 ppg Mud Push II spacer @ 5 bpm.P/U Volant tool and drop bottom plug via Schlumberger Rep onsite.Schlumberger pumped 478 bbl 10.77 ppg Lead Cement @ 5 bpm,bottom plug seat @ 467 bbl away, • burst @ 700 PSI.Pumped 64 bbl 12.5 ppg Tail Cement @ 4 bpm.P/U Volant tool and drop top plug.Schlumberger pumped 10 bbl water to flush line and kick out plug.Rig chased plug @ 5.5 bpm ICP 240 PSI,FCP 370 PSI.Slow pumps to 3 bpm 20 bbl before bumping plug.Mud push seen at 315 bbl away,cement seen @ 359 bbl away.Bump top plug @ 444.3 bbl away.CIP @ 07:08,FCP 310 PSI, Press.up to 840 PSI for 5 Min,checked floats(Good)85 bbl cement seen at surface.R/D cement manifold and hoses.Pull landing joint as per Vetco Grey Rep onsite.UD GBR Volant tool and Equip.as per GBR Rep onsite.Clean and clear rig floor.C/O elevators to 5"D.P.M/U stack washer Johnny Whacker&P/U stand.Wash stack W 110 bbl Black Water @ 8 bpm,80 RPM.Install Bell Guide on TS-8. • N/D Diverter system and Diverter stack.Prep and set Mufti Bowl Well Head as per Vetco Grey Rep onsite.Test Well Head to Hanger seals to 2.000 PSI for 10 Min.(Good)M/U Landing joint to Tubing Hanger and perform dummy run and test of Hanger seats.Lower seals tested to 5,000 PSI.(Good)Upper Hanger seals section failed.SIMOPS:Cleaning pits and surface Equip.Load and strap 5"D.P.in Pipe Shed.Re Torque lock down pins to Spec.as per Vetco Grey Rep onsite via Torque Multiplier and test.Upper Hanger seals failed.After discussion with down,moving forward W/N/U BOPE. ' Operation at 07.00 P/U M/U 5"D.P.from Pipe Shed. 24h Forecast Finish N/U BOPE.P/U M/U 5"D.P.from Pipe Shed.Test BOPE.P/U M/U BHA#3. Lithology Shows MAASP(kgflcm°) Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL H 8 P PJSA Cont.condition mud&circulate @ 4.5 bpm 80 PSI as per MI Swaco Plan forward to achieve<20 YP. 00:30 01:00 0.50 1.00 DRILL H 20 P PJSA Blow down TS-8,R/U Cement line to Volant tool. 01:00 01:30 0.50 1.50 DRILL H 8 P PJSA Cont.condition mud&circulate @ 4.5 bpm 140 PSI as per MI Swaco Plan forward,final YP 15. 01:30 07:30 6.00 7.50 DRILL H 9 P PJSM with a essential personnel involved in cement job.Pump 10 bbl water and test cement line to 1,000 PSI low and 3,000 PSI high.Pump 111 bbl 10.1 ppg Mud Push II spacer @ 5 bpm.P/U Volant tool and drop bottom plug via Schlumberger Rep anode.Schlumberger pumped 478 bbl 10.77 ppg Lead Cement @ 5 bpm,bottom plug seat @ 467 bbl away,burst @ 700 PSI.Pumped 64 bbl 12.5 ppg Tail Cement @ 4 bpm.P/U Volant tool and drop top plug.Schlumberger jh pumped 10 bbl water to flush line and kick out plug.Rig chased plug @ 5.5 bpm ICP 240 PSI,FCP 370 PSI.Slow pumps to ,(y 3 bpm 20 bbl before bumping plug.Mud push seen at 315 bbl away,cement seen @ 359 bbl away.Bump top plug @ '�/ ' 444.3 bbl away.CIP @ 07:08,FCP 310 PSI,Press.up to 840 PSI for 5 Min,checked floats(Good)85 bbl cement seen at surface. 07.30 10:00 2.50 10.00 DRILL G 20 P PJSA R/D cement manifold and hoses.Pull landing joint as per Vetco Grey Rep onsite.UD GBR Volant tool and Equip.as per GBR Rep onsite.Clean and Gear rig floor.C/O elevators to 5"D.P.M/U stack washer Johnny Whacker&P/U stand. Wash stack W 110 bbl Black Water @ 8 bpm,80 RPM.Install Bell Guide on TS-8. 10:00 12:00 2.00 12.00 DRILL C 20 P PJSM N/D Diverter system and Diverter stack. 12:00 14:00 2.00 14.00 DRILL C 20 P PJSM Cont.N/D Diverter,surface riser,speed head&remove divener line section. 14:00 15:30 1.50 15.50 DRILL C 20 P PJSA Prep and set Multi Bowl Well Head as per Vetco Grey Rep onsite.Test Well Head to Hanger seals to 2,000 PSI for 10 Min.(Good) 15:30 17:00 1.50 17.00 DRILL C 20 P PJSM M/U Landing joint to Tubing Hanger and perform dummy run and test of Hanger seals.Lower seals tested to 5,000 PSI.(Good)Upper Hanger seals section failed.SIMOPS:Cleaning pits and surface Equip.Load and strap 5"D.P.in Pipe Shed. 17:00 19:30 2.50 19.50 DRILL C 20 P PJSA Re Torque lock down pins to Spec.as per Vetco Grey Rep onsite via Torque Multiplier and test.Upper Hanger seals failed.After discussion with down.moving forward W/BOPE N/U.SIMOPS:cleaning pits.load and strap 5"D.P.in Pipe shed. 19:30 21:00 1.50 21.00 DRILL C 20 P PJSA Break out Lock Down screws and UD Tubing Hanger. 21:00 00:00 3.00 24.00 DRILL C 20 P PJSM N/U BOPE. 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Mafls Coordinator 907-685-0718 Eni representative Mach 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 ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date • CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgflcm°) 1111* En/E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • Date:91312013 - Report#: 9 API/UWI:50 629-23494-00-00 ' i 'r o page 1 of 1 Wellbore name: SI35-W4 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information • Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0135-704 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 6.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 967.74 734.79 0.00 100.0 2.8 Overcast WC 32' NE @ 24 MPH Daily summary operation 24h Summary N/U BOPE and test as per AOGCC specs to 250/3500 psi,2500 psi Annular.Witness waived by Jeff Turkington.P/U&M/U 5"DP and rack back in derrick. • Operation at 07.00 P/U M/U BHA#3 24h Forecast M/U and RIH w/BHA#3.Perform shallow hole test and RIH to float collar.Test casing to 2500 psi for 30 charted min.Drill shoe track plus 20'of new hole.Displace well to new LSND mud as per MI. Perform FIT/LOT to 13 ppg equivalent.Set drilling parameters and drill ahead. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL C 20 P PJSA N/U BOPE.Simops-process 5"DP in pipe shed. 01 00 02:00 1.00 2.00 DRILL E 20 P Process 5"DP. 02:00 02.30 0.50 2.50 DRILL I E 20 P H2S drill with rig personnel and all third party contractors.5 min response time. 02:30 12:00 9.50 12.00 DRILL E 20 P PJSA L/D 3 stands of HWDP from derrick.P/U&M/U 177 jts.of 5"DP and rack in derrick. 12:00 15:30 3.50 15.50 DRILL E 20 P PJSA complete P/U 5"DP,144 jts,rack back in derrick. 15:30 16.00 0.50 16.00 DRILL E 20 P Clear and clean rig floor. 16:00 17.00 1.00' 17.00 DRILL E 25 P Service draw works and adjust brakes. 17:00 17.30 0.50 17.50 DRILL E 20 P PJSA M/U 5"test jt.and set Vetco test plug. 17:30 18:00 0.50 18.00 DRILL C 12 P R/U testing equipment. 18:00 00:00 6.00 24.00 DRILL C 12 P Testing BOPE w/5"test jt as per AOGCC spec's @ 250/3500 psi,2500 Annular.Witnessed waived verbally by Jeff DC Turkington. Daily Contacts rS 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 Too Di ii Eni E&P Division Well Name: SI35-W4 J ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • APIIUWM:50-629-23494-00-00 2^n Date:9/4/2013 - Report#: 10 II II II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator EM Share(o) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI35-W4 DRILLING 8/28/2013 6.069.18 1,100.21 6,074.97 166.72 36.4 7.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1.073.20 769.85 105.46 1.93 54.6 101.0 5.6 Overcast,WC 33` NNE @ 14 MPH Daily summary operation 24h Summary M/U BHA#3 and RIH,perform shallow hole test,tag Float collar and perform casing test to 2500 psi for 30 charted min.Drill shoe track and 20'of new hole to 3195'.Displace well to 9.3 ppg LSND mud. Perform LOT test to 11.62 ppg.Drill ahead to 3521'MD. Operation at 07.00 Dulling ahead @ 4,090'MD. 24h Forecast Drill 12.25"intermediate hole as per SLB. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL C 12 P PJSA Test choke A.B,and super choke to 1500 psi. 00:30 01:00 ' 0.50 1.00 DRILL E 20 P R/D all test equipment,pull test plug,blow down choke manifold,choke and kill lines. 01:00 01:30 0.50 1.50 DRILL E 25 P Service ng blocks,top-drive,draw works,and MP2's work orders on crown blocks,top-drive and traveling blocks. 01:30 02:30 1.00 2.50 DRILL E 20 P Set wear bushing as per Vetco,install short mousehole,and bring BHA equipment to rig floor. 02:30 05:30 3.00 5.50 DRILL E 4 P PJSA with personnel for P/U BHA#3.PIU as per SLB and RIH to 349',100k pow,95k sow. '05:30. 06:00 0.50 6.00 DRILL E 4 P PJSA RIH wl 5"DP to 1003'. 06:00 06:30 0.50 6.50 DRILL E 12 P Perform shallow hole test as per SLB MWD @ 650 gpm,680 psi. 06:30 08:30 2.00 8.50 DRILL E 4 P RIH f/1003'-2865',155k pow,110k sow,fill pipe as needed. 08:30 10:00 1.50 10.00 DRILL E 25 P PJSA Shp and cut 68'of ddg.line,adjust brakes and calibrate blocks with SLB MWD. 10:00 10:30 0.50 10.50 DRILL E 4 P PJSA wash down f/2865'-Top of float collar @ 3062'@ 378 gym.330 psi,155k pow,112k sow. 10:30 12:00 1.50 12.00 DRILL E 12 P PJSA R/U to test csg and test to 2500 psi for 30 charted min. 12:00 12:30 0.50 12.50 DRILL E 20 P PJSA R/D test euipment. 1230 15:30 3.00 15.50 DRILL E 3 P Establish cleanout rates @ 550 gpm,660 psi,60 rpm.2-10k web,8-12k tq.Cleanout shoe tack to FC @ 3075'.FS @ 3160'.rathole to 3175',and new hole to 3195' 15:30 17:00 1.50 17.00 DRILL E 7 P PJSM Displace well to 9.2 ppg LSND mud,pump 50 bbls of hi-vis sweep followed w/398 bbls 9.2 ppg LSND @ 9 bpm,300 psi.60 rpm,8-10k tq,while reciprocating.Pull stand of 5"DP to 3148'. ` , 17:00 18:30 1.50 18.50 DRILL E 9 P PJSA R/U and perform LOT to 11.0 ppg equivalent.R/D from test. ,,c" j / - 18:30 00:00 5.50 24.00 DRILL E 3 P Wash down to 3195',drill f/3195-3521'MD(2528'TVD)@ 450 gpm,380 psi,60 rpm,2-10k wob,8-10k tqn,7k tqf,9.53 ECD,Max Gas 40,150k pow,115k sow,130k rotw,1.93 ADT,1.93 Bit,26.56 Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile i' ,a 'q Eni representative Mike Ross ENI 'Senior Drilling Supv 'SIDDnlling@enipetroleum.com 907-685-0715 ✓ 1r 1 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Mails Coordinator f-11,1, ..1. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 i 1, L 1- 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 Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 1111#1 D Eni E&P Division 'Well Name:0135-W4 ENI Petroleum Co.Inc. Daily ReM Well Code:27429 Field Name: Nikaitchuq • API/UWI:50-629-23494-00-00 2^n Date:9/5/2013 - Report#: 11 Illi ii page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 8.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature CC) Weather Wind 1.658.42 858.60 585.22 15.67 37.3 102.0 1.7 Overcast,WC 25' E @ 17 MPH Daily summary operation 24h Summary Drill ahead f/3521'-5541'(2814'TVD). Operation at 07.00 Drilling ahead @ 5,790'MD. • 24h Forecast Drill 12.25"intermediate hole as per SLB. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. • 00:00 06:00 6.00 6.00 DRILL -E 3 P PJSA Ddg.f/3521'-4361'(2683'TVD),@ 800 gpm,1140 psi,140-160 rpm,4-15k tqn,8k tqf.4-12k wob,150k puw,110k sow,130k rotw,10.09 ECD,Max Gas 62,3.47 ADT,5.4 Bit,30.0 Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg f/4361'-4648'(2716'ND)@ 848 gpm.1280 psi,130-180 rpm,4-17k tqn,9k tqf.6-15k wob,150k puw,115k sow,130k rotw,9.9 ECD,Max Gas 48,3.68 ADT,9.08 Bit.33.68 Jars.No losses this tour. 12:00 18:00 6.00 18.00 DRILL E 3 °P PJSA Drlg f/4648'-5055'(2766'ND)@ 800 gpm,1210 psi,65-160 rpm,5-20k tqn,11k tqf,2-15k wob,165k puw,105k sow,130k rotw,9.90 ECD,Max Gas 64,4.22 ADT,13.30 Bit,37.90 Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Ddg f/5055'-5441'(2814'ND)@ 548 gpm.1360 psi,130-180 rpm,6-12k tqn,8k tqf.8-14k wob.158k puw,108k / sow.132k rotw,9.99 ECD,Max Gas 64,4.3 ADT,17.60 Bit.42.20 Jars. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-6685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondelling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 ft* Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • API/UWI:50-629-23494-00-00 2�,,f Date:9/6/2013 - Report#: 12 1111 II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI35-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6.074.97 166.72 36.4 9.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,273.81 938.72 615.39 16.92 36.4 102.0 1.1 Cloudy,Fog,WC 22' NE @ 28 MPH Daily summary operation 24h Summary DrIg.f/5441'-7460'(3076'TVD). Operation at 07.00 Drilling ahead @ 7,566'MD. 24h Forecast Drill 12.25"intermediate hole as per SLB. Lithology Shows MAASP(kgffcm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'.00 06.00 6.00 6.00 DRILL E 3 P PJSA Ddg f/5441'-6132'(2900'TVD)@ 850 gpm.1550 psi,120-180 rpm.10-12k tqn,106 tqf.2-14k wob,162k puw, 110k sow,132k rotes.10.24 ECD,Max Gas 4.4.08 ADT,21.68 Bit.46.28 Jars. 06:00 12-.00 6.00 12.00 DRILL E 3 P PJSA Ddg 5 6132'-6724'(2980'TVD)@ 900 gpm,1850 psi,120-200 rpm,10k tqn,5k tqf,2-14k wob,168k puw,110k sow.138k rotw,10.09 ECD,Max Gas 2,3.64 ADT,25.32 Bit,49.92 Jars. 12:00 18.00 6.00 18.00 DRILL E 3 P PJSA DrIg 5 6724'-7244'(3048'TVD)@ 907 gpm,1940 psi,120-200 rpm,9-10k tqn,7k tqf,2-14k wob,9-10k tqn,7k tqf. 165k paw,110k sow,142k rotw,10.01 ECD,Max Gas 4,4.32 ADT,29.64 Bit.54.24 Jars. 18:00 00'.00 6.00 24.00'DRILL E 3 P PJSA DrIg f/7244'-7460'(3076'TVD)@ 907 gpm.1940 psi,120-200 rpm.10k tqn,7k tqf,2-14k wob,165k puw,108k sow.138k rotw,9.91 ECD,Max Gas 3, 4.88 ADT,34.52 Bit,59.12 Jars.SPR @ 7124'(3035'TVD)w/9.2 MW', #1/#2/#3 @ 30-220,@ 40-250. Daily Contacts Position I Contact Name Company Title E-mail Office Mobile Eni representative I Mike Ross •ENI Senior Drilling Supv SIDDnIling@enipetroleum.com 907-685-0715 Em representative Russ Wimmer ENI Dnlling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Em representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Em representative Jack Kvasnikoff ENI HOE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 11"1* * Eni E&P Division .. 'Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • API/UWI:50-629-23494-00-00 2�, Date:9/7/2013 - Report#: 13 II II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6.069.18 1,100.21 6,074.97 166.72 36.4 10.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,525.27 972.52 251.46 19.66 12.8 102.0 0.6 Cloudy,WC 20° E @ 30 MPH Daily summary operation 24h Summary Ng f/7460'-8285'(3187'TVD). Operation at 07.00 Drilling ahead @ 8.563'MD. 24h Forecast Drill 12.25"intermediate hole as per SLB. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg f/7460'-7597'(3095'TVD)@ 864 qpm.1690 psi,185 rpm.10k wob.10k tqn,8k tqf,168k puw.105k sow,139k rotw,9.85 ECD,Max Gas 1. 06.00 12.00 6.00 12.00 DRILL E 3 P PJSA Ddg f/7597'-7635'(3092'TVD)@ 864 gpm.1690 psi,182 rpm.10k wob,11k tqn,8k tqf.168k puw,108k sow,139k rotw.9.85 ECD,Max Gas 1,10.28 ADT,44.80 Bit.69.40 Jars. 12:00 18.00 ' 6.00 18.00 DRILL E 3 P PJSA Ddg f/7635'-7950'(3143'TVD)@ 900 gpm,1920 psi,140-200 rpm.2-16k wob.10k tqn,7k tqf,170k puw,110k sow,140k rotw,9.99 ECD,Max Gas 11,6.06 ADT,50.86 Bit,75.46 Jars. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSA DrIg f/7950'-8285'(3187'ND)@ 900 qpm,1990 psi,140-200 rpm.2-16k wob.10k tqn,7k tqf,170k puw,105k sow,140k rotw,10.07 ECD,Max Gas 17,3.32 ADT,54.18 Bit,78.78 Jars.SPR @ 8192'(3175'TVD)w/9.2 MW,#1 @ 30 -210,@ 40-220,#2 @ 30-200,@ 40-220,#3 @ 30-210,@ 40-220. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDnIling@enipetroleum.com -907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnIling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator 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 Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 963.17 732.93 LSND 1114.4 20.4 13926 102.0 look Eni E&P Division I Well Name:SI35-W4 I ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 2 II^• Date:9/8/2013 - Report#: 14 I' II n page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type , 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 11.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,836.77 1,025.44 311.51 17.82 17.5 105.0 0.0 Cloudy,WC 19" NE @ 29 MPH Daily summary operation 24h Summary Ddg f/8285'-9307'(3361'TVD). Operation at 07.00 Drilling ahead @ 9,499'MD 24h Forecast Drill 12.25"intermediate hole as per SLB. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg f/8285'-8573'(3234'TVD)@ 857 gpm,1840 psi,10k wob.12k tqn.9k tqf.205k puw,90k sow,142k rotw,9.96 ECD,Max Gas 3.4.95 ADT,59.13 Bit,83.73 Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drtg f/8573'-8669'(3251'TVD)@ 860 gpm. 1800 psi.110 rpm,10k wob.10k tqn.9k tqf.195k puw 98k sow,143k rotw.9.85 ECD,Max Gas3,4.44 ADT,63.57 Bit,88.17 Jars. -12:00 1800 6.00' 18.00 DRILL E 3 'P PJSA Ddg f/8669'-9016'(3361'TVD)@ 850 gpm,1820 psi,120-200 rpm 2-14k wob,11k tqn,7k tqf,180k puw,102k sow,145k rotw,9.97 ECD,Max Gas 21,4.96 ADT,68.53 Bit,93.13 Jars.SPR @ 8752'(3271'TVD)w/9.2 MW;#1/#2/ #3/@ 30-210 psi.@ 40-220 psi. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Ddg f/9016'-9307'(3361'TVD)@ 650 gpm.1200 psi,120-200 rpm,2-14k wob,14k tqn,9k tqf,180k puw,105k sow,142k rotes,9.77 ECD,Max Gas 41,3.47 ADT,72.00 Bit,96.60 Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv .SIDDnlling@enipetroleum.com '907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonly@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING _ 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 Irifi* Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq • API/UW1:50-629-23494-00-00 2 Illi�, Date:9/912013 - Report#: 15 page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information - _..._ Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5135-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6,074.97 166.72 36.4 12.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,915.72 1,038.96 78.94 4.51 17.5 105.0 0.0 Fog,Mist,WC 21' NE @ 16 MPH Daily summary operation 24h Summary Ddg f/9307'-9566'(3404'TVD).Could not get directional results and decided to POOH.Perform K&M cleanup cycle and BROOH to 4642'. Operation at 07.00 BROOH @ 3529'. 24h Forecast BROOH to 3160'and circulate hole clean.Monitor well and work on Brakes and/BOP.Pull 5 stands and monitor well.Pump dry job and POOH LD BHA#3.M/U New BHA as needed and RIH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -05:30 5.50 5.50 DRILL E -3 P PJSA Ddg f/9307'-9566'(3404'TVD)@ 650 gpm.1200 psi,130 rpm,10-14k wob,13k tqn,9k tqf,182k puw,105k sow, 145k rotw,9.89 ECD,Max Gas 25,4.51 ADT,76.51 Bit,101.11 Jars.SPR @ 9566'(3404'TVD)w/9.2 MW;#1/#2/#3/@ 30-220 psi,@ 40-250 psi. 05:30 '12:00 6.50 12.00 DRILL E '4 P PJSA Perform K&M cleanup cycle @ 4 CBU's racking back stand each btms up.f/9566'-9036'@ 900 gpm,1950 psi.135 rpm.11k tq,180k puw.102k sow. 12:00 18:00 6.00 18.00'DRILL E 4 P PJSA BROOH f/9036'-6327'@ 900 gpm,1650 psi,130 rpm,10k tq,160k puw,110k sow.130k rotw,9.94 ECD. 18-00 00:00 6.00 24.00 DRILL E "4 P PJSA BROOH 1/6327'-4642'@ 900 gpm,1550 psi,130 rpm,5-11k tq,170k puw,100k sow.128k rotw.21 bbl fluid loss for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross 'ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator 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@doyondrilling.com 907-685-0716 Tool Push Pete Madinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 111#1 Eni E&P Division I Well Name:5135-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 enII Date:911012013 - Report#: 16 I' II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI35-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 13.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.915.72 1,038.96 0.00 106.0 1.1 Cloudy,WC 24" E @ 20 MPH Daily summary operation 24h Summary BROOH to shoe @ 3160'and circ.hole clean.POOH on elevators and UD BHA#3.Note:excessive BHA wear.P/U&M/U BHA#4 and RIH to 1000'and perform shallow hole test.Continue to RIH taking surveys as per SLB MWD schedule to 3520'. Operation at 07.00 RIH @ 6.360'MD. 24h Forecast RIH taking surveys as per SLB.Wash to bottom and set drilling parameters and doll ahead as per SLB. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0530 5.50 5.50 DRILL E 4 P PJSA BROOH f/4642'-3151'@ 900 gpm,1350 psi,130 rpm,5k tq,145k puw,123k sow.134k rotw. 05:30 07:30 2.00 7.50 DRILL E 7 P PJSA Circulate and condition mud @ shoe @ 900 gpm,1350 psi,125 rpm,5k tq,145k puw,123k sow.Monitor well- static. 07:30 08:00 0.50 8.00 DRILL E 25 P PJSA Service draw works,top-drive and traveling equipment. 08:00 10:00 2.00 10.00 DRILL E 4 P PJSA POOH on elevators fl 3151'-350'. 10:00 13:00 3.00 13.00 DRILL E 4 P PJSA UD BHA#3 as per SLB.Excessive BHA wear.Toady fluid loss-12 bbls. 13:00 14:30 1.50 14.50 DRILL E 20 P PJSA UD BHA#3 from dg floor and clean area. 14:30 16:30 2.00 16.50 DRILL E 20 P PJSA P/U BHA#4 tools and start M/U. 16.30 17:00 0.50 17.00 DRILL E 25 P Service rig. 17.00 18:00 1.00 18.00 DRILL E 12 P Program new Arc tool. 18.00 19:00 1.00 19.00 DRILL E 4 P PJSA P/U and M/U BHA#4 and RIH to 350'. 19.00 00:00 5.00 24.00 DRILL E 4 P PJSA RIH to 1000'and perform shallow hole test @ 650 gpm,640 psi.Continue RIH to 3157 and set down 10k.Pick up to 3150'and kelt'up and wash down through obstruction @ 650 gpm,710 psi.RIH to 3520'taking surveys as per SLB MWD schedule.145k puw.124k sow.132k rotw. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator 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 dg15@doyondrilling.com 907-685-0716 Tool Push Pete Madinusen Doyon Drilling Tour Pusher dg15@doyonddlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 1111* * Eni E&P Division I Well Name:S135-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 2�fi,c,II rl Date:9/11/2013 - Report#: 17 page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) I Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.371 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 14.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,429.00 1.083.47 512.98 7.40 69.3 106.0 0.0 Fog,Mist,WC 19" ENE @ 20 MPH Daily summary operation 24h Summary RIH to 9567'.Dug f/9567-11.250'Geologist's TD(3550'TVD).BROOH f/11,250'-11,214'as per K&M schedule. Operation at 07.00 BROOH @ 10,898'. 24h Forecast BROOH to 1150'and CBU.POOH and L/D BHA#4. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 4 P PJSA RIH f/3520'-7700'surveying @ 3519',3800',4360'and every 20 stands when filling pipe. 06:00 07:00 1.00 7.00 DRILL E 4 P PJSA Wash 8 ream f/7700'-7900'@ 600 qpm,800 psi,80 rpm,8-16k tq,185k puw,95k sow,135k rotw. 07:00 08:00 1.00 8.00 DRILL E 4 P PJSA RIH f/7900'-9567'. 08:00 12:00 4.00 12.00 DRILL E 3 P PJSA Ddg f/9567'-9885'(3450'TVD)@ 857 gpm.1940 psi,140 rpm,8k wob.12k tqn,9k tqf,180k puw,110k sow,147k rotw,9.95 ECD,Max Gas 13,1.71 ADT,1.71 Bit,102.81 Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg f/9885'-10,712'(3521'TVD)@ 850 gpm,2120 psi.160 rpm,2-10k wob.13k tqn.8k tqf.10.19 ECD,Max Gas 602,180k puw,105k sow,147k rotw,3.31 ADT,5.02 Bit,106.12 Jars. 18:00 23:30 5.50 23.50 DRILL E 3 P PJSA Drlg fl 10,712'-11,250'(3550'TVD)@ 850 gpm,2200 psi,160 rpm,2-10k wob,14k tqn,8k tqf,10.38 ECD,Max Gas 60,180k puw,107k sow,150k rotw,2.38 ADT,7.40 Bk,108.5 Jars.SPR @ 11,250'(3550'TVD)w/9.2 MW:#1 @ 30 -290,@ 40-330.82 @ 30-300,@ 40-350,#3 @ 30-300,@ 40-340. 23.30 00:00 0.50 24.00 DRILL E 4 P PJSA Monitor well @ 11,250'.BROOH f/11,250'-11,214'as per KW schedule @ 850 gpm,2200 psi,130 rpm,10k tq. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator 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 Dulling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 r.* Eni E&P Division I Well Name:S135-W4 EN!Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq • API/UW:50-629-23494-00-00 2^n Date:9/12/2013 - Report#: 18 I� II'I page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI35-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6,074.97 166.72 36.4 15.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,429.00 1,083.47 0.00 108.0 0.6 Overcast,Light Fog, E @ 13 MPH WC 23° Daily summary operation 24h Summary BROOH f/11,214'-3149'as per K&M schedule. Operation at 07.00 Circulating @ 1,150'. 24h Forecast BROOH and L/D BHA#4.Clear and clean rig floor.Change upper rams to 9 5/8"and test.R/U Tesco casing equipment and P/U&M/U 9 5/8"casing and float in hole. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 1200 ' 12.00 12.00 DRILL 'E '4 P PJSA BROOH f/11,214'-8289'@ 850/860 gpm,2030/1730 psi,140 rpm,l l k tq,170k puw.100k sow,140k rotw.Tourty fluid loss 17 bbls. 12:00 00.00 12.00 24.00 DRILL °E 4 ,.P PJSA BROOH f/8289'-3149'@ 850 gpm.1200 psi,130 rpm,7k tq,129k rotw.Monitor well static.Tourly fluid loss 7 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI °Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 °715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator 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 ng15@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(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 Eni E&P Division . !Well Name:5135-W4 fit* ENI Petroleum Co.Inc. Daily Repo }` Well Code:27429 Field Name: Nikaitchuq • Date:9/13/2013 - Report#: 19 API/UWI:50-629-23494-00-00 e) i r' page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(Ye) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 16.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind • 3,429.00 1,083.47 0.00 107.0 2.8 Light Rain,WC 30" S @ 12 MPH Daily summary operation 24h Summary BROOH to 1150',CBU,POOH and L/D BHA#4.Chg upper rams to 9 5/8"and test.R/U Tesco casing equipment and P/U&M/U 9 5/8"40#L80 H563 casing.Test floats and RIH floating casing in to 8145'.Begin rotating @ 6195'@ 40 rpm.8-9k tq. Operation at 07.00 RIH floating 9 5/8"casing @ 11.080'. 24h Forecast RIH floating 9 5/8"csg to setting depth of 11.232'.Install cement head and R/U and fill casing as per schedule.Install cement plugs in head and break circulation increasing to 7 BPM.PJSA for cementing,pump cement and displace to bumping plug.Pressure up to 500 psi over circ pressure and hold for 5 min.Bleed pressure and R/D.N/D stack and raise to have Vetco to set emergency slips and cut casing. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1096.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 P PJSA BROOH f/3149'-1150'@ 873 gpm,1040 psi,129 rpm,3k tq,115k puw.112k sow.115k rotw. 03:30 04:00 0.50 4.00'DRILL E 7 P PJSA CBU @ 1150'@ 871 gpm,1010 psi,135 rpm. 04:00 05:00 1.00 5.00 DRILL E 4 P PJSA Blow down top-drive.POOH on elevators to 350'. 05:00 07:30 2.50 7.50 DRILL E 4 P PJSA L/D BHA#4 as per SLB. 07:30 08.30 1.00 8.50 DRILL E 20 P PJSA Clear and clean floor and Sim Ops preping for ram change. 08:30 09.30 1.00 9.50 DRILL C 20 P PJSA Change upper rams to 9 5/8". 09:30 12.00 2.50 12.00 DRILL C 12 P PJSA Pull wear bushing.set test plug w/9 5/8"test It and test 9 5/8"rams to 250/3500 psi for 5 chased min.R/D test equipment and Vetco set modified wear ring. 12:00 14:30 2.50 14.50 DRILL G 20 P PJSA R/U Tesco casing equipment and prep to run casing. 14:30 00:00 9.50 24.00 DRILL G 4 P PJSA P/U 8 M/U 9 5/8"shoe track,fill w/LSND mud and check floats Float casing in hole w/9 5/8"40#L-80 H563 casing to 8145'.Begin rotating @ 6195'@ 40 rpm,8-9k tq. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15@doyondnIling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 0.01 963.17 9/1/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgftcm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 • If* Eni E&P Division I Well Name: SI35-W4 ENI Petroleum Co.Inc. Daily ReportWell Code:27429 Field Name:Nikaitchuq • APIIt1Wl:50-629-23494-00-00 2^0 Date:9/14/2013 - Report#: 20 II 'I page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N' Operator ENI Share(%( Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S135-5V4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 17.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 3,429.00 1,083.47 0.00 105.0 0.0 Overcast,WC 20" N @ 18 MPH Daily summary operation 24h Summary RIH w/9 5/8"406 L-80 H563 casing to 11,232'.R/U cement head and fill casing w/9.15 ppg LSND mud as per MI schedule.Break circulation and stage up to 8 bpm,400 psi.PT cmt lines and pump 218 bbls of cmt and displace w/LSND mud and bump plug to 1060 psi.Floats held and CIP @ 2050 Hrs.Perform injectivity test w/25 bbls of 9.15 ppg LSND mud.R/D from cement job and begin N/D BOPE. Operation at 07.00 Changing out Vetco Gray multibowl. 24h Forecast N/D BOPE and P/U stack and set Vetco emergency slips and cut 9 5/8"casings as per Vetco.Pull and L/D cut casing.Set back stack and remove riser and Vetco multi bowl.Install new mullibowl and install packoff and test.N/U riser and stack.Change upper rams to 3.5"X 6"variables and prep to test BOPE w/AOGCC Bob Noble. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1096.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 DRILL G 4 P PJSA RIH w/9 5/8"casing f/8175'-11,232', 40-50 rpm,8-9k tq,70k sow,88k rotw. 04:30 05:30 1.00 5.50 DRILL G 4 P PJSA R/D Tesco casing equipment and R/U cement head. 05:30 11:00 5.50 11.00 DRILL G 19 P PJSA Fill 9 5/8"casing w/9.15 ppg LSND mud as per MI schedule,1/2,3/4 and top off.R/D from filling operations.SLB load plugs in cement head. 11:00 12:00 1.00 12.00 DRILL G 7 P PJSA Break circulation @ 1.5 bpm,330 psi and stage up to 3 bpm,340 psi. 12:00 17:00 5.00 17.00 DRILL G 7 P PJSA Stage circulation rate to 8 bpm,400 psi,and lower YP to 17. 17.00 21:00 4.00 21.00 DRILL H 7 P PJSA PT Cmt.line to 500/3500 psi.Rig pump 100 bbls of 10.5 ppg Mud Push II @ 6 bpm,280 psi.Drop btm plug and SLB pump 218 bbls of 12.5 ppg DeepCrete cement @ 6 bpm.ICP 1040 psi,FCP 560 psi.Drop top plug and kick out w/12 bbls 4 water and displace w/rig pumps a total of 830 bbls @ 7/3 bpm,110/560 psi.Bumped plug and pressure up to 1060 psi fir's.,, and hold for 5 min.Bleed of pressure and floats held.CIP @ 2050 hrs.R/D and blow down cement lines. 21:00 21:30 0.50 21.50 DRILL E 9 P PJSA Close annular preventer and inject 25 bbls of LSND mud down annulus @ 3 bpm,635 psi.Bleed of pressure. ,,--= 21:30 22.00 0.50 22.00 DRILL E 20 P PJSA R/D cement head,clean and remove from floor. 22:00 23:30 1.50 23.50 DRILL E 20 P PJSA Install bails,M/U TIW,5' 5"pup and stand of 5"DP&displace mud in 9 5/8"casing.Pull and R/D.Blow down choke &kill lines.Suck out stack. 23:30 00:00 0.50 24.00 DRILL C 20 P PJSA N/D BOPE. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyonl5@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 Dnlling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgftcm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 Eni E&P DivisionWell Name:SI35-W4 ft* ENI Petroleum Co.Inc. DCI I Iy Report Well Code:27429 Field Name:Nikaitchuq • Date:9/15/2013 - Report#: 21 APIIIAM:50 629-23494-00-00 e "H page 1 of 1 Wellbore name: SI35-W4 Well Header • Permit/Concession N° Operator EM Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6.069.18 1.100.21 6.074.97 166.72 36.4 18.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,429.00 1.083.47 0.00 106.0 -2.8 Overcast,WC 17° NE @ 9 MPH Daily summary operation 24h Summary N/D BOPE and set Vetco emergency slips and cut 9 5/8"casing.C/O Vetco mu8ibowl,install packoff and N/U BOPE and test equipment.R/U and test BOPE as per AOGCC witnessed by Bob Noble. Freeze protect Annulus w/105 bbls of diesel @ 1 bpm.1000 psi.R/U and M/U 4.5"DP and rack in derrick. Operation at 07.00 M/U 4.5"DP and rack back 67 stands in derrick. 24h Forecast M/U and rack 4.5"DP in derrick.Cut and slip drig line and C/O saver sub.P/U and M/U BHA#5 as per SLB and RIH to 1000'and perform surface test.RIH logging cement to TO float collar.Test casing to 3000 psi for 30 charted min.Displace well to FazePro mud.Drill shoe track&20'of new hole. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1096.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL C 20 P PJSA N/D BOPE and prep to set emergency slips. 01:30 02:30 1.00 2.50 DRILL C 20 P PJSA Set Vetco emergency slips w/100,0000 over.Cut 9 5/8"casing and L/D landing jt.w/4.70'cut piece. 02.30 06:30 4.00 6.50 DRILL C 12 P PJSA C/O Vetco mullibowl assy.and install 9 5/8"packoff and test to 2472 psi. 06.30 09:00 2.50 9.00 DRILL C 20 P PJSA N/U BOPE and C/O upper rams to 3.5"X 6"variables. 0900 10:30 1.50 10.50 DRILL C 12 P PJSA R/U and set test plug and perform body test on BOPE. 10:30 13:00 2.50 13.00 DRILL E 20 P PJSA P/U&M/U 4.5"DP and rack back in derrick. 13:00 14:00 1.00 14.00 DRILL C 20 P PJSA set test plug,R/U to test BOPE and fill stack/choke. 14:00 20:00 6.00 20.00 DRILL C 12 P PJSA Test BOPE w4.5"and 5.5"test jts.as per AOGCC regs and witnessed by Bob Noble.Test all alarms and gas detectors. 20:00 21:00 1.00 21.00 DRILL C ''12 P PJSA Blow down choke manifold,test spare upper and lower IBOP to 250/3500 psi.R/D testing equipment. 21:00 22:00 1.00 22.00 DRILL C 20 P PJSA pull test plug and set wear bushing(9.00"ID).Sim-Ops;Freeze protect 13 3/8"X 9 5/8"Annulus w/105 bbls of diesel with Lil Red Services @ 1.5 psi,825 psi.Job completed @ 2330 hrs.R/D and secure well. 22:00 22:30 0.50 22.50 DRILL E 20 P PJSA Install mousehole and prep to P/U DP. 22:30 00:00 1.50 24.00 DRILL E 20 P PJSA P/U&M/U 4.5"DP and rack in derrick. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com '907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator 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@doyondniling.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(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 fl"441 Eni E&P Division (Well Name:SI35-W4 EN/Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq •eft] Date:9/16/2013 - Report#: 22 APIIUWI 50 629-23494-00-00 II II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 19.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,429.00 1,083.47 0.00 106.0 -2.8 Overcast,WC 14° NE @ 20 MPH Daily summary operation 24h Summary P/U 4.5"DP and rack in derrick.Replace saver sub.M/U BHA#5 as per SLB and RIH to 8200'and begin logging cement bonding to 11.148'TO float collar. Operation at 07.00 Displacing well to FazePro OBM. 24h Forecast Perform casing test to 3000 psi f/30 charted min.PJSA and displace well to 9.2 ppg FazePro OBM.Cut and slip drill line and calibrate blocks.Set drilling parameters and drill shoe track plus 20'of new hole.CBU and balance mud and rack back stand.Perform FIT/LOT and report results.Drill ahead as per SLB. _ Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1096.4 • Time Log k Start End Cum 1 Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 6.00 6.00 DRILL E 20 P PJSA P/U&M/U 4.5"DP and rack in derrick. i 06.00 08.00 2.00 8.00 DRILL E 25 P PJSA C/O saver sub. 08.00 09.00 1.00 9.00 DRILL E 20 P PJSA Clear and clean ng floor.Mobilize BHA#5 and prep for P/U. 09.00 12:30 3.50 12.50 DRILL E 4 P PJSA P/U&M/U BHA#5 as per SLB and RIH to 371'. 12:30 13:00 -0.50 13.00 DRILL E 20 P PJSA Change handling equipment to 4.5". 13.00 1630 3.50 16.50 DRILL E 4 P PJSA RIH f/371'-1321'110k puw/sow.Perform shallow hole test @ 330 gpm,400 psi.RIH f/1321'-8152',135k puw, 104k sow. 16.30 00:00 7.50 24.00 DRILL E 4 P PJSA Kelly up and send down link as per MWD @ 400 gpm,1150 psi.Perform Medd Pass @ 900 ft/hr f/8152'-11.066'. Wash down f/11,066'and tag TO float collar©11,148'@ 130 gpm,460 psi.MWD down link @ 400 qpm.1150 psi.POOH to 11.066',182k puw,104k sow. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie 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 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(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 963.17 732.93 LSND 1114.4 20.4 1392.6 102.0 ft* En!E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • API/UWI:50-629-23494-00-00 2�,r, Date:9117/2013 - Report#: 23 If II ii page 1 of 1 Wellbore name: SI35-W4 Well Header PermitIConcession N° Operator ENI Share)%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL • Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 _ 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6,074.97 166.72 36.4 20.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hourss)hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,827.37 1,085.91 398.37 5.08 78.4 106.0 -1.1 Overcast,WC 15" NE @ 28 MPH Daily summary operation 24h Summary R/U to perform 30 Min 9 5/8"Csg.test to 3.000 PSI on chart.Witnessed by Co Rep.R/D test Equip.9 bbl to achieve test Press.,W/8.5 bbl returned back Men bled down.Displace LSND to Faze Pro as per MI Swaco plan forward.Pumped 27 bbl Hi Vis spacer,28 bbl LVT spacer and 789 bbl OBM.ROT WT 145K,SLK 110K,940 PSI.Slip and cut drilling line,service traveling Equip..Drawv arks&Top Drive.Adjust Brakes,SIMOPS clean surface Equip.from displacement.Drill out Float Equip.F/11,232'to 11.250'MD.HST 180K.SLK 108K,ROT 144K.TRQ 10K.RPM 55.450 GPM,2,060 PSI,WOB 5-8K,Drill 20'of new hole F/11,250'to 11,270'MD.Rack back one stand and L/D single Jnt to 11,232'MD.HST 180K,SLK 108K,ROT 144K.TRO 9K,MW 9.1 ppg.Max Gas 2 units.ADT 0.15 Hrs,Bit r(-f Hrs 0.15,Jar Hrs 0.15.Monitor well,static.CBU and prep for FIT.CBU to balance MW to 9.2 ppg.450 GPM,2,060 PSI,55 RPM,TRQ 8-9K.Blow down Top Drive.R/U to FIT well,close Annular Preventer and FIT to 13.0 ppg EMW.Pumped 2.5 bbl,bled back 2.4 bbl.Open Annular Preventer,blow down&R/D.Wash and ream F/11,232'&tag bottom @ 11,270'MD.Shoot survey and send down link as per Sclumberger DD.Drill 8.75"production hole F/11,270'to 12,557'MD(3.557'TVD)550 GPM,2,960 PSI,170 RPM.TON 15K,TQF 12-13K,WOB 4-8K,HST 186K,SLK 83K,ROT 141K,ECD 11.10 ppg W/9.2 ppg MW.Max Gas 1,584 units.ADT 5.08.Bit Hrs 5.08,Jar Hrs 5.08.Monitor well,static. Operation 0107.00 Drill 8.75"to 12,784'MD. 24h Forecast Drill 8.75"Production hole as per Well Plan and Schlumberger DD to-19,912'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 12 P PJSA R/U to perform 30 Min 9 5/8"Csg.test to 3.000 PSI on chart.Witnessed by Co Rep.R/D test Equip.9 bbl to achieve test Press.,W/8.5 bbl retumed back when bled down. 01:30 0430 3.00 4.50 DRILL E 9 P PJSA Displace LSND to Faze Pro as per MI Swaco plan forward.Pumped 27 bbl Hi Vis spacer,28 bbl LVT spacer and 789 bbl OBM.ROT WT 145K,SLK 110K,940 PSI. 04:30 06.30 2.00 6.50 DRILL E 20 P PJSA Slip and cut drilling line,service traveling Equip.,Drawworks&Top Drive.Adjust Brakes,SIMOPS clean surface Equip.from displacement. 06:30 11:30 5.00 11.50 DRILL E 3 P PJSA Drill out Float Equip.F/11,232'to 11,250'MD.HST 180K,SLK 108K,ROT 144K,TRO 10K,RPM 55,450 GPM, 2.060 PSI,WOB 5-8K. 11:30 12:30 1.00 12.50 DRILL E 3 P PJSA Drill 20'of new hole Fl 11,250'to 11,270'MD.Rack back one stand and L/D sindle Jnt to 11,232'MD.HST 180K, SLK 108K,ROT 144K,TRQ 9K,MW 9.1 ppg.Max Gas 2 units.ADT 0.15 Hrs,Bit Hrs 0.15,Jar Hrs 0.15.Monitor well, static.CBU and prep for FIT.CBU to balance MW to 9.2 ppg.450 GPM,2,060 PSI,55 RPM,TRQ 8-9K.Blow down Top Drive, SPR @ 11,132'MD(3,542'TVD)W/9.2 ppg MW MP#1 30-200,40-250 MP#2 30-200,40-250 MP#3 30-200,40-250 12:30 13.30 1.00 13.50 DRILL E 11 P PJSA R/U to FIT well,close Annular Preventer and FIT to 13.0 ppg EMW.Pumped 2.5 bbl,bled back 2.4 bbl.Open rr Annular Preventer,blow down&R/D. r 1 1 13:30 14.00 0.50 14.00 DRILL E 4 P PJSA Wash and ream F/11,232'&tag bottom @ 11,270'MD.Shoot survey and send down link as per Sclumberger DD. ��! 500 GPM,2,440 PSI,50 RPM,TRO 9K,HST 192K,SLK 98K,ROT 140K. 14:00 18:00 4.00 18.00 DRILL E 3 P PJSA Drill 8.75"production hole F/11,270'to 11,716'MD(3,559'TVD)550 GPM,3,020 PSI,150 RPM.TON 13-14K.TQF 11-12K,WOB 4-12K,HST 186K,SLK 98K,ROT 140K,ECD 10.96 ppg W/9.15 ppg MW.Max Gas 1,294 units.ADT 2.06, Bit Hrs 2,21,Jar Hrs 2.21.Monitor well,static. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"production hole Fl 11,716' to 12,557'MD(3,557'TVD)550 GPM,2,960 PSI,170 RPM.TON 15K.TQF 12 -13K,WOB 4-8K,HST 186K,SLK 83K,ROT 141K.ECD 11.10 ppg W/9.2 ppg MW.Max Gas 1,584 units.ADT 2.87,Bit Hrs 5.08,Jar Hrs 5.08.Monitor well,static. SPR 12,089'MD(3.558'TVD)W/9.15 ppg MW MP#1 20-260,30-340 MP#2 20-250,30-330 MP#3 20-250,30-330 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling@enipetroleum.corn 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Dolling 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(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test _ - Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.429.61 1,083.52 FazePro 11264 49.9 1587.1 171.9 1, Eni E&P Division (Well Name:S135-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • API/UWI:50-629-23494-00-00 enil Date:9/18/2013 - Report#: 24 II II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) •RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5135-004 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 21.27 Daily Information End Depth(mKB) End Depth(TVD((... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,270.55 1,084.72 443.18 16.27 27.2 108.0 0.0 Light Snow WC 22° ENE @ 24 MPH Daily summary operation 24h Summary Drill 8.75"production hole F/12,557'to 14,011'MD(3,556'ND)550 GPM,2,990 PSI,120-180 RPM,TQN 18-20K.TQF 14-15K,WOB 6-14K,HST 197K,SLK 83K,ROT 141K.ECD 11.34 ppg W/9.25 ppg MW.Max Gas 1.152 units.ADT 16.27.Bit Hrs 21.35,Jar Hrs 21.35.Monitor well,static.Encountered slow drilling due to crossing from OA 3 to OA 2 sand. Operation at 07.00 Drill 8.75"to 14,424'MD. 24h Forecast Drill 8.75"Production hole as per Well Plan and Schlumberger DD F/14,011'to-19.912'MD. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End ' Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00' 6.00 DRILL .E 3 P PJSA Drill 8.75"production hole FI 12,557'to 12,837'MD(3,559'ND)536 GPM,2,750 PSI.170 RPM,TQN 16-17K.TQF 13K,WOB 8-10K,HST 195K,SLK 83K,ROT 141K.ECD 11.05 ppg W/9.15 ppg MW.Max Gas 1,300 units.ADT 4.15,Bit Hrs 9.23,Jar Hrs 9.23.Monitor well,static. 06.00 12:00 6.00' 12.00 DRILL •E 3 P PJSA Drill 8.75"production hole FI 12,837'to 13.398'MD(3,564'ND)552 GPM,2,760 PSI,161 RPM,TON 16K,TQF 15K,WOB 4-6K,HST 190K.SLK 83K,ROT 141K.ECD 11.39 ppg W/9.15 ppg MW.Max Gas 1,325 units.ADT 2.92,Bit Hrs 12.15,Jar Hrs 12.15.Monitor well,static. SPR @ 13,115'MD(3,569'ND)WI 9.2 ppg MW MP#1 30-370,40-470 i MP#2 30-370,40-470 MP#3 30-370,40-470 12:00 18:00 6.00 18.00 DRILL .8 3 P PJSA Drill 8.75"production hole F/13,398'to 13,864'MD(3.557'ND)550 GPM,2,990 PSI.120-190 RPM,TON 18-20K. TQF 14-15K,WOB 4-18K,HST 198K,SLK 83K,ROT 141K.ECD 11.39 ppg W/9.25 ppg MW.Max Gas 2,968 units.ADT 4.17,Bit Hrs 16.32,Jar Hrs 16.32.Monitor well,static. 18:00 00:00 6,00 24.00 DRILL 'E 3 P PJSA Drill 8.75"production hole F/13,864'to 14,011'MD(3,556'ND)550 GPM,2,990 PSI,120-180 RPM,TON 18-20K, TQF 14-15K,WOB 6-14K,HST 197K,SLK 83K,ROT 141K.ECD 11.34 ppg W/9.25 ppg MW.Max Gas 1,152 units.ADT 5.03,Bit Hrs 21.35,Jar Hrs 21.35.Monitor well,static.Encountered slow drilling due to crossing from OA 3 to OA 2 sand. SPR @ 13,957'MD(3,554'ND)W/9.2 ppg MW MP#1 20-320,30-400 MP#2 20-320,30-400 MP#3 20-320,30-400 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 Dnlling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher 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) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.429.61 1,083.52 FazePro __ 1126.4 49.9 1587.1 171.9 If* Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc- Daily Report Well Code:27429 Field Name:Nikaitchuq • 2^I�,t Date:9/19/2013 - Report#: 25 API/UW:50 629-23494-00-00 illi page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI35-W4 DRILLING 8/28/2013 6069.18 1.100.21 6,074.97 166.72 36.4 22.27 Daily Information , End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 4.966.11 1,084.41 695.55 13.63 51.0 103.0 -1.1 Cloudy WC 30` Calm Daily summary operation 24h Summary Drill 8.75"production hole F/14,011'to 16,293'MD(3,556'TVD)530 GPM,3,050 PSI,120-180 RPM,TON 18K,TQF 15K,WOB 6-8K,HST 205K,SLK 83K,ROT 140K.ECD 11.65 ppg W/9.25 ppg MW. Max Gas 2,357 units.ADT 13.63,Bit Hrs 34.98,Jar Hrs 34.98.Monitor well,static. Operation at 07.00 Drill 8.75"to 16,574'MD. 24h Forecast Drill 8.75"Production hole as per Well Plan and Schlumberger DD F/16,293'to-'19.912'MD. Lithology Shows MAASP(kgflcm2) Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"production hole F/14,011'to 14.705'MD(3.542'TVD)545 GPM,3,060 PSI,120-180 RPM,TON 18K, TQF 15K,WOB 6-8K,HST 210K,SLK 83K,ROT 139K.ECD 11.55 ppg W/9.25 ppg MW.Max Gas 1,370 units.ADT 3.38, Bit Hrs 24.73,Jar Hrs 24.73.Monitor well,static. 06'00 12.00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"production hole F/14,705'to 15.266'MD(3.537'TVD)545 GPM,3,050 PSI,120-140 RPM,TON 19K, TQF 18K,WOB 6-8K,HST 205K,SLK 83K,ROT 140K ECD 11.69 ppg W/9.25 ppg MW.Max Gas 1,242 units.ADT 3.15, Bit Hrs 27.88,Jar Hrs 27.88.Monitor well,static. SPR @ 14,985'MD(3,539'TVD)W/9.2 ppg MW MP#1 20-360,30-460 MP#2 20-360,30-450 MP#3 20-360,30-450 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"production hole F/15,266'to 16.003'MD(3.555'TVD)550 GPM,3,230 PSI,120-180 RPM,TON 17-19K, TQF 16K,WOB 4-12K.HST 235K,SLK 83K,ROT 145K.ECD 11.84 ppg W/9.25 ppg MW.Max Gas 1,544 units.ADT 3.95,Bit Hrs 31.83,Jar Hrs 31.83.Monitor well,static. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"production hole F/16,003'to 16,293'MD(3,556'TVD)530 GPM,3,050 PSI,120-180 RPM,TQN 18K, TQF 15K,WOB 6-8K,HST 205K,SLK 83K,ROT 140K ECD 11.65 ppg W/9.25 ppg MW.Max Gas 2,357 units.ADT 3.15. Bit Hrs 34.98,Jar Hrs 34.98.Monitor well,static. SPR @ 16,013'MD(3,539'TVD)W/9.2 ppg MW MP#1 20-390,30-490 MP#2 20-390,30-490 MP#3 20-390,30-490 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 Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher dg15@doyondrilling.com /907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 1.73 3,423.51 9/14/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm2) 3,429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 litAilliS Eni E&P DivisionWell Name:SI35-W4 ENI Petroleum Co.Inc. Daily ReportWell Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 enEl Date:9/20/2013 - Report#: 26 �I 'I page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6.069.18 1,100.21 6,074.97 166.72 36.4 23.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,535.17 1,082.89 569.06 12.95 43.9 103.0 0.0 Light Snow WC 22' ENE @ 22 MPH Daily summary operation 24h Summary Drill 8.75"production hole Fl 17,740'to 18,160'MD(3,552'TVD)500 GPM,2,940 PSI,120-180 RPM,TON 20-21K,TQF 16K,WOB 4-20K,HST 210K,SLK 83K,ROT 135K.ECD 11.83 ppg WI 9.2 ppg MW.Max Gas 2,286 units.ADT 12.95,Bit Hrs 47.83,Jar Hrs 47.83.Well began taking fluid @ 17,480'MD,losses are from 20-40 bph.Shut down pumps and received 40 bbl back.Well losing about 20- • 40 bph w/ballooning.Monitor well,static.Dynamic loss for day 137 bbl.At 16,760'MDL/D 5"D.P.single 8 R/U Circ.Head.Circ.hole @ 2 bpm 450 PSI,while CIO Swivel Packing on TDS-8.R/D Circ. Head.P/U M/U 5"D.P.single and Kelly up. Operation at 07.00 Drill 8.75"to 18.440'MD. 24h Forecast Drill 8.75"Production hole as per Well Plan and Schlumberger DD F/18,160'10-19.912'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 DRILL E 3 P PJSA Drill 8.75"production hole F/16,293'to 16.760'MD(3,547'TVD)550 GPM,3,230 PSI,120-180 RPM,TQN 18-19K, TOE 16-17K,WOE 4-12K,HST 213K,SLK 83K,ROT 142K.ECD 11.86 ppg WI 9.2 ppg MW.Max Gas 1.365 units.ADT 3.41.Bit Hrs 38.39,Jar Hrs 38,39.Monitor well static. 06.30 07.30 1.00 7.50 DRILL E 20 P PJSA L/D 5"D.P.single&R/U Circ.Head.Circ.hole @ 2 bpm 450 PSI,while C/O Swivel Packing on TDS-8,R/D Circ. Head.P/U M/U 5"D.P.single and kelly up. 07.30 12.00 4.50 12.00 DRILL E 3 P PJSA Drill 8.75"production hole F/16,760'1017,039'MD(3,535'TVD)520 GPM,3.130 PSI,120-180 RPM.TON 18-24K. TQF 16-17K,WOB 4-20K,HST 213K,SLK 83K,ROT 142K.ECD 11.84 ppg W/9.25 ppg MW.Max Gas 1.684 units.ADT 2.17.Bit Hrs 40,46,Jar Hrs 40.46,Monitor well,static. SPR @ 17,039'MD(3,535'TVD)W/9.25 ppg MW MP#1 20-380,30-480 MP#2 20-380,30-480 MP#3 20-380,30-480 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"production hole F/17,039'to 17,740'MD(3,546'TVD)500 GPM,3,000 PSI,120-180 RPM,TON 17-19K, TOE 15-17K,WOB 4-14K,HST 225K,SLK 83K,ROT 141K.ECD 11.71 ppg W/9.2 ppg MW.Max Gas 1,635 units.ADT 3.51,Bit Hrs 43.97.Jar Hrs 43.97.Well began taking fluid @ 17,480'MD.losses are from 20-40 bph.Shut down pumps • and received 40 bbl back.Monitor well,static. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"production hole F1 17,740'to 18.160'MD(3,552'TVD)500 GPM,2,940 PSI,120-180 RPM,TON 20-21K, TQF 16K,WOB 4-20K.HST 210K.SLK 83K,ROT 135K.ECD 11.83 ppg W/9.2 ppg MW.Max Gas 2,286 units.ADT 3.86. Bit Hrs 47.83,Jar Hrs 47.83.Well losing about 20-40 bph w/ballooning.Monitor well.static.Dynamic loss for day 137 bbl. 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 Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • Date:9/21/2013 - Report#: 27 APIIIAM:50-629-23494-00-00 e m "1 page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6,074.97 166.72 36.4 24.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 6,075.27 1,104.02 540.11 10.16 53.2 105.0 -2.8 Overcast WC 18° WNW @ 9 MPH Daily summary operation 24h Summary Drill 8.75"production hole Fl 18,160'to 19,932'MD(3,619'TVD)430 GPM,2,520 PSI,120-150 RPM,TON 18-21K,TQF 17-16K,WOB 4-12K,HST 226K,SLK 83K,ROT 142K.ECD 12.05 ppg W/9.2 ppg MW.Max Gas 2,186 units.ADT 10.16,Bit Hrs 57.99,Jar Hrs 57.99.Shoot survey&down link as per Schlumberger DD.Well losing about 20-40 bph w/ballooning.Monitor well,static.CBU 2X w4tte BROOH as per K&M BROOH schedule F/19,932'to 19,650'MD,450 GPM,2,790 PSI,130 RPM,TRQ 18-19K,ECD 11.73 W/9.25 ppg MW.Max Gas 760 units.Pumps on ROT W'133K. BROOH as hole dictates&per K&M BROOH schedule F/19,650'to 19,279'MD,450 GPM,2,640 PSI,130 RPM,TRQ 18K,ECD 11.71 W/9.25 ppg MW.Max Gas 265 units.Pumps on ROT WT 132K.Dynamic loss about-30 bph.Dynamic loss for the day 551 bbl. Operation at 07.00 BROOH as per K&M BROOH schedule @ 17,640'MD. 24h Forecast BROOH as per K&M BROOH schedule and hole dictates F/19,279'MD to BHA. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"production hole F/18,160'to 18,626'MD(3,562'TVD)450 GPM,2,480 PSI,165 RPM,TON 19-22K,TOE 16K,WOB 10-20K,HST 235K,SLK 83K,ROT 132K.ECD 11.82 ppg W/9.2 ppg MW.Max Gas 2,086 units.ADT 3.10,Bit Hrs 50.93,Jar Hrs 50.93.Well losing about 20-40 bph w/ballooning.Monitor well,static. 06:00 12.00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"production hole F/18,626'to 19,000'MD(3,579'ND)450 GPM,2,350 PSI,150 RPM,TON 18-23K,TQF 17K,WOB 6-22K,HST 230K,SLK 83K,ROT 135K.ECD 11.82 ppg W/9.2 ppg MW.Max Gas 1,013 units.ADT 3.39,Bit Hrs 54.32,Jar Hrs 54.32.Well losing about 20-40 bph ad ballooning.Monitor well,static.Dynamic loss for Tour 254 bbl. SPR @ 18,906'MD(3,576'ND)W/9.25 ppg MW MP#1 20-480,30-570 MP#2 20-490,30-560 MP#3 20480,30-560 1:2 00 '19.30 7.50 19.50 DRILL E 3 P PJSA Drill 8.75"production hole F/19,000'to 19,932'MD(3,619'ND)430 GPM,2,520 PSI,120-150 RPM,TON 18-21K, TQF 17-18K,WOB 4-12K,FIST 226K,SLK 83K,ROT 142K.ECD 12.05 ppg W/9.2 ppg MW.Max Gas 2,186 units.ADT 3.67,Bit Hrs 57.99,Jar Hrs 57.99.Shoot survey&down link as per Schlumberger DD.Well losing about 20-40 bph wl ballooning.Monitor well,static.Dynamic loss during drilling 179 bbl. SPR @ 19,931'MD(3,619'ND)W/9.25 ppg MW MP#1 20-530,30-620 MP#2 20-520,30-600 MP#3 20-510,30.600 19.30 21:30 2.00 21.50 DRILL E 6 P PJSA CBU 2X wfiile BROOH as per K&M BROOH schedule F/19,932'to 19,650'MD,450 GPM,2.790 PSI,130 RPM. TRQ 18-19K,ECD 11.73 W/9.25 ppg MW.Max Gas 760 units.Pumps on ROT WT 133K.Lost 87 bbl while Circ. 21 30 00:00 2.50 24.00 DRILL E 6 P PJSA BROOH as hole dictates&per K&M BROOH schedule F/19,650'to 19,279'MD,450 GPM,2,640 PSI,130 RPM. TRO 18K,ECD 11.71 W/9.25 ppg MW.Max Gas 265 units.Pumps on ROT WT 132K.Dynamic loss about-30 bph. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDrilling@enipetroleumcom 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.corn 907-685-0722 Eni representative 011w Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3,423.51 9/14/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P Leakoff(kgf/cm') 3,429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 1111* Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • 2^o Date:9/22/2013 - Report#: 28 API/UWI:50 29-23494-00-00 I' II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 25.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 6,075.27 1,104.02 0.00 105.0 -5.6 Overcast WC 17' SW @ 4 MPH Daily summary operation 24h Summary BROOH as hole dictates&per K&M BROOH schedule FI 19,279'to 8,917'MD,510 GPM,2,370 PSI,140 RPM,TRF 10K,ECD 10.58 ppg W/9.25 ppg MW.HST 158K,SLK 113K,ROT 130K.Max Gas 47 units.Dynamic loss 1-2 bph.Lost 7 bbl to formation.CBU 1.5X 550 GPM,2,610 PSI,140 RPM,TRQ 10K.ROT 130K,ECD 10.73 ppg W/9.25 ppg MW.Blow down TS-8.C/O handling Equip.to 4.5". Monitor well for 10 Min.,static.POOH on Elevators Fl 8,917'to 8,442'MD @ 24 Min.per stand as per K&M BROOH schedule.HST 155K,SLK 113K.Hold kick while drilling.Pump 15 bbl 10.8 ppg Dry Job @ 5 bpm,430 PSI.Chase with 10 bbl of 9.25 ppg Faze Pro @ 7 bpm.Blow down TS-8.POOH on Elevators as per K&M BROOH schedule F/8.442'to 6,733'MD HST 155K,SLK 118K,Lost 7 bbl while POOH.Clean Rig floor of OBM and service TS-8,Drawworks&Blocks.Total lost to formation today 96 bbl of Faze Pro. Operation at 07.00 POOH on Elevators as per K&M BROOH schedule @ 709'MD. 24h Forecast POOH on Elevators as per K&M BROOH schedule and hole dictates F/6,733'MD to BHA#5.L/D BHA#5 as per Schlumberger DD&MWD.P/U M/U BHA#6 as per Schlumberger DD and RIH to spot Breaker. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 6 P .PJSA BROOH as hole dictates&per K&M BROOH schedule F/19,279'to 16,203'MD,450 GPM,2,400 PSI,140 RPM, TRQ 17K,HST 195K,SLK 83K,ROT 138K.Max Gas 216 units.Dynamic loss slowing to-4 bph @-18,000'MD. 06:00 12:00 6.00 12.00 DRILL E 6 P 'PJSA BROOH as hole dictates&per K&M BROOH schedule F/16,203'to 12,933'MD,450 GPM,2,140 PSI,140 RPM, TRF 15K,HST 190K,SLK 95K.ROT 135K.Max Gas 47 units.Dynamic loss 1-2 bph.Calculated displacement 57 bbl, actual displacement 139 bbl.Lost 82 bbl for this Tour. 12:00 16:30 4.50 16.50 DRILL E 6 P .PJSA BROOH as hole dictates&per K&M BROOH schedule F/12.933'to 8,917'MD,510 GPM,2,370 PSI,140 RPM.TRF 10K,ECD 10.58 ppg W/9.25 ppg MW.HST 158K,SLK 113K,ROT 130K.Max Gas 47 units.Dynamic loss 1-2 bph.Lost 7 bbl to formation. 16:30 17:30 1.00 17.50 DRILL E 7 P .PJSA CBU 1.5X 550 GPM,2 610 PSI,140 RPM,TRQ 10K,ROT 130K,ECD 10.73 ppg W/9.25 ppg MW.Blow down TS-8. 17:30 21:00 3.50 21.00 DRILL E 20 P 'PJSA CIO handling Equip.to 4.5".Monitor well for 10 Min.,static.POOH on Elevetors F/8.917'to 8,442'MD @ 24 Min.per stand as per K&M BROOH schedule.HST 155K,SLK 113K,Hold kick while drilling. 21:00 21:30 0.50 21.50 DRILL E 7 P PJSA Pump 15 bbl 10.8 ppg Dry Job @ 5 bpm,430 PSI.Chase with 10 bbl of 9.25 ppg Faze Pro @ 7 bpm.Blow down TS- 8. 21:30 23:00 1.50 23.00 DRILL E 4 P PJSA POOH on Elevators as per K&M BROOH schedule F/8.442'to 6.733'MD HST 155K.SLK 118K.Lost 7 bbl while POOH. 23:00 00:00 1.00 24.00 DRILL E 20 P "PJSA Clean Rig floor of OBM and service TS-8,Drawworks&Blocks. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Ent representative Jack Keener ENI Senior Dolling Supv SIDDrilling@enipetroleum.com .907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HOE 907-605-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com •907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3.423.51 9/14/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 • IP* Eni E&P Division (Well Name: SI35-W4 ENI Petroleum Co.Inc. Daily Repo,.} Well Code:27429 Field Name:Nikaitchuq e API/UWI: 50-629-23494-00-00 2^ Date:9/23/2013 - Report#: 29 If lI page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N` Operator ENI Share)%) Well Configuration type • 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.16 1.100.21 6,074.97 166.72 36.4 26.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 6,075.27 1,104.02 0.00 105.0 -6.1 Overcast WC 15° SW @ 5 MPH Daily summary operation 24h Summary POOH on Elevators as per K&M BROOH schedule F/6,733'to 375'MD HST 95K,SLK 95K,Lost 7 bbl while POOH.Monitor well,seepage loss.Calculated displacement 48 bbl,actual displacement 62 bbl.Lost 14 bbl during trip.UD BHA#5 as per Schlumberger DO&MWD Rep onsite.Unload nuclear source.The top drill collar showed signs of forward whirl other than that the BHA looked good.Bit grade was 0-1-CT-S-X-IN-NO-TD Clear and clean rig floor of SLB tools,Bring BHA#6 to rig floor via Beaver Slide.Adjust Drawworks Brakes,re torque TS-8 shock pin bolts and secure.P/U M/U BHA#6 as per Schlumberger DD Rep onsite.RIH 2 stands 5"HWDP to 200',CIO Elevators to 4.5".HST 85K,SLK 85K TIH F/200'to 4,945'MD W/4.5"D.P.Filling every 2,000'of D.P.HST 132K,SLK 110K. No losses to formation.TIH W/4.5"D.P.F/4,945'to 8,744'MD,CIO Elevators and slips for 5"D.P.Cont TIH W/5"D.P.F/8,744'to 11,077'MD.HST 170K,SLK 111K Filling D.P.every 2,000'.Cut and slip drilling line.Adjust brakes and rollers.TIH W/5"D.P.F/11,077'to 17,427'MD HST 201K,SLK 75K.Encountered tight spot @ 17,137'MD.Reamed twice and did not see it passing by again.Rotate in the hole Fl 17,427'to 19,853'MD,60 RPM,TRQ 15K,HST 211K,ROT WT 140K Wash and ream to bottom @ 19,932'MD,60 RPM,TRO 15 K,3.5 bpm,590 PSI.Begin Circ.@ 3.5 bpm,580 PSI,60 RPM,TRO 15K,ROT WT 140K.260 bbl pumped.Begin budding Faze Away Breaker at the Mud Plant.Slight seepage loss during TIH. Operation at 07.00 Pump Faze Away Breaker @ 2.5 bpm. 24h Forecast Circ.©3.5 bpm while building Faze Away Breaker.Spot Faze Away Breaker in open hole.Drop Rabbit and POOH on Elevators to 11,000'MD and displace to Brine. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End ' Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 4 P PJSA POOH on Elevators as per K&M BROOH schedule F/6,733'to 375'MD HST 95K,SLK 95K,Lost 7 bbl while POOH. Monitor well,seepage loss.Calculated displacement 48 bbl,actual displacement 62 bbd.Lost 14 bbl during trip. 04:00 06.30 2.50' 6.50 DRILL E 4 P PJSA UD BHA#5 as per Schlumberger DD&MWD Rep onsite.Unload nuclear source.The top drill collar showed signs c, forward whirl other than that the BHA looked good.Bit grade was 0-1-CT-S-X-IN-NO-TD 06:30 07:00 0.50' 7.00 DRILL E 20 P Clear and clean rig floor of SLB tools,Bring BHA#6 to ng floor via Beaver Slide. • 07:00 07:30 0.50' 7.50 DRILL E 20 P PJSA Adjust Drawworks Brakes,re torque TS-8 shock pin bolts and secure. 07:30 08:30 1.00' 8.50 DRILL E 20 P PJSM P/U M/U BHA#6 as per Schlumberger DD Rep onsite.RIH 2 stands 5"HWDP to 200',CIO Elevators to 4.5".HST 85K,SLK 85K. 08:30 12:00 3.50 12.00 DRILL E 4 P PJSA TIH Fl 200'to 4,945'MD WI 4.5"D.P.Filling every 2,000'of D.P.HST 132K,SLK 110K.No losses to formation. 12:00 16:00 4.00 16.00 DRILL E 4 P 'PJSA TIH W/4.5"D.P.F/4,945'to 8,744'MD,C/O Elevators and slips for 5"D.P.Cont TIH W/5"D.P.FI 8,744'to 11,077' MD.HST 170K,SLK 111K.Filling D.P.every 2,000'. 16:00 17:30 1.50' 17.50 DRILL E 20 P PJSA Cut and slip drilling line.Adjust brakes and rollers. 17:30 23:00 5.50' 23.00 DRILL E 4 P PJSA TIH W/5"D.P.FI 11,077'to 17,427'MD HST 201K,SLK 75K.Encountered tight spot @ 17,137'MD.Reamed twice and did not see it passing by again.Rotate in the hole F/17,427'to 19,853'MD,60 RPM,TRO 15K,HST 211K,ROT WT 140K.Wash and ream to bottom @ 19,932'MD.60 RPM,TRQ 15 K,3.5 bpm,590 PSI.Slight seepage loss was seen TIH. 23:00 00:00 1.00- 24.00 DRILL E 7 P PJSA Begin Circ.@ 3.5 bpm,580 PSI.60 RPM.TRO 15K.ROT WT 140K.260 bbl pumped.Begin building Faze Away Breaker at the Mud Plant. 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 Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig 15@doyondrilling com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig 15@doyondrilling com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3,423.51 9/14/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3.429.61 1,083.52 FazePro 1126.4 49.9 1587.1 1719 f ,,iiS Eni E&P Division p [Well Name:SI35-W4 EN/Petroleum Co.Inc. Daily fte pO� Well Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 2 II Illi^n Date:9/24/2013 - Report#: 30 page 1 of 1 Wellbore name: SI35-W4 • Well Header Permit/Concession N. Operator ENI Share)%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) •DFS(days) 5135-1104 DRILLING 8/28/2013 6,069.18 1,100.21 6,074.97 166.72 36.4 27.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 6,075.27 1,104.02 0.00 104.0 -8.3 Clear WC 8" SE @ 7 MPH Daily summary operation 24h Summary Cont.Circ.@ 19,932'MD 3.5 bpm,650 PSI,60 RPM,TRQ 15K,ROT WT 142K.SIMOPS Build 700 bbl Faze Away Breaker @ MI Mud Plant.PJSM W/all essential personnel for spotting Faze Away Breaker.Test lines F/Mud Plant to Rig W/Brine.Pump 630 bbl Faze Away @ 2.3 bpm,ICP 410 PSI.60 RPM.TRQ 18.5K,ROT WT 142K,HST 210K.Lost 30 bbl to formation.PJSM W/all essential personnel for spotting Faze Away Breaker.Pumped a total of 655 bbl Faze Away @ 2.3 bpm,320 PSI.Spot in place W/125 bbl Faze Pro mud @ 2.5 bpm,320 PSI.Pump 30 bbl 11.4 ppg Dry Job @ 2.5 bpm.230 PSI,60 RPM.TRQ 18-19K,ROT WT 142K,HST 210K.POOH on Elevators as per K&M POOH schedule F/19,932'to 11,006'MD.HST 176K,SLK 105K.Lost 94 bbl to formation on top.PJSM W/all essential personnel on displacing OBM to 9.1 ppg Brine.Pump 30 bbl LVT spacer @ 5 bpm,520 PSI,pump 60 bbl Citric Acid spacer @ 5 bpm 640 PSI,Displace well W/9.15 ppg KCL/NaCl Brine @ 6 bpm.500 PSI,60 RPM,TRQ 10K.240 bbl displaced.Lost 37 bbl. Operation at 07.00 POOH on elevators @ 10,076'MD 24h Forecast POOH on elvators.L/D 24 stands of 4.5"D/P.L/D BHA 06.R/U GBR to run 4.5"Liner.RIH W/4.5"Liner as per tally. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start • End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 06:00 600 6.00 DRILL E 7 P PJSA Cont.Circ.@ 19,932'MD 3.5 bpm.650 PSI,60 RPM,TRO 15K,ROT WT 142K.SIMOPS Build 700 bbl Faze Away Breaker @ MI Mud Plant. 06.00 12:00 6.00 12.00 DRILL E 9 P PJSM W/all essential personnel for spotting Faze Away Breaker.Test lines F/Mud Plant to Rig W/Brine.Pump 630 bbl Faze Away @ 2.3 bpm,ICP 410 PSI.60 RPM,TRO 18.5K,ROT WT 142K,HST 210K.Lost 30 bbl to formation. 12'00 14:00 2.00 14.00 DRILL E 9 P PJSM W/all essential personnel for spotting Faze Away Breaker.Pumped a total of 655 bbl Faze Away @ 2.3 bpm,320 PSI.Spot in place WI 125 bbl Faze Pro mud @ 2.5 bpm,320 PSI.Pump 30 bbl 11.4 ppg Dry Job @ 2.5 bpm.230 PSI,60 RPM,TRO 18-19K.ROT WT 142K,HST 210K. 14.00 '21:30 7.50 21.50 DRILL E 4 P PJSA POOH on Elevators as per K&M POOH schedule F/19,932'to 11.006'MD.HST 176K,SLK 105K,Lost 94 bbl to formation on trip. 21 30 '00:00 2.50 24.00 DRILL E 9 P PJSM W/all essential personnel on displacing OBM to 9.1 ppg Brine.Pump 30 bbl LVT spacer @ 5 bpm,520 PSI,pump 60 bbl Citric Acid spacer @ 5 bpm 640 PSI,Displace well W/9.15 ppg KCUNaCI Brine @ 6 bpm,500 PSI,60 RPM,TRQ • 10K.240 bbl displaced.Lost 37 bbl. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv ' 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 1.73 3,423.51 9/14/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 T 1 , IfY* Eni E&P Division I Well Name:SI35-W4 J ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq Date:9/25/2013 - Report#: 31• APIIUWI:50 629-23494-00-00 e i II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type • 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S135-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6.074.97 166.72 36.4 28.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 6,075.27 1,104.02 0.00 99.0 -2.8 Overcast WC 15° W @ 16 MPH Daily summary operation 24h Summary Cont.displacing to 9.1 ppg 3%KCL/Nacl Brine @ 6 bpm FCP 320 PSI TRO 11.5K.Total pumped 866 bbl 9.1 ppg Brine.lost 25 bbl to formation @ 12 bph.Clean surface Equip.of OBM.Monitor well 6 bph static loss.L/D 1 Jnt 5"D.P.Blow down TS-8.POOH 5"D.P.on elevators F/10,975'to 8.917'MD.C/O handling Equip.to 4.5"D.P.POOH 4.5"D.P.on elevators F/8.917'to 2,478'MD.POOH F/ 2,478'to 202'MD laying down 4.5"D.P.in Pipe Shed.HST 80K,SLK 80K.Displacement actual 172 bbl,calculated displacement 87 bbl,lost 85 bbl for trip.CIO handling Equip.to 5"L/D BHA#6.X/O.2 Juts 5"HWDP,Saver Sub,7"Jars,3 Jnts 5"HWDP,X/O,Bit Sub 6 8.75"Hole Opener.Clear and clean dg floor of nonessential subs and Equip.Stand by due to no transformation off island in case of emergency.Grease TS-8,Blocks and Crown,change oil and oil filters in TS-8.Grease Drawworks.Lost 20 bbl to formation.About 4-5 bph static loss.W/all essential personnel,R/U Volant tool as per GBR Rep onsite.R/U to run 4.5"Liner.Lost 5 bbl to formation.M/U ECC Nose Guide Shoe and RIH W/4.5"11.69,L-80,HYD 521 Liner to 2.392'MD.HST 95K,SLK 95K,Replaced Jnt#33 W/spare.30 bbl lost to formation.Ran 59 Jnts.Total lost today 177 bbl. Operation at 07.00 RIH W/4.5"Liner on Volant tool @ 3.729'MD. 24h Forecast RIH W/4.5"Liner,ICD's and Swell Packers W/Volant tool F/2.392'MD to 8,923'MD.P/U M/U SLZXP Packer as per Baker Rep.Cont.to RIH W/5"D.P.to TD @ 19,924'MD. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0200 2.00 2.00 DRILL E 9 P PJSM Cont.displacing to 9.1 ppg 3%KCL/Nacl Brine @ 6 bpm FCP 320 PSI,TRO 11.5K.Total pumped 866 bbl 9.1 ppg Brine,lost 25 bbl to formation @ 12 bph.ROT WI 140K,HST 195K.SLK 90K. 02:00 03.00 1.00 3.00 DRILL E 20 P PJSA Clean surface Equip.of OBM.Monitor well 6 bph static loss.L/D 1 Jnt 5"D.P.Blow down TS-8. 03:00 04:30 1.50 4.50 DRILL E 4 P PJSA POOH 5"D.P.on elevators F/10,975'to 8,917'MD.HST 175K,SLK 100K. 04:30 07:30 3.00 7.50 DRILL E 4 P PJSA C/O handleing Equip.to 4.5"D.P.POOH 4.5"D.P.on elevators F/8,917'to 2,478'MD. 07:30 10:30 3.00 10.50 DRILL E 4 P PJSM POOH F/2,478'to 202'MD laying down 4.5"D.P.in Pipe Shed.HST 80K,SLK 80K.Displacement actual 172 bbl. calculated displacement 87 bbl,lost 85 bbl for trip. 10:30 11:30 1.00 11.50 DRILL E 4 P PJSA C/O handling Equip.to 5"UD BHA#6.X/O,2 Jnts 5"HWDP,Saver Sub,7"Jars,3 Jnts 5"HWDP,X/O,Bit Sub& 8.75"Hole Opener. ' 11:30 12:00 0.50 12.00 DRILL E 20 P PJSA Clear and clean ng floor of nonessential subs and Equip. 12:00 16:30 4.50 16.50 DRILL E 22 P Stand by due to no transformation off island in case of emergency.Grease TS-8,Blocks and Crown,change oil and oil filters in TS-8.Grease Drawworks.Lost 20 bbl to formation,About 4-5 bph static loss. 16:30 17:30 1.00 17.50 DRILL G 20 P PJSM WI all essential personnel,R/U Volant tool as per GBR Rep onsite.R/U to run 4.5"Liner.Lost 5 bbl to formation. 17:30 00:00 6.50 24.00 DRILL G 4 P PJSA M/U ECC Nose Guide Shoe and RIH W/4.5"11.68,L-80,HYD 521 Liner to 2,392'MD.HST 95K,SLK 95K, Replaced Jnt#33 W/spare.30 bbl lost to formation.Ran 59 Jnts. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI 'Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher og15@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(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L-80 3,353.56 6.074.05 9/26/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3429.61 1.083.52 FazePro 1126.4 49.9 1587.1 171.9 l D Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • APIIUWI:50-629-23494-00-00 2 n o Date:9/26/2013 - Report#: 32 'I 'I page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 DRILLING 8/28/2013 6.069.18 1,100.21 6,074.97 166.72 36.4 29.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 6,075,27 1,104.02 0.00 103.0 -1.1 Overcast WC 20' E @ 12 MPH Daily summary operation 24h Summary PJSM WI all essential Personnel for Volant Tool,RIH W/4.5"Liner as per tally F/2,392'to 8,892'MD,216 Jnts in hole.HST 124K,SLK 97K.0/O Jnt#71&72.Total of 15 ICD's,6 Swell Packers.R/D Volant tool and Csg.Equip as per GBR Rep onsite.R/U 5"D.P.handling Equip.PJSM WI all essential personnel.P/U M/U SLZXP Packer as per Baker Rep onsite.Mix and pour Pal Mix,let set for 30 Min.MIU XO&stand of 5"D.P.RIH to 9,030'MD,Circ.25 bbl thru Packer Assy @ 3 bpm.80 PSI,HST 125K,SLK 97K.RIH W/4.5"Liner&Packer on 5"D.P.F/9,030'to 11,071'MD,HST 150K,SLK 111K.Circ.5"D.P.volume(40 bbl)@ 3 bpm,80 PSI.Gather rotating parameters as per K&M Rep onsite,HST 150K.SLK 111K,ROT WT 128K,TRO 7.5K @ 30 RPM,TRO 8K @ 40 RPM. RIH W/4.5" Liner&Packer on 5"D.P.F/11,071' to 18.836'MD,HST 202K,SLK 75K.ROT WT 148K.TRQ 17K @ 40 RPM.Rotated in hole F/18.620'to 18,836'MD.ROT WT 148K,TRQ 17K @ 40 RPM,lost 21 bbl during trip.Total lost to formation today 84 bbl. Operation at 07.00 Slip and cut drilling line. 24h Forecast RIH 4.5"Liner on 5"D.P.F/18,836'to 19,931'MD.Set SLZXP Packer as per Baker Rep onsite.Chart and test Packer to 1,500 PSI for 10 Min.Cut and slip drilling line,POOH UD 5"D.P. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL G 4 P PJSM W/all essential Personnel for Volant Tool.RIH W/4.5"Liner as per tally F/2,392'to 4,672'MD,114 Jnts in hole. HST 103K.SLK 98K.CIO Jnt#71&72. 06.00 12:00 6.00 12.00 DRILL G 4 P PJSA RIH WI 4.5"Liner as per tally F/4,67210 7,180'MD,174 Jnts in hole.HST 115K,SLK 97K.Calculated displacement 23 bbl,actual displacement 17.Lost 40 bbl for tour. 12:00 15:00 3.00 15.00 DRILL G 4 P PJSA RIH W14.5"Liner as per tally F/7.180'to 8,892'MD,216 Jnts in hole.HST 124K,SLK 97K.Total of 15!CD's,6 Swell Packers,Calculated displacement 8.5 bbl,actual displacement-6.5 bbl.Lost 15 bbl for the trip. 15:00 16:00 1.00 16.00 DRILL G 20 P PJSA R/D Volant tool and Csg.Equip as per GBR Rep onsite.R/U 5"D.P.handling Equip. 16:00 17:00 1.00 17.00 DRILL G 20 P PJSM W/all essential personnel.P/U MIU SLZXP Packer as per Baker Rep onsite.Mix and pour Pal Mix,let set for 30 Min. M/U XO&stand of 5"D.P.RIH to 9,030'MD,Circ.25 bbl thru Packer Assy @ 3 bpm,80 PSI,HST 125K,SLK 97K. 17:00 18:30 1.50 18.50 DRILL G 4 P PJSA RIH WI 4.5"Liner&Packer on 5"D.P.F/9,030'to 11,071'MD.HST 150K.SLK 111K. 18:30 19:00 0.50 19.00 DRILL G 7 P PJSA Circ.5"D.P.volume(40 bbl)@ 3 bpm,80 PSI.Gather rotating parameters as per K&M Rep onsite.HST 150K.SLK 111K.ROT WT 126K,TRO 7.5K @ 30 RPM,TRO 8K @ 40 RPM. 19:00 00:00 5.00 24.00 DRILL G 4 P PJSA RIH W/4.5"Liner&Packer on 5"D.P.F/11,071' to 18,836'MD,HST 202K,SLK 75K.ROT WT 148K.TRQ 17K @ 40 RPM.rotate in hole F/18.620'to 18,836'MD.ROT WT 148K,TRQ 17K @ 40 RPM,lost 21 bbl during trip. Daily Contacts Position Contact Name Company Title E-mail Office Mobile 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 AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.corn 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondnlling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L-80 3,353.56 6,074.05 9/26/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.429.61 1,083.52 FazePro 11264 49.9 1587.1 171.9 • fi _n Eni E&P Division (Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq • Date:9/27/2013 - Report#: 33 APIIl1W1:50 629-23494-00-00 i i "ii page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(in) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5135-W4 DRILLING 8/28/2013 6,069.18 1.100.21 6,074.97 166.72 36.4 30.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind • 6,075.27 1.104.02 0.00 102.0 -1.1 Overcast WC 24" N @ 6 MPH Daily summary operation 24h Summary Set 4.5"liner as per tally.set packer.test and release.POOH and L/D Baker running tool.RIH w/4.5"DP and POOH L/D same.Last Drilling report. Operation at 07.00 Testing BOPE. 24h Forecast On completion AFE as of 0001 hrs.Test BOPE as per AOGCC regs.Jim Regg waived witness.R/U and run 4.5"completion. Lithology •Shows MAASP(kgflcm') Mud Weight(g/L) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02.00 2.00 2.00 DRILL G 4 P PJSA Ream 4.5"liner in hole f/18.836'-19,987'@ 40 rpm,16k to 208k puw,148k rotw.break connection and drop 1.625" Baker ball,M/U conn.and ream to 19,933'and P/U to setting depth @ 19,928'. 02:00 03:00 1.00 3.00 DRILL G 19 P PJSA Set Baker SLZXP packer as per Baker pumping down @ 3 bpm, 215 psi,and seat ball w/1500 psi,pressure to 3000 psi(setting tool set @ 2000 psi),pressure to 3500 psi(neutralizer shear @ 3240 psi),slk off 50k and pressure to 4000 psi and hold.Confirm release @ 190k puw.TOL @ 11,005'. 03:00 04:00 1.00 4.00 DRILL G 12 P PJSA R/U and test packer to 1500 psi for 10 charted min.RID from test and std back stand of 5"DP,Blow down kill line. • 04:00 05:30 1.50 5.50 DRILL E 25 P PJSA Cut and slip 94'of drip line,service top-drive,blocks,draw works and adjust brakes. 05:30 07:00 1.50 7.00 DRILL E 4 P PJSA POOH wl 5"DP 0 19,928'-10,965',180k puw,110k sow,rack back in derrick. 07:00 12:00 5.00 12.00 DRILL E 4 P PJSA POOH LDDP f/9194'-3962'.Tourty Fluid loss 25 bbls. 12.00 15:30 3.50 15.50 DRILL E 4 P PJSA POOH LDDP f/3962'-42'.L/D Baker conning tool. 15.30 16:00 0.50 16.00 DRILL E 20 P PJSA Clear and clean ng floor. 16.00 19:30 3.50 19.50 DRILL E 4 P PJSA R/U 4.5"handling equipment and trip 4.5"DP in hole to 6262',148k puw 105k sow. 19:30 00:00 4.50 24.00 DRILL E 4 P PJSA POOH LDDP(16262'-2466'Toudy fluid loss @ 25 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnIling@enlpetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher dg15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L-80 3,353.56 6,074.05 9/26/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgfIcm') 3.429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 • lifYi* Eni E&P Division I Well Name:SI35-W4 EN!Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • API/UW:50-629-23494-00-00 2�, Date:9/28/2013 - Report#: 1 If II page 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI35-W4 COMPLETION 31.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 100.0 -1.7 Light Snow WC 21` NNE @8MPH Daily summary operation 24h Summary Complete LDDP and clear rig floor.R/U and test BOPE.Witness waived by Jim Regg.R/U Volant running equipment and M/U and RIH w/4.5"12.66,L-80 H563 completion tubing as per tally to 2766'. Operation at 07.00 Running 4.5"12.69,L-80 H563 completion tubing at 5,355 MD 24h Forecast RIH w/4.5"completion as per tally and land No-Go on top of Liner @ 11,005'.Space out tubing and set on tubing hanger.Test upper and lower hanger seals to 5000 psi f/10 min.Set Halliburton packer as per service hand and hold pressure for 30 charted min.Reduce tbg pressure to 2000 psi and pressure annulus to 2500 psi and hold for 30 charted min.Shear mirage plug.Shear GLM valve and UD landing jt and seat BPV. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr, 00:00 01:30 1.50 1.50 COMP K 4 P PJSA POOH LDDP 6 2465. 01:30 03:30 2.00 3.50 COMP K 20 P PJSA Clear and clean rig floor,pull wear bushing and set test plug as per Vetco.R/U to test BOPE.Monitor well losing @ 3 bph. 03:30 11:00 7.50 11.00 COMP K 12 P PJSA Test BOPE wl 4.5"test joint as per AOGCC regs.Witness waived by Jim Regg. 11:00 13:00 2.00 13.00 COMP K 20 P PJSA RID test eqipment.Blow down choke manifold,kill 8 choke lines. 13:00 15.00 2.00 15.00 COMP K 20 -P PJSM R/U Volant running tool,bail extension 8 single jt.elevators. 15:00 16.00 1.00 16.00 COMP K 25 P PJSA Service ng and skate. 1600 18:00 2.00 18.00 COMP K 4 P PJSA Load and strap completion tools in pipe shed.P/U&M/U and RIH w/4.5"12.69,L-80,H563 completion tubing as per tally to 302',78k sow. 18.00 0000 6.00 24.00 COMP K 4 P PJSA RIH w/4.5"completion to 2766'.98k puw,95k sow.Toudy fluid loss @ 26 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L-80 3,353.56 6.074.05 9/26/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.429.61 1 083.52 FazePro 1126.4 49.9 1587.1 171.9 1 �` -� Eni E&P Division I Well Name:SI35-W4 ENI Petroleum Co.Inc. Daily Report Well Code:27429 Field Name: Nikaitchuq • APIIUWI:50-629-23494-00-00 2^,1 Date:9/29/2013 - Report#: 2 II "IIpage 1 of 1 Wellbore name: SI35-W4 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information • Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI35-W4 COMPLETION 32.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 100.0 -3.3 Overcast WC 14' ENE 14 MPH Daily summary operation 24h Summary Run 4.5"completion tubing,space out and land on Vetco hanger @ No-Go @ 11,013'.Test hanger seals to 5000 psi for 10 min.RID Volant equip,clear rig floor and R/U to test.Set Halliburton packer and test tbg to 3500 psi for 30 min.and IA to 2500 psi.Shear out Mirage Plug and GLM shear valve. Operation at 07.00 N/U Tree. 24h Forecast N/D BOPE and N/U tree and test.Secure wet and prep for move. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00'COMP K 4 P PJSA RIH w/4.5"12.6#L-80 H563 completion tubing as per plan via Volant running equipment f/2766'-9344'. 128k puw, 95k sow. 12:00 16:00 4.00 16.00 COMP K 4 P 'PJSA RIH w/4.5"completion tubing to 10,987',132k puw,92k sow.PU 2-jts and tag up @ 11,013'.Space out wl 5.85'pup and 5.87'XO pup.MU Vetco hanger and land string.RILDS and test upper and lower hanger seals to 5000 psi for 10 min. 16.00 17:00 1.00 17.00 COMP K 20 P PJSA R/D Volant tools and clear rig floor. 17.00 18:00 1.00 18.00 COMP K 20 P PJSA R/U testing equipment and prime mud pumps. 18.00 00.00 6.00 24.00 COMP K 12 P PJSA Pressure up tubing @ 1700 psi autofill closed, packer set @ 2100 psi and pressured up to 3500 psi.Pressure bleeding off and attempted to test two more times.R/D test equipment and pull landing jt and C/O o-ring and reinstall landing jt and pressure up to 3500 psi for tubing integrity test for 30 charted min.Bleed tubing to 2000 psi and presure up IA. to 2500 psi for 30 min for integrity test.Bleed off IA and pressure up tubing to 4625 psi and sheared out Mirage plug. Pressure up IA and sheared GLM valve @ 2100 psi. Daily Contacts Position j Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Sups. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein EM Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon 15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L-80 3.353.56 6.074.05 9/26/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 , Eni E&P Division I Well Name: SI35-W4 EN!Petroleum Co.Inc. Daily Report Well Code:27429 Field Name:Nikaitchuq • API/UWI:50-629-23494-00-00 enII Date:9/30/2013 - Report#: 3 " II page 1 of 1 Wellbore name: S135-W4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-101 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.36 12.37 11.23 9.74 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S135-W4 COMPLETION 33.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 96.0 -2.2 Light Snow WC 16` ENE @ 15 MPH Daily summary operation 24h Summary N/D stack and riser.N/U Vetco tree and test w/diesel to 500/5000 psi.Secure well and install BPV.Rig released @ 0600 hrs. Operation at 07.00 Rig released @ 0600 hrs.9-30-13. 24h Forecast R/D rig and move off well.LAST COMPLETION REPORT Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 COMP K 20 P PJSA RID test equipment and blow down all lines.Pull landing joint and Vetco set BPV. 00:30 01:00 0.50 1.00 COMP K 20 P PJSA Blow down choke and kill lines.L/D mouse hole. 01:00 03:00 2.00 3.00 COMP K '20 P PJSA Nipple down BOPE and remove stack and set back.Remove Hi-pressure riser and set back. 03:00 06.00 3.00 6.00 COMP K II12 P PJSA Nipple up Vetco tree and test void to 5000 psi for 10 min..Pull BPV and set two way check.Fill tree w/diesel and test to 500 psi f/5 min/5000 psi f/15 min.Charted.Pull TWC and set BPV.Secure well. Rig released @ 0600 hrs.9-30-13. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative .Ben Perry 'ENI Senior Dulling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative 'Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Mariinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 3.960 L-80 3,353.56 6,074.05 9/26/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 3429.61 1,083.52 FazePro 1126.4 49.9 1587.1 171.9 L) WW pp� y 'RE'''," mp 0 C 44 CmE 1",R" OD EEE, tRm''', hmmem a NCO Omi lav Em T �rr2m I$.c�io EMmoo ITio�N' Y) Mrd f°e�i{Mp tNp IrminvniMto mN pm, s m.rsLm� iommmm Nnn0 Ao-'-H -"Qm)-sE mlFinss meNsn MM 1 2 .T,2 n8,',ItA2 v2iNn.N inn N1,t1 Ip.NNIp v'pi N.N. �i iizzs .. 2 NNNN. 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IIA & F ®.k§! ®® #§!S§ ■ 2 e ` -` \§§ |.$§\§§ $ :SEE o ! ,4• ;;# 7 f-§#§f4 !§§ | ;km § 2 |k(§ f m 4..§§ ® j , 2�; [ f. jU,*;■ U. §) § k! a) | 1®6§ 2` (kk k) 9 cd2 |E $ \ ! )ra 0 f EE f R 4_Cltu S2.35---kid 4 !'m Z-(3lotc Regg, James B (DOA) From: Maugeri Giuseppe [Giuseppe.Maugeri@enipetroleum.com] Sent: Thursday, October 10, 2013 9:26 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Simeone Davide; Nofziger Laura; Kuck Marc Subject: S135-W4 Pre-injection MIT form Attachments: 2013 09 MIT NIK S135_Pre Inj.xls Dear Jim, Dear Phoebe, Kindly find attached the Pre-injection MIT form for S135-W4 well. Best regards, Giuseppe Maugeri Completion Engineer Eni Petroleum Office: (907) 865-3328 Cell: (907) 947-9110 Email: giuseppe.maugeriCa�enipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reocaalaska.gov• doa.aoacc.prudhoe.bavt alaska.gov; phoebe.brooks(rilalaska.govi tom.maunderaalaska.gov OPERATOR: Eni US Operating Co Inc Z''(et (0 °(t 3 FIELD/UNIT/PAD: Nikiatchuq Field/Oliktok Point Pad DATE: 09/29/13 OPERATOR REP: Ben Perry AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well#55 SI35-W4 ' Type Inj. W - TVD - 3,548' Tubing 0 ' 3,700 - 3,700, -3,700 Interval 0 P.T.D. 2131010 • Type test P Test psi 1,500 Casing 0 2,500 2,500 . 2,500 _ P/F P ✓ Notes: Pre Injection MIT OA 250 300 - 300 300 Well# Type Inj. TVD _Tubing._ Interval P.T.D. Type test Test psi Casin9_ P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) P,D,T=Permit to Drill Form 10-426(Revised 06/2010) 2013 09 MIT NIK SI35_Pre Inj.xls ft* HALLIBURTON 211 11 Enil P&tiroHeum Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq S135-W4 Shipping Date: 24-Sep-2013 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 6900 Arctic Blvd. Anchorage,AK 99501 Anchorage,AK 99515 Attn: Howard Oakland 907-739-1235 Item Description 111111111111.111111r Interval Packaging Box Description S135-W4 Washed and Dried Samples-50' 3,200'to 4,950' Paper envelopes 1 of 9 Washed and Dried Samples-50' 5,000'to 6,800' Paper envelopes 2 of 9 Washed and Dried Samples-50' 6,850'to 8,600' Paper envelopes 3 of 9 Washed and Dried Samples-50' 8,650'to 10,450' Paper envelopes 4 of 9 Washed and Dried Samples-50' 10,500'to 12,350' Paper envelopes 5 of 9 Washed and Dried Samples-50' 12,400'to 14,250' Paper envelopes 6 of 9 Washed and Dried Samples-50' 14,300'to 16,100' Paper envelopes 7 of 9 Washed and Dried Samples-50' 16,150'to 18,350' Paper envelopes 8 of 9 Washed and Dried Samples-50' 18,400'to 19,932'TD Paper envelopes 9 of 9 i / DOne(1)Bundle 7c�lI Contains all Nine(9)Boxes Notes: Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Andrew Buchanan 907-865-3388 Received by Expediter: LDate:3 0 41"-PZk aI3 — ltd ( w w��\\I 49 THE STATE Alaska Oiland Gas .-- • °fALlConservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 1p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Davide Simeone Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Pool, SI35-W4 ENI US Operating Co. Inc. Permit No: 213-101 Surface Location: 4428' FSL, 1492' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 383' FSL, 5217' FEL, SEC. 14, T14N, R8E, UM Dear Mr. Simeone: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely wr orman ommissioner DATED this 4day of July, 2013. �` it:,Li'; ,?. fit ..A, STATE OF ALASKA AL .(A OIL AND GAS CONSERVATION COMMI. )N J, iN 2 7 2013 PERMIT TO DRILL 20 MC 25.005J( ( ' la.Type of Work: lb.Proposed Well Class: Development-Oil U Service- Winj U- Single Zone Q. 1c.Specify if well is proposed) ..' • '- Drill ❑✓ 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 Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627• SI35-W4 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 19910 • TVD: 3589• Nikaitchuq/Schrader Bluff 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4428 FSL,1492 FEL,S19T14N R9E UM • ADL0391283;ADL0588575;ADL0388574 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 126 FSL,3980 FEL,S24 T14N R8E UM • ADL 417493 8/1/2013. Total Depth: 9.Acres in Property: 77�� P I II j3 14.Distance to Nearest Property: 383 FSL,5217 FEL,S14 T14N R8E UM • 5388' l(/•.0 7800'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- 511419 y- 6053609 Zone- 4 • GL Elevation above MSL: . 13.1 feet to Same Pool: 1100'to SP33-W3 16.Deviated wells: Kickoff depth: • 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 92.02 degrees Downhole: 1542 psig • Surface: 1168 psig. 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed 1358 TOTAL sx 16" 13-3/8" 68 L-80 BTC 3202 35 35 3237 2454 LEAD:1149 sx 10.7 ppg ASL TAIL:208 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 11314 33 33 11347 3570 808 TOTAL sx 808 sx 12.5 ppg DeepCrete 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 8762 11147 3556 19910 3589 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch .i Drilling Program .i Time v.Depth Plot _ Shallow Hazard Analysi2 Diverter Sketch L, Seabed Report _Drilling Fluid Program st 20 AAC 25.050 requirement 21. Verbal Approval: Commission Representative: Date 6/20/2013 22. I hereby certify that the foregoing is true and correct. Contact Lara Occhionero 907-947-4100 Email lara.occhioneropa.enipetroleum.com Printed Name Davide 1Siimeo e Title Well Operation Project Manager . ("-- Signature lXnV Phone (907)865-3320 Date 6/20/2013 Commission Use Only Permit to Drill API umber: Permit Approval 1 See cover letter for other Number: &)2 /01 50-6,4,y -a3��cly-00 -O-o Date: \a�� requirements. Conditions of approval: ,� p -7;:"";.- If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in sha� Other: ' 3 S6O /9Sc- 4& ` 7 r Samples req'd: Yes❑ No ZI. Mud log req'❑fes [ 'No //'' -' G`Lc�av,� HZS measures: Yes❑ No Q Directional svy req'{Ies ❑ No [��g ®�` K _ Spacing exception req' Yes❑ No[� Inclination-only svy rep Yes[�No �-( A io 3 G l I c cL3L ,-e APPROVED BY 1.(,i(i3 Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL *Pf_is glib 1'�'t�' 6 Submit Form and ". Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplic n, y, A .:-..t,,,,, ., i :... w ,. JI�i Enhi n it(e)Ileum r r r o 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907)865-3323 Email: Davide.Simeone@enipetroleum.com June 18,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI35-W4 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the Offshore Injector well 5I35-W4.This well will be drilled and completed using Doyon 15. The planned spud date could be as early as 8/1/2013. 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 Lara Occhionero 907-947-4100 Sincerely, Davide Simeone W 1 Operatio roject Manager (7 /, En Petirolleuim eno Application for Permit to Drill SI35-W4 Saved:20-Jun-13 Application for Permit to Drill Document Injector Well S135-w4 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(0 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(6) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 Requirements of 20 MC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program 6 (LSND) 6 Lateral Mud Program 6 (MI FazePro Mineral Oil Base) 6 8. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25 005(c)(9) 6 9. Seismic Analysis 7 Requirements of 20 MC 25 005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 10 Printed:20-Jun-13 • En Petirolleum ens Application for Permit to Drill SI35-W4 Saved:20-Jun-13 10. Seabed Condition Analysis 7 Requirements of 20 MC 25 005(c)(11) 7 11. Evidence of Bonding 7 Requirements of 20 MC 25005(c)(12) 7 12. Proposed Drilling Program 7 Requirements of 20 MC 25 005(c)(13) 7 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 MC 25.005(c)(14) 9 14. Area of Review 9 15. Attachments 10 Attachment 1 Drilling Procedure 10 Attachment 2 Directional Plan 10 Attachment 3 Drilling Hazards Summary 10 Attachment 4 BOP and Diverter Configuration 10 Attachment 5 Cement Loads and CemCADE Summary 10 Attachment 6 Formation Integrity And Leak Off Test Procedure 10 Attachment 7 Surface Platt 10 Attachment 8 % Mile Scan Report 10 Attachment 9 Casing Design Program 10 AOGCC PERMIT Document.doc Page 2 of 10 Printed:20-Jun-13 1,9* • Eird PtiroIkuim 2n� Application for Permit to Drill SI35-W4 Saved:20-Jun-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: SI35-W4 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 4428 FSL, 1492 FEL, S19T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation feet'AMSL Northing: 6,053,609' Easting:511,419' Pad Elevation feet'AMSL • Location at Top of Productive Interval 126 FSL, 3980 FEL, S24 T14N R8E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 11,347' Northing: 6,049,298' Easting: 503,854' Total Vertical Depth, RKB: 3,570' Total Vertical Depth, SS:: 3,515' Location at Total Depth 383 FSL, 5217 FEL, S14 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 19,910' Northing: 6,054,835' Easting: 497,331' Total Vertical Depth, RKB: 3,589' Total Vertical Depth, SS: 3,535' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 MC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan AOGCC PERMIT Document.doc Page 3 of 10 Printed:20-Jun-13 1014t - • Enil PtiroIIeum 2nll Application for Permit to Drill SI35-W4 Saved:20-Jun-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 MC 25.035,20 MC 25.036,or 20 QAC 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 = (3,535'TVDss)(0.45 - 0.11 psi/ft) = 1168 psi (B)data on potential gas zones The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 10 Printed:20-Jun-13 EnO• P ern] Application for Permit to Drill SI35-W4 Saved:20-Jun-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 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 160'/ 160' Pre-Installed 1358 TOTAL sx LEAD: 1149 sx 10.7 ppg 13-3/8 16 68 L-80 BTC 3202' 35 / 35 3237'/ 2454' ASL TAIL: 208 sx 12.5 ppg DeepCrete 808 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 11314' 33/ 33 11347'/ 3570' 808 sx 12.5 ppg DeepCrete TOC: 8,736.14D/�3,419T/D 8-3/4"OA 4-1/2 Sand 11.6 L-80 Hydril 521 8762' 11147'/ 3556' 19910'/ 3589' 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 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 4: BOP Configuration. AOGCC PERMIT Document-doc Page 5 of 10 Printed:20-Jun-13 co* • Einii PtIroIkLuIm 2no Application for Permit to Drill SI35-W4 Saved:20-Jun-13 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended 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 15 - 25 Funnel Viscosity (CP) (seconds) 45 60 Yield Point Plastic Viscostiy (lb/100 sf) 15 20 (CP) 12 18 HTHP Fluid loss Yield Point (ml/30 min <5.0 (lb/100 sf) 18-24 200psi& 100°F API Filtrate4 6 Oil/ Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/I) <500 Electrical >600 pH 9.0 - 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. AOGCC PERMIT Document.doc Page 6 of 10 Printed:20-Jun-13 W ftis Enil PtiroIkum anti Application for Permit to Drill SI35-W4 Saved:20-Jun-13 9. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratiqraphic 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(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program ,,-/ Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 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. (31. �-'°""" 8) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 11.00 ppg 10) Directionally drill to 9-5/8" casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. AOGCC PERMIT Document.doc Page 7 of 10 Printed:20-Jun-13 /PO* • EnM P 2n� Application for Permit to Drill SI35-W4 Saved:20-Jun-13 12) RU casing drive system. 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8" Emergency Slips. 15) Install 9-5/8" packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17) Pressure test casing to 3000 psi per AOGCC 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. 21) PU dumb iron assembly and TIH to TD 22) Displace well to 9.5 ppg FazeAway Delayed Breaker 23) POOH on elevators to intermediate casing shoe and displace to 9.0 ppg KCI brine. 24) POOH on elevators and LD BHA. RU to run 4-1/2" liner. 25) PU and run 4-1/2" liner to TD. Ensure cross over and FOSV is on the floor. 26) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. 27) Bleed DP pressure to zero, close annular and test annulus to 1500 psi for 10 min on chart. 28) POOH laying down DP as required. 29) RU tubing running equipment and run 4-1/2"tubing. Land tubing. 30) Test upper and lower seals to 5000 psi for 10 min. 31) RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. 32) Pressure down tubing string to 1200 psi to close autofill valve and monitor for leaks. 33) Increase pressure down tubing to 3,500 psi to set packer and hold for 30 minutes. Record on chart as tubing integrity test. Ensure inner annulus is open and monitor for returns. \� 34) Reduce tubing pressure to 2,000 psi. Rig up and pressure inner annulus to 2,500 and hold for 30 minutes. Record annulus pressure on chart as inner annulus integrity test. Bleed annulus pressure to zero. 35) Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 36) Pressure inner annulus to 2,500 to shear valve in GLM. If valve does not open, cycle annular pressure from 0 to 2,500 psi several times while allowing tubing to bleed pressure. 37) Pull landing joint and set BPV. AOGCC PERMIT Document.doc Page 8 of 10 Printed:20-Jun-13 V41/0s • Enil PtIroIkLuIm 2no Application for Permit to Drill SI35-W4 Saved:20-Jun-13 38) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). p ik, • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the ,t,)/"N t tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. '} g•l 3 • 39) Pull BPV and set TWCV. 40) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 41) Pull TWCV. 42) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 43) Set BPV and secure tree and wellhead. 44) RDMO 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 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. 14. Area of Review Requirements of 20 MC 25 To the knowledge of Eni US Operating Co. Inc. there are no other wells completed in the Schrader Bluff formation other then those stated in the attached 1/4 mile scan report. The Nikaitchuq Unit also includes the following wells drilled by Kerr McGee Oil & Gas Corporation: Nikaitchuq #1: Plugged and Abandoned 04/01/04 Nikaitchuq #2: Plugged and Abandoned 04/01/04 (East of Nikaitchuq Unit) Nikaitchuq #3: Plugged and Abandoned 04/26/05 Nikaitchuq #4: Plugged and Abandoned 04/21/05 Kigun #1: Plugged and Abandoned 03/30/05 Tuvaaq State #1: Plugged and Abandoned 03/09/05 To Eni US Operating Co. Inc.'s knowledge all wells have been cemented across the Schrader Bluff formation as per AOGCC regulations and plugged and abandoned. All wells that fall into the 1/4 mile radius said herein have been drilled and completed in the Schrader Bluff formation in accordance with 20 AAC 25 AOGCC regulations. Please See attachment 8 — 1/4 Mile Scan Report AOGCC PERMIT Document.doc Page 9 of 10 Printed:20-Jun-13 =n0 PetiroHeum 2rnn� Application for Permit to Drill SI35-W4 Saved:20-Jun-13 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment S Cement Loads and CemCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 % Mile Scan Report Attachment 9 Casing Design Program AOGCC PERMIT Document.doc Page 10 of 10 Printed:20-Jun-13 f • eno us operrafins WELL SI35-W4 Drilling Procedure SI35-W4 Spy Island Conductor slot #35 Reservoir location #W4 Injector (Schrader Bluff) Nikaitchuq Project SI35-W4 Drilling Wellplan Page 1 of 39 06/18/13 ft* 2rn1n us operra1 f9 WELL SI35-W4 Spy Island Nikaitchuq Field eno petroleum North Slope - Alaska SI35-1N4 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO - Cement to Surface 20" Hole Angle .1.''. X-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A GR/Res o :1 SurtaCsa Dir/PWD 0 ce 13-3/8" y 68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 1,900' 1,678' P L-80,BTC 8.8-9.5 Lost Circulation W Hole Cleaning '°^ Casing Sections KOP:200' Casing Wear DLS: Surface T/Tail Cement 2,783' 2,253 0-3.8°/100' I. ori IT Is e Hole Angle 69.64 Deg 13-3/8"Csg 3,237' 2,454' W:.• i 16" 50"F WBM GR/RES/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 86.00 Deg BHA Expense Intermediate TOC 8,736' 3,419' i Pick-up Top of Sand 1 41P d' .a N Top 9,736' 3,418' mC. ` iZi ',. 1.. PHL Injection Packer 11,047' 3,829' 1° 1 Hole Angle TOL 11,147' 3,556' ;► `�;,', 86.00 Deg 9-5/8"Csg 11,347' 3,570' 12.25" 85"F WBM GR/RES �p p� EcoSCOPE/PWD 1� EI Wellbore Stability Lost Circulation ICD IA= Hole Cleaning 4-1/2" Torque&Drag 11.6# MW(ppg) Casing Sections Xceed 675 IE El L-80,Hydril 521 8.7-9.4 Casing Wear ICD BHA Expense FO El ICD 10 El p� �p Hole Angle 89.79 Deg 4 1/2"liner 19,910' 3,589' 8-3/4" 85°F MOBM SI35-W4 Drilling Wellplan Page 2 of 39 06/18/13 e n i us operating WELL SI35-W4 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 29 ATTACHMENTS 32 Recommended Drilling Practices 33 Health, Safety & Environment 34 Safety Meeting Topics 35 Well Shut In Procedure While Running Production Tubing 37 Conductor Broach—Contingency Cementing Plan 38 TAM PORT COLLAR Utilization Decision Tree 39 SI35-W4 Drilling Wellplan Page 3 of 39 06/18/13 111* 2n0 us operating WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 4 of 39 06/18/13 e n ll us operrahng WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 5 of 39 06/18/13 • eno us operating WELL SI35-W4 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (APO Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators, and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. ➢ Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). 5I35-W4 Drilling Wellplan Page 6 of 39 06/18/13 tf,* • 2no us operr hng WELL SI35-W4 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Formation Tops 1leasured Vertical Comments Depth. ft Depth. ft SV-4 ""1 "64 SV-3 1160 1119 SV-2 14S2 13'4 N Permafrost 1900 1675 SV-1 2240 1919 Ugnu Top (1.-G4) ="36 2228 13-3:8" Csg 3237 2454 SCP UG-2 Coal Bed Marker 4544 =714 Lower L-gnu S094 31'5 Schrader Bluff Top 9254 3345 N Sequence Top L 952S 33S" N Top 9736 3418 ReCalc Intermediate Cement w- Actual N Bottom 10038 345S N Sequence Base 10616 =51 S 9-5 8" Csg 1134" 35-0 ICP - Set ABOVE OA Sand Top OA Top 11401 3573 0.00 0A-2 Top 3583 4 12" liner :oo:;_ 3559 Total Depth SI35-W4 Drilling Wellplan Page 7 of 39 06/18/13 04.04, 2f�1n us Op rrahnc WELL SI35-W4 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/0 (ml/30min) 110'— 1900' 8.8 -9.2 20—24 <8 <2000 9.0—9.5 Surface: 1900'—C.P. 9.2—9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD _ Directional LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppj) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections SI35-W4 Drilling Wellplan Page 8 of 39 06/18/13 2rnn� �s operrarons WELL S135-W4 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. 101 2rr11� us operratuns WELL L S135-W4 J • 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. { OTIC IIIA T1..:11:._,_111,_11._1.._.. T)..._,. 1!1 ..C'2f1 !1L/1O/1'I y1 Y en II FIs operating WELL SI35-W4 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PO Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) Opt. OD WT Grade Conn.Type Make Up (in) (PIA) Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: ➢ obtain SO Weights every 10 ioints ➢ obtain PU Weights every 10 joints SI35-W4 Drilling Wellplan Page 11 of 39 06/18/13 It* 2rnlo us operrafin9 ► WELL SI35-W4 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 SI35-W4 Drilling Wellplan Page 12 of 39 06/18/13 riAtt e 1 us operr Vns WELL SI35-W4 Surface Centralizer Placement } 10' RP- 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),l 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. A SI35-W4 Drilling Wellplan Page 13 of 39 06/18/13 I* • em us o@crmons WELL S135-W4 Surface Cementing Program Section Casing Size Type of Fluid / Cmt Volume Properties Mudpush 11 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 491 bbls Yield 2.40 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) �R bbls 3 Top of Tail @ 2,783'MD Yield 1.56 ft/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. ➢ 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. D If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool D If necessary,rack TAM running tool in derrick and ready to run D Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. ➢ Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns D Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. D Do not over displace the cement(no more than Y2 the shoe joint volume). SI35-W4 Drilling Wellplan Page 14 of 39 06/18/13 eno us operating WELL SI35-W4 ➢ 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. D. In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) D. Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low D. 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 SI35-W4 Drilling Wellplan Page 15 of 39 06/18/13 e us operrefins WELL SI35-W4 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120-140 RPM ➢ See BHA attachment for running order and specifications 2. Rill 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 Pluas PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50' of new hole using spud mud. 5. Displace hole to new LSND mud system. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. SI35-W4 Drilling Wellplan Page 16 of 39 06/18/13 2nf us operr arms WELL SI35-W4 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Measured Formation Tops Vertical Comments Depth. ft Depth, ft SV-4 --a 764 SV-3 1160 1119 SV-2 14S: 13"4 B. Permafrost 1900 16 SV-1 =40 1919 L-gnu Top (L-G4) 2736 2228 13-3 8" Csg -- 2454 SCP 1L-G-2 Coal Bed Marker 4544 2704 Lower L-gnu S094 3175 Schrader Bluff Top 9254 3345 N Sequence Top 9528 3387 N Top 9736 3418 ReCalc Intermediate Cement w Actual N Bottom 10i038 3458 N Sequence Base 10616 3518 9-5 8" Csg 1134" 3570 ICP - Set ABOVE OA Sand Top OA Top 11401 3573 OA-2 Top 11555 3583 4 1 2" liner 19910 3589 Total Depth To* en o us operating WELL SI35-W4 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 MT B (ppg) Reading (ml/30min) (%) 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 Pine Tool Joint Body DP WT Conn. Joint Tool Body Make Up Torsion Torsional capacity Tensile Pipe (ppb Grade Type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity (in) ID(in) (rt.lbs (ft lbs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300' TVD from the top of the uppermost OA sand and at least 200'MD in length. b. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). c. Shallow test MWD tools. d. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off'slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. S135-W4 Drilling Wellplan Page 18 of 39 06/18/13 Ifif* e n FIs operraing WELL S135-W4 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. SI35-W4 Drilling Wellplan Page 19 of 39 06/18/13 it* 2n� us operating WELL SI35-W4 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max. OD (�� Grade Conn. Type TMgpe,�h- Make Up Make Up Yield Torque lbs(in) Torque Torque 9-5/8 40 L-80 H563i1 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. ➢ Draw a longitudinal line across the pin and box and reapply the published target torque. ➢ If the drawn line does not move more than'h"after the second torque application,continue running the rest of the string normally using the published target torque. ➢ If the drawn line moves more than%2"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than'A",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than'/2",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 1/2". SI35-W4 Drilling Wellplan Page 20 of 39 06/18/13 VW* 2rnn ll us operr hng WELL SI35-W4 ■ 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 Float shoe—Davis-Lynch Model 501-DV-PVTS 1 down jet float shoe(double valve)**** Baker-Lock 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. D K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. D Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000' MD and check flow through floats. Circulate bottoms up each time. D 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: D obtain SO Weights every 10 joints 6. Once on bottom with the casing: D 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. SI35-W4 Drilling Wellplan Page 21 of 39 06/18/13 los i 2nd us operating WELL SI35-W4 Intermediate Centralizer Placement a 10' Float Collar 9-5/8" x 11-3/4" Hydroform Centralizers 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+1-1000' above the shoe- 1 centralizer floated between collars • l centralizer floated between collars from N sand oil bearing zone to+1-500' above N sand oil bearing zone a c= S135-W4 Drilling Wellplan Page 22 of 39 06/18/13 2rr110 us operating I WELL SI35-W4 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9-5/8" Mudpush II 100 bbls Density 10.5 ppg DeepCrete 225 bbls Density 12.5 ppg Top of Cement @ 8,736'MD (808 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 V2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! D. 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. D Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. D 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 D Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. D. Do not exceed 80%of intermediate casing collapse D. Record test on IADC report and in WellView 5I35-W4 Drilling Wellplan Page 23 of 39 06/18/13 • us operan WELL SI35-W4 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite SI35-W4 Drilling Wellplan Page 24 of 39 06/18/13 r� Jff#s • 2rnno us operrahnc WELL SI35-W4 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. > 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. 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 SI35-W4 Drilling Wellplan Page 25 of 39 06/18/13 ...w • 2no us op&racing WELL SI35-W4 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) Measured True Formation Tops Depth, ft Vertical Comments Depth, ft SV-4 771 764 SV-3 1160 1119 SV-2 1482 1374 B/ Permafrost 1900 1678 SV-1 2240 1919 Ugnu Top (UG4) 2736 2228 13-3/8" Csg 3237 2454 SCP UG-2 Coal Bed Marker 4544 2704 Lower Ugnu 8094 3175 Schrader Bluff Top 9254 3345 N Sequence Top 9528 3387 N Top 9736 3418 ReCalc Intermediate Cement w/ Actual N Bottom 10038 3458 N Sequence Base 10616 3518 9-5/8" Csg 11347 3570 ICP- Set ABOVE OA Sand Top OA Top 11401 3573 OA-2 Top 11555 3583 4 1/2" liner 19910 3589 Total Depth SI35-W4 Drilling Wellplan Page 26 of 39 06/18i 13 2nf us operafi nns WELL SI35-W4 Production Mud Program: FazePro Density HTHP FL Electrical Interval (1)Pg) YP (m1/30min) Oil:water Stability mlVolts Production 9.2 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/EcoSCOPE Production Drill Pine Tool Joint Body DP Pipe Make UTensile WT Grade Conn. Joint Joint Body Torquep Torsion Torsional capacity Capacity (ppJ) type OD ID(in) al Yield Yield w/conn. (in) ID(in) (ft.lbs) (ft lbs) (ft.lbs) (gal/ft) fps) 5" DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 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. SI35-W4 Drilling Wellplan Page 27 of 39 06/18/13 Iff* n us operarons WELL SI35-W4 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE: 2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreaming until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. ➢ Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town SI35-W4 Drilling Wellplan Page 28 of 39 06/18/13 ipoit • ens • us operrahng WELL S135-W4 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (laps) 4-1/2 11.6 L-80 HS dl 1 4.695 4.000 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Mm' Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up field (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: SI35-W4 Drilling Wellplan Page 29 of 39 06/18/13 TIM* 2nf ass operating WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 30 of 39 06/18/13 fif* • 2nd us operaing WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 31 of 39 06/18/13 tffyos 2rno us operafing I WELL SI35-W4 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 SI35-W4 Drilling Wellplan Page 32 of 39 06/18/13 2n D us operata nns WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 33 of 39 06/18/13 • ern10 ens operr fins WELL SI35-W4 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. // 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SI35-W4 Drilling Wellplan Page 34 of 39 06/18/13 en usop rr nns WELL SI35-W4 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. D Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. D Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. > 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. S135-W4 Drilling Wellplan Page 35 of 39 06/18/13 tios 2rno us operahng WELL SI35-W4 D Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion D Operation of the control line spooler. D Pinch points associated with tongs and slips. D Proper tripping practices and hole fill calculations with tubing and control line. D Well control practices while running production tubing with control line. D Pressure testing and minimizing personnel exposure to pressurized lines. It SI35-W4 Drilling Wellplan Page 36 of 39 06/18/13 o • ��0 us operating WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 37 of 39 06/18/13 enoperahngs WELL SI35-W4 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. SI35-W4 Drilling Wellplan Page 38 of 39 06/18/13 I 119* 2rn1f us op r�Cfirnnc• - WELL SI35-W4 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job r No Cement Cement to to Surface Surface ' Drilling Foreman and Nipple Up an.0 Engineer determine the X Test BOP' Top of Cement ...„. `r / Top of ToriliMPF Cement / Cement Continue with above Port below Port Completion / Collar Collar (1000'TVD)/ (1000'TVD) -- — X Indicators of Cement Top Perform Top Job as per ► Open Port Collar IfTop Job is ineffective or 1. Observation of Tracers in Spacer ahead of lead cement requirements of using drillpipe 2. Calculated Displacement AOGCC unacceptable to AOGCC P 3. Displacement Pressures during Primary Cement Job — 4. Other indications that cement is near surface Nipple Up and Circulate Cement Test BOP's to Surface and close Port Collar • • Continue with Nipple Up and Completion Test BOP's Continue with Completion SI35-W4 Drilling Wellplan Page 39 of 39 06/18/13 M O C? n C C A N N O Q N S V n Q N NS N O N N M(0 0 0 )OO.CA)„yV c.;':,,, 3 N ONQ 0NNNNDNNCdo- N00QO N0)N rM00yiMNO �10000 O0N(.0O 4) WZ QQOQQ QQrQQ QQQQQ QQ,00 MMMM MMMM NN,.w.m- 0 0 W 0 O W N t O N N N N y t O N N N y v)N y N y N N N N t O N N N N y N Y) N N N y N N N N Y)N d N M r nN b yy a CNroc72NO 02SO) COO2 r Ot0 �OMMg00 00roQ ' .i. 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Well: SI35-W4 Borehole: 0135-W4 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection fillers: Definitive Surveys-Definitive Plana-Definitive surveys exclude definitive plane -All Non-Def Surveys when no Def-Survey is set Inc borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. ' Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Den.(60 Fact. Rub MD(ft) 1 TVD(ft) Alert I Mina I Major 5034-FN1(P1)(Def Plan) Warning Alert 8.00 6.64 6.77 1.35 N/A MAS=2.02(m) 0.00 0.00 CtCtc_15m<15.00 Enter Alert I 8.001 6.84 600 1.351 8.79 MAS=2.02(m) 200.00 200.00 MinPts 8.10 8.641 5.90 1.46 7.03 MAS=2.02(m) 259.97 259.97 MINPT-O-EOU 9.19 6.64 6.84 2.551 369.81 364.76 MinPt-O-SF 4711 6.64 43.45 41.27 14.43 MAS=2.02(m) 851.78 649.12 CICts=15m>75.00 Ent Alert 444.32 17.81 432.04 426.51 OSF 1.50 1205.07 1156.51 MinPt-O-SF 3290.05 120.11 3209.84 3169.93 41.41 OSF 1.50 4061.83 2839.99 MinPt-O-SF 3055.78 144.82 3858.91 3810.97 OSF 1.50 4739.19 2720.81 MinPt-O-SF 7585.99 220.91 7418.38 7345.07 OSF 1.50 8411.53 3216.63 MinPt-0-SF 9524.88 236.30 9387.02 9288.58 60.71 OSF 1.50 8991.11 3303.30 148461-0-OF 9528.01 240.68 9385.23 9285. 59.61 OSF 1.50 915120 3328.78 88461-0-SF 0852.05 228.02 0500.31 6424.63 43.9E. OSF 1.50 9758.42 3421.02 MinP50-SF 8328.82 198.79 8195.94 8130.03 47.99 OSF 1.50 10272.08 3485.60 Mn%-O-PDP 6328.10 197.91 6195."8.41 6130.19 48.19 OSF 1.50 10284.82 3480.97 MINPT-O-EOU NEMIEE 19636 6196.42 6131.20 48.57 OSF 1.50 10307.12 3489.34 MInPt-CICI 1445 288.87 3028.69 3632.83 21.47 OSF 1.50 17257.64 3584.55 MinPt-CICI 4121,90 289. 2028. 3831.91 21.39 OSF 1.50 1720719 3564.75 MINPT-O-EOU 4122.13 29026 3928. 3831.8 21.37 OSF 1.50 1730713 3584.79MinPt-0-ADP 4380.51 318.46 4167.87 40622..- 20.•• OSF 1.50 18314.70 3568.47 MinPt-O-SF 4440.96 323.84 4230.74 4123.1.11111111521M OSF 1.60 18503.08 3570,94 MinP1-0-SF 4828.17 348.14 4597.08 4482..< OSF 1.50 19513.07 3587.79 MinPt-0-SF 4994.14 358.32 4754.93 4835.82 20.90 OSF 1.50 19909.64 3589.26 TD 16826.43 8315 15770.13 15742. 288.11 OSF 1.60 834.40 824.80 Min%-04F 12372.85 7485 12322.03 12208.01 251.25 OSF 1.50 1057.43 1029.12 MinPt-PSF 11120.48 38.18 11094.89 11062.33 OSF 1.50 1278.37 1216.98 MInPI-O-SF 10351.30 34.38 10328.02 10318.9 488.08 OSF 1.50 1437.30 1340.82 MinPFO-SF 11179.45 83.37 11136.85 11116.08 269.13 OSF 1.50 2381.88 2000.80 MinPl.0.SF 12515.24 96.37 12450.08 12418.87 OSF 1.50 2528.59 2107.03 MinPt-O-SF llIIMI.E 241.140 10973.94 10893.88 89.54 OSF 1.50 9154.23 3320.28 MinPts SP36-W5(P4)(Def Plan) :sr.,.'.:. Warning Alert l'�8.06� 6.69 683 137 N/A MAS=2.04(m) 0.00 0.00 CtCt<=15m<15.00 Enter Alen 1 "°I 6..' 8.88 MAS=2.04(m) 200.00 200.00 Moats 8.07 8.89 6.07 1.:l MAS=2.04(m) 220.01 220.01 MinPt-O-SF 32.31 12.17 23.79 20.1 MIME OSF 1.50 849.44 83886 MinPl-O-SF 07.72 24.39 51.05 43. .l( OSF 1.50 1198.60 1151.09 MinPI-O-SF 18925 81.78 134.3.I!l" EIE OSF 1.50 2700.26 2207.87 MinPts 187.18 72.1:MOLE 115.00 3.93 OSF 1,50 3233.82 2452.89 MINPT-0-EOU 180.77 71.84 138.5. OSF 1.50 3254.18 245917 MMPts 180.05 71..�. ., 114.96 3.94 OSF 1.50 3264.47 2483.55 MNPT-0-EOU MIIEE 71.31 138.65 115.23 3.90 OSF 1.50 3285.40 2470.76 14846e-01CI 198.10 60.48 157.49 137.88 4.98 OSF 1.50 365887 257708 OSF>5.00 Ent Nat 173.29 41.43 145.3,MHO 0.40 OSF 1.50 4183.82 2856.19 MinPt-O-ADP 189.28 38. MIME 132.79 7.12 OSF 1.50 4202.54 2870.80 MINPT-0-EOU Ili/ 29.84 145.98 198.42 8.84 OSF 1.50 4500.09 2698.12 MinPt-CtCt 178.25 53.1 lei 125.08 5.10 OSF 1.50 4925.07 2754.45 MINPT-0-EOU 179.38 54.83 142.49 124.54 4.97 OSF 1.50 4944.83 2757.07 OSF<5.00 Enter Alert 195.34 73.83 145.74121.51 4.00 OSF 1.50 5172.15 2787.21 MinPI-0-NDP 274.58 127.42 180.29 147.1 3.251 OSF 1.50 5923.27 2886.78 MinPt-0-SF 665.41 200.55 531.39 484.87 4.99 OSF 1.50 8674.82 3253.01 OSF>5.00 Ent Alert 1041.66 150.81 940.78 890. 10.4 OSF 1.50 11438.16 3575.82 MinP50-SF 990.63 130.75 903.1 859. 11.44 OSF 1.50 1174247 3587,73 MInPt-0-ADP 990.20 130.291 903.0 859.97 11.48 OSF 1.50 1175531 3587.82 MINPT-0-E01.1 lq 129.42 903.35 880.53 11.55 OSF 1.50 11781.01 3587.89 14001-CICI 1005.75 19745 879.79 808.31! 1 OSF 1.50 13008.07 3591.19 MinPt-0-SF 94139 283.32 752.18 658.07 5.00 OSF 1.50 1788477 3567.10 OSF<5.00 Enter Nal =NH=NH 346.511 683.84 568.721 3.971 OSF 1.50 19909.64 358825 MinPts SP33-W 3(Del Survey) Wamir9 Melt- 15.99 13.04 1477 2.95 N/A MAO=3.97(m) 10.00 1000 CtCt<=15m<15.00 Enter Abet Main 13.04 1429 2.841 40.52 MAS=3.97(m) 150.00 15000 MinPts 15.90 13.041 14.09 286 24.98 MAS=3.97(m) 199.97 129.97 101461-0.500 1 .q 13.04 17.8e 10.781 4.80 MAS=3.97(m) 774.59 707.88 Mins 24.22 13. 17.49 11.18 4.18 MAS=3.97(m) 833.93 824.24 MNPT-O-EOU • 27.01 13.04 18.90 13.9 =ME MAS=3.97(m) 924.80 908.89 MInPt-O-SF 55.24 17.68 49.04 37.-•MICE OSF 1.50 1198.77 1149.54 MInPt-0-SF 82.83 20.20 48.89 42 1 OSF 1.50 1298.84 1233.32 MlnPt-O-SF • • 67.18 21.58 52.38 45...MIKIC OSF 1.50 1359.66 1281.59 MInPI-O-SF • 81.81 25.42 64.48 56.39 5.00 OSF 1.50 1500.37 1387.42 OSF>5.00 Ent Nert 208.77 87.34 253.47 231. OSF 1.50 2705.84 2210.98 MinPt-0-SF • 304.86 68.87 25887 238.1• 5.7 OSF1.50 2799.06 2261.79 MinPt-0-SF 300.70 00.15 26221 240.• 7.04 OSF 1.50 3045.24 2379.30 MinPt-0-ADP 300.03 86.051 262.2 240.57 7.05 OSF 1.50 3053.86 2382.90 MINPT-0-E0U 233.99 70.97 188.35 163.02 4.99 OSF 1.50 3872.55 2614.93 OSFe5.00 Enter Nat Man I. 108.88 148.15 112.18 3.06 OSP 1.50 4722.07 2727.54 MinPt-CtCt 221.31 111. 14614 110.24 3.001 OSF 1.50 480207 2738.15 MinPts lam"/ 112. 144.50 107.34 2.94 OSF 1.50 5082.04 2775.26 MinPts 220.01 112.67 144.57 107. 214 OSF 1.50 5082.04 2776.59 M00t-0.4DP 220.09 112.71 144.02 107. 2. OSF 1.50 5102.04 2777.91 MinPt-0-SF =En 128.88 145.42 102.79 2.71 OSF 1.80 643147 2954.15 MinPt-CICI 232.00 129.9 MOM 102.03 2.89 OSF 1.50 6511.40 2964.75 MINPT-PEOU 232.48 130.55 146.11 IIINZE 2.68 OSP 1.50 6551.46 2970.05 MinPt-O-ADP 235.39 132.72 146.58 102.6 OSF 1.50 6881.42 2987.28 MinPt-POF 158.66 140.03 84.98 18.•<MIB'L• OSP 1.60 8343.47 3207.61 MinPt-O-SF 156.57 138.08 64.2'MOM 1.70 OSF 1.50 8352.66 3208.83 M.Pt-O-ADP 14417 124.1. 20.87 1.75 OSF 1.50 8407.61 3216.11 MINPT-0-EOU =ME 79.58 75.58 4938 2.44 OSF 1.50 8552.43 3235.31 MInPt-CtCt 148.32 110..Z 38.12 2.02 OSF 1.50 8705.01 3257.76 MINPT-0-EOU • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S135-W4\S135-W4\S135-W4(P5) 6/18/2013 7:35 AM Page 1 of 10 o N 0 \ \ \ ! | 0 .......... : : 0 = : T..... . , § .. CID i ! © 2 - E _ g :„.„ /\ y \ Szuz \\! 2 Z « P« § 7/ a \ § ) ;;\ ( hi — } . . . . . 0 ? y g 7 /a ! \)\ :i: ,4,_ ®g! ! / §! A )!; o , 0 o / \(\ 1 / Cr 4 % 2 / | ! „ 2 S; .d ° ) 2 ®! . 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Rule MD(N) I TVD(ft) Alert I Minor I Major 16502 131.02 77.34 34.00 1.80 OSF 1.50 8756.09 3265.89 MinPt-2-ADP 17519 140.30 81.34 34.90 7.849 OSF 1.50 8781.23 3269.89 MinPt-OSF 674.21 203.90 53795 470.31 4.98 OSF 1.50 9518.52 3385.96 OSF>5.00 Exit Alert 1111.79 103.33 998.58 942.4 -..0 OSF 1.50 11397.28 3572.97 M940.43SF Mr.1= 187.20 1008.35 950.94 10.08 OSF 1.50 1240481 3580.71 MInPt-CICt 1122.46 180. •�„E 941.94 9.97 OSF 1.50 12539.73 3580.49 MINPT-0-EOU 1124.90 189.55 1002.,=:. 923 OSF 1.50 12508.37 3581.11 MinPt-O-ADP 1134.07 201.1 Man 932.91 8.49 OSF 1.50 12897.60 3589.21 MINPT-0-EOU 1134.68 201.82 999.81=MO 8.47 OSF 1.50 12928.55 3589.97 MInPI-O-ADP 1137.30 20441 1000.'•=ISE 8.38 OSF 1.50 13090.49 3591.20 101n14I-0-ADP I 210.23 998.27 928.52 8.18 OSF 1.50 1338038 3591.20 MinPt-CtCI MIME 235.56 840.41 862.22 7.01 OSF 1.50 14449.10 3565.83 M8P8-CICI 109799 238..:WIDE 861.91 7.00 OSF 1.50 14409.08 3565.13 MINPT-O-EOU 109820 236.34 040.3.Ma11:5 6.99 OSF 1.50 14479.07 3584.77 Mint-0-ADP Malta 302.72 88930 788.72 5.42 OSF 1.50 18748.24 3558.83 M9n1:1-CICI 1091.98 304. =ZIIE 787.70 5.40 OSF 1.50 16798.07 3559.18 MINPT-0-EOU 1092.74 305.24 888.9.1 , 5.38 OSF 1.50 18827.98 3559.53 MinPt-2-ADP • 1098.53 318.8 =MI 770.85 5.18 OSF 1.50 17247.32 3584.44 MINPT-O-EOU 1090.02 320.32 886.,•=KO 5.18 OSF 1.50 17297.38 3564.75 MInPt-2nADP 1105.22 330.41=Mil 774.80 5.03 OSF 1.50 17602.97 3580.03 MINPT-2.E20 1105.87 331.20 884.7'=ME 5.02 OSF 1.50 17627.20 3566.19 MinPt-2-ADP 1109.07 333.51 886.41 775.57 5.00 OSF 1.50 17897.11 3588.42 00F05.00 Enter Abri 1124.58 339.92 897.82 784.54 77 OSF 150 17890.87 3507.12 MinPt-2-SF "L• 373.39 942.77 818.83 4.80 OSF 1.50 18892.09 3570.54 MinPl-CtCt 384.59 937.32 809.46 4.07 OSF 1.50 19212.85 3583.58 MinPI-CtCI 1198.15 403.••MIII31117.1 795.87 4.49 OSF 1.50 19663.00 3588.34 MINPT-O-EOU 1197.27 401.67 929.1.MOO 4.48 OSF 1.50 1970297 3588.49 MinP1-0-ADP 1207.21 445.•• �'I OSF 1.50 19496.66 858830 MinPts SD37-DSP1(Dei Survey) T• ^+%,Y.r"t iNT' ;'. Warning Alert 2468 19.94 23 45 473 N/A MAS=6.08(m) 0.45 0.45 CrCt<=15m<15.00 Enter Alert ® 1994 18.83 2.761 13.88 MAS=6.08(m) 370.41 370.38 MinPts 22.73 19.941 19.91 2.79 13.48 MAS=6.08(m) 300.37 390.29 MINPT-0.E20 24.92 19.94 21.71 4.•:1MM MAS=6.08(m) 489.57 489.17 MInPt-2-SF 2680 19.94 23.43 6.::1E MAS=8.08(m) 519.07 518.45 MinPt-2-SF 47.91 1994 43.61 27.97 15.14 MAS=floe(m) 663.85 680.90 CtCK=15m41500 Exit Merl 481221 19.94 4798.68 4792.26 383.71 MAS=6.08(m) 3361.70 2496.39 TD 5132-W2(Def Survey) 24.08 1951 22.85 4.57 WA MAS=5.95(m) 0.48 0.48 CICI<=15m475.00 Enter Alert I 23.201 19.51 21.10 3.691 24.99 MAS=5.95(m) 310.34 310.33 MinPls 23.20 19.511 21.00 3.70 24.70 AVS=5.95(m) 320.33 320.31 MINPT-0-EOl7 19.51 20.93 9.04 3.91 MAS=5.95(m) 918.88 901.58 MinPts 28.81 19.611 20.25 9.11 3.84 MAO=5.95(m) 936.38 919.74 MINPT-O-EOU 29.18 19.51 20.55 9.651 1 MAS=5.95(m) 975.73 955.74 MInPI-O-SF 49.11 19.51 39.53 29.60 5.79 MAS=6.95(m) 1241.43 1180.74 CtCt4=15m>15.00 Exit Alert ® 22.71 211.76 204.60 15.78 OSF 1.50 2402.84 2027.85 MInPt-C80t 227.44 23.1 211.5 204.25 15.45 OSF 1.50 2457.83 2062.87 MINPT-0.EOU 227.48 23.24 211. 204.2 15.41 OSF 150 2486.98 2088.66 MinPtAADP 227.81 23.39 211.81 204. 15. OSF 1.50 2503.57 2091.58 MinPt-0.SF E 55.09 381.84 383.60 11.58 OSF 1.50 4284.23 2669.50 Mini-CICI f 42491 70.411 354.49 9.16 OSF 150 4888.10 2720.12 MMPT-0603 I![• 42722 73.03 977.x,�r 8.80 OSF 1.50 4743.27 2730.35 MInP1-OADP 429.12 75.59 378. �., 8.01 OSF 1.50 4803.09 2738.28 MinPl-O-ADP 574.59 120.88 489.68 447. • OSF 1.50 7428.47 3088.31 MInPI-OSF 235351 200.24 2219.69 2153.2 1® OSF 1.50 9882.58 3435.41 MInPI-2.SF 2160.30 149.78 2080.1 NE= 21.77 OSF 1.50 10614.83 3517.89 M1nPI-2.ADP 2301.02 15091 2200.,• 2150.11 23.01 OSF 1.50 1158975 3584.11 MINPT-O-EOU Effgrill 189.49 2131.20 2068.38 17.90 OSF 1.50 12634.20 3587.65 MInPt-CICI 2258.38 192..M-< 2086.06 17.70 OSF 1.50 12904.20 3589.37 MINPT-O-EOU 225889 192.66 2129.•0 ME= 17.87 OSF1.50 12922.58 3580.83 MInPI-0-460tP 2280.07 193.99 2130. ,^•• , 17.50 OSF 1.50 13007.25 3591.19 MinPt-OADP 237.28 1993.10 1914.33 13.65 OSF 1.50 1487386 355532 M8rPI.CICI MIRE 243.21 1989.13 1908.38 13.32 OSF 1.50 15004.01 3551.20 M,nPI-CICI 2152.19 244. 1907.39 13.24 OSF 1.50 1515471 3550.89 MINPT-0-EOU lI 251.48 1086.31 1902.82 12.90 OSF 1.50 15304.58 355077 MI0PI-C1CI MULE 260.69 1080.80 1883.98 12.43 OSF 1.50 1572635 3552.05 MInP8.CICI 2157.30 260. 1979.2 1890.71 12.18 OSF 1.50 15918.11 3558.08 MINPT-2.EOU 2158.33 287.80 1079.4 1890. 12.13 OSF 1.50 15956.05 3559.23 MinP1-0-ADP 2537.21 425.04 2253.52 2112.16 8.97 OSF 1.50 19803.63 3589.19 TD 13117.01 113.85 13040.77 13003.1'MIENZEI OSF 1.50 220103 1891.75 MInP1-0-SF SX31-FN2(Pt)(Del Plan) ",1 Warning Alen 32.04 25.87 30.81 6.16 N/A MAS=7.89(m) 0.00 0.00 CtCI<=15m415.00 Enter Alert I 32.041 25.87 30.,•�' '. 39.59 MAS=7.89(m) 200.00 200.00 MinPts 32.17 25.8 ME= 6.29 30.78 MAS=7.89(m) 289.88 289.88 MINPTAEOU 43.99 2537 40.24 18.11 MEE MAS=7.89(m) 58445 583.08 MinPt-OSF 47.22 25.87 43.29 21. I'1 MAS=7.89(m) 603.34 601.66 MinPI-0-SF 40.04 25.87 45.03 23.16 16.09 MAS=7.89(m) 612.72 610.88 CtCK=15m>15.00 Exit Alert 471.89 25.87 460.91 4459 MUM MAS=7.89(m) 1174.84 1131.02 MinPl-0-SF 1247.73 25.87 1230.42 1221.85® MAS=7.89(m) 1523.10 1404.14 MInPI-0-65 1391.81 28.11 1372.08 1363.•MEM OSF 1.50 157844 1444.77 Min141-0-0F 2233.06 31.92 2211.42 2201.1 =IEEE OSF 1.50 1738.48 1580.02 MIn141-0-SF 2370.20 33.84 2347.28 2336.3'MIKE OSF 150 1742.55 1564.42 Min114-03F 290.52 5170.49 5073.92 27.79 OSF 150 17256.53 3564.54 MinPFCICI 5364.70 201.3615170.1 5073.34 27.71 OSF 1.50 17286.74 356470 MINPT-0-EOU 5385.13 29193 5170.1 5073.21 27.66 OSF 150 17306.82 3564.78 Mint-OADP 5894.36 328.42 5478.42 5387.941 26.24 OSF 1.50 1851152 3571.06 MinPl-0SF 1. 6243.89 35885 6004.48 5885.24 28.18 OSF 150 19909.64 3589.25 TD 7429.49 222.71 7280.69 7200. 50.2 OSF 1.50 987558 3437.17 MinPI-0-SF 8902.21 182.13 0750,41 0720. 57.15 OSF 1.50 10496.36 3507.85 MinPl-OADP 6901.53 181.30x 6780.''',"',,1111 0720.24 57.41 OSF 1.50 10507.74 3508.87 MINPT-2.E00 Imo. .1 179.82 6780.86 6721.25 67.87 OSF 150 10527.05 3510.62 MInPt-CtCCt 12052.40 03.07 12010.08 11989.•�' OSF 1.50 967.43 948.18 MinPt-2SF 10795.09 37.95 10789.83 10757.7 MI= OSF 1.50 1120.89 1084.58 MInPt-OSF 1026764 35.47 10243.64 10232.1. OSF 1.50 1188.89 1142.91 MinPt-O-SF 10189.23 3519 10165.41 10154., 1 OSF 1.50 1199.75 1152.09 MinPt-OSF 485185 141.29 4557.13 4510.•liwzyfE OSF 1.50 4742.04 2730.19 MinPt-0.SF 1093593 70.97 10888.26 10884.••M. OSF 1.50 2509.53 2131.91 MinPt-04F 1228271 93.03 12220.37 121896.MEM OSF 1.50 2723.93 2221.02 MinPt-OSF SP30-W 1P81(Def Survey) At,„ W amin9 Alert • 48.02 3281 4600 1522 N/A MAS=10.00(m) 0.18 0.18 CICIr_15m<15.00 Enter Alert I 48.021 32.81 46.76 15.24 1173.52 MAS=10.00(11) 54.10 54.10 MinPts 48.28 32.811 48.60 15.46 106.88 MAS=10.00(m) 140.18 140.18 MINPT-2.EOU 49.19 3281 46.80 18.38 94.58 MAS=10.00(m) 280.00 280.00 CtCt<=15m>15.00 Exit Alen 51.17 32.81 ME:lal 18.37 15.44 MAS=10.00(m) 479.40 479.06 MINPT-O-EOU 78.91 32.81 60.32 44.10 4.92 MAS=10.00(m) 871.89 859.73 OSF<5.00 Enter Alert 84.13 32.81 6435 51.321 4.471 MAS=10.00(m) 945.12 92777 MinP1-03F Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\S135-W4\S135-W4(P5) 6/18/2013 7:35 AM Page 2 of 10 I Offset Trajectory Separation Allow Sep. Controlling Reference Traleetory Rink Level Alert Status Ct•Ct(ft)I MAS(ft)I EOU(R) Dew.(ft) Foot. Rule MD(R) I TW(R) Alert I Minor I Major 94.70 32.81 74.74 81.80 4.99 MAS=10.00(m) 102397 999.30 OSF>5.00 Exit Alert 38.04 574.11 581.46 23.69 OSF 1.50 3593.80 2562.50 MltrPt-CICI 801.36 42.91 572.4 558.45 21.48 OSF 1.50 3768.17 2508.88 MINPT-O-EOU 601_95 43131 572. 558. 21.15 OSF 1.50 3804.94 2005.02 MinPt-3-ADP 802.14 43.81 572. 558. 21.06 OSF 1.50 3814.12 2806.47 MinPt-0-60P • 649.50 02.03 007.82 587. 15.94 OSF 1.50 4795.86 2737.32 MinPtbSF ' 724.93 78. 872. 848.90 14.09 OSF 1.50 6097.70 2909.90 MINPT-O-ECU 728.07 78.43 872.7 648. 13.86 OSF 1.50 6128.71 2913.75 MinPt-0-ADP I 908.47 128.48 822.48 778.98 10.68 OSF 1.50 689633 3016.77 MInPt-0-SF 1 3003.87 199.79 3770.38 3704. 29.4 0971.50 9984.06 3451.52 MInPt-0-OF 111EME 174.90 3307.38 3338.37 30.20 0571.50 12580.73 358141 MinP4-01C( 3075.1 302.721 2873 011 2772441 15.281 OSF 150 1579030 3554.48 MinPts • SP3O-W 1(Def Survey) Warning Alert 48.02 3281 4680 15.22 N/A MAS=10.00(m) 0.18 0.18 CtCt<=15m<15.00 Enter Alert ' 1 48.021 32.81 46.7+MEM 1173.52 MAS=10.00(m) 59.10 54.10 MinPts 4828 32.81'' 15.48 106.86 MAS=10.00(m) 140.18 140.18 Mk4PT-0.EOU 40.19 32.81 46.90 16.38 4458 MAS=10.00(m) 280.00 260.00 CICK=15m>15.00 5x8 Alen 51.17 32.81 MEM 18.37 15.44 MAS=10.00(m) 479.40 479.00 MINPT-0-EOU 76.01 32.81 80.32 44.10 4.02 MAS=10.00(m) 871.90 859.73 057<5.00 Enter Alert 84.13 32.81 04.35 51.32 MEM MAS=10.00(m) 845.12 927.77 MInPI-0-SF 94.70 3281 74.74 61.90 4.90 MAS=10.00(m) 1023.87 999.30 0570500 Exit Alert 38.04 574.11 581.46 23.69 057 1.50 359339 2582.50 MinPt-CtCI , 801.38 42.91 MEE 558.45 21.48 0071.50 3768.17 2598.88 MINP1'-0.E011 601.95 43.01 572. NOME 21.15 OSF 1.50 3804.94 2005.02 MInPI-0-ADP 802.14 43.81 572,MEE 21.06 OSF 1.50 3814.12 2016.47 MMPI-0-ADP 649-50 62.03 007.82 587._,MEE 097 1.50 4795.86 2737.32 MinP1-0.5F 724.03 78..•�- �-, 846.90 14.09 OSF 1.50 6087.70 2909.90 MINPT-O-EOU 1 720.07 79.43 672.;1111111:= 13.86 OSF 1.90 8128.71 2013.75 MMM-0-PDP 808.47 128.40 822.48 779.•:M' OSF 1.50 8698.33 3015.77 80985-0-SF 3903.87 199.79 3770.38 3704_x' OSF 1.50 9984.85 3451.52 MinPI-0-SF E 174.90 3307.38 3338.37 30.20 OSF 1.50 12580.73 3581.41 MInPt-CtOt l 200.67 2964.63 2878.10 17.74 0571.50 15690.70 3557.02 MinPt-CtOt 3144.31 270.1 .• -T' 2874.16 17.52 007 1.50 18010.41 3581.04 MINPT-0-E09 3145.07 271.04 2964.1 a 17.40 057 1.50 16049.32 3501.90 MinPt-0-ADP 3677.72 357.64 3438.06 3320.x. : OSF 1.50 18851.20 3575.84 68981-0SF 6910.28 410.34 3032.39 3493.93 14.12 OSF 1.50 10808.90 3588.87 TD 11469.51 79.76 11438.01 11400.7 MEM OSF 1.50 1458.96 1358.80 M98t-0SF 11455.37 83.05 11399.88 11372.3- OSF1.50 2226.89 1909.66 MinP66SF 12591.78 114.60 1251505 12477.1 1 0571.50 235503 1906.28 MInP1-0S7 5129-S2(Def Survey) '1#`x,, . ::Peas ... 32.811 54.77 23.19 N/A MAS=10.00(m) 0.08 008 MinPts I ® 32.81 5250 2246 35.10 MAS=10.00(m) 378.22 37816 MinPts 55.35 32.84 5238 2254 3103 MAS=10.00(m) 407.47 407.37 MINPT-0-E00 58.51 32.81 54.98 25.70 MME MAS=10.00(m) 484.72 484.35 MMPI-OSF i 3108.02 40.67 3078.50 3065.35 MEM OSF 1.50 1913.01 1887.80 MinPt-OSF 5092.20 13210 5003.81 4060.10 58.25 OSF 1.50 12070.25 3584,65 TD 1127.09 130.09 1040.92 097...MEE 0571.50 5854.97 2877.72 MnPt-0SF MEE 85._100 779900,448 78245 15.10 0571.50 6235.08 2928.11 MinP1-01C1 847.81 85.61 r00.4q 78213 15.00 OSF 1.50 6244.88 2929.38 MINPT-O£OU I 848.42 88.38 790. 782.0414.89 OSF 1.50 625420 2030.85 M98t-0-ADP 1019.88 127.21 934.74 892- 12.111 OSF 1.50 8534.41 2967.79 MOP1-0SF SX28-FN3(P1)(Def Pim) Pass 64.12 32.81 62.89 31.31 N/A MAS=10.00(m) 0.00 0.00 Surface I! 3281 6212 31.311 81.84 MAS=10.00(m) 20000 20000 MinPts 64.24 32.81 62.01 31.43 6277 MAS=10.00(m) 26077 280.77 MINPT-0-E00 84.83 32.81 62. 3202 45.92 MAS=10.00(m) 409.02 408.01 MINPT-0-EOU 93.97 32.81 88.91 61.1 111111M MAS=10.00(m) 711.23 706.91 MInP1-0-SF MEM 181.00 7507.12 7537.11 64.30 057 1.50 11447.79 3576.49 MinPt-C1C( mum 298.97 8501.03 6481.70 34.18 057 1.50 17411.68 3585.22 MinPt-CICt 8791.09 300.1.1111) 8490.90 94.05 0571.50 17451.41 358569 MINPT-D-EOU 8791.32 300.38 0590.7 ' 34.02 0571.60 17481.35 350543 M9860-PDP 7111.34 337.25 0886.18 6774..'MEE OSF 1.50 18848.35 3575.59 MinPt-0-SF 7480.10 384.09 7237.08 7118.08 3090 0971.50 19900.64 3580.25 TD 10758.58 236.89 10800.32 10521..:•MEE OSF 1.50 054630 3380.14 80nP1-0-O7 8520.88 216.13 8376.47 8304.• 59.'. OSF 1.50 9983.89 345142 MinPt-0SF 7715.40 168.37 7602. 7547..< 00.13 0571.50 10701.74 3524.44 MMPt-O-ADP 7714.80 107.7 7802. 7547.14 69.38 OSF 1.50 10711.62 3525.14 MINPT-0-E09 6340.92 133.18 8251.81 6207.MEI OSF 1.50 4743.82 2730.40 MinPt-0-SF 10401.21 169.55 10287.85 10231.60 92.5 OSF 1.50 6563.15 2871.00 MInPI-0-57 • 12058.70 48.15 12024.27 12008.55 0571.50 801.13 877.87 MInPt-06F 18245.27 904.14 18108.84 18041.15 OSF 1.50 8556.40 9235.85 MinP1-0.5F 18292.24 204.67 1815546 18087.57.70 OSF 1.50 8593.04 3240.90 MinP1-0SF 12012.05 81.47 11957.41 11930. 0571.50 204854 2335.82 MinPt-0-SF ' 8584 18085.021 16036.72, 284.84 0071.50 300785 238284 MinPts 5727-N1(Del Survey) Pass :, ;j..: ® 32.81 69.21 38.501 80.18 MAS=10.00(m) 289.91 289.90 MinPts 71.32 32.811 69,10 38.51 77.89 MAS=10.00(m) 298.87 299.88 MINPT-0-EOU 182.08 32.81 149.15 129.27 MIZI1Z MAS=10.00(m) 1105.18 1148.20 M'InPI-0-SF 997.20 96.10 932.74 001.01=ME 057 1.50 4958.98 2758.05 MInPI-0-SF 6187.47 200.300 8053.81 5887.1 MEE 0071.50 8020.46 3165.08 MinPt-0-SF 5061.03 208.90 4921.44 4852.1 MEE 05F 1.50 1000368 3453.05 MInPI-0-SF • 4851.93 167.2 4540.11 4484.80 41.98 0571.50 1130207 3568.30 MINPT-0-EOU 4652.54 167.93 4540.2 4484.601 41.79 OSF 1.50 11322.91 3567.79 MinP1-0-ADP 4855.51 188.64 4544. 4488.86 4214 0571.50 11485.58 3578.91 MINPT-0-EOU 164.32 4544.99 4490.55 42.74 OSF 1.50 11509.78 358032 MinPS-CtCt .: 201.77 4320.74 4253.81 33.28 0571.50 13195.10 3591.20 MinP1-010 4455.68 202.1.MEE 4253.54 33.22 OSF 1.50 13212.82 3591.20 MINPT-0-EOU 4455.70 202.32 4320.• ' 33.19 OSF 1.50 13222.82 3501.20 MinPt-0-ADP 277.84 3820.28 3728.00 21.71 OSF 1.50 18074.44 3582.82 MInPI-C1C1 4005.70 278..-WEIDE 3727.74 21.88 OSF 1.50 16088.07 3583.01 MINPT-0-EOU 400509 278.35 3820.1.MEffiiE 21.66 OSF 1.50 18098.05 3503.30 MInPt-0-ADP •• 4286.39 307.02 4080.98 3558.78 20.87 0571.50 17073.75 3582,41 TD 9928.28 88.57 9882.17 9859.61 MEE OSF 1.50 2107.38 1889.20 MinPt-O-SF • 5X28-FN4(P1)(Def Plan) Pass 8008 32.81 7885 47.27 N/A MAS=10.00(m) 000 000 Surface 1 80.081 32.81 78.08 47.271 102.38 MAS=10.(10(m) 200.00 200.00 MinPts 80.20 32.811 7707 47.39 78.70 MAS=10.00(m) 269.72 200.71 MINPT-0-EOU 116.23 32.81 110.77 83.43 27. MAS=10.00(m) 728.22 721.40 MInPt-O-SF 500.32 32.81 490.73 473.51 B0. MAS=10.00(0) 1141.15 1102.24 MinP60-57 8313.45 171.68 8198:4 8141. 73.05 OSF 1.50 11540.34 9582.36 MInPt-0-ADP 8312.90 171.021 8198.5"11 8141.89 73.33 OSF 1.50 11559.54 3582.83 MINPT-0-E0U Nom 180.88 8108.05 8142.65 73.81 OSF 1.50 1157730 3583.61 MinPt-CICt 230.73 7838.14 7759.58 52.16 057 1.50 14953.59 3553.82 MinPt-CICt 799042 231.13x 0 7759.29 52.07 OSF 1.50 14973.35 3553.45 M1NPT-0-E0U Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/18/2013 7:35 AM Page 3 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Stator Cl-Ct(ft)I MAS(ft)I EOU(ft) Dev.(RI Fact. Rule MD(61) 1 TVD(ft) Alert 1 Minor I Major 7990.58 231.33 7836.03 7759.24 52.03 OSF 1.50 14983.23 3553.26 MInPt-0.ADP 8716.78 364.12 8473.71 8352.66 30.00 OSF 1.50 19909.64 3589.25 TD 8980.52 201.22 883505 8768.31 67.19 OSF 1.50 10167.73 3473.90 WIN-0.SF 7453.21 115.33 7376.0D 7337.88 97.78 OSF 1.50 4464.21 2693.36 MInPt-0-5F 8445.53 13085 8357.96 8314.87 OSF 1.50 4739.58 2729.88 MinPt-0-SF 11992.28 38.61 11967.54 11955.67 OSF1.50 84730 838.84 MinPt-O-SF ME= 78.04 13003.271 12977.58 254.07 OSF 1.50 3303.15 2476.82 MinPts 5125-N2(DM Survey) Pass F. 1 3281 81.88 52 151 4507 MAS=1000(m) 45855 45831 MinPts 85.10 32.811 81.74 52.30 39.17 MAS=10.00(m) 488.41 488.01 MINPT-0-EOU 187.06 32.81 189.30 154.25 MEM MAS=10.00(m) 1300.71 1234.98 MinPt-0-SF 429.33 55.57 391.88 373. IIMEE OSF 1.50 2351.92 1994.22 MInPI-0.5F 470.03 60.60 429.22 409. I OSF 1.50 2508.83 209484 MnP1-0-SF 1454.20 103.24 1385.04 1350.1 NEM OSF 1.50 4742.24 2730.22 MinPt-0.SF 6245.42214.80 610203 6030.8-1111=E11 OSF1.50 10115.03 3487.69 MInPt-0.SF 4-� 271.54 5278.84 5188.45 30.27 OSF 1.50 1530034 3550.82 MinPO-COCl 5460.28 272.5.E-'.- 518777 30.18 OSF1.50 15334.24 3550.80 M1NPT-O-E0IJ =Z1NE 286.33 5286.30 5171.19 28.68 OSF 1.50 15818.00 3555,21 MInPI-CICI 5457.80 287.•walE 5170.60 28.60 OSF 1.50 15845.08 3558.05 M1NPT-0.E30 5458.06 287.52 5266.0 MO:, 28.57 OSF 1.50 15855.98 3558,36 MI1Pt-0-ADP 5478.17 303.••=ffijE 5175.17 27.20 OSF 1.50 1835706 3563.11 MINPT-0-E30 5479.65 304.88 5276 e•=ME 27.04 OSF 1.50 16417.02 3562.33 MInPt-0-ADP 5585.40 378.92 5332.46 5206.48 22.16 OSF 1.50 17022.20 3581.81 TD 5579.67 210. 5438. 5368.08 39.85 OSF 1.50 12858.15 3588.19 MINPT-O-EOU 5580.95 212 51 5438. 5368.44 39.574 OSF 1.50 12896.06 3580.17 MinPLO ADP 5585.52 214.52 5442.18 5371.00 39.24 OSF 1.50 13010.10 3591.20 MinPt-0.SF 41 159.44 5299.351 5246.54 51.18 OSF 1.50 11788.47 3587.80 MinMs SP24-SE1(P2)(Def Nen) •u , e;,a}T' 2$1 1, - -.. Fan j.' 32.81 93.80 65.011 34.63 MAS=10.00(m) 558 69 557.67 MinPts 9786 32.81 93.73 65.05 33.20 MAS C 10.00(m) 587.73 588.59 MINPT-O-EOU 12768 32.81 120.68 94.871 MAS=10.00(m) 719.95 715.34 MinP1-0.5F 2233.58 56.35 2195.69 2177.23 60.49 OSF 1.50 3491.09 2535.78 TD 1742.11 88.78 1807.27 1875. irU OSF 1.50 3227.88 2450.80 MinP1-0-5F 1892.59 64.91 1848.99 1627.:. 3D..• OSF 1.50 3255.71 2450.51 MInP6-0-5F 1846.58 60.48 1605.94 1586.1. 41.50 OSF 1.50 3318.51 2481.34 M4P1-0.ADP 1848.50 80.34) 1605. 1588.15 41.58 OSF 1.50 3318.19 2481.91 MINPT-O-E34J jY 80.23 1605.99 1588.24 41.68 OSF 1.50 3319.87 2482.47 MInP1-CICi SP22-FN1PB3(Def Surey) b -?"' iE : §' *s'' '4`-ff, Pass 8864.37 163.28 6755.19 6701.•1=. '1 OSF 1.50 11520.86 3580.92 MinPt-O-SF MEW 32.81 125.1:j ' N/A MAS=10.00(m) 41.00 41.00 MlnPts 127.30 32.81 125.24 94 =Mil MAS=10.00(m) 262.75 262.74 WIN-0.SF 127.21 32.81 125.14 94 •j MAS=10.00(m) 289.66 289.65 MinPt-O-SF 11=ME 32.81 113.••NEM 48.11 MAS=10.00(m) 559.80 558.76 MinPts 117.66 32.81=MEE 84.85 40.20 MAS=10.00(m) 589.04 567.89 MINPT-0830 125.27 32.81 120.19 92.48 32.151 MAS=10.00(m) 684.81 681.30 M1nPt-3-SF =ME 88.84 3689.64 3660.37 83.96 OSF 1.50 3885.30 2613.95 MinPts 4674.59 137.80 4582.47 4538.98 OSF 1.50 4802.11 2738.15 MInPt-0.0F 7979.84 228.43 7827.23 7751.41 52.6 OSF 1.50 8103.44 3175.79 MinPI-0-SF mon 74.801 3731.20 3706.68 77.02 OSF 1.50 3233.57 2452.80 Min% j 32.81 2990.47 2976.81 1118.35 MAS=10.00(m) 1629.81 1482.38 MnPis MIME 32.81 3539.52 3528.89 188.21 MAS=10.00(m) 1628.40 1479.87 WPM A(.r., 32.81 6748.73 6738.05 321.40 MAS=10.00(m) 1588.00 1451.77 MinPt-CICi 11.. �13569.37 32.81 13548.71 13536. 680. MAS=10.00(m) 957.70 939.30 MinP1-0-SF • W 309.72 4457.87 4354.96 22.68 OSF 1.50 17215.09 3564.07 MInPt-C1Cl 4665.20 311.3-jam 4353.89 22.54 OSF1.50 17264.42 3564.80 MINPT-3.E0U 4665.78 311.95 4457.•j 22.50 OSF 1.50 17284.14 3584.80 Min1=1-0.ADP 5192.74 395.89 4928.49 4796.8851972 OSF 1.50 1990964 3589.25 TD 730528 246.48 7140.61 7058./89 44.81 OSF 1.50 9681.31 3410.02 MinPt-0.SF 15839.21 205.96 6701. 6833. 50.04 OSF 1.50 10210.55 3478.80 MInFl-0-ADP 683806 204.571 8701. 6633.49 50.38 OSF 1.50 10224.97 3480.42 M1NPT-0-E0U 192.65 6700.06 664217 53.48 OSF 1.50 10343.26 3493.11 Min1N-CtCt +fir 172.- �.� -r.,�-•�'- OSF 1.50 11433.10 3575.47 MlnPts WOE 169.. 6670 7 Waal M.r ( OSF 1.50 12532 91 3560.38 MinPts SP22-FN1PB1(Def Survey) Pass 6864.37 183.28 6755.19 6701.•1 MOM OSF 1.50 11520.86 3580,92 Mir1=1-0-5F 32.81 125.9.Min N/A MAS=10.00(m) 41.00 41.00 MinPts 127.30 32.81 125.24 94.'=EU MAS=10.00(m) 262.75 282.74 MinPt-0.SF 127.21 32.81 125,14 94.•1L MAS=10.00(m) 289.88 289.65 WIN-0.5F j• 32.81 113.••Z 48.11 MAS=10.00(m) 559.80 558.78 MinPts 117.66 32.81=En 84.85 46.20 MAS=10.00(m) 569.04 567.80 MINPT-0-509 125.27 32.81 120.19 92.46=EEO MAS=10.00(m) 884.81 681.30 8546143SF s 85...j 63.98 OSF 1.50 3865.30 2613.95 MinPts 4674.59 137.69 4582.47 4536...=MI OSF 1.80 4802.11 2738.15 MinPO-0SF 7979.84 228.43 7827.23 7751.41 j X t-0. OSF 1.50 8103.44 3175.79 MInPSF j 74.•'WEIDE=UM 77.02 OSF 1.50 3233.57 2452.80 MinPts 32.81==EL ME= 168.35 MAS=10.00(m) 1829.81 1482.36 MinPts MERE 32.81=EOM 1E 188.21 MAS=10.00(m) 1828.40 1479.87 MinPts =man 32.81 6748.73 6738.05 321.40 MAS=10.00(m) 1588.00 1451.77 MInPI-CICi 12259.45 80.86 12212.68 12189.7:MERE OSF 1.50 2512.82 2097.19 MinPt-0-SF 12518.37 71.02 12488.80 12445.3 =•r' OSF 1.50 2537.28 2112.34 MirPS-0-SF 1-.4 309.72 4457.87 435496 2288 OSF 1.50 17215.09 3564.07 MinPO-C1C1 4665.20 311. .==jjE 4353.80 2254 OSF 1.50 17264.42 3584.00 MINPT-O-EOU 4885.78 311.05 4457..MSEE 22.50 OSF 1.50 17284.14 3564.80 M895-0-ADP 5178.44 395.91 4914.17 4782.52 19.66 OSF 1.50 19909.84 3589.25 TD 730526 246.48 7140.61 7058. 44.0 OSF 1.50 9681.31 3410.02 MY465-0SF 883921 205.96 6701.1 6633. 50.04 OSF 1.50 10210.55 3478.80 MYPI-O-ADP 6838.06 204.574 6701. 8833.49 50.38 OSF 1.50 10224.97 3480.42 M1NPT-0-E39 =ZEE a 192.65 6708.05 8842.17 53.48 OSF 1.50 10343.28 3493.11 MinPt-C1C1 INILME 172.. MEM MI=MEE OSF 1.50 11433.10 3575.47 MinPts MUM 189.•• .�• 'MIME M.; OSF 1.50 12532.91 358088 MInPts SP22-FN1(Def Survey) Pass 6791.95 168.32 6870.41 6623...Min OSF 1.50 12528.43 3580.31 MinPt-0-SF =FRE 32.81 125.1• N/A MAS=10 00(m) 41.00 41.00 MinPts 127.30 32.81 125.24 90.'jJ MAS=10.00(m) 262.75 262.74 MinP8-0-SF 12721 3281 125.14 94.•=MIE MAS=1000(m) 289.88 289.65 MYPt-O-SF j• 32.81 113.••MIEME 48.11 MAS=10.00(m) 559.80 558.76 MinPts 117.68 32.81 MOM 84.85 46.20 MAS=10.00(m) 56804 56789 MINPT-0.809 125.27 32.81 120.19 92.46 MEE MAS=10.00(m) 684.81 081.30 WIN-0-5F j 88.-'W.=ME= 03.96 OSF 1.50 3865.30 2813.95 MinPts 4874.59 137.69 4582.47 4538.1•MIME OSF 1.50 4802.11 2738.15 MinPt-0.SF 7979.84 228.43 7827.23 7751.41 INWEEE OSF 1.50 8103.44 3175.79 MinP1-0-5F �- r-• 74.:'WEIDEMUM 77.02 OSF 1.50 3233.57 2452.80 MinPts M=Cil 165.--MMEEE jam-• IIMME OSF 1.50 11208.81 3569.83 MinPts 3008.6- 32 81 ME= 186.35 MAS=10.00(m) 1629 81 1482.36 851% Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/18/2013 7:35 AM Page 4 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-CLIN.A MAS(ft) SOU1ftj Day.fO(IL Fact. Rule MD(ft) I TVD(ft) Alert I Minot I Major 3559 4 32.81 3539.52 3526.89 188.21''1 MAS=10.00(m) 1620.40 1479.87 MinPts 13569.37 32.81 13548.71 13538.58 680.80 MAS=10.00(m) 957.70 930.30 MinPt-0-SF 20458.89 4428 20429.051 20414.61 708.77 OSF 1.50 719.05 714.47 M1nPI-O-ADP 1."..""a7"1 309.72 4457.87 4354.96 22.66 OSF 1.50 17215.09 3564.07 MNPt-CICI 4665.20 311. . 4353.89 22.54 OSF 1.50 17264.42 3564.60 MINPT-0-EOU 4665.78 311.95 4457._,MEME 22.50 OSF1.50 17284.14 3564.69 MinP1-0-ADP 5192.74 395.89 4928.49 4796.85 1972 OSF 1.50 19909.64 3558.25 TD 7305.28 246.48 7140.81 7058. 14.6 OSF 1.50 0681.31 3410.02 MInPI-O-SF 6839.21 205.96 6701.581 0633.2 50.04 OSF 1.50 10210.55 3478.80 MinPI-0-ADP 6838.06 204.571 8701.3 6633.49 50.38 OSF 1.50 10224.97 3480.42 MINPT-O-EOU =MEE 192.65 6706.06 6642.17 53.48 OSF 1.50 10343.26 3493.11 MMPI-CICI WINE 172.: MCIEIZ =MOE OSF 1.50 11433.10 3575.47 MinPts SP22-FN1PB2(Del Survey) 11,y `-4a•, r.,,8^' P,5:4-'414I''"`9„:,-0., ,2' .•0 '' 'W^.` r t,' 6864.37 16328 8755.19 6701 r•( . OSF 1.50 11520.86 358092 MInPI-O-SF IIE 32.81 125.••llllllll N/A MAS=10.00(m) 41.00 41 00 MinPts 127.30 32.81 125.24 04." ) MAS=10.00(m) 282.75 28274 MInPI-O-SF 127.21 32.81 125.14 04..MEM MAS=10.00(m) 289.66 289.65 MinPt-O-SF 'S 32.81 113...=121E 48.11 MAS=10.00(m) 559.80 558.76 MmPls 117.68 32.81 NEM 84.85 46.20 MAS=10.00(m) 569.04 507.89 MINPT-O-EOU 125.27 32.61 120.19 92.46 32.151 MAS=10.00(w) 684.81 681.30 MinP1-0-SF Mg= 88.84 3869.671 3660.37 03.96 OSF 1.50 3865.30 2813.95 MmPls 4674.59 137.60 4582.47 4536. 51.2 OSF 1.50 4802.11 2738.15 MInPI-0-SF 7979.84 228.43 7827.23 7751.41 52.0 OSF 1.50 8103.44 3175.79 MInPI-0-0F IMMIE 74.69 3731.21 3708.66 77.02 OSF 1.50 3233.57 2452.80 MinPts 3009.8- 32.81 2990.4 2970.81 166.35 MAS=10.00(m) 1829.81 1482.36 MinPts MI= 32.81 3539.5 3526.69 188.21 MAS=10.00(m) 1626.40 1479.87 MlnPls M.= 32.81 6748.73 6738.05 321.40 1462110.00(w) 1588.00 1451.77 M051-CICI 309.72 4457.87 4354.96 22.66 OSF 1.50 17215.09 3564.07 M058-CICI 4685.20 311. .W2filE 4353.89 22.54 OSF 1.50 17264.42 3504.60 MINPT-O-EOU 4665.78 311.05 4457.•NC= 22.50 OSF 1.50 17284.14 3584.69 14inFl--ADP 5102.74 305.89 4028.40 4796.85 19.72 OSF 1.50 19909.04 3589.25 TD 7305.26 240.48 7140.01 7058.7 44.6 OSF 1.50 9881.31 3410.02 MinPI-0-OF 8839.21 205.96 6701.54 8633._2611 50.04 OSF 1.50 10210.55 3478.80 MintI--ADP 8838.06 204.571 6701.35' 8033.49 50.38 OSF 1.50 10224.97 3180.42 MINP1-O-EOU MaEnE 192.65 6706.06 6042.17 53.48 OSF 1.50 10313.26 3493.11 59961-Clot IC= 172.:+lull �3 ^y MDE OSF 1.50 11433.10 3575.47 MAPS WEEK 169...M23352MIZIZIEINIECE OSF 1.50 12532.01 3580.38 MoPls SP22-FNIPB4(Def Survey) Mit,401$ Pass 6867.07 162.91 0758.13 6704.1. 5E1 OSF 150 11523.99 3581 09 MinP1-0-SF MEE 32.81 125.••jlllllllf N/A MAS=10.00(m) 41.00 41.00 MinPts 127.30 32.81 125.24 94.•J MAS=10.00(m) 28275 282.74 MinPt-0-SF 127.21 32.81 125.14 94.•lllllll E MAS=10 00(m) 269.66 259.65 MinPI-O-SF MEM 32.81 113...1=ZIE 48.11 MAS=10.00(m) 559.80 558.76 MinPts 117.66 32.81=OM 84.85 46.20 MAS=10.03(m) 559.04 567.59 MINPT-O-EOU 125.27 32.81 120.19 92.46 32.14 MAS=10.00(m) 684.81 681.30 MInPt-O-SF IIID 88.84 3689.671 3680.37 63.96 OSF 1.50 3885.30 2813.95 MAPS 4874.59 137.69 4582.47 4536. 51.2 OSF 1.50 4802.11 2738.15 14051-0-SF 7979.84 228.43 7827.23 7751.41 52.0 OSF 1.50 8103.14 3175.70 MMPI-O-SF ' MEM 74.69 3731.3 3708.88 77.02 OSF 1.50 3233.57 2452.80 SAWN 3009.6. 32.81 2990.4 2978.81 166.35 MAS=10.00(m) 1629.81 1482.36 MMPts =ME 32.81 3539. 3528.80 188.21 //AS a 10.00(m) 1628.40 1479.87 MlnPts MOE 32.81 6748.73 8738.05 321.40 MAS=10.00(m) 1555.00 1451.77 MInPt-CICt 13509.37 32.81 13548.71 13536.•=Tin MAS=10.00(m) 957.70 939.30 MInPt-O-SF Imo:: 309.72 445787 435496 22.66 OSF 1.50 17215.09 3564.07 MinPl-C1C1 4665.20 311. 4457. 4353.69 22.54 OSF 1.50 17264.42 3564.60 MINPT-O-E00 4665.78 311.95 4457. 4353.84 22.50 OSF 1.50 17284.14 3564.59 M05t-O-ADP 5192.74 695.59 4928.49 4796.85 19.72 OSF1.50 1990954 3589.25 TD 7305.26 246.48 7140.61 705814. OSF 1.50 9681.31 3410.02 MinPt-OSF 6869.21 205.90 6701. 0033.2 50.04 OSF 1.50 10210.55 3478.80 94961-0-ADP 6838.06 204.5 8701.3 6833.49 5038 OSF1.50 10224.97 3480.42 MINPT-O-EOU i EB<'. 192.65 8708.06 6642.17 53.48 OSF 1.50 10343.26 3493.11 MInPt-CICO M=11E 172.:+•. . W,MM OSF 1.50 1143310 3575.47 MinPts �. .l 168..• 6675.0 WIECIEC OSF 1.50 12530.67 3580.35 MinPis SP23-N3PB1(Def Survey) Pass =HE 32 81 117.8 86.281 N/A MAS=10.00(m) 0.11 0.11 MinPts 124.19 32.811 114.7 91.38 14.99 MAS=10.00(m) 587.58 580.16 MINPT-O-EOU 150.37 32.81 132.75 117.56 9.1 MAS=10.00(m) 905.80 891.50 MInPI-0-SF 615.58 75.84 584.64 539.70 12. OSF 1.50 2512.85 2097.20 MinPts • 1840.09 93.48 1778.04 1747.21 29. OSF 1.50 4397.89 2684.57 MInPt-0-SF 1880.12 95.92 1824.84 1793. 29. OSF 1.50 4414.24 2688.71 MMPI-0-SF 8449.53 169.80 6336.04 0279.73 5730 OSF 1.50 12264.48 3582.41 MMP1-0-903P 6748.70 251.19 6580.92 8497.51 40.45 OSF 1.50 13114.85 3591.20 TD 8698.92 172.99 6583.28 6525.• TEE OSF 1.50 10524.40 3510.35 M9nM-O.SF 8886.88 178.74 6567.40 0508.1-Ili OSF 1.50 11406.22 3573.60 M051-0SF 5313.59 148.65 5215.50 5166.9'llllllllf 1 OSF 1.50 5076.04 2774.47 MInPt-O-SF 5P23-N3(De(Survey) r Y + v >.fir �-%. ,i:k!P y +4�,,441,-"'. ..oy im 9,zt C 32 811 117.871 86.28 N/A MAS=1000(m) 0.11 0.11 MinPts 124.19 3281 114.74 91.38 14.99 MAS=10.00(m) 587.58 586.16 MMPT.O.EOII 150.37 32.81 132.75 117.58 9.1C' MAS=10.0D(m) 905.80 591.50 Minh-OSF 615.58 75.84 564.84 539.70 12.32 OSF 1.50 2512.65 2097.20 MinPts 1 1840.69 93.48 1778.04 1747.21 29.84 OSF 1.50 4397.89 2684.57 14051-0-SF 1889.12 05.02 1824.84 1793. OSF 1.50 4414.24 2686.74 MInPt-O-SF 8449.53 169.80 6338.001 6279.73 57.30 OSF 1.50 12264.48 3582.41 M1nPI-O-ADP MIME 220.44 66630.54 0557.69 46.32 OSF 1.50 13828.52 3589.99 MMM-CldI • 6779.10 225.•/MIME 6553.12 45.19 OSF 1.50 13877.85 3583.91 M1NPT-PEW 6770.87 220.56 6828. x.).., 45.06 OSF 1.50 13907.76 3583.18 MIrP1-0.803P 1- 4 258.04 6861.07 0575.06 39.87 OSF 1.50 15170.00 3550.88 MIOPI-C1CI 6834.57 269.- �-. •y 6575.14 39.66 OSF 1.50 15220.02 3550.86 MMPT-PE01.1 6835.28 200.25 6601.-MIME 39.54 OSF 1.50 15249.95 3550.84 MinPt-0-ADP 6841.86 266.08 6664.1•lull 1 38.71 OSF 1.50 15459.63 3550.74 MinP1-0-ADP 274.52 6656.61 6565.43 37.50 OSF 1.50 1576822 3553.79 68601-COCl 8840.66 276.811 6855.70 6503.84 37.20 OSF 1.50 15840.19 3558.08 MINPT-0-EOU 6841.37 277.68 6855.93 6503.701 37.08 OSF 1.50 15878.17 3558.90 MMP1-0•ADP 0850.84 212.221 6681.70 6564.62 35.31 OSF 1.50 15355.37 3563.13 MINPT-PE0tt 6859.14 294.94 6882.18 6561.201 35.00 OSF 1.50 16445.15 3561.97 MinMAADP 6865.70 438.37 6573.12 0427.33 23.54 OSF 1.50 16972.04 3581.22 TD 7568.74 201.45 7434.11 7367.29 56.83 OSF 1.50 10151.01 3471.95 MInPI-O-SF 6890.21 177.88 6780.29 6721.32 58.48 OSF 1.50 10454.45 350401 MInP1-0-SF 869892 17299 6583.20 0525.93 58.41 OSF1.50 10524.46 3510.35 14051-0-SF 6686.88 178.74 6587.40 6508.15 56.42 OSF 1.50 11406.22 3573.00 14051-0-SF 9185.68 121.14 9104.59 9064.541 114.60 OSF 1.50 1108.26 1125.42 MOPt-0SF 9348.15 125.16 9264.69 9223.00 112.91 OSF 1.50 2743.03 2231.82 100.056-0-SF 891564 200.99 8781.31 8714.85 66.86 OSF 1.50 621700 2925.71 MinPt-0-SF 0621-N1(P1)(Del Plan) Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/18/2013 7:35 AM Page 5 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Statue Ct-Ct(ft)I MAS(ft)i EOU(ft) Dev.((t) Fact. Rule MD(ft) 1 TVD(ft) Alert 1 Minor 1 Major 135.19 32.81 133.96 102.38 N/A MAS=10.00(m) 0.00 0.00 Surface E 32.81 133.1'C 173.89 MAO=10.00(m) 200.00 200.00 MinPts 135.25 32.81 C 102.44 143.69 MPS=10.00(m) 240.67 249.86 M61PT-6EW 135.47 32.81 133.30 102...NM= MAS=10.00(m) 299.32 229.91 Min%-O-SF 231.69 32.81 213.92 198...MEE MAS=10.00(m) 1303.41 1237.15 MinPt-O-SF 435.11 79.04 382.01 356.0 C OSF 1.50 2794.70 2259.18 Min%-OSF 1734.26 130.15 1647.16 1604.11�(X OSF 1.50 4741.65 2730.14 MInP4OSF 749.20 116.08 672.16 834.19.. OSF 1.50 8730.85 2993.83 MinPt-O-SF 594.20 84.72 550.7 529.•' 13.98 OSF 1.50 6802.49 3003.33 MinPt-O-ADP 591.55a61.57/ 650.1 529.99 14.62 OSF 1.50 60 807.88 3004.04 MINPT-0-50 4 58.39 551.08 531.92 15.40 OSF 1.50 6815.02 3004.99 MinPt-CICt 816.86 114.51 740.20 702.3 11.11DE OSF 1.50 6901.93 3016.51 M1n%-0-5F 4134.28 161.30 4028.38 3972.'.M OSF 1.50 10845.13 3520.25 09n61A-SF 4328.99 171.61 4214.25 4157. = OSF 1.50 11355.42 3570.05 Mm%A0F 4487.98 301.59 4286.57 4186.36 22.39 OSF 150 17340.79 3584.93 TD 5120-N4P61(Def Survey) rm.b .-,zmoitk' , .1 C 32.81 140.56 109.651 20763 MAS=10.00(m) 269.57 26057 MinPts 142.53 32.811 140 52 109.73 179.26 MAS=10 00(m) 299.35 299.34 MINPT-O-EOU 249.07 32.81 233.24 21626 1696 MAS=10.00(m) 1198.65 1151.13 MInFt-0-5F 2200.22 42.33 2171 64 2157.89 IIIIIKER OSF 1.50 2889.37 2307,40 MInPt-0-SF 9120-N4(Def Survey) ' =prd. �� u =I i11 32.81 140.56 109.651 20763 MAS 0 10.00(m) 269.57 249.57 MnPts - 142.53 32.811 140.52 109.73 179.28 MAS=10.00(m) 269.35 289.34 MINPT-0-E00 249.07 32.81 233.24 216.-ME-- MAS=10.00(m) 1198.65 1151.13 MiPt-OSF 8087.88 138.13 7995.4 Illllll 88.45 OSF 1.50 11823.57 3587.71 MiiPt-O-ADP 8087.27 137.. •• a 7948.86 88.91 OSF 1.50 11831.98 3587.63 MINPT-O-EOU 8097.99 162.-MEMEK 7935.54 75.22 OSF 1.50 1242206 3580.50 MINPT-0-E00 8098.75 163.47 7989. BUM 74.75 OSF 1.50 12442.01 3580.28 Min%-0-ADP 8231.72 217.86 8086.1-MELEE 5893 OSF 1.50 16920.31 3582.87 MIn141A4/DP WICK 251.63 8025.68 7942.13 49.03 OSF 1.50 15226.64 3550.86 MinP4C1CS 8194.25 253. 6026.23 7941.2'11 48.78 OSF 1.50 15278.69 3550.83 MINPT-6EW 8194.93 253.88 8025.35 7941.051 48.60 OSF 1.50 15306.54 3550.82 Min141-0-ADP 8244.41 284.061 8054.71 7980.35 43.68 OSF 1.50 16340.73 3583.32 MINPT-O-EOU 8244.94 284.68 8054.82 7960.261 43.59 OSF 1.50 18360.72 3583.08 Mln%A48DP 8278.98 340.12 8051.90 7938.85 36.61 OSF 1.50 16942.55 3500.87 TD 9369.65 213.20 9222.19 9151 OSF 1.50 1010494 3468.48 Min%-O-0F 8831.73 129.74 8744.90 8701...=Ina OSF 1.50 4739.96 2729.91 Min%-0SF 2620.30 42.31 2591.74 2577..•�' I OSF 1.50 2798.76 2261.31 Min%ASF WOE 88..MEM NOM 111151M OSF 1.50 3207.93 2443.89 MinPts 5119-FN2(P6)(Def Plan) ;--rte,:v,.,'n,.'r?.; 32.81 149 21 M 210 30 MAS=10.00(m) 190.45 190.45 MinPts �1' •' 32.81 139.091111111 'I 51.32 MAS=10.00(m) 587.83 588.40 MinPts 14325 32.81="7 110.44 48.81 MAS=10.00(m) 605.90 694.18 MINPT-O-EOU 189.00 32.81 181.08 156.1'11111111111XEx' MAS=10.00(m) 810.69 810.50 MIn%-O-SF 200.63 32.81 192.31 187.:.MEM MAS=10.00(m) 841.10 831 00 MirPI-O-SF IMZIMIJ 283.27 5796.14 5702.04 31.80 OSF 1.50 17302.47 3684.77 Min%-C1Ct 5985.55 284,EMU 5701.52 31.72 OSF 1.50 17332.30 3564.89 MINPTAEW 5988.00 284.54 5795.9 O.01E 31.66 OSF 1.50 17352.19 3564.98 Mir4840-ADP 0452.46 350.55 6218.43 6101.91 27.68 OSF 1.50 19909.64 3589.25 TD 4674.73 112.12. 4599.66 4562.:.MajlE OSF 1.50 4083.88 2642.04 MinPIaSF 5564.85 137.84 5472.63 5427.0. !) OSF 1.50 4741.31 2730.09 Mi461-0-SF 7874.35 213.22 7731.88 7661.1 55.8' OSF1.50 998295 3451.30 MIn141-0-SF 7446.00 168.58 732001 7257.• 59.53 OSF 1.50 10530.54 3510.88 MIn%A-ADP 7445.88 168.34 7319.94 7257.52 59.80 OSF1.50 10535.69 3511.32 MINPT-O-E05 WaffE 187.92 7320.11 725780 59.74 OSF 1.50 1054508 3612.21 MInPt-CICt 11889.71 48.51 11857.04 11841..=ME OSF 1.50 1002.21 979.73 Min%-0-0F 12063.11 81.35 12008.55 11981.7. 225.1 OSF 1.50 2720.22 2222.28 Min%A-SF MIME 51.081 18305.851 182758 305.: OSF 1.50 2883.99 2304.75 MAPS 5119-FN2 current(Nan-Def Sor)4Y) Pass 1 143 321 32.81 139.59 110.511 56 82 M55=10 00(m) 551.46 550.52 Min%s 143.40 32.811 169.507 110.59 53 26 MAS=10.00(m) 570.10 588.93 M1NPT-O-EOl1 156.45 32.81 151.33 123.541 1 MAS=10.00(m) 729.21 724.20 MinPt-O-SF 331.20 5798.24 5688.15 27.33 OSF 1.50 17707.59 3566.46 MIn%-CICS 6019.88 332.2 MEELE 5687.44 27.25 OSF 1.50 17737.47 3508.59 M1NPT-O-EOU 8020.21 332.88 5797.9 tj259 t'. 27.20 OSF 1.50 17757.40 3566.67 M1n141-0-PDP 6433.75 402.20 6165.29 6031.55 24.05 OSF 1.50 19908.64 3589.25 TD 5508.31 137.29 5418.46 5371..4 MEM OSF 1.50 4740.25 2729.95 MinPt-O-SF 8143.19 242.28 7981.34 7900.91 50.6. OSF 1.50 9820.45 3429.66 MinPt-0-SF 7403.17 18240 7281.21 7220. 61.20 OSF 1.50 10467.04 3505.18 MInP1-0-ADP 7402.65 181.801 7281.1 7220.85 61.40 OSF 1.50 10472.22 3505.66 M1NPT-0EOl1 179.43 7282.03 7222.55 0221 OSF 1.50 1049297 3507.55 Min%-ClCl 5117-5E2(P3)(Def Plan) Pass =EH 32.81 157.01 128.711 48.76 MAS=10.00(m) 592.15 590.66 MinPts 181.89 32.811 156.87 128.88 44.82 MAS=10.00(m) 609.55 607,76 MINPT-O-EOU 211.33 32.81 202.26 178.531 28.751 MAS=10.00(m) 803.78 795.67 MinPt-O-0F main 69.05 2195.55 2172.86 49.38 OSF 1.50 2712.43 2214.65 MIn%-CICt 2242.14 69.• WILDE 2172.49 48.96 OSF 1.50 2713.15 2215.05 MINPT-O-EOU 224230 69.84 2195.41 MUIFEE 48.82 OSF 1.50 2713.38 2215.18 MInP4O-PDP 2398.19 83.20 2342.39 2314..,IL OSF 1.50 2720.38 2224.02 Min%ASF 9743.38 85.66 9685.95 9657.72 172.59 OSF 1.50 2780.85 2251.85 1D SP18-495(Def Survey) '1 Pass 167.1 32.811 185.92 134.3 N/A MAS=10 00(m) 0.23 0.23 MinPts 166 5 32.81 163.83 133.7 110.53 MAS=10.00(m) 408.56 408.46 MinPts 166.63 32.81 163.70 133.82 90.59 MAS=10.00(m) 438.10 437.93 MINPT-0-600 296.55 32 81 282.01 263.7 22.1 MAS=10.00(m) 1198.08 1150.64 MinPI-0-SF 1024.04 42,75 995.18 981. 38.8 OSF 1.50 2290.60 1953.20 MinPt-0-SF 948757 155.74 9363.411 9311. 91.76 OSF 1.50 11779.81 3587.89 MinPt-O-ADP 9487.38 155.501 9383. 9311.88 91.90 OSF 1.50 11782.11 3587.89 M1NPT-O-EOII 155.01 9363.55 9312.21 92.19 OSF 1.50 11786.69 3587.89 MIn%-CICS 159.82 9355.97 0303.02 89.35 OSF 1.50 12126.93 3584.07 Min%-CICS 9463.50 161.•'MIME 9301.64 88.23 OSF1.50 1217692 3563.47 MINPT-O-EO5J 9404.50 163.09 9355.- 9301.41 87.57 OSF 1.50 12206.91 3563.10 1M%-0-ADP 9502.45 187.'.111111' 9314.56 76.25 OSF1.50 12541.81 3580.53 MINPT.0.EOl1 9503.41 189.07 9377.0 '=�1 75.78 OSF 1.50 12549.94 3580.68 Min141-0-ADP 10975.16 242.09 10813.44 10733.0 C OSF 1.50 1011667 3467.89 Min%-O-SF 10816.75 238.77 10657.24 10577.•. OSF 1.50 10152.30 3472.10 MinPt-O-SF 213.14 9411.87 9340.95 67.54 OSF 1.50 13220.88 3591.20 Min%-CICt 9554.30 213 701411.51 9340.60 67.37 OSF 1.50 13250.03 3591.20 M1NPT-O-E2S 9554.47 213.89 9411. 0340.54 6731 OSF 1.50 13260.62 3591.20 MinP1-0-ADP MMIK 225.77 9400.30 9331.37 63.77 OSF 1.50 13820.17 3585.32 MIn%-01C1 9557.46 226.• M=IM.. 9330.82 63.52 OSF 1.50 13680.16 3584.34 MINPT-O-ECU 955805 227.28 0406.. 9330. 83.35 OSF 1.50 13890.14 3533.61 MIn%-O-4DP 955847 227.71 9406.' 9330. 63.23 OSF 1.50 16910.13 3583.12 Min%-0-PDP Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\S135-W4\S135-W4(P5) 6/18/2013 7:35 AM Page 6 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Traleetory Risk Level Alert Status CI-Ctlft)I MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor Major 9521. 249.75 0354.80 9271.88 57.41 OSF 1.50 14820.94 3556.32 MinP1-0101 0521.86 250. 9354.53 9271.36 57.24 OSF 1.50 14850.70 3555.78 MINPT-O-EOl1 9522.08 250.74 9354.58 9271.331 57.18 OSF 1.50 14880.81 3555.57 MInPI-0.ADP 9551.14 271.24 9389.97 9279.88 53.00 OSF 1.50 15837.53 3550.74 MINPT-0.EOU 9551.83 27205 9370.131 9279. 52.85 OSF 1.50 15671.78 3551.20 M'inPt-O-ADP 9581.10 287.60 9389.03 9293. 50.14 OSF 1.50 16203.26 356494 Min1,4-0.ADP • 9593.10 209.03 9393.4 9294. 48.28 OSF 1.50 16579.40 3560.23 MInPt-O-ADP 9605.42 308.70 9399.29 9290.71 46.82 OSF 1.50 16006.07 3500.45 TD 3163.32 68.90 3117.00 3094. OSF 150 2007.71 1755.07 MInP50-SF 2888.53 633.15 2848.10 2825.3 110.11 OSF 1.50 2147.84 1854.47 MinP10SF MEM 46.881 1670811 1655.31 55.5• OSF 1.50 241754 2037.10 MInPts SP18-N5P81(Del Survey) Pass am' a 32 811 16592 134.331 N/A MAS=1000(m) 023 0.23 MinPts jl�." tri 32.81 163.83 133.74 110.53 MRS=10.00(m) 408.56 408.48 MinPts 166.63 32.811 103.70 133.82 96.59 MAS a10.00(m) 438.10 437.93 MINPT-0.560 296.55 32.81 282.01 263.74 22.1 MAS=10.00(m) 1198.08 1150.84 MinPI-O-SF 1024.04 42.75 99518 981. 35. OSF 1.50 2290.60 1953.20 MinPt-OSF 957772 100.00 0466. 9411.02 88.89 05F 1.50 1167604 3588.76 MinPt-0-ADP 9497.66 151.30 9396. 9346.30 94.77 OSF 1.50 11816.95 3587.76 MinPI-O-ADP 0407.17 150.74 9396. 934648 95,14 OSF 1.50 11822.94 3587.72 MINPT-0-E3IJ 9498.9. 149.78 9386.74 9347.14 05.73 OSF 1.50 11832.06 3587.63 MInPt-CtCt Eir.ZOE 150.80 9395.89 9345.95 95.07 OSF 1.50 11899.21 3588.83 MInPt-CICI 9497.23 152.:•MDULE 93.77 OSF 1.50 11059.16 3588.10 MinPts 185.35 9412.83 9351.38 77.58 OSF 1.50 1252506 3580.27 MinPt-CICI 0537.50 188.211 9349.30 78.41 OSF 1.50 12545.18 3580.59 MINPT-0-E0U 953846 189.34 9411.'.1' 75.95 OSF 1.50 12553.18 3580.75 MinPI-0-ADP 9543.14 203.62 9407.06 9339.52 70.84 OSF 1.50 12780.03 3588.05 TD 3163.32 68.99 3117.00 3094.r MTH OSF 1.50 2007.71 1755.07 MInP1-0-SF 2888.53 63.15 2848.10 2825.3 69.6 OSP 1.50 2147.64 1854.47 MinPt-O-SF ll( 46.88/ 1670 611 165631 565. OSF 160 241754 2037.10 MinPts SP16-FN3(Def Survey) Pass 32.81 170 65 141 611 68.09 MAS=10.00(m) 518.45 517.84 MinPts , 17448 32811 170.59 141.68 64.92 MAS=1000(m) 536.58 53580 MINPT-O-EOU 215.87 32.81 210333 183.07 49.841 456$=10.00(m) 766.93 780.52 MinPt-0.SF 1 8024.56 173.18 7908.74 7851.38 69.89 OSF 1.50 1146380 357754 MinPt-O-ADP 8022.42 170.871. 7008.311 7851.75 70.91 OSF 1.50 1148411 3578.88 MINPT-0.E31J 165.90 7909.89 7854.92 72.94 OSF 1.50 11524.88 3581.13 Min1:4-CIC1 9033.42 230.06 8879.12 8802.•l OSF 1.50 9982.73 344889 M8Pt-OSF 7167.47 130.42 7094.20 70/8. OSF 1.50 4708.50 2737.41 MinP1-05F 1899207 242.20 18830.22 18745.7.=11Mc OSF 1.50 8539.92 3233.65 M8Pt-O-SF 19170.30 245.43 19006.35 18824.:. I Z OSF 1.50 8898.33 325670 MinPl-0.SF • 321.93 7048.29 6541.31 39.04 OSF 1.50 17477.98 3565.50 MInPI-CICt 7283.66 323. .))) 8940.43 33.81 OSF 1.50 17517.74 3565.67 MINPT-0.EOU 7263.92 323.55 7047.,MIM 33.77 OSF 1.50 17527.60 3585.71 M1nPI-O-ADP 7851.71 400.18 7384.50 7251.53 28.75 OSF 1.50 19908.64 3580.25 TD WE= 81.3'MILigan Minh/y MELD-'' OSF 150 3022.01 2309.20 MinPts 5X15-N2(P1)(Def Pin) _.P:W-4C +. `st : - • Via. 191.11 3281 189 88 158.30 N/A MAS=1000(m) 0.00 0.00 Surface =EMI 32.81 189.11 158.301 246.46 MAO=1000(m) 200.00 200.00 MinPts19123 32.811 189. 158.42 189.47 MAO=10.00(m) 200.34 20933 . MINPT-0.EW 191.38 32.81 189.02 158. '�.'T-- MAS=10.00(m) 200.04 290.03 MinPt-O-SF 276.73 32.81 260.55 243.9.M MAS=10.00(m) 1303.37 1237.11 MinP1-0.5F 582.07 73.80 533.07 508.8111111111111!)2 OSF 1.50 2696.97 2206.02 MinPt-O-SF 1007.55 105.40 936.98 902.1' 14.• OSF 1.50 5558.87 2838.47 MInPt-0-SF 789.72 53.12 753.081 736.... 22.60 OSF 1.50 5059.94 2851.87 MinP1-0-ADP __..788.50. 51.64 753.741 736.85 23.31 OSF 1.50 5881.13 2852.03 MINPT-0-EW i� "W1 49.23 754.43 738.35 24.46 OSF 1.60 5683.50 285234 MinPt-CICI 1150.35 100.01 1063.35 1050. man OSF 1.50 5700.59 2858.45 MinP0.O-SF 5324.81 103.54 521546 5161.2 MINEXE OSF 1.50 10707.27 3524.83 MinPt-O'SF 5597.75 176.25 5479.93 5421.51 OSF 1.50 11401.04 3573.23 MinP50.SF 5885.54 220.64 5518.11 MZME. 38.68 OSF 1.50 14083.30 3579.35 MinP1-0-ADP 5683.85 302.25 5482.02 538160 28.30 OSF 1.50 17361.88 3584.97 TD MEM 100. EMU 4883 OSF 1.50 11786.32 3587.89 MinPts 5113-FN4(Def Survey) Pass 1 198 711 32.81 191.19 165.901 3138 MAO=1000(m) 547.51 54662 MlnPts 199.21 32.811 190.01 166.40 24.83 MAS=1900(m) 593.69 592.17 MINPT-0-000 202.71 32.81 192.72 169.90 22.991 MA5 a 10.00(m) 86244 650.52 MIn1:4-05F 8480.97 149.88 8360. 8311.00 85.23 OSF 1.50 11847.11 3586.03 MinPl-046DP 8458.59 147.04 8300.23 8311.54 88.86 OSF 1.50 11671.57 3580.64 MINPT-0.EW .' 144.57 8360.04 8313.08 88.34 OSF 1.50 11601.56 3587.09 MinPt-CICI 1 9777.18 223.48 9627.84 9553.'r C OSF 1.50 10033.76 3457.74 MinPt0SF 8530.58 174.31 8414.05 8356.2 MINIM OSF 1.50 11428.61 3575.16 MInPt0SF 1. ......4 221.14 8182.63 8100.25 58.75 OSF 1.50 14225.83 3573.68 MinPF00 • 8332.14 229.81 MEM 8102.33 54.61 OSF 1.50 14556.07 3502.07 MINPTOEOII Erna 285.02 8091.28 7906.60 43.73 OSF 1.50 18413.92 3562.37 MinPt-CICI 8282.55 287. M1=5 7994.78 43.32 OSF 1.50 16502.10 3561.23 MINPT-0.E00 • 8283.58 288.99 8090...MEMM 43.14 OSF 1.50 16541.22 3500.72 M'InP5O-ADP 8038.56 304.70 8675.04 8543.77 34.04 OSF 1.50 19900.64 3580.25 TD 9032.24 136.79 8940.69 8895.451 00.81 OSF 1.50 4740.89 2730.03 MInPtOSF 15887.32 168.40 1557464 15518.831 140.54 OSF 1.50 8174.58 2920.00 MInPtOSF 15973.13 171.55 15858.41 15801.59 140.53 OSF 1.50 6290.29 2035.43 MInPt-0.SF 16018.59 172.03 15903.54 15846.550. OSF 1.50 630821 2937.81 94i4650.SF 18609130 179.18 16680.79 16830.4 10.58 OSF 1.50 6571.35 297280 Mn46t-0SF 17688.90 187.81 17583.34 17501.09 142.08 OSF 1.50 6873.55 3012.75 MinPt-0.SF ® 80.24 13483.891 1343751 256.23 OSF 1.50 3377.30 2501.47 MinPts 5114-N6(P2)(Def Plan) Pass Ia 3281 C=OM 256.81 MAS=1000(m) 200.00 200.00 MinPts • 199.65 32.81 107.01 166.:.=23:2 MAS=1000(m) 290.02 299.01 MinPt-0.SF 314.98 32.81 300.12 282.17 MAS=10.00(m) 1198.04 1150.81 MinPt-0.SF 10772.93 157.90 10667.-.II '= 102.03 OSF 1.50 11729.73 3587.61 MInPt-O-ADP 10771.57 156.. 10687.. 1061528 104.02 OSF 1.50 11743.47 3587.74 9414001-0.50 .�X I) 153.00 10668.16 1001749 106.27 OSF 1.50 11770.96 3587.88 MInP5C1CI KIM 18727 10618.19 10556.09 88.50 OSF 1.50 12540.29 3580.50 MinPt-C1C1 10781.53 324.83 10584.85 10456.70 49.93 OSF 150 17000.97 3561.56 TD 5149.82 59.14 5110.07 5000.60 13281 OSF 1.50 1250.37 1199.10 MinP1-0-SF 1 5124.45 58.85 5084.49 5065. 132.81 OSF 1.50 1253.60 1198.82 MInPt-0-SF 6079.83 38.98 3953.28 3040.65 157.41 OSF 1.50 1506.92 1392.24 MInP4-0-SF MUM 34.54 1888.281 1877.11 76. OSF 1.50 2348.71 1090.77 MinPts SP12-5E3(P2)(Del Plan) Pass ® 32.81 217.96 189.441 7200 MAS 0 10.00(m) 572.43 571.23 MlnPts 222.41 32.811 217.86 18961 68.37 MAO=10.00(m) 589.87 58841 MINPT-0-EOU 298.23 32.81 287.88 265.421- MAS=10.00(m) 840.48 838.87 MInPt-O-SF 00.74 2928.55 290668 74.58 OSF 1.50 2234.29 1914.76 4071.01C1 2987.68 01.04= '290604 7317 OSF 1.50 2238.54 1917.08 l.0N71-0-EOU Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S)35-W4\SI35-W4\S135-W4(P5) 6/18/2013 7:35 AM Page 7 of 10 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory- Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(1,11.. Fact. Rule MD(ft) 1 TVD(85) Alert I Minor I Major 2968.23 62.30 2926.33 2905.92 72.68 OSF 1.50 2241.66 191083 MInPt-O-ADP 3283.97 91.00 322298 3192.08 54.711 OSF 1.50 2400.28 2025.03 MInP/-0-SF 1009745 100.59 10030.06 909686 152.04 OSF 1.50 2648.10 2177.07 TD SI11-FN6(55)(Del Plan) Pass 1 238.264 32 81 238.2 205.451 307.86 MAS=10.00(m) 200.00 200.00 MinPts 238.38 32.81 238.1 205.57 236.53 MAS=10.00(m) 269.18 260.17 MINPT-O-EOU 238.96 32.81 238.1 206.15 151.13 MAS=10.00(m) 435.97 435,81 MINPT-0-EOU 298.30 32.81 290.41 265.49 Imo" MAS=10.00(m) 872.92 88,8 MinPI-O-OF 550.42 32.81 540.50 517.6.E MAS=10.00(m) 1119.02 1083.13 MInPt-0.SF 11329.04 383.07 11088.26 10905.37 40.85 OSF 1.50 19909.04 3589.25 TD 11043.72 184.04 10920.10 10858.79. 90.05 OSF 1.50 10329.96 3401.73 MinPI-0.5F 18924.51 128.47 18838.54 18796.04 222.65 OSF 1.50 480017 2737.90 M448-O-SF 12083.91 3281 12004.59 12051.19.10 MAS=10.00(m) 799.83 791.92 M66't-O-SF MEM 32.81/ 1775.711 1766.66 142.57 MAO=10.00(m) 1304.88 1308.78 MinPts SP10-FNS(Def Survey) „ r :. Pass =111E1 32.81 245.04 213.531 3297.45 MAS=10.00(m) 66.18 66.18 MinPts 246.51 32.811 244.93 213.70 677.16 MAS=10.00(m) 140.18 140.18 MINPT-O-EOU MOM 32.81 248.05 218.4404 127.03 MAS=10.00(m) 509.11 508.57 MinPts 251.32 32.811 247.02 218.51 115.38 MAS=10.00(m) 527.28 620.67 MINPT-O-EOU 314.00 32.81 307.72 281.19 61.834 MAS=10.00(m) 848.40 837.88 MInP1-0-0F 9027.83 133.67 8038 8894.16 102.04 OSF 1.50 11769.51 3587.87 MinP1-0-ADP 9021.35 127.03 8935. 883.72, 106.84 OSF 1.50 11827.80 3587.67 MinPt-O-ADP 9020.82 120.764 8935. 883.84 107.55 0551.50 11838.75 3687.58 MINPT-O-EOU Z 145.51 8022.15 8873.98 93.00 OSF 1.50 12278.33 3582.24 MinSt-C1Ct WME 155.99 8915.27 8863.80 8727 OSF 1.50 12457.24 3580.10 MInPFCICt 9020.76 150.118914.35 8861.84 85.58 055 1.50 12478.41 3580.00 MINPT-0.E0U 9022.11 100.78 8914.80 8881.331 84.68 OSF 1.50 1248.03 3580.01 MinP1-0-ADP 9052.05 188.821 8027.31 8865.43 73.13 OSF 1.50 12827.02 3587.50 MINPT-O-EOU 905287 187.77 8027.30 8885.101 72.89 OSF 1.50 12847.54 3587.08 MinPt-O-ADP 10094.47 388.19 9835.35 070628 39.10 OSF1.60 19909.84 3589.25 TD 10698.24 212.81 10556.04 10485.43 75.76 OSF 1.50 10107.42 3488.78 MinPI-O-SF 10033.26 92.23 9971.44 9941.03 OSF 1.50 815.32 2020.00 MInP1-0-5F 15188.18 138.44 15005.53 15049.72`85.73 OSF 1.50 4801.50 273807 66n51-0-SF 18814.24 32.81 18793.08 18781.44 932.11 MAS=10.00(m) 872.84 689.48 MinPI-0-5F 18556.35 32.81 18535.48 18523.54, 831.97 MAS=10.00(m) 67587 072.60 MinPt-O-SF 1778732 32.81 17767.13 17754.51 928.24 MAO=10.00(m) 888.50 684.88 MinPI-0-SF MIME 88.804 11718.551 118834 20102 OSF 1.60 3815.14 2000.03 MWIs 500-N3(P1)(Del Plan) 254.28 32.81 253.05 221.47 N/A MAO=10.00(m) 0.00 0.00 Surface MMEO 32.81 25228 221.471 328.44 MAS=10.00(m) 20.00 200.00 MOO'S 254.34 32.811 252.18 221.53 271.40 MAS=10.00(m) 249.38 249.37 MINPT-0-EOU 254.58 32.81 262.40 221. =MIE MAS=10.00(m) 298.74 298.73 WPM-O-SF 402.14 32.81 383.79 369. 'MEM MAS=10.00(m) 1300.22 1234.58 MInPI-O-SF 766.33 87.05 721.23 899..:M11115M 055 1.50 2321.57 1974.03 MinP1-0-SF 856.67 77.54 8044.52 779.1 I OSF 1.50 2789.92 2256.66 MinP1-0-5F 107521 83.8 1019.09 991. - EIDE OSF 1.50 4528.27 2701.85 WPM-0-5F 928.07 45.76 897..n=--n 31.00 OSF 1.50 4812.08 2730.55 MinPt-O-ADP 925.82 42.::111M=M 882.78 33.12 OSF 1.50 4821.99 2740.79 MINPT-0.EOU 924. 39.28 897.82 885.05 38.16 OSF1.50 4833.76 274235 MInPPCtCt 1335.70 8.03 1276.02 1248.8 MEM OSF 1.50 4928.30 2754.88 Mei%-0-0F 6344.18 208.09 62208.46 8138,:MEM OSF 1.50 12908.38 358.43 MinPI-0SF I 6687.79 217.117 0542.8 8470.0'MEM 0551.50 13812.53 3585.50 MInPI-0-0F 6881.00 290.25 681.17 8581.75 34.80 OSF 1.50 17357.51 3665.00 TD 6070.76 165.8 5980.01 5905.1 113E OSF 1.50 10672.84 3522.34 MInPt-0-0F 6335.24 178.11 13216.17 6157.1 MEE OSF 1.50 1130027 3673.11 MinPt-0SF SP8-N7(P5)update(Del Plan) ''''''..g ,' ae8 Y 262 27 32 81 261.04 225 46 N/A MAS=10.00(m) 0.00 0.00 Sol 1 262.271 32.81 MMEE IMMO 338 81 MAS=10.00(m( 200.00 20.00 MinPts 263.15 32.81 281.07 230. M1EZIE MAS=10.00(m) 298.71 298.70 MnPI-0SF 43922 32.81 423.33 40.411111111 MAS=10.00(m) 1198.44 1150.95 M1n191-0SF 757.11 33.06 734.8 724.'' i:11] OSF 1.60 1760.24 1577.24 Mm%-0.SF 1105940 18.99 11848.41 i®" 108.77 OSF 1.50 11733.07 387.05 MInPt-0-ADP 11957.80 18.8 EI 11790.77 18.14 OSF 1.50 11748.63 387.78 MINPT-0-EOU MIME103.04 11847.35 11793.34 110.8 OSF 1.50 11776.30 387.8 MInPI-CtCt IIIIIMEE 195.77 1180.78 11735.8 01.87 OSF 1.50 125148 3580.36 MInPt-CICI 11977.84 332.24 1178.02 11845.80 54.23 OSF 1.50 1887.35 3561.40 TD 6172.71 91.8 0111.06 0080.7-MEEK OSF 1.50 1066.51 1063.52 MInPt-0-5F 8098.5190.77 6037.87 6007.7 MIME 0551.50 1103.63 189.74 MinP1-0-0F 42. mama mirimE iEIE OSF 1.50 2315.54 198999 MAPls 5107-SE4(P2)(Def Plan) _ P - 1 268.524 32.81 265 23 235.711 120 65 MAS=10.0(m) 481 00 480.85 MinPts 268.58 32.814 265.17 235.77 122.05 MAS=10.00(m) 499.30 408.83 MINPT-0-EOII 38.76 32.81 352.02 32564.8 MAS=10.00(m) 840.31 830.28 MInPt-O-SF 3776.23 8.41 3738.04 3717.8 98.75 0551.50 1043.60 1492.43 MinPt.0.PDP 4401.82 107.07 4329.51 4293.8 61.701 OSF 1.50 2202.23 1892.58 MinP1-0-5F 10568.08 127.23 10482.92 10440.84 125.56 OSF 1.50 2526.81 2105.8 TD SX06-N4(P1)(Del Plan) a. 94,5 -:i , Pass 286.30 32.81 285 07 253.49 N/A MAS=10.0(m) 0.0 00 Surface 1 28.301 32.81 284 301 253 44 38.90 MAS=10.00(m) 200.00 200.00 MinPts 28.42 32.811 284 191 253.61 284.43 MAS=10.00(m) 28.01 28.01 MINPT-0-EOU 28.54 32.81 284.21 253.73 258.00 MAS=10.00(m) 298.8 298.57 Mir1Pt-0-SF 267.94 32.81 285.61 255.13 MAS a 10.00(m) 397.07 396.08 MnP1-0-SF 521.74 32.81 503.14 48.93' 29.90 MAO=10.00(m) 1302.80 1236.8 MinF1-0-SF 1015.8 84.33 972.20 051.1 OSF 1.50 2236.77 1910.47 MiMI-0-SF 1094.24 72.13 1045.80 1022.12 OSF 1.50 2796.41 2259 55 MinPt-0SF 108.75 64.84 1043.1 1021.91 25.64 0551.50 3141.20 2418,64 MinPt-0-ADP 108.28 84.30 1043. 1021.8 25.71 0551.50 3151.28 2422.54 M1nPt-O-ADP 1084.50 62.01 1042.81 1022.49 28.67 OSF 1.60 3195.8 2439.21 MINPT-0-000 5592 1045.49 1027.18 29.55 OSF 1.50 3303.15 2470.82 MinPt-C1C1 1690.10 8.55 1647.40 1826..MEM OSF 1.8 388.59 285.82 MinPt-0-SF 4926.20 85.32 486899 48408 1 OSF 1.50 269620 2205.59 MinPl-0-5F 7417.80 170.19 7304.02 7247.81 MIK OSF 1.50 10880.20 3522.88 MinPt-0-SF 771284 182.90 7590.8 7529. Imo-= OSF1.50 1148.79 573.57 MinPI-0-SF 7686.71 208.78 754721 7477.: EI.; OSF 1.8 13092.51 3591.20 MinPt-O-SF 7696.87 208.04 787.18 7487.: OSF 1.50 13120.70 501.20 MinPI-0-SF 7890.85 214.70 7747.8 7876.1 MEM OSF 1.8 138764 590.87 MInPI-0-5F 8073.54 30.8 7872.70 7772.86 40.40 OSF 1.50 17370.73 3565.05 TD 89197 131.76 8303.81 8260. 96.2 0551.50 4738.96 2729.78 440151-0-5F - 8.181 6479.261 64498 1112 OSF1.50 3483.12 2533.8 MinPts SP05-FN7P01)Def Survey) ,h;.'-^'. '`.»E .. ,.,,( 's. ( - -pip 11111 0 32 81 2 .73 260.511 214 70 MAS 0347.88 10 (m) 347.86 MinPts 293.51 32 811 290 56 20.70 169 79 MAS=10.0(m) 415.48 415.37 MINPT-O-EOU Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\5135-W4(P5) 6/18/2013 7:35 AM Page 8 of 10 1 I Offset Trajectory Separation Allow Sap. Controlling Reference Trajectory Risk Level AIM Status ' Ct•Ct(ft)1 MAO(R)1 SOU(ft) Dov.(ft) Fact. Rule MD(1t) I TVD(R) Alert I Minor I Major 349.58 32.81 343 06 316.77 65.71 MAS=10.00(m) 789.21 762 71 MInPI-O-SF 363.28 32.81 358.55 330.47 65.83 MAS=10.00(m) 795.88 788.17 MinP4-0-5F 370.78 32.81 363.95 337.98 6582 MAS=10.00(m) 808.78 800.43 MInPI-0-SF 12463.38 306.52 12218.89 12096.84 51.14 OSF 1.50 19909.84 3589.25 TD 12084.44 178.40 11965.18 11900.. IIIIIII OSF 1.50 10343.40 3493.12 MifP10SF 11993.24 177.19 11874.79 11818..:MEM OSF 1.50 10357.42 3494.55 MinP10SF 11889.03 174.74 11722.21 11064.•IIIIIII I 05F 1.50 10381.70 3496.99 WIN-0-5F 11677.30 172.47 11561.99 11504.8 jjjjlll E OSF 1.50 10408.11 3499.59 MInP10SF 14985.58 32.81 14966.42 14952.7 IMMIM MAS=10.00(m) 712.52 708.16 MInPI-0-0F 1472586 32.81 1470.89 148928 mom MAS.1000(m) 718.69 714.13 MInPI0SF 14433.90 32.81 14415.54 14401.,MEM MAS=10.00(m) 724.58 719.81 MMPI-0-5F 14035.79 32.81 14017.80 14002.•;MOE MAS=10.00(m) 733.57 728.49 MMPI05F 13789.15 32.81 13751.44 13738. =.' .. MAS=10.00(m) 738.47 733.21 MMPIOSF 13123.45 32.81 13106.45 13090.: =Ma MAS=10.00(m) 753.48 747.84 MinPtOSF 12744.42 32.81 12727.86 12711.61 WIDE MAS=10.00(m) 763.79 757.52 MinPt-O-SF 12349.83 32.81 12333.55 12316.8.=3EC3 MAS=10.00(m) 775.88 789.07 MinPt-OSF 12086 12 32 81 12070.30 12053.31 WEE MAS=10.00(m) 784.59 777.41 MInFt-0-SF ' 11983.44 32.81 11967.78 11950.6 .110712 MAS=10.00(m) 787.71 730.39 MInPt-0-0F MEMIE 32.81®IIIIIf1i )man MAS=10.00(m) 1212.68 1162.88 MinPts SP05-FN7(Del Survey) Pass 32.81 290.73 260.511 214.70 MAO=1000(m) 34788 34785 MinPts 293.51 32 811 290.50 280.70 159.79 MAS=1000(m) 415.48 415.37 MINPT-0-EOU 349.58 32.81 343.06 316.77 IIIIIIIIMIEn MAS=10.0(m) 709.21 702.71 MInP1-0-SF 36328 32.81 356.55 330.4 IIIIIIIIE -. MAS=10.00(m) 705.88 788.17 MinP1-0-SF 370.78 32.81 383.95 337. MTEE MAS=10.00(m) 808.78 800.43 MInP1-0-SF 12483.36 366.52 2218.09 12098.84 51.14 OSF 1.50 19900.64 3589.25 TD 12084.44 178.40 1985.18 11906.. =192 OSF 1.50 10343.40 3493.12 16I90185F 11993.24 177.19 1874.79 11816..:MEE OSF 1.50 10357.42 3494.55 16I905-0-SF 11889.0 174.74 1722.21 11684.•ir.E0 OSF 1,50 10381.70 349899 MInP1-0-SF 11577.30 172.47 1581.99 11504.8 IIIIIIIEI E OSF 1.50 10408.11 3499.59 MMPI-0-SF 18858.83 36.34 8834.28 18822.5.x.. OSF 1.50 646.17 64384 MInP10SF 18572.07 35.87 8548.78 18537..jjjjjjj OSF 1.50 060.41 647.79 MInP505F 17714.08 34.01 7091.08 17030...x. y OSF 1.50 885.51 662.52 MinP145F 17004.85 32.81 8982.78 10972.. WIME MAS=10.00(m) 077.65 074.34 MIn61.0SF 16209.43 32.81 8188.03 16176.8.MBE MAO=10.00(m) 688.93 885.30 16i90105F 15859.54 32.81 5839 24 15826. 'Illlllj. MAS=10.00(m) 305.38 691.56 MInP14SF 15585.15 32.81 5565.21 15552.3 =MI MAS=10.00(m) 700.44 896.48 MInP10SF 15334.82 32.81 5315.19 15302.0.NOM MAS=10.00(m) 705.18 701.06 MInP14SF 14985.58 32.81 4906.42 14952.7 MIME MAS=10.00(m) 712.52 708.16 MInPI-0-SF 14725.86 32.81 4706.89 14092.8 =--)' MAS=10.00(m) 718.69 714.13 MInP10SF 14433.90 92.81 4415.54 14401...mail MAS=10.00(m) 724.58 719.81 MinPt-O-SF 14035.79 3281 4017.80 14002.•:Ill mu MAS=10.00(m) 733.57 728.49 609010SF 13789.15 3281 3751.44 13736. WEIE MAS=10.00(m) 738.47 733.21 161P105F 13123.45 3281 3106.48 13090.. NEM MAO=10.00(m) 753.48 747.84 MMPI-0-SF 12744.42 32.81 2727.88 12711.81=ME MAS=10.00(m) 703.79 757.52 MInPI-O-SF 12349.63 32.81 2333.55 12316.8.Illlllj.FAM MAS=10.00(m) 775.85 709.07 MN-0-5F 12080.12 32.81 2070.30 12053.31 111111= MAS=10.00(m) 784.59 777.41 MinPI-O-SF 11963.44 3281 1967.78 11950.6 MEM MAS=10.00(m) 78771 780.39 MinP10SF MEM 32.81®MIMI III aa-1 MAS=10.00(m) 1212.68 1182.88 WIN. SP0-SE5(P2)(Def Plan) ..„.e.. Pass =OE 32 81 300 23 269 421 390.67 MAS=10.00(m) 200 00 20 00 MmPts 302.35 32.811 30.12 289.54 30 35 MAS=10.0(m) 268.96 268.96 MINPT-O-EOU 418.10 3281 410.77 385.29 EWE MAS=10.0(m) 903.0 889.45 WIN-0-SF 8240.77 128.39 6156.19 8114.• ri., OSF 1.50 2146.0 1853.17 16I171-0-5F 11113.31 148.87 11013.74 10964.44 112 71 OSF 150 2409.98 2032.22 TD 5903-N5(P1)(DM Plan) ,,,g,-,:-Ai-z-,..;Nt>'t•h3E ;{rM- Pass 310.29 3281 309.07 27748 N/A MAS=10.0(m) 0.0 000 Surface I 1 310.291 32.81 308.30 M 401.14 MAS=10.00(m) 20.0 200.00 MinPts 310.35 32.81 C 277.54 331.47 MAS=10.0(m) 249.24 249.24 MINPT-O-EOU 310.06 32.81 308.46 277.8 MBE MAS=10.0(m) 298.47 298.40 MMPI-O-SF 579.28 32.81 580.42 546. MEE@ MAS=10.0(m) 1298.11 1232.89 MI1710SF 937.02 48.89 904.02 888.1 MEM OSF 1.50 1811.97 1614.68 MInP105F 990.17 52.23 954.94 937.• In..•.^-- OSF 1.0 1890.78 1671.41 MMPIOSF 1041.02 54.77 1004-10 988.'IIIIIIII E OSF 1.50 1970.30 1728.38 MMPI-OSF 1132.85 59.88 1092.66 1073.18(IIIIIIIII OSF 1.50 2130.00 184218 169171-0-5F 1040.99 203.31 1055.11 102876 jjjjjjjjj ii j OSF 1.0 10158.12 3472.78 MinPt-O-SF 10171.67 197.45 1039.72 9974.2 mram OSF 1.0 10257.46 3484.01 MinPt-O-SF 9416.16 183.33 9293.81 9232.: =ME OSF 1.50 10401 10 3507.38 MInPI-O-SF 0387.97 182.79 9265.78 920.1:1111111WEE OSF 1.50 10499.17 3508.11 MMPI-0-SF 9114.55 177.88 8995.77 8930.8 Illll .aril OSF 1.30 1058320 3515.33 60M90105F 9090.03 184.48 8972.73 8911.5 minE, OSF 1.50 11401:02 3573.23 95491-0SF 8955.78 207.48 8817.13 8748..MMEE OSF 1.0 13064.53 3591.20 16117-0SF 9270.89 302.29 9069.04 896881 46.15 OAF 1.0 17377.57 3585.08 TD MUM 40.571 2158.231 2143.031 72.011 OSF 1.50 2738.0 2228.74 MinPts SI02-5E6(P2)(Def Plan) 9/7 `e,` .s„`90/ €: MEM 32.81 316.22 285.401 411.41 995=10 0(m) 20.0 200 00 MinPts 318.26 32.811 316.17 285.45 366.13 MAS=10.0(m) 229.53 229.53 MINP70E01J 487.02 32.81 459.89 434. •MIK MAS=10.0(m) 859.28 848.08 MMPI-0-SF 477.95 32.81 47087 445.1 IIIIIIIII MAS=10.0(m) 870.49 858.0 MMPI-O-SF 7637.04 161,47 7529.07 7475.5 man OSF 1.50 1888.19 1853.73 MInPI-O-SF 11749.44 194.60 11619.38 11554.84 91.02 OSF 1.50 2308.57 196396 TD SP01-0E7(P2)(Def Plan) :".77-)., ,,),'t Pass C 3281 324.33 293 511 421.93 MAS;10.0(m) 200.0 20.0 MinPts 32644 32.811 324.21 293.63 324.38 MAS=10.0(m) 268.88 288.87 MINPT-O-E00 492.0 32.81 485.15 400.• MAS=10.0(m) 912.81 897.99 M990108F 9245.85 187.38 9120.00 9058.4 ISMTM OSF 1.50 1892.58 1528.12 M601-OSF 9277.98 188.03 9152.28 909.•.IIIIIIIIFZI OSF 1.60 1702.33 1535.21 MInPl-0-SF 11853.87 221.33 1170599 11532.54 80.09 OSF 1.0 2192.53 1885.82 TD Kigun 1(Def Survey) MMILE 32 81 4024872 0 021 8456.42 MAS=10. (m) 159.07 199 07 MinPts I 4904.86 32 811 402.2 4872.07 6876 71 MAS=10.0(m) 199.07 199.07 MINPTOEOU 490483 3281 402.18 4872. 66373 MAS=10.0(m) 299.44 289.43 MMP1-0-SF ( 1457 631 131 971 1369 081 1325.66 16 7 OAF 1.0 7223.32 3059.12 MinPls 6096.63 53.87 8080.13 6042.76 175.45 057 1.50 8027.11 3165.67 TD Klgun 1 PB1(Der Survey) Paas 1^°'1 32.81 4902 3 4872 021 0 8456.42 MAS=10. (m) 169.07 169.07 Mel% 4904.88 32.811 402.255J 487207 6876.71 MAS 100(m) 19907 19907 M1NPT-0-500 4904.83 32.81 402.18 4872.03 6637.39 MAS=10.00(m) 290.44 299.43 MinP1-0-5F -' 128 931 1446.40 1404.01 180 OSF1.50 7174.23 3052.61 MMPIs Tuva s ST 1(Def Survey) Pass -.-- 32.81 402.31 4872 021 8456.42 MAS=10.0(m) 169.07 169.07 MinPts 4904.88 32 811 4902 2 4872 07 0876.71 MAS=10 0(m) 199 07 199.07 MINPT-0-EOU Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\5135-W4(P5) 6/18/2013 7:35 AM Page 9 of 10 1 Offset Trajectory Separation Allow Sep. Controlling Reference TralectorY Risk Leval Alert Status Ct-Ct(f)I MAS(ft)I EOU(R) Dev.00 Fact., Rule MD(ft) f ND(R) Alert I Minor I Major 4901.83 32.81 4002.18 487Z03 0637.39 MAS=10.00 On) 289.44 299.43 M1nPt-0-SF .IMMIMI 117.74 1571.33 1532.67 21.32 OSF 1.50 7140.43 3048.13 Mi1191-C1C1 1650.08 118 M•' 1532.17 21.19 OSF 1.50 7149.53 3049.20 MINPT-0-EOU 1650.93 118.85 1571.11 I' 21.13 OSF 1.50 7152.82 3049.74 MinPt-O.ADP 1718.80 130.22 1631.50 1588.••x.0 OSF 1.50 7314.56 3071.21 5865-0-SF 3281.05 160.87 3173.35 3120.: OSF 1.50 9754.77 3420.51 MinPt-O-SF 3058.78 127.02 2973. -I 34.81 OSF 1.50 10449.23 3503.52 MinPl-0.ADP 3057.34 125. 1111EME 2032.08 37.11 OSF 1.50 10477.41 3508.14 MINPT-0-E05J •E. t 118.25 2278.15 2037.32 39.32 OSF 1.50 10588.08 3515.80 MinPI-CtCt 2441.68 178.47 2323.40 2205.11�"' 03F 1.50 14579.22 3561.25 MinPt-O-SF 2425.83 177.70 2306.83 2248.1 20.8. OSF 1.50 15081.29 3551.42 MinPt-0-SF MIEDE 177.271 2304.501 2245.9. 20.68 OSF 1.50 15229.28 3560.85 MInPts 2423.38 177.90 230463 2246.0 20 681 OSF1.50 15252.15 3550.84 MinPt-0.SF 3377.95 128.57 3291.70 3249.38 3989 OSF 1.50 1990964 3589.25 TD Nikeilchuq 3PB3(Def Survey) Pass O9 32.81 8065.15 6034.201 322462.27 MAS=10.00(m) 52.00 52.90 MinPts 8067.38 32 811 8064.53 8034.55 8754.41 MAS=1000(m) 217.25 217.25 MINPT-0.500 8067.83 32.81 8064.65 8035.. WILK MAS=10.00(m) 287.10 287.00 MinPtA-SF 8349.07 32.81 8332.80 8316.•i` MPS=10.00(w) 1373.58 1292.38 5,001-0-SF 9126.79 41.21 9098.67 9085.:=T. OSF 1.50 2198.29 1889.84 MinPI-09F 9171.91 41.43 9143.65 9130.48 MIME OSF 1.50 2200.38 1807.55 MinPI-0-SF 11728.58 48.50 11695.61 11680.08 37750 OSF 1.50 2460.23 2034.39 TD Nlkeechuq 3PB1(Def Survey) 7+4a 1# .-, 4 A- ei,%-h""'.Z'.1 .em16�'l„ "?.,k1=5-44.4 it 32.81 8065.15 8034.29j 322482.27 MAS=10.00(m) 5290 52.90 Mirets 8087.36 32.811 8064.53 8034.55 8754.41 MAS=10.00(m) 217.25 217.25 MINPT-0-E0U 8087.83 32 81 8084.65 8035.03 •:•" MAS=10.00(m) 287.10 287.09 MInPt-O-SF 8340.07 32.81 8332.69 8316.•111.43TE MAS=10.00(m) 1373.56 1292.38 MInP1-0.9F 9120.79 41.21 9098.67 9085..M•• OSF 1.50 2198.20 1889.84 MInPI-0-SF 9171.91 41.43 9143.65 9130.48=MOO OSF 1.50 2209.98 1897.55 MInPI-0-SF 1001908 46.30 10887.55 10872.7•Man OSF 1.50 2465.54 2007.74 MinPt41SF 11550.30 49 28 11516.81 115010•=Ella OSF 1.50 2401.05 2083.77 MInP1.0-SF 81506185793(Def Survey) .'1 )0 Pass WrEgE 32 81 8065.15 8034.291 322482.27 MAS=10.00(m) 52 90 52.90 MinPts 8067.36 32.811 8064.53 8034.55 8754.42 MAS=10.00(m) 217.25 217.25 MINPT-0.E011 80177.83 32.81 8064.65 8035..6T.• ' MAS=10.00(m) 287.10 287.09 MinPt-O-SF 8349.07 32.81 8332.00 8316.•h2 MAS=10.00(w) 1373.58 1292.38 MinPt-0-SF 9128.79 41.21 9098.67 0085.:IIIA' OSF 1.50 2108.29 1880.84 MinPt-O-SF 9171.91 11.43 9143.65 9130.4813E OSF 1.50 2200.38 1897.55 MinP1-09F 11687.38 48.38 11654.49 11039.00 377.28 OSF 1.50 2459.12 2003,08 TD 12024.74 49.53 11991.08 11975.21 378. OSF 1.50 2453.48 2000.11 MinPt-0-SF 1. • 60.211 13739.901 13720.4 354.54 OSF 1.50 2442.31 2052.99 MlnPla Nikeitchuq 3PB2(Def Survey) .. . rink kv ..K ., . F ??'eC' i•a'*�9",b",. `4'l"xz+x,.9 ",... 1 09 32 81 8065.15 8034 291 322462.27 MAO=10.00(m) �• 52.90 52.90 MlnPls 8067.36 32.811 8064.53 8034.55 8754.41 MAS=10.00(m) 217.25 217.25 MINPT-0•EOU 8067.83 32.81 8064.65 8035.. WIDE MAS=10.00(m) 287.10 287.09 MinPt-O-SF 8349.07 32.81 8332.69 8316.• MAS=10.00(m) 1373.56 1292.38 MInPI-O-SF 9128.79 41.21 9098.67 0085..I- OSF 1.50 2198.29 1889.84 M1nP1-09F 9171.91 41.43 9143.65 9130.181 E OSF 1.50 2200.38 1897.55 Mi1P1-0-SF 11008.86 47.19 10974.76 10050.6 MirrE OSF 1.50 2400.06 2070.35 MinPt-0-SF 11301.28 48.17 11268.51 11253.09 388.44 OSF 1.50 2472.82 2072.34 TO MEM 48.201 11277.361 11281.931 386.50( OSF 1.50 2472.82 2072.34 MInPIs Nikeilchuq 4(Def Survey) .v" .;-S.w'",Fu, PX'.. ,rf,s, .6 . s.'^y.,a`ti&. '6lr r't;dr' N,'t . `i'a, ( MESEIE 32.81 8313.1•M 332583.56 MAS=1000(m) 52.90 52.00 MInPIs 8315.05 32.81�•T1'-, 8282.25 141080.93 MAS=10.00(m) 82.84 82.84 51580-6E00 8323.61 92.81 8320.60 8290..MESEEED MAS=10.00(m) 288.86 288.85 MinPI-OSF 8329.52 32.81 8326.05 8298.7.MEE iiIj MAS=1000(m) 420.34 420.21 MinP1A-SF 8616.94 32.81 8602.58 8586.1' 596.6. MAS=10.00(m) 1333.43 1281.02 MI1P1-0.9F 8830.17 32.81 8613.78 8597.•�'• r•, MAS=10.00(m) 1347.00 1272.17 MinPtASF 8648.55 32.81 8830.14 8813.7 MAS=10.00(m) 1308.87 1288.76 MInPt-0-SF 8523.54 32.81 8502.99 8490.83 455.04 MAS=10.00(m) 1518.63 1303.50 TD 8082.48 7104 8034.•mmia 175.34 OSF 1.50 1255.91 1198.175 MinP1-0-ADP 808232 70.85 n 8011.47 175.83 OSF1.50 1256.88 1190.43 MINPT-0-EOU .= 6736 8035.94 8014.12 185.20 OSF 1.50 1274.08 121348 McrPI-CICt Nikatchuq 1(Def Survey) ma y':#„:,A.,. . �ss'ixi s,. = k ,ti1/40a ;a; s 8199.17 32.81 8166 3 9667 - MAO=10.00(m) 308 34 308.32 MlnPls 32.81 8198.4. 8168.36 0885.04 MAS=10.00(m) 318.08 318.00 MinPts 8379.34 32.81 8362.47 8348.'IMErn MAS=10.00(m) 999.10 978.92 MInPI-O-SF 8471.64 32.81 8451.63 8438.. =EDE MAS=10.00(m) 1048.80 1021.48 MInP1-0.9F 8865.08 3281 8643.87 8832.,�-•r. MAS=10.03(w) 1107.04 1073.50 MInPI-0-SF 10383.61 45.21 10352.83 10338.3•MEM OSF 1.50 1305.77 1230.03 MinPt-0-SF 10791.78 47.54 10896.44 10684.2 =MK OSF 1.50 1338.02 1281.07 MInP1-0-SF 11210.75 40.65 11177.01 11181.1•=OM OSF 1.50 1370.03 1289.65 M1nPtA-SF 11335.00 50.16 11301.88 11285..• OSF 1.50 137840 1296.12 MinP1-0.9F 11504.07 51.33 11550.21 11542. MIMED OSF 1.50 1304.32 1308.35 MinPt-0-SF 11856.56 51.98 11821.27 11804..® OSF 1.50 1410.13 1320.39 MInP1-0-SF 12121.38 53.07 12085.36 12068.31 MIME OSF 1.50 1427.30 1333.33 Mm086-0-SF 13275.77 55.24 13238.30 13220.53 373.39 OSF 1.50 1783.82 1579.84 TD Nikeilchuq 4PB1(DN Survey) Pass I 8315 041 3281 8313.10 8282.231332563.56 MAS=10.00(m) 5290 52.90 M:rPts 8315,05 32.811 8313.08 8282.25 141680.03 MAO=10.00(m) 62.84 62.84 MINPT-0-EOU 8323,51 32.81 8320.89 8200.•I111:113M MAS=10.00(m) 236.86 288.85 MInPt-0-SF 8329,52 32.81 8326.95 8208.7..1L.1JMAS=10.00(m) 420.34 420.21 MinPl-0.SF 3641.29 32.81 8624.87 8008.-�' •T'•• MAS=10.00(m) 1355.60 1278.43 MInPI-0-SF 8095.85 32.81 8974.71 8063.04 • y�'S MAS=10.00(m) 1807.32 1011.30 MInPt-0-SF Nikeilchuq 2(Def Survey) . Pala 16101 59 32811 16099.67 15068 781 N/A MAS=10.00(m) 14.15 14.15 MinPts 16079.54 32.81 16063.78 16046 73 1162.00 MAS=10.00(m) 1229.01 1176.07 MinPts 15079.69 32811 18087.58 10048.88 1132.82 MAS=10.00(m) 1250.84 1104.32 M84PT-0-E0U 16079.:• 32.81 18083.01 16047.051 1078.71 MAS=10.00(m) 1202.01 1227.99 MinPls 16079.91 32 811 18002.87 10647.10 1003.04 MAS=10.00(m) 1300.50 1238.02 MINPT-0-501I 18247.97 30.04 16221.91 18208. MEM OSF 1.50 1578.16 1444.57 M1nPI-0-SF 10336.70 45.31 16305.88 10291.3 =MO OSF 1.50 1830.43 1482.81 MinP1-0-SF 16404.04 45.87 16372.82 18358.1 MEM OSF 1.50 1665.20 1508.18 MInPI-0-SF 16475.80 4555 16413.97 18429.••Man OSF 1.50 1004.22 1520.31 MinP1-0-SF I 18507.32 48.01 16475.61 18400.71 IMMO OSF 1.50 1708.15 1539.44 MInPI-0-SF 10540.58 46.77 16514.717 1849081 MIZM OSF 1.50 1720.66 1552.80 MInPI-0.SF 18705.85 48.66 16672.78 16057.2•MEM OSF 1.50 1775.79 1588.51 MinPl-0-SF 18063.08 64.61 18020.27 17999.3=ME OSF 1.50 2149.22 1865.45 MInP1-0-SF 18230.90 65.14 18188.83 18105.7•MOE OSF 1.50 2159.81 1862.01 MinPt-0-SF 18564.35 65.87 18519.80 18498.49 435.40 OSF 1.50 2180.31 1881.48 TD Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S135-W4\S135-W4\S135-W4(P5) 6/18/2013 7:35 AM Page 10 of 10 Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum Non: Oriented EOU N Well: 5135-W4 Dimension Field: Nikaitchuq Structure: Spy Island NoGo Region Anti- ' Date: June 14, 2013 Collision rule used: Minor Risk - Separation Factor North 350 - 10 0 - 700'md 340�■r��I�, i, `\ 20 330 �, ,'P , w, 30 320 r '/ A\ �� 40 Rilliallib, -4W ,110,7#4• 310 4IF Illppo.4k AiAirier4,NI',l, )i %I��!72,11: /��, 50 o...1fiTl ll , -, AWAfigildiliklib 6° i-ger4p..------ ,`�1 \ 111111pV,41011461/** 290 �� rI q �� , ) , .70 it,.�►•. o � --,, ;,,-�, IJP �� ►�-� , leo1411.4111114441114%.****: "1"Fliffir- � 111111 ��\ `'Iaor`�vp;� ts%vittibbilKi4. 90 r , ;.sols.��Iill ..‘ 1 .../Iviiitimive yiiiiiiiiiir4•-•;•7441 41.1 ��,�;��;�.tcti��,� 260 liti , ,,,, � 0, ,��L��//'� ik•e=0"b \ , 0f.\\�,*41 '. lt-, 100 4 t 4 ,4Ae-viksirki ,vier* ItT 250 111 4116-\ VAil�� v.A, ��//A��®�`�� - v ��'T®M:; 110 ♦ Pa 400 240 111 4.40,, 141111111 6 -N„,„, •.-- ----------_,z. -.4 . - 1NT20 230 -♦ ,,,sirt.,,, ,rior ' I ` 130 y,�f'tU1Js i4Wr 220 gill ``�4.�40 21�' 1111 `' 150 200 ■ 160 Ism .__ 17n Well Ticks Type: MD on SI35-W4(P5) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH= 10.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum on: Oriented EOU N Well: SI35-W4 Dimension - Field: Nikaitchuq Structure: Spy Island NoGo Region Anti- ' Date: June 14, 2013 Collision rule used: Minor Risk - Separation Factor North 350 u 10 0 - 700'md 340 � 20 33111101111111111140 30 � 30 140 320 111100111111.1\ 1 \74,1 , � 40 �� .��_taripirillelLiLibk•I‘. 310 r! iiivi."4--A4rot, <�F w ��r� ,,ate ent , ir A. iShi ,• i/L� I� A. >. c46ti 300 .101,11167111110 ....ACt i trllk rI��g�g�`4101c� % ,k A 60 'a�'�l1��►y��lr �i. �- 4 . ' ��. `,moi//. 2904 b.-NI, .,,,A''vfl 4414_ $t*Ailktr."vq!...4,44';'1"..k:t7-_ !=' .--_-,- 44411110 eliglIAVI) . ` 70ii* WN. tA 4!! ilWA IftaA%4;t41011„S�o,:14�4�*' ,�; at re v;a nim 280 �� W %G `��;�/�',..-,-,!....,74,;,` � ,. .i:::�°'!�"� ;t ,�';,,.so 270 11111111111111t117Zikl4S �,1 `,,..:,i -:-..w, v�d ia�` � ice` /' q0 gempulti.u4N4.,-_,�'_' �a � �� \�:WY � �.'t a � './r yam. III III �� ! ��► .. � ��ti 120-N4PB1 26010IP ♦ ii o.► \= ��kit 100 cb \vs 250 ! 4,440a4itilliti 41 *111111140,s,0 Ili e -...ci _ 110 p 240 120 .41* laillnli.. 230 41604111riiiiiitoo 130 , 1‘* 220 111W111�� 140 210150 200 160 190 1 o 170 Well Ticks Type: MD on SI35-W4(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum on: Oriented EOU N Well: SI35-W4 Dimension ' Field: Nikaitchuq Structure: Spy Island NoGo Region Anti- ' Date: June 14, 2013 Collision rule used: Minor Risk - Separation Factor North 350 - 10 700'md - 2500'md 340 1t1 ,:, - - AIEs o� -1 kI*lk:l....ofA r 11', 330 . 34 V�� -,,, i,, 30 320 4� ..r ��1 ++,teNI irl �� 40 *Iirrirlib›,,lirilliNifirA,A Arair 7.-'-',.7: 4PWIIIMM.• 730-W1P B 1 310 \ow , J morarkfrovirt„or., 4, vows 7�0a triMitav410.-411*.1,d �I O44150(IPAA300 �Sail � �.��®'�,O IPA!AP M.CO��/G,"•y` 60 �� !. ♦ tri iti �i��►t. ii.-1-4:--- -#.:4, 0. !o .��4:5-•*:..P23 N3PB1 290APimih4*1417i 414 lef��a.��i,iri ��r�a�s\`t�4 ��\��1`�� `70 260 4& ;�r ryq� Viti ►<<t iilliiSbuVtiittOrtv„ititioin101tirigirk2,r4j \ms's �►�� h1�s 4ao e, . 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MIR *V 230 itleript11111111 130 Amp 220 ario, , 140 IRO • t 210 150 200 160 190 1 R 170 Well Ticks Type: MD on SI35-W4(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: Eni Petroleum Well:N on: Oriented EOU SI35-W4 Dimension W A 41 Aft....._ Field: Nikaitchuq Structure: Spy Island NoGo Region Anti- 4 /011" Date: June 14, 2013 Collision rule used: Minor Risk - Separation Factor North 350 v 10 340__Aiiiiii.11W7-- Ario20 2500'md - 11400'md 330 -Lair ---"11113°° -----F -.11*--frOw - *2 000441tOraigall- "6111Spr 4,1*-7041‘42 320 All illi i ,tat,IIN NW.-44%40 viarreakVAINftillt * ' I _ riowAmigvaossatt4-rlit* 310 AMP 100P- tiligVISIIIIIZOPlirodigkle,14,li /AV 50 ' 411kVIOC/..miggilffifiV..4" \• R'''' /,*4 N .. ,A 1 firio, Airl.. ...----JIM im. kirphi A ( 300 41 4044IP lop.-,111.1011111MialloWlerhh..4:- it S fr 4 60 # 4 11161FACINW4eiliS".1. 4 4 41fr4A* 4%p' 4,..1111011,111,grImai.--41.01% Pl" ‘14 k ‘. 29 ' iI11 -iit-p-,,-,,--Min•alwipi,vl.amsiimrl?lil"wbw"i,m..p-ao4.P' 1w,l-,0iippr•A---I.A.v...AAS*I..,...T.%.iii isk 70 280 f 80 • , 441,41k N-1 i e.r:Aouvallid;,111,...61 • u- ,,fati -001-40-r...--Ezaz--.1.4%-a v i" AA.,,. bilinsflamsam., \ AlSI alltil041414*: 270 Illir 10;01-- ir,hiarririvillttkrAirvips, , \ i A ,01,,,g• 000, /pivot, „solo , ,f-....-zift,--,..-::::- -,,-:,, *14144,' ,--=: rab.-:-:;:-.--$4.:,., , at it,ii„ viyi,' 4,—froit'ft ri-,=__,..-_..__-..- ---211'.."-:IN'-. .-...t.-3,-,.----:•;„ 260 ‘‘AiVat.-059.4iPikW *41/111iffik4i7 ' wAll/A.-,k1OZ•Ac4 /11 i re. we z.1.! ,e,Ty//,,,,..:A \, * Ismas,v,Ayr..m , Attir,..04 i A.% • 7 ... 4 vi \;•21iff-,-017,.... amrip,,i/vii I . 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'--z-'''........ .---- -•;* - Wiffht,eL-461pArAitil101d, kifilliiiat *: ---7"------ 220 S 14'W'''4,4141.111111W , "AO--.0".1:7101111111110 .____ - 140 th#4pAps-jo,a,...-.44101/r0/1/0410111 AIrgirAdrim.- :- agiganIMIIIaint 's, 2104111Cmg --• graZ's 0111„,,----Aorgekaavor 150 4•, 20C ------"IP244"111- -"Ii/P----4. --;-11-I- PAIIIILI!SD; 101) .SP36-W5(IN& Well Ticks Type: MD on S135-W4(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger TRAVELING CYLINDER PLOT NoGo Region EOU's based Client: Eni Petroleum on: Oriented EOU i`l Well: SI35-W4 Dimension Field: Nikaitchuq AStructure: Spy Island NoGo Region Anti- 740 Date: June 14, 2013 Collision rule used: Minor Risk - Separation Factor North 350 10 11400'md - TD 3a0 320 20 330 �_300 WA* 30 ��280 320 ' 260 OW 40� ,�e240 �% 310 ,1*P 220 i�, % 50 �� .NIP`♦ - 200 ��., r � �1 , , , ' 180 ows*�• 4300 ,, ,/,, i m :fart" oittil.60 "� ��I��fir, 140,��'�,�� ,290 ,,, , , Ali 12 'ery7 III, 4.44".#111a*, 280 /1111111144:::::::::!! ij111�r�i�, ., ��r ., I�♦ ��. � 80 4° 44011011 6111X1 All 11111111MMBRUIVI 0 0 , 260 O ' r ' �S)9%11IIt **0144 ON/. ,00 t�� SW � ori ►, . spsis�► roar ., .0141034:4.•"#P1 0 ��; V# II 250 c.4 ca , • 4 �,■� ®� 4, 110 '0 % .4.--t I ®## ,♦ o o�ti o4, � ‘,#####. 240 tmmm� w - o ,�4, 120 230 •47410811111111111011 lop � . I,% 130 220 ..G .140 wft.2,``�i■m.■�� 150 200 111111111111111.1111111 160 190 180 170 Well Ticks Type: MD on SI35-W4(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft N LL Z N m ZOO Z M N J 1 LL Zci, N ( R M 1 M CO M L.L CO I9 `Zr O CO L6 ZI o Z t o[n CO a 0 Z N O Z cII)KV co)O O N 1O N (n w °0, 1 LX c%j " - XX 0I 5t X ! co •• co U)e i (go U) CO /,t U) I EE(/? I •��°1 co 8 12osi _ 1,., • 7f/�'I IP• •I®O ,'d. .•,. ••. 1T\.14c/ OOS£ — O •: r co in 'fr-'c',..‘,,, es„ •!•` ' '•, le : • (),_ •• , V CO )11111 @ 9 f C`r• O (n J ♦ a IlIl ji _etf / • 8 fA p •, iii rf �r �Q `Cp •ell p, •Qqe !t9 e re .1) .,„, .= 2$ eit!£ •• ,�4 ty A__ S a 1_ 'r .• 6lt . O rS91. •kb 9e •i'-V4‘.. (/1 a•'r• _ ., • b!F • ' fy�f . O� 'rlff , Q� I •, O fes'[• _ O CODQ. 3 o0a . • T7' O le f M •p K P_ +titi+££ <rf ' �/ orf A X • 7�tl� Q. /N. t •�t �r n (Ur S -. ._ O W �§ r • -G� f yt9 'IOS / O> f f _ ill shy r$ I •� F . M •� rg O E (/) 2 'r up $ : �8r'O Q /le, * rrf •i rtrO -z! • f o II � NCC •�8ggr£ • �r� _ N N f • L p 3 W Nf£rf Illr (n �—' •r t !!; • f )1111r16 f' O s? (4TS CI Cli, m m. VW., a a c-c_.)a 0 M = In U) 1 (n 1 1 00 0 0 0 0 0 0 0 (D CO N CO (2 Yr «< N 01)0094 4 = eleos S >>> Sclimberler S135-W4(P5)Anti-Collision Detailed Report fl fi Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: June 20,2013-14:01 North Reference: True Analysis Machine: AKA-DEC-9010 Client Eni Petroleum Database\Project: localhostldrilling-Nikaitchuq Version/Patch: 2.8.1168.0 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 in is always included for borehole diameters. All local minima indicated. Results filtered:Depth 11400.00 k 00 MD 00 19010.00 ft,Ct-Ct separation c=3000.00 k Anti-Collision Rules Used Rule Set Name DEM AntiCollision Standard S002 v5.1/5.2 Exemption Risk Level: Minor Rule Name J2hk Leval Rule Tvoe Jtule Label JdoGo Rulq SLB Alert Zone Threshold OSF=5.0 S002 05.1/5.2 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 v5.115.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule S002 v5.1/5.2 Major CT_CT MAS=32.81(R) SLB Alert Zone Threshold CtCK=15m S002 05.1/5.2 Alert CT_CT MAS=49.21(ft) Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 1 of 65 Reference Trajectory Summary Field: Nikailchuq Well: 5135-W4 Structure: Spy Island Borehole: SI35-W4 Slot: SP35 Trajectory: S135-W4(P5) Client: Eni Petroleum Type: Def Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08831467° Grid Scale Factor: 0.999900148 Magnetic Declination: 19.723° Magnetic Declination Date: September 05,2013 Magnetic Model: BOOM 2013 Reference Point: Nort�hin Eastina Elevation Structure Unc. Slot Unc. 6053608.810(f/US) 511418.730(WS) 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 Survev-ne Proe: Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.000 1/100.000 SLB_NSG+MSHOT-Depth Only-No Global 16.000 5135-W4/S135-W4(P5) 41.000 1200.000 1/100.000 SLBNSG*MSHOT-No Global 16.000 SI35-W4/SI35-W4(P5) 1200.000 2700.000 1/100.000 SLB_MWD+SAG-No Globe 16.000 SI35-W4/5135-W4(P5) 2700.000 3237.301 1/100.000 SLBMWD0GMAG-No Globe 16.000 SI35-W4/SI35-W4(P5) 3237.301 4740.000 1/100.000 SLB MWD-)SAG-No Globe 12.250 SI35-W4/SI35-W4(P5) 4740.000 11347.496 1/100.000 SLB_MWDOGMAG-No Globe 12.250 SI35-W4/SI35-W4(P5) 11347.496 12850.000 1/100.000 SLB_MWD+SAG-No Globe 8.750 SI35-W4/SI35-W4(P5) 12850.000 19909.637 1/100.000 SLB_MWD+GMAG-No Globe 8.750 SI35-W4/SI35-W4(P5) Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4)5135-W4\5135-W4(P5) 6/20/2013 2:02 PM Page 2 of 65 Offset Trajectory Summary Offset Selection Criteria• Wellhead distance scan:Not performed! Offset Selection Criteria:Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive piens -All Non-Det Surveys when no Def-Survey is set Inc borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Selection Summary Wells Selected:43 Boreholes Selected:58 Definitive Surveys Selected:37 Non-Def Surveys Selected:1 Definitive Plans Selected:20 Non-Def Plans Selected:0 Total Trajectories:58 None OSF filter in detailed report Tra cto Borehole Well Type SX34-FN1(P2) SX34-FN1 SX34-FN1 Def Plan SP384/5(P4) SP38-W6 SP38-W5 Def Plan SP33-W3 SP33-W3 SP33-W3 Dot Survey SD37-DSP1 SD37-DSP1 SD37-DSP1 Def Survey SI32-W2 S132-W2 S132-W2 Def Survey SX31-FN2(P2) SX31-FN2 SX31-FN2 Def Plan SP30-W1 SP3O-W1 SP3O-W1 Def Survey SP30-W1PB1 SP30-W1PB1 SP3S-W1 Def Survey OP14-S3 OP14-S3 OP14-S3 Def Survey 5129.52 5129-S2 S129-S2 Def Survey SX28-FN3(P2) SX28-FN3 SX28-FN3 Def Plan SP27-N1 SP27-N1 SP27-N1 Def Survey SX28-FN4(P2) SX26-FN4 SX26-FN4 Det Plan SI25-N2 SI25-N2 SI25-N2 Def Survey SP24-SE1(P2) SP24-SE1 SP24-SE1 Def Plan SP22-FN1PB3 SP22-FN1PB3 SP22-FN1 Def Survey SP22-FN1PB2 SP22-FN1PB2 SP22-FN1 Def Survey SP22-FN1 PB1 SP22-FN1 PB1 SP22-FN1 Def Survey SP22-FN1PB4 SP22-FN1PB4 SP22-FN1 Def Survey SP22-FN1 SP22-FN7 SP22-FN1 Def Survey SP23-N3 SP23-N3 SP23-N3 Def Survey SP23-N3PB1 SP23-N3PB1 SP23-N3 Def Survey SX21-N1(P2) SX21-N1 SX21-N1 Def Plan S120-N4PB1 S120-N4PH S120-N4 Def Survey S120-N4 S120-N4 5120-N4 Def Survey S119-FN2 S119-FN2 5119-FN2 Non-Def Survey SI17-SE2(P3) SI17SE2 SI17-SE2 Def Plan SP18-N5PB1 SP18-N5PB1 SP18-N5 Def Survey SP18-N5 SP18-N5 SP18-N5 Def Survey SP18-FN3 SP18-FN3 SP18-FN3 Def Survey SX15-N2(P2) SX15-N2 SX1SN2 Def Plan S114-N8(P2) SI14-N8 5114-N8 Def Plan 5113-FN4 5113-FN4 5113-FN4 Def Survey SP12-SE3(P2) SP12-SE3 SP12-SE3 Def Plan 5111-FN8(P6) S111-FN8 SI11-FNB Def Plan SP10-FN5 SP10-FN5 SP10-FN5 Def Survey SX09-N3(P2) SX09-N3 SX09-N3 Def Plan SP08-N7(P5)update SP08-N7 5P08-N7 Def Plan 5107-SE4(P2) 5107-5E4 5107-5E4 Def Plan SX08-N4(P2) SX08-N4 5X08-N4 Def Plan SP05-FN7PB1 SP05-FN7PB1 SP05-FN7 Def Survey SP05-FN7 SP05-FN7 SP05-FN7 Def Survey SP04-SE5(P2) SP04-SE5 SP04-SE5 Def Plan SX03-N5(P2) SX03-N5 5X03-N5 Det Plan 5102-SE8(P2) 5102-SE8 5102-SEB Def Plan 5P01.5E7(P2) SP01-SE7 SP01SE7 Def Plan OP09-S1 OP09S1 OP09-S1 Def Survey Kigun 1 Kigun 1 Tuveaq ST 1 Def Survey Kigun 1 PB1 Kigun 1 P131 Tuveaq ST 1 Def Survey Tuveaq ST 1 Tuveaq ST 1 Tuveaq ST 1 Def Survey Nikaitchuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Def Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Def Survey Nikaitchuq 3PB1 Nikaitchuq 3PB1 Nikaitchuq 3 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Def Survey Nikaitchuq 4 Nikaitchuq 4 Nikaitchuq 4 Def Survey Nikaitchuq 1 Nikaitchuq 1 Nikaitchuq 1 Det Survey Nikaitchuq 4PB1 Nikaitchuq 4PB1 Nikaitchuq 4 Def Survey Nikaitchuq 2 Nikaitchuq 2 Nikaitchuq 2 Def Survey Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\S135-W4\S135-W4\S135-W4(P5) 6/20/2013 2:02 PM Page 3 of 65 • Field: Nikeitchuq Well: SP38-W5 Structure: Spy Island Borehole: SP38-W5 Slot: SP38 Trajectory: SP38-W5(P4) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08825355° Grid Scale Factor: 0.000000148 Magnetic Declination: 19.811° Magnetic Declination Date: July 10,2013 Magnetic Model: BGGM 2013 Reference Point: Isaias ailing elevation Structure One Slot Unc 6053607.230(SUS) 511410.830(fOUS) 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 Prow, Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole I Sunray 0.000 41.000 1/100.000 SLB_NSG+MSHOT-Depth Only-No Global 18.000 SP36-W5/SP36-W5(P4) 41.000 850.000 1/100.000 SLB_NSG+MSHOT-No Globe 18.000 SP38-W5/SP36-W5(P4) 850.000 2350.000 1/100.000 SLB_MWD+SAG-No Globe 16.000 SP36-W5/SP36-W5(P4) 2350.000 4267.041 1/100.000 SLB_MWD+GMAG-No Globe 16.000 SP38-W5/SP38-W5(P4) 4267.041 5770.000 1/100.000 SLB_MWD+SAG-No Globe 12.250 SP30-W5/SP36-W5(P4) 5770.000 12463.539 1/100.000 SLB_MWD+GMAG-No Globe 12.250 5P36-W5/SP36-W5(P4) 12463.539 13960.000 1/100.000 SLB_MWD+SAG-No Globe 8.750 SP30-W5/SP36-W5(P4) 13960.000 21991.309 1/100.000 SLB MWD+GMAG-No Globe 8.750 SP36-W5/SP36-W5(P4) 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 (6) (ft) (ft) (ft) (ft) (ft) (ft) (9) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 11400.00 ft cn MD<0 19910.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Cl-Ct separation m 6240.00 ft 11400.00 3573.16 -4273.05 -7617.72 12609.66 3521.75 -5047.70 -8294.69 213.69 1030.05 120.73 949.24 12.89 OSF 1.50 Pass 11500.00 3579.77 -422224 -7703.59 12708.28 3526.89 -4983.09 -8369.01 215.57 1012.16 121.80 930.63 12.55 OSF 1.50 Pass 11600.00 358450 -4166.87 -7786.71 12809.79 3528.67 -4916.23 -8445.36 218.76 999.24 123.46 918.60 12.23 OSF 1.50 Pass 11700.00 3587.20 -4106.77 -7866.57 12909.45 3528.46 -4850.43 -8520.21 222.06 991.83 126.30 907.31 11.86 OSF 1.50 Pass 11781.82 3587.89 -4054.22 -7929.27 12991.23 3528.29 -4796.44 -8581.63 2247 989.9 129.24 903.47 11.57 OSF 1.50 Pass 11800.00 3587.86 -4042.15 -7942.86 1300941 3528.25 -4784.43 -8595.28 225.37 990.05 129.92 903.11 11.51 OSF 1.50 Pass 11840.82 3587.53 -4014.52 -797292 13050.22 3528.17 -4757.48 -8625.93 226.72 990.93 131.6•�°-r 1t36 OSF 1.50 Pass 11900.00 3586.82 -3973.97 -8016 01 13109.36 3528.04 -4718.44 -8670 35 226.68 992.90 134.22 9.3.9 11.17 OSF 1.50 Pass 12000.00 3585.61 -3905.44 -8088.83 13208.35 3528.28 -4853.15 -8744.76 226.58 996.29 139.11 903.22 10.81 OSE 1.50 Pass 12100.00 3584.40 -3836.92 -8161.84 13308.28 3528.69 -4587.27 -8819.89 22648 999.71 14460 902.98 10.43 OSF 1.50 Pass 12200.00 3583.19 -3768.39 -823446 13408.20 3529.09 -4521.39 -8895 02 226.38 1003.13 150.60 902.40 10.05 OSF 1.50 Pass 12300.00 3581.98 -3699.86 -8307.28 13508.13 3529.49 -4455.51 -8970 15 22628 1006.55 157.06 901.52 9.86 OSF 1.50 Pass 12400.00 3580.77 -3631.34 -8380.10 13608.15 3529.91 -4389.56 -9045.36 226.17 1009.98 163.90 900.39 9.29 OSF 1.50 Pass 12500.00 3580.04 -3563.30 -8453.38 13709.03 3532.05 -4323.08 -9121.19 224.60 1012.69 170.70 898.56 8.94 OSF 1.50 Pass 12600.00 3581.89 -3497.93 -8529.02 13809.02 3534.81 -4257.19 -9196.35 223.03 1011.94 178.03 892.93 8.57 OSF 1.50 Pass 12700.00 3584.35 -3433.21 -8605.22 13909.00 3537.58 -4191.31 -9271.51 223.02 1010.37 185.84 886.15 8.19 OSF 1.50 Pass 12800.00 3586.81 -3368.49 -8881.41 14008.99 3540.35 -4125.42 -9346.67 223.01 1008.80 192.68 880.02 7.89 OSF 1.50 Pass 12900.00 3589.27 -3303.77 -8757.61 14108.96 3543.11 -4059.54 -9421.82 222.99 1007.22 195.73 876.41 7.75 OSP 1.50 Pass 13000.00 3501.17 -3239.01 -8833.78 14207.80 3544 25 -3994.40 -9496.13 223.12 1005.74 195.94 874.79 7.73 OSF 1.50 Pass 13100.00 3591.20 -3174.08 -8909 83 14307.79 3544.51 -392848 -9571.32 223.16 1004.43 196.13 873.35 7.71 OSF 1.50 Pass 13200.00 3591.20 -3109.14 -8985.87 14407.76 3544.76 -3862.57 -9646.51 223.15 1003.13 196.41 871.86 7.89 OSF 1.50 Pass 13300.00 3591.20 -3044.19 -9061.91 14507.77 3545.02 -3796.66 -9721.70 223.14 1001.83 196.78 870.32 7.67 OSF 1.50 Pass 13400.00 3591.20 -2979.25 -9137.95 14607.76 3545.28 -3730.74 -9796.89 223.13 1000.53 197.23 888 71 7.64 OSF 1.50 Pass 13500.00 3591.20 -2914.30 -9213.99 14707.75 3545.32 -3684.82 -9872.07 223.13 999.23 197.77 867.06 7.61 OSF 1.50 Pass 13600.00 3590.65 -2849.36 -9290.03 14807.74 3545.28 -3598.90 -9947.25 223.08 997.90 198.37 885.32 7.58 OSF 1.50 Pass 13700.00 3588.25 -2784.45 -9366.06 14907.70 3545.24 -3533.00 -10022.41 222.95 996.48 199.09 863.42 7.54 OSF 1.50 Pass 13800.00 3585.81 -2719.54 -9442.09 15007.66 354520 -3467.09 -10097.57 22281 995.06 19989 861.47 7.50 OSF 1.50 Pass 13900.00 3583.37 -2654.62 -9518.12 15107.63 3545.16 -3401.19 -10172.73 222.68 993.65 200.77 859.48 7.45 OSF 1.50 Pass 14000.00 3580.93 -2589.71 -9594.14 15206.47 3543.77 -3336.03 -10247.04 222.62 992.29 201.81 857.42 7.40 OSF 1.50 Pass 14100.00 3578.11 -2524.80 -9670.16 15305.66 3539.22 -3270.71 -10321.53 222.73 991.05 20289 855.46 7.36 OSF 1.50 Pass 14200.00 3574.59 -2459.89 -9746.15 15405.63 3533.98 -3204.88 -10396.60 22283 989.81 203.97 853.51 7.31 OSF 1.50 Pass ' 14300.00 3571 07 -2394.99 -9822.15 15505.77 3528 74 -3138.95 -10471.78 222.93 988.58 205.10 851.52 7.26 OSF 1.50 Pass 14400.00 3587.56 -2330.09 -9898.14 15607.25 3525.60 -3072.08 -10548.05 222.91 987.26 206.00 849.60 7.22 OSF 1.50 Pass 14500.00 3564.04 -2265.18 -9974.14 15708.11 3525.83 -3005.58 -10623.87 222.69 985.81 207.11 847.41 7.17 OSF 1.50 Pass 14600.00 3560.59 -220027 -10050.13 15808.00 3526.82 -2939.73 -10698.98 222.44 984.34 208.50 845.02 7.11 OSF 1.50 Pass 14700.00 3558.59 -2135.34 -10126.16 15907.94 3527.82 -2873.84 -10774.12 222.28 982.94 209.83 842.73 7.05 OSP 1.50 Pass 14800.00 3556.71 -2070.41 -10202.18 16007.90 3528.81 -2807.94 -10849.27 222.11 981.56 211.36 840.32 6.99 OSF 1.50 Pass 14900.00 3554.83 -2005.48 -10278.21 16107.85 3529.80 -2742.05 -10924.42 221.95 980.18 212.95 837.88 6.93 OSF 1.50 Pass 15000.00 3552.95 -1940.54 -10354.24 16207.72 3530.94 -2676.21 -10999.51 221.77 978.81 21455 835.45 6.87 OSF 1.50 Pass 15100.00 3551.12 -1875.61 -10430.27 16307.67 3532.18 -2610.33 -11074.66 221.60 977.46 216.25 832.96 6.80 OSF 1.50 Pass 15200.00 3550.87 -1810.87 -10506.31 16407.65 3533.42 -2544.43 -11149.84 221.52 976.14 217.94 830.52 8.74 OSF 1.50 Pass 15300.00 3550.82 -1745.72 -10582.35 16507.63 3534.66 -2478.53 -11225.01 221.45 97483 219.77 827.99 6.88 OSF 1.50 Pass 15400.00 3550.77 -1680.78 -10658.39 16607.61 3535.90 -2412.63 -11300.19 221.37 973.52 221.66 825.41 6.61 OSF 1.50 Pass 15500.00 3550.72 -1615.83 -10734.43 16708.07 3538.71 -2346.43 -11375.70 221.21 972.18 223.42 822.91 6.55 OSF 1.50 Pass 15600.00 3550.67 -1550.89 -10810.47 16807.99 3542.54 -2280.60 -11450.77 220.98 970.84 225.45 820.21 6.48 OSF 1.50 Pass 15700.00 3551 89 -1485.95 -10886.50 16907.94 3546.37 -2214.75 -11525.86 220.85 869.51 227.36 817.61 6.42 OSF 1.50 Pass 15800.00 3554.76 -1421.03 -10962.51 17007.93 3550.20 -2148.87 -11600.98 220.79 966.20 229.47 814.90 6.35 OSF 1.50 Pass 15900.00 3557.62 -1356.12 -11038.52 17107.75 3553.30 -2083.10 -11676.00 220.78 966.90 231 64 812.15 6.28 OSF 1.50 Pass 16000.00 3560.49 -1291.20 -11114.53 17207.56 355383 -2017.30 -11751.05 220.93 965.62 233.84 809.40 6.21 OSF 1.50 Pass 16100.00 3563.35 -1226.28 -11190.54 17307.51 3553.59 -1951.41 -11826.21 221.10 964.36 236.08 806.65 8.15 OSF 1.50 Pass 16200.00 3564.95 -1161.35 -11266.57 17407.48 3553.55 -1885.51 -11901.39 221.18 963.09 238.37 803.85 6.08 OSF 1.50 Pass 16300.00 3563.85 -1096.41 -11342.60 1750747 3553.51 -1819.60 -11976.57 221.11 961.79 240.74 800.97 6.01 OSF 1.50 Pass 16400.00 3562.55 -1031.47 -11418.64 1760745 3553.47 -1753.69 -12051.76 221.03 960.48 243.15 798.06 5.94 OSF 1.50 Pass 16500.00 3561.26 -966.53 -11494.67 17707.69 3553.28 -1687.60 -12127.12 220.97 959.17 245.59 795.12 5.88 OSF 1.50 Pass 16600.00 3559.96 -901.59 -11570.71 17807.68 3552.96 -1621.67 -12202.29 220.91 957.84 248.08 792.13 5.81 OSF 1.50 Pass 16700.00 3558.68 -836.65 -11646.74 17907.86 3552.63 -1555.74 -12277.46 220.85 956.52 25061 789.12 5.74 OSF 1 50 Pass 16800.00 3559.21 -771.71 -11722 78 1800785 3552.30 -1489.81 -12352.63 220.92 955.21 252.88 786.29 5.68 OSF 1.50 Pass 16900.00 3560.38 -706 77 -11798.82 1810783 3551.98 -1423.88 -12427.79 221.01 953.90 255 47 783.25 5.62 OSF 1.50 Pass 17000.00 3561.55 -641 83 -1187485 18207.13 3550.65 -1358.29 -12502.60 221.16 952.62 258.14 780.20 5.55 OSF 1 50 Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 5 of 65 Trajectory:5135-W4(P5)Vs.SP36-W5(P4) 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 (fl) (ft) (ft) (h) (ft) (fl) (ff) (ft) (°) (fl) (n) (ff) 17100.00 3582.72 -576.89 -11950.89 18307.06 3548.42 -129203 -12577.72 221.37 951.38 260.77 777.20 5.49 OSF 1.50 Pass 17200.00 3563.89 -511.95 -12026.92 18407.00 3546.19 -1226.57 -12652.85 221.58 950.15 263.46 774.18 5.42 OSF 1.50 Pass 17300.00 3564.76 -447.01 -12102.96 18506.94 3543.96 -1160.70 -12727.99 221.76 948.92 266.18 771.14 5.36 OSF 1.50 Pass 17400.00 3565.18 -382.06 -12179.00 18808.99 3541.75 -1094.77 -12803.20 221.92 947.89 268.90 788.10 5.30 OSF 1.50 Pass 17500.00 3565.59 -317.12 -12255.04 18707.81 3541.64 -1028.30 -12879.02 221.95 948.42 271.23 765.27 5.25 OSF 1.50 Pass 17600.00 3566.01 -252.18 -12331.08 18807.87 3543.59 -962 36 -12954.24 221.86 945.09 273.89 762.17 5 19 OSF 1.50 Pass 17700.00 3566.43 -187.23 -12407.12 18907.85 3545.55 -896.47 -1302940 221.77 943.76 276.79 758.91 5.13 OSF 1.50 Pass 17800.00 3586.84 -122.29 -12483.16 19007.83 3547.51 -830.57 -13104.57 221.67 942.44 279.72 755.63 5.07 OSF 1.50 Pass 17900.00 3567.15 -57.36 -12559.21 19107.80 3549.47 -764.68 -13179.74 221.57 941.10 282.68 752.32 5.01 OSF 1.50 Pass 18000.00 3567.46 7.58 -12635.26 19207.61 3550.79 -698.90 -13254.77 221.51 93978 285.67 749.00 4.95 OSF 1.50 Warning 18100.00 3567.77 72.51 -12711.31 19307.60 3550.91 -632.97 -13329.96 221.52 938.46 288.66 745.69 4.89 OSF 1.50 Warning 18200.00 3568.09 137.44 -12787.36 19407.59 3551.03 -567.05 -13405.14 221.54 937.15 291.68 742.37 4.83 OSF 1.50 Warning 18300 00 3588.40 202.38 -12863.41 19507.58 3551.18 -501.12 -13480.32 221.55 935.83 294.72 739.02 4.77 OSF 1.50 Warning 18400.00 3569.56 267.31 -12939.45 19607.72 3551.38 -435.10 -13555.81 221.63 934.55 297.46 735.91 4.72 OSF 1.50 Warning 18500.00 3570.90 332.25 -13015.48 19708.48 3554.57 -368.71 -13631.32 221.51 933.21 300.10 732.82 487 OSF 1.50 Warning 18600.00 3572.24 397.19 -13091.52 19808.60 3561.35 -302.85 -13708.43 221.18 931.82 303.01 729.49 4.62 OSF 1.50 Warning 18700.00 3573.58 462.13 -13167.55 19908.42 3568.47 -237.20 -13781.29 220.83 930.47 306.24 725.98 4.57 OSF 1.50 Warning 18800.00 3574.92 527.07 -13243.58 2000825 3575.58 -171.56 -13856.15 220.47 929.15 309.48 722.50 4.51 OSF 1.50 Warning 18900.00 3576.70 592.00 -13319.61 2010822 3581.84 -105.77 -13931.17 220.20 927.86 312.54 719.17 446 OSF 1.50 Warning 19000.00 3578.90 856.93 -1339563 2020844 3584.05 -39.72 -14006.50 220.20 926.56 315.73 715.74 4.41 OSF 1.50 Warning 19100.00 3581.10 721.86 -13471.66 20308.41 3584.05 26.19 -14081.67 220.33 925.24 318.93 71229 4.36 OSF 1.50 Warning 19200.00 3583.30 786.79 -13547.68 20408.38 3584.05 92.10 -14156.83 220.47 923.94 322.15 708.84 4.31 OSF 1.50 Warning 19300.00 3585.50 851.72 -13623.70 20508.35 3584.05 158.01 -14231.99 220.61 92264 325.39 705.38 4.26 OSF 1.50 Warning 19400.00 3587.36 916.65 -13699.73 20608.32 3584.05 223.92 -14307.16 220.71 921.34 328.65 701.91 4.21 OSF 1.50 Warning 19500.00 3587.75 981 60 -13775.77 20707.40 3583.82 289.23 -14381.67 220.75 920.05 331.97 698.41 4.17 OSF 1.50 Warning 19600.00 3588.11 1046.54 -13851.81 20807.13 3582.24 354.89 -14456.72 220.87 918.88 335.27 695.04 4.12 OSF 1.50 Warning 19700.00 3588.48 1111 48 -13927.85 20907.11 3580.64 420.70 -14531.96 220.99 917.71 338.57 691.67 4.07 OSF 1.50 Warning 19800.00 3588.85 117643 -14003.89 21007.08 3579.04 486.52 -14607.20 221.12 916.54 341.89 688.29 4.03 OSF 1.50 Warning 19900.00 3589.21 1241.37 -1407993 21110.16 3576.00 554.46 -14684.65 221.33 915.26 345.06 684.90 3.99 OSF 1.50 Warning 19909.64 3589.25 124763 -14087.26 21120.20 3575.43 561.09 -14692.16 221.3 :IiINE 345.3. OSF 1 50 Warning End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 6 of 65 Field: Nikaifohuq Well: SP33-W3 Structure: Spy Island Borehole: SP33-W3 Slot: SP33 Trajectory: SP33-W3 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08843614° Grid Seale Factor: 0.909900149 Magnetic Declination: 20.419° Magnetic Declination Date: August 01,2012 Magnetic Model: BGGM 2011 Reference Point Northing Eating Ljevation 'frustum Unc. Slot Unq, 6053611.830(ftUS) 511434.430(ftUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajeslora Error Model:ISCWSAO 3-12 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 41.000 Act-Sins SLB NSG+SSHOT-Depth Only-No Global 16.000 SP33-W3/SP33-W3 41.000 648.000 Act-Stns SLB_NSG+SSHOT-No Global 16.000 SP33-W3/SP33-W3 848.000 3060.350 Act-Sine 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-Sins 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 Azim Ct-Ct Distance Separation Clearance OSF Rule Status (8) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 11400.00 ft<=MD<=19910.00 ft Results filtered:Ct-Ct separation r_3000.00 ft Results highlighted:Ct-Ct separation<=8240.00 ft 11400.00 3573.16 -4273.05 -7817.72 11087.38 359414 -3408.62 -6939.37 31.67 1099.02 14493 1002.07/ 11.44( OSF 1.50 Pass 11500.00 3579.77 -4222 24 -7703.59 1116940 359754 -3357.58 -700349 33.34 1112.70 144.45 1016.07 11.62 OSF 1.50 Pass 11600.00 3584.50 -4166 87 -7786.71 11249.23 3599.78 -3306.86 -7065.08 36.27 1122.77 143.97 1026.46 11.77 OSF 1.50 Pass 11700.00 3587.20 -410677 -7866.57 11330.63 3600.29 -3254.02 -7127.01 39.32 1128.85 144.11 1032.44 11.82 OSF 1.50 Pass 11800.00 3587.86 -404215 -7942.86 11410.24 3600.45 -3201.35 -7186.70 42.55 1130.87 144.33 1034.33 11.82 OSF 1.50 Pass 11900.00 3586.82 -3973.97 -8016.01 11507.52 3600.40 -3135.89 -7258.66 43.96 1129.66 147.57 1030.96 11.55 OSF 1.50 Pass 12000.00 3585.61 -390544 -8088.83 11625.16 3602.20 -3057.74 -734656 44.13 1126.87 154.12 1023.80 11.03 OSF 1.50 Pass 12100.00 358440 -3836.92 -8161.64 11714.35 360469 -2998.82 -741347 44.31 1123.65 156.71 1018.85 10.81 OSF 1.50 Pass 12200.00 3583.19 -3768.39 -823446 11807.39 3606.03 -2936.62 -7482.65 4444 1121.42 160.25 1014.26 10.55 OSF 1.50 Pass 12300.00 3581.98 -3699.86 -8307.28 11909.86 3605.96 -2867.95 -7558.70 4450 1119 39 165.47 1008.75 10.20 OSF 1.50 Pass 12400.00 3580.77 -3631.34 -8380.10 11886.31 3605.00 -2816.28 -7815.03 44.5.iilinIE 167.11 1006.41 10.09 OSP 1.50 Pass 12500.00 3580.04 -3563.30 -8453.38 1207657 3603.68 -2754.03 -7680.38 43.11 1119.38 170 8,iligiE 9.87 OSF 1.50 Pass 12600.00 3581.89 -3497.93 -8529.02 12169.42 3601.86 -2689.73 -7747.33 41.45 1124.56 175.25 1007.39 9.87 OSF 1.50 Pass 12700.00 3584.35 -3433.21 -8605.22 12286.24 3598.89 -2808.87 -7831.60 41.15 1130.59 183.23 1008.11 9.30 OSF 1.50 Pass 12800.00 3586.81 -3368.49 -8881.41 12429.82 3594.85 -2513.88 -7939.16 40.77 1131.97 194.66 1001.87 8.76 OSP 1.50 Pass 12900.00 3589.27 -3303.77 -8757.61 12518.06 3590.64 -2455.51 -800521 40.44 1133.87 198.051 1001.604 8.62 OSF 1.50 Pass 13000.00 3591.17 -3239.01 -8833.78 12622.81 3585.52 -2386.39 -808348 40.16 1135.76 200.51 1001.76 8.53 OSF 1.50 Pass 13015.71 3591.20 -3228.82 -8845.74 12638.99 3584.82 -2375.59 -809576 40.18 1136.00 200.8'IIIMMOMME 8.52 OSF 1.50 Pass 13100.00 3591.20 -317408 -8909.83 12718.79 3581.72 -2322.90 -8155.63 40.02 1137.28 201.87 1002.37 8.48 OSF 1.50 Pass 13200.00 3591.20 -3109.14 -8985.87 12827.95 3578.03 -2250.65 -8237.36 39.84 1139.05 205.02 1002.04 6.37 OSF 1.50 Pass 13300.00 3591.20 -3044.19 -9061.91 12948.76 3575.57 -2172.19 -8329.19 39.71 1139.08 209.78 998.90 8.18 OSF 1.50 Pass 13400.00 3591 20 -2979.25 -9137.95 13037.87 3573.88 -2114.57 -8397.14 39.63 1138.76 210.41 998.16 8.15 OSF 1.50 Pass 13500.00 3591.20 -2914.30 -9213.99 13160 40 3573.33 -2035.62 -8490.84 39.60 1138.13 215.46 994.17 7.95 OSF 1.50 Pass 13600.00 3590.65 -2849.36 -9290.03 1327951 3574.76 -1961.10 -8583.75 39.73 113495 220.18 987.83 7.76 OSF 1.50 Pass 13700.00 3588.25 -278445 -9366.06 13379.18 3574.71 -1899.04 -8661.73 39.85 1131.46 222.47 982.82 7.66 OSF 1.50 Pass 13800.00 3585.81 -2719.54 -9442.09 13488.82 3572.48 -1831.09 -8747.76 39.87 1127.66 226.10 976.60 7.51 OSF 1.50 Pass 13900.00 3583.37 -2654.62 -9518.12 1359444 3571.29 -1766.32 -8831.17 39,94 1123.00 229.22 969.86 7.37 OSF 1.50 Pass 14000.00 3580.93 -2589.71 -9594.14 13700.08 3569.73 -1701.95 -8914.92 39.99 1117.85 232.41 962.58 7.24 OSF 1.50 Pass 14100.00 3578.11 -252480 -9670.16 13801.12 3569.77 -1640.55 -8995.16 40.18 1112.47 234.98 95545 7.13 OSF 150 Pass 14200.00 357459 -2459.89 -9746.15 13904.87 3572.64 -1577.90 -9077.81 40.52 1106.62 237.90 947.69 7.00 OSF 1.50 Pass 14300.00 3571.07 -239499 -9822.15 13990.22 3576.77 -1526.12 -9145.53 40.89 1101.26 238.42 941.9:IMMEER OSF 1.50 Pass 14400.00 3567.56 -2330.09 -989814 1405917 357895 -1483.03 -9199.30 41.1• 1098.1: 236.7: 940.06 6.98 OSF 1.50 Pass 14500.00 3564.04 -226518 -997414 14116.17 357939 -1445.98 -924261 41.26 1098.39 23345 942.43 7.08 OSF 1.50 Pass 14800.00 3560.59 -2200.27 -1005013 14175.77 357915 -140533 -9286.19 41.37 1102.68 23039 948.75 7.20 OSF 1.50 Pass 14700.00 3558.59 -2135.34 -1012616 14279.41 3581.04 -1333.75 -9361.10 41.60 1108.31 23337 952.40 7.15 OSF 1.50 Pass 14800.00 3556.71 -2070.41 -10202.18 14375.87 358341 -126702 -9430.71 41.81 1114.15 23555 956.79 7.12 OSF 1.50 Pass 14900.00 3554.83 -2005.48 -10278.21 14490.95 358273 -118787 -9514.23 41.88 1119.34 24042 958.73 7.01 OSF 1.50 Pass 15000.00 355295 -1940.54 -1035424 14625.12 3580.30 -1097.42 -9613.31 41.88 1122.76 247.85 957.20 6.82 OSP 1.50 Pass 15100.00 3551.12 -1875.61 -1043027 14747.89 357923 -1017.48 -9706.48 41.94 1122.96 253.65 953.53 6.66 OSP 1.50 Pass 15200.00 3550.87 -1810.67 -10506.31 1484674 3578.50 -953.67 -9781.96 41.91 1122.44 256.28 951.27 6.59 OSF 1.50 Pass 15300 00 3550.82 -174572 -10582.35 14964.83 3577.21 -878.01 -9872.63 41.85 1121.30 261.55 946.61 6.45 OSF 1.50 Pass 1540000 355077 -168078 -10658.39 1507820 3576.28 -80715 -9961.11 41.81 1118.07 26619 940.28 6.32 OSF 1.50 Pass 15500.00 3550.72 -1615.83 -1073443 15167.14 357545 -751.35 -10030.36 41.77 1115.19 267.68 93641 6.27 OSF 1.50 Pass 15600.00 3550.67 -1550.89 -1081047 15264.28 357468 -889.65 -10105.39 41.74 1113.30 27022 932.82 6.20 OSF 1.50 Pass 15700.00 3551.89 -1485.95 -1088650 15372.91 357272 -621.31 -10189.80 41.53 1110.60 27420 927.47 6.09 OSP 150 Pass 15800.00 3554.76 -1421.03 -10962.51 15475.19 3567.87 -557.20 -10269.34 41.13 1107.65 27760 922.25 6.00 OSF 1.50 Pass 15900.00 3557.62 -135612 -11038.52 15567.22 3562.93 -499.54 -10340.90 40.74 1104.73 279.65 917.96 5.94 OSF 1.50 Pass 16000.00 356049 -129120 -1111453 15666.85 3561.57 -436.38 -10417.92 40.52 1102.72 282.62 913.98 5.87 OSF 1.50 Pass 16100.00 3563.35 -1226.28 -11190.54 15766.91 3563.99 -373.36 -10495.60 4049 110019 285.67 909.42 579 OSF 1.50 Pass 16200.00 3564.95 -1161.35 -1126657 15861.97 3565.45 -31313 -10569.13 4053 1098.13 28816 90570 573 OSF 1.50 Pass 16300.00 356385 -1096.41 -11342.60 15951 40 3565.12 -256.09 -10838.01 40.57 1098.63 289.93 903.01 569 OSF 1.50 Pass 1640000 356255 -103147 -11418.64 16044.75 3563.05 -19576 -10709.22 4053 1098.21 29220 901.08 5.64 OSP 1.50 Pass 16500.00 3561.26 -966.53 -1149467 16150.32 3560.71 -127.60 -10789.80 40.48 1095.74 296.07 898.03 5.56 OSF 1.50 Pass 16600.00 3559.96 -901.59 -11570.71 1627611 3556.13 -47.68 -10886.82 40.32 1094.02 302.60 891.96 5.44 OSF 1.50 Pass 16700.00 3558.68 -836.65 -11646.74 16354.18 3553.26 1.58 -10947.31 4022 1091.72 302.95 889.41 5.424 OSF 1.50 Pass 16727.16 3558.55 -819.01 -11667.39 1637450 355216 1462 -10962.86 40.16 1091.4' 302.854 889.2 5.42 OSF 1.50 Pass 16760.70 3558.75 -797.23 -11692.89 16398.35 355072 30.06 -10980.98 40.0:1l'I 302.54 88945 5.42 OSF 1.50 Pass 16800 00 3559.21 -771.71 -11722.78 16425.92 3548.99 48.11 -11001.75 39.97 1091.83 302.17 89005 5.43 OSP 1.50 Pass 16900 00 3560.38 -706.77 -11798.82 16516.02 3543.00 108.21 -11068.59 39.61 1094.41 304.05 891.38 5.41 OSP 1.50 Pass 17000 00 3561.55 -641.83 -11874.85 16631.33 3536.98 184.04 -11155.24 39.22 1095.67 309.31 889.14 5.33 OSF 1.50 Pass 17100.00 3562.72 -576 89 -11950.89 16734.47 3538 19 251 74 -11233.03 39.22 1096.61 312.89 887.69 5.27 OSF 1.50 Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 7 of 65 Trajectory S135-W4(P5)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 Aam Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) 17200.00 3563.89 -511.95 -12026.92 16827.46 3543.94 312.71 -11303.00 39.47 1097.50 315.14, 887.08 5.24 OSF 1.50 Pass 17300.00 3564.76 -447.01 -12102.96 16912.57 3548,69 369.22 -11386.46 39.67 1099.51 31641 888.24 5.22 OSF 1.50 Pass 17400.00 3585.18 -382.06 -12179.00 17020.19 3552.62 441.47 -11446.13 39.85 1102.48 320.75 888.32 5.17 OSF 1.50 Pass 17500,00 3565.59 -317.12 -12255.04 17133.24 3556.25 515.92 -11531.11 40.02 1103.69 325.76 886.19 5.09 OSF 1.50 Pass 17600.00 3566.01 -252.18 -12331.08 17222.24 3558.83 574.54 -11598.03 40.13 110493 327.6 44I96 IIEE OSF 1.50 Pass 17700.00 3566.43 -187.23 -12407.12 17298.07 3560.48 62405 -1165277 40.20 1107.82 32744 88920 5.09 OSF 1.50 Pass 17800.00 3566.84 -122.29 -12483.16 17370.93 3562.47 675.75 -11706.87 40.28 1113.34 327.30 894.81 5.11 OSF 1.50 Pass 17900.00 3567.15 -57.38 -12559.21 17453 82 3564.15 733.77 -11765.77 40.35 1120.47 328.23 901.32 5.13 OSF 1.50 Pass 18000.00 3567.48 7.58 -12635.26 17523.82 3565.18 784.12 -1181468 40.39 1129.77 327.37 911.20 5.19 OSF 1.50 Pass 18100.00 3567.77 72.51 -12711.31 17599.92 3568.35 839.95 -11888.37 40,44 1141.44 327.24 922.95 5.24 OSF 1.50 Pass 18200.00 3568.09 137.44 -12787.36 17741.84 3570.01 943.53 -11962.99 40.60 1152.98 338.50 928.3 ZIER OSF 1.50 Pass 18300.00 3568.40 202.38 -12863.41 17831.89 3571.26 1008.29 -12025.85 40.65 1162.33 338.59 938.28 5.16 OSF 1.50 Pass 18400.00 3569.56 267.31 -12939.45 17916.81 3570.64 1069.85 -12084.34 40.64 1172.72 339.80 945.85 5.19 OSF 1.50 Pass 18500.00 3570.90 332.25 -13015.48 18059.23 3570.06 1171.56 -12184.00 40.52 1181.44 349.10 948.38 5.09 OSF 1.50 Pass 18800.00 3572.24 397.19 -13091.52 18172.81 356965 1251.06 -12265.11 40.42 1188.30 354.31 951,76 5.04 OSF 1.50 Pass • 18700.00 3573.58 462.13 -13167.55 18334.42 3567.08 1360.20 -12384.24 40.20 1191.70 365.40 947.77 4.90 OSF 1.50 Warning 18800.00 3574.92 527.07 -1324358 18447.55 356644 1434.49 -12469.55 40.09 11r.73 370.35 945.50 484 OSF 1.50 Warning 18900.00 3576.70 592.00 -13319.61 18544.84 3585.00 1497.11 -12544.00 39.9- iliENIT 3733 .1EY35 4.80 OSF 1.50 Warning 19000.00 3578.90 656.93 -13395.63 18623.90 3562.41 1549.22 -12603.40 39.73 1193.35 374.42 943.41 4.79 OSF 1.50 Warning 19100.00 3581.10 721.86 -13471.66 18751.56 3559.90 1633.44 -12699.29 39.48 1 9498 381.11 940.58 4.71 OSF 1.50 Warning 19200.00 3583.30 786.79 -13547.68 18849.14 3560.24 1696.08 -12774.10 08.3r IllilillICE 384.35 937.49 4.67 OSF 1.50 Warning 19300,00 3585.50 851.72 -13623.70 18943.62 3559.91 1757.68 -12845.74 39.28 119442 387.25 935.93 463 OSF 1.50 Warning 19400.00 3587.36 916.65 -13699.73 19045.87 356030 1824.18 -12923.41 39.20 119458 391.03 93356 4.59 OSF 1.50 Warning 19500.00 3587.75 98160 -13775.77 19143.24 3560.02 1887.52 -12997.35 39.17 1194.74 394.25 931.58 4.55 OSF 1.50 Warning 19600.00 3588.11 1046.54 -13851.81 19237.86 3562.99 1949.36 -13068.91 39.30 1195.26 397.0 =M:REg 4.52 OSF 1.50 Warning 19700.00 3588.48 111148 -13927.85 19317.68 3566.07 2002.03 -13128.80 39.43 1196.89 398.17 930.91.c OSF 1.50 Warning 19800.00 3588.85 1176.43 -14003.89 19395.17 3567.72 2054.40 -13185.89 39.50 1200.17 398.95 933.87 4.52 OSF 1.50 Warning 19900,00 3589.21 1241.37 -14079.93 19476.55 3569.88 2110.30 -13245.00 39.59 1205.20 400.14 938.12 453 OSF 1.50 Warning 19909.64 3589.25 1247.63 -14087.26 19483.82 3570.09 2115.34 -13250.23 39,60 1205.78 400.17 938.67 4.53 OSF 1.50 Warning End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 8 of 65 Field: Nikeitchuq Well: S132-W2 Structure: Spy Island Borehole: S132-W2 Slot: SP32 Trajectory: S132-W2 Client: Em Petroleum Type: Del Survey 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: 20.047° Magnetic Declination Date: March 08,2013 Magnetic Model: BGGM 2012 Reference Point: figlihing Eaatina flevatiog Structure Um Slot Unc 6053613.370(NUS) 511442.370(NUS) 53.620(N)MSL 0.000(N)(1 sigma) 0.000(N)(1 sigma) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pro.: Description MD From(N) MD To(H) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.520 Act-Stns SLB_NSG+MSHOT-Depth Only-No Global 16.000 SI32-W2/SI32-W2 40.520 821.880 Act-Stns SLB_NSGOMSHOT-No Global 16.000 SI32-W2/SI32-W2 821.880 2737.120 Act-Stns SLB_MWDOGMAG-No Global 16.000 S132-W2/S132-W2 2737.120 9259.750 Act-Stns SLB_MWDOGMAG-No Global 12.250 SI32-W2/SI32-W2 9259.750 18282.740 Act-Stns SLB_MWD+GMAG-No Global 8.750 SI32-W2/SI32-W2 18282.740 18350.000 Act-Stns SLB_BLINDOTREND-No Global 8.750 5132-W2/SI32-W2 Minimum Reference Traveling Cylinder Allowable EOU-EOU Controlling MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Palm Ct-Ct Distance Separation Clearance OSF Rule Statue (N) (N) (N) (N) (N) (N) (N) (N) (*) (N) (8) ON • All local minima indicated. Results filtered:Depth 11400.00 ft<=MD m 19910.00 N Results filtered:Ct-Ct separation 4=3000.001 Results highlighted:Ct-Ct separation 0=8240.00 N 11400.00 3573.16 -4273.05 -7617.72 9787.38 3629.66 -2602.54 -6131.89 32.30 2236 33 125.15 2152.57 27.01 OSF 1.50 Pass 11500.00 3579.77 -4222.24 -7703.59 9847.10 3628.64 -2562.47 -617625 33.89 2256.10 123.99 2173.11 27.50 OSF 1.50 Pass 11600.00 358450 -416687 -7786.71 9916.17 3627.65 -2515.31 -6226.71 38.72 2272.25 124.02 2189.24 27.69 OSF 1.50 Pass 11700.00 3587.20 -4106.77 -7866.57 9895.80 3626.95 -2460.32 -6284.30 39.71 2283.84 125.30 2199.98 27.54 OSF 1.50 Pass 11800.00 3587.86 -4042.15 -7942.86 10076 44 3826.84 -2404.28 -6342.28 42.88 2290.41 127.06 2205.37 27.24 OSF 1.50 Pass 11900.00 3586.82 -3973.97 -8016.01 10143.72 3626.94 -2356.91 -6390.07 4424 2293.50 128.17 2207.73 27.04 OSF 1.50 Pass 12000.00 3585.61 -3905.44 -8088.83 10263.34 3627.86 . -2272.28 -6474.59 4430 2296.69 133.67 220724 25.95 OSF 1.50 Pass 12100.00 358440 -3836.92 -8161.64 10454.41 3625.56 -2141.20 -6613.56 44.30 2296.46 145.17 2199.35 23.88 OSF 1.50 Pass 12200.00 3583.19 -3768.39 -8234.46 10558.00 3625.17 -2071.22 -6689.93 4432 2295.15 149.99 2194.83 23.10 OSF 1.50 Pass 12300.00 3581.98 -3699.86 -8307.28 10880.11 3835.92 -1865.27 -6937.06 4470 2290.45 171.78 2175.60 20.11 OSF 1.50 Pass 12400.00 3580.77 -3631.34 -8380.10 10962.87 3637.52 -1815.61 -7003.25 4477 2279.43 175.38 2162.18 19.60 OSF 1.50 Pass 12500.00 3580.04 -3563.30 -8453.38 11048.53 3637.56 -1763.62 -7071.32 43.32 2269.86 179.30 2150.00 19.09 OSF 1.50 Pass 12600.00 3581.89 -3497.93 -8529.02 11146.96 3638.62 -1703.61 -7149.33 41.71 2264.14 184.29 2140.96 18.52 OSF 1.50 Pass 12700.00 358435 -3433.21 -8605.22 11206.71 3838.10 -1668.94 -7196.50 41.66 2259.88 186.95 2134.92 18.22 OSF 1.50 Pass 12800.00 3586.81 -3368.49 -868141 11252.72 3837.52 -1637.82 -7232.12 41.621 2257.934 18860 2131.87 18.04 OSF 1.50 Pass 12900.00 3589.27 -3303.77 -8757.61 1131360 3636.33 -1598.25 -7278.37 41.55 2258.13 190.644 2130.711 17.854 OSF 1.50 Pass 13000.00 3591.17 -3239.01 -8833.78 11396.05 3633.32 -1543.80 -7340.20 41.51 2259.71 191.20 2131.92 17.81 OSF 1.50 Pass 13100.00 3591.20 -3174.08 -8909.83 11543.08 3629.34 -1447.49 -7451.23 41.47 2260.55 196.35 2129.32 17.35 OSF 1.50 Pass 13200.00 3591.20 -3109.14 -8985.87 11755.23 3627.40 -1315.79 -7617.50 41.42 2256.07 206.31 2118.20 16.47 OSF 1.50 Pass 13300.00 3591.20 -3044.19 -9061.91 11858.71 3625.64 -1252.86 -7699.62 41.38 2250.75 208.61 2111.35 16.25 OSF 1.50 Pass 13400.00 3591.20 -2979.25 -9137.95 11959.08 3621.84 -1192.51 -7779.73 41.28 2244.57 210.76 2103.74 16.04 OSP 1.50 Pass 13500.00 3591.20 -2914.30 -9213.99 12024.83 3617.71 -1152.34 -7831.62 41.18 2239.68 210.44 2099.05 16.03 OSF 1.50 Pass 13600.00 3590.65 -2848.36 -9290.03 12097.55 3613.28 -1107.15 -7888.41 41.10 2236.14 210.59 2085.42 16.00 OSF 1.50 Pass 13700.00 3588.25 -2784.45 -9366.06 12174.06 3609.94 -1058.89 -7547.69 41.07 2233.78 211.04 2092.76 15.94 OSF 1.50 Pass 13800.00 3585.81 -2719.54 -944209 12349.90 3809.12 -949.00 -8084.93 41.16 2230.97 218.74 2084.81 15.36 OSF 1.50 Pass 13900.00 3583.37 -265482 -9518.12 12518.08 3612.06 -848.77 -8219.93 41.35 2224.23 226.00 207323 1482 OSF 1.50 Pass 14000.00 3580.93 -2589.71 -959414 12673.74 3613.58 -759.93 -8347.72 41.49 2214.21 232.42 2058.94 14.34 OSF 1.50 Pass 14100.00 3578.11 -2524.80 -9670.16 12762.41 361126 -709.84 -8420.85 41.58 2203.62 234.11 204722 14.17 OSF 1.50 Pass 14200.00 357459 -2459.89 -9746.15 12829.32 3807.87 -671.50 -8475.59 41.55 2194.03 234.24 2037.55 14.10 OSP 1.50 Pass 14300.00 3571.07 -2394.99 -9822.15 12938.52 3603.00 -607.97 -8564.75 41.53 2185.29 237.43 2026.68 13.86 OSF 1.50 Pass 14400.00 3567.56 -2330.09 -9898.14 13042.41 3602.82 -548.56 -8649.47 41.63 2175 84 240.22 2015.36 13.64 OSF 1.50 Pass 14500.00 3564.04 -2265.18 -9974.14 13114.78 3803.57 -50.66 -870848 41.72 2166.99 240.82 2006.11 13.55 OSF 1.50 Pass 14579.48 3561.24 -221360 -10034.53 13158.51 3603.57 -480.89 -8743.80 41.76 2161.03 240.29 2000.51 ilgE$ OSF 1.50 Pass 14600.00 3560.59 -2200.27 -10050.13 13168.32 3603.52 -475.01 -8751.66 41.74 2159.73 240.03 1999.38 13 5 OSF 1.50 Pass 14700.00 3558.59 -2135.34 -10126.16 13216.23 3603.01 -445.73 -8789.58 41.72 2154.81 238.89 1595.35 13.59 OSF 1.50 Pass 14800.00 3556.71 -2070.41 -10202.18 13269.71 3602.07 -412.07 -8831.13 41.72 2152.19 237.85 1993.30 1362 OSF 1.50 Pass 14900.00 355483 -200548 -10278.21 13329.30 3600.86 -373.59 -8876.80 41,72 liipiarm 237.46 1993.04 13.64 OSF 1.50 Pass 15000.00 3552.95 -1940.54 -10354.24 13434.51 3600.71 -305.03 -8956.40 41.77 2152.01 240.54 1991.32 13.47 OSP 1.50 Pass 15081.87 3551.41 -1887.38 -1041648 13523.95 3601.79 -247.30 -9024.71 41.84 2151.61 243.351 1989.051 13.311 OSF 1.50 Pass 15100.00 3551.12 -1875.61 -10430.27 13534.50 3601.94 -240.47 -9032.74 41.85$ 2151.594 243.26 1989.10 13.32 OSF 1.50 Pass 15200.00 3550.87 -181067 -1050.31 13592.67 3602.88 -202.26 -9076.60 41.88 2152.61 242.75 1590.45 1335 OSF 1.50 Pass 15300.00 3550.82 -1745.72 -10582.35 13710.59 360.15 -124.14 -9164.86 41.97 215449 248.89 1989.57 13 14 OSF 1.50 Pass 15400.00 3550.77 -1680.78 -10658.39 13832.93 3610.13 -44.86 -9257.96 42.0: 251 43 1986.34 12 90 OSF 1.50 Pass 15500.00 3550.72 -1615.83 -10734.43 13923.64 3612.96 14.43 -932654 4215 2154.94 253.58 1985.56 12.79 OSF 1.50 Pass 15600.00 3550.67 -1550.89 -10810.47 14037.67 3615.47 88.48 -9413.21 4222 2155.02 257.57 1982.97 12.59 OSF 1.50 Pass 15700.00 3551.89 -1485.95 -10886.50 14136.19 3615.46 152.40 -5488.19 42.19jjjjjjjjilitiE 260.29 1981.03 12.46 OSF 1.50 Pass 15800.00 355476 -1421.03 -1096251 14213.98 3614.49 203.14 -8547.15 42.10 2155.18 261.6e I'.'.r 12.40 OSF 1.50 Pass 15900.00 3557.62 -1356.12 -11038.52 14295.93 3612.92 257.35 -9608.58 42.00 2156.63 263.24 1980.81 12.33 OSF 1.50 Pass 16000.00 3560.49 -1291.20 -11114.53 14375.24 3611.23 31013 -9667.76 41.89 2158 70 264.68 1981.9.lilililjljljljljljljjlEltii OSF 1.50 Pass 16100.00 3563.35 -1226 28 -1119054 14439 10 3609.80 35335 -9714.74 41.80 216226 264.94 198530 12.28 OSF 1.50 Pass 16200.00 356495 -116135 -11266.57 14494.04 360861 391.28 -975448 41.65 2167.71 26447 1991.07 1233 OSF 1.50 Pass 16300.00 3563.85 -1096.41 -1134260 1456410 360724 44068 -980413 41.59 217518 265.18 1998.07 12.34 OSF 150 Pass 16400.00 3562.55 -103147 -1141864 1469125 3604.85 53030 -9894.29 41.56 2182.79 27038 2002.21 1215 OSF 1.50 Pass 18500.00 3561.28 -966.53 -11494.67 14825.71 360422 623.38 -9991.33 41.59 2188.54 278.12 2004.13 11.93 OSF 1.50 Pass 16600.00 3559.98 -901.59 -11570.71 14928.12 3604.00 69349 -10065.96 41.61 2193.28 27943 20066 IIIIIIIIII1. OSF 1.50 Pass 16700.00 3558.68 -836.65 -11646.74 14995.08 3603.69 739.81 -10114.32 41.64 2198.99 280.02 2011.98 11.82 OSF 1.50 Pass 16800.00 3559.21 -771 71 -11722.78 15065.22 3603.20 789.05 -10164.28 41.70 2206.09 28061 2018.69 11.83 OSF 1.50 Pass 16900.00 3560.38 -706 77 -11798.82 15141.53 3602.13 843.29 -10217.93 41.64 2214.42 281.96 2026.1.04 OSF 1.50 Pass 17000.00 3561.55 -641 83 -1187485 15205.37 3800.07 889.10 -10262.35 41.57 2223.83 282.36 2035.26 11.85 OSF 1.50 Pass 17100.00 3562.72 -576 89 -11950.89 15248 89 3598.09 921.61 -1029241 41.50 2235 46 281.19 2047.67 11.96 OSF 1.50 Pass 17200.00 3563.89 -51195 -1202692 15305.78 3595.19 03.87 -10329.40 4141 224945 280.93 201.83 12.05 OSF 1.50 Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 10 of 65 Trajectory:5135-W4(P5)Vs.5132-W2 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-Cl Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (6) (n) (ft) (ft) (ft) (`) (ft) (ft) (fl) 17300.00 3564.76 -447.01 -12102.96 1540035 3592.50 1035.28 -10391.10 41.25 2264.60 283.70 2075.14 12.01 OSF 1.50 Pass 17400.00 3565.18 -382.06 -12179.00 15542.08 3591.55 1141.37 -10485.07 41.20 2278.36 290.19 2084.57 11.81 OSF 1.50 Pass 17500.00 3565.59 -317.12 -12255.04 15630.65 3590.67 1207.30 -10544.21 41.17 2291.60 292.59 096.2 11.78 OSF 150 Pass 17600.00 3566.01 -252.18 -12331.08 15941.01 3586.78 1430.45 -10759.66 4103 230240 311.7.11 -ZiE68 11.11 OSF 150 Pass 17700.00 3566.43 -187.23 -12407.12 1604841 3587.71 150358 -1083831 41.04 2306.61 315.55 2095.91 1..•• 051 1.50 Pass 1778646 3566.78 -131.08 -1247286 16126.65 3587.12 1556.84 -10895.62 41.02 2310.23 317.87 2097.9•MONOWET OSF 1.50 Pass 17800.00 3566.84 -122.29 -12483.16 16134.80 3586.98 1562.41 -10901.57 41.00 231086 317.93 2098.57 10.93 OSF 1.50 Pass 17900.00 3567.15 -5736 -12559.21 18194.92 3585.81 1603.93 -10945.03 40.97 2316.42 318.41 2103.62 10.94 OSF 1.50 Pass 18000.00 3567.46 7.58 -12635.26 18302.46 3583.52 1678.94 -11022.05 40.90 2322.96 32231 2107.7 inii OSF 1.50 Pass 18100.00 3567.77 72.51 -12711.31 18368.20 3582.51 1724.92 -11069.02 40.87 2329.76 323.15 211400 10.84 OSF 1.50 Pass 18200.00 3568.09 137.44 -12787.36 1652223 3581.92 1832.50 -11179.25 40.84 2336 54 33039 2115.96 1064 OSF 1.50 Pass 18300.00 356840 20238 -12863.41 16615.52 3581.77 1896.80 -11246.84 4083 2341 91 33331 211938 10.57 OSF 1.50 Pass 18400.00 356956 26731 -12939.45 1670402 3582.77 1957.99 -11310.77 40.87 2347.59 335.66 212349 10 OSF 1.50 Pass 18500.00 3570.90 332.25 -13015.48 16780.32 3583.94 2011.16 -11365.48 40.87 235401 337.33 2128.8.1i OSF 1.50 Pass 18600.00 357224 39719 -13091.52 1684039 3585.32 2053.60 -11407.96 40.88 2361.82 337.82 2136.28 10.51 OSF 1.50 Pass 18700.00 3573.58 462.13 -13167.55 1690213 3587.32 2097.94 -11450.89 40.91 237128 33839 214536 10.54 OSF 1.50 Pass 18800.00 357492 52707 -13243.58 16969.24 3589.35 2146.85 -11496.78 40.94 238228 33935 2155.72 10.56 OSF 1.50 Pass 18861.77 3575.86 567.18 -13290.55 17032.81 3590.52 219343 -11540.02 4100 2389.41 341.54 2161.3rI. a OSF 1.50 Pass 18900.00 3576.70 592.00 -13319.61 17059.75 3590.74 221318 -11558.34 40.99 2393.84 341.94 2165.56 1053 OSF 1.50 Pass 19000.00 3578.90 656.93 -13395.63 17100.01 3591.42 2243.12 -11585.24 40.98 2407.01 340,84 217945 10.62 OSF 1.50 Pass 19100.00 3581.10 721.86 -13471.66 17139.98 3592.70 2273.49 -11611.21 40.99 2422.59 33964 2195.84 10.73 OSF 1.50 Pass 19200.00 3583.30 786.79 -13547.68 17335.22 3596.96 2420.83 -11739.20 40.99 2437.39 35034 2203.50 10.46 OSF 1.50 Pass 19300.00 3585.50 851.72 -13623.70 17472.10 3599.00 2521.39 -11832.03 40.96 2449.09 356.55 2211.06 10.33 OSF 1.50 Pass 19400.00 3587.36 916.65 -13699.73 17563.92 3599.82 2588.62 -11894.57 40.84 2460.54 35946 2220.57 10.29 OSF 1.50 Pass 19500.00 3587.75 981.60 -13775.77 17671.80 3600.71 2667.78 -11967.85 40.83 2472.25 363.52 2229.57 1022 OSF 1.50 Pass 19600.00 3588.11 1046.54 -13851.81 1776722 3601.35 2737.49 -12033.01 40.83 2483.45 366.69 2238.66 10.18 OSF 1.50 Pass 19700.00 3588.48 111148 -13827.85 17856.63 3601.56 2803.12 -12093.72 40.83 2495.16 36943 2248.55 10.15 OSF 1.50 Pass 19800.00 3588.85 117643 -14003.89 17989.19 3603.92 2900.13 -12184.03 40.87 2506.64 37522 2256.17 10.04 OSF 1.50 Pass 19900.00 3589.21 1241.37 -14079.93 18094.58 3605.83 2976.46 -12256.68 40.90 2516.95 379.10 2263.89 9.98 OSF 1.50 Pass 1990964 3589.25 1247.63 -14087.26 18101.90 3605.96 2981.76 -12261.73 40.90 251795 37928 2264.7 9.9 OSF 1.50 Pass End of results • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 11 of 65 Field: Nikaitchuq Well: Tuveaq ST f Structure: Nikaitchuq Exploration Borehole: Tuveaq ST 1 Slot: Tuveaq ST 1 Trajectory: Tuveaq ST 1 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.05667531° Grid Seale Factor: 0.999900061 Magnetic Declination: 24.151° Magnetic Declination Date: February 15,2005 Magnetic Model: BGGM 2009 Reference Point: Realm EISLUDg J lavation Structure Unc Slot Unc 8050899.000(ftUS) 507330.900(NUS) 35.030(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 Fres' Survey Tool Type Hole Diameter(In) Borehole l Survey 0.000 32.890 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 Tuveaq ST 1/Tuveaq ST 1 32.690 2949.020 Act-Stns SLB_MWD*GMAG-No Global 30.000 Tuveaq ST 1/Tuveaq ST 1 2949.020 8882.810 Act-Stns SLB_MWD*GMAG^^2-No Global 30.000 Tuveaq ST 1/Tuveaq ST 1 8882.810 17830.000 Act-Stns SLB MWD*GMAG^^3-No Global 30.000 Tuveaq ST 1/Tuveaq 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 Aam Ct-Ct Distance Separation Clearance OSF Rule Status (0) (ft) (ft) (ft) (ft) (ft) (ft) (ff) (°) (0) (0) (ft) All local minima indicated. Results filtered:Depth 11400.00 ft<=MD<=19910.00 ft Results filtered:Ct-Ct separation<=3000.00 ft Results highlighted:Ct-Ct separation<=6240.00 ft 11400.00 3573.16 -4273.05 -7617.72 4774.91 3647.01 -1577.18 -6367.31 31.07 2972.65 139.55 2879.08 32.31 OSF 1.50 Pass 11500.00 3579.77 -4222.24 -7703.59 4867.28 3681.76 -1541.90 -6445.27 33.60 2962.76 140.07 2868.85 32.08 OSF 1.50 Pass 11600.00 358450 -4166.87 -7786.71 4951.50 371394 -1509.81 -6516.18 37.50 2948.05 140.71 2853.71 31.78 OSF 1.50 Pass 11700.00 3587.20 -4106.77 -7866.57 5022.66 3739.89 -1482.01 -6576.33 41.47 2928 72 141.27 2834.00 31.44 OSF 1.50 Pass 11800.00 3587.86 -4042.15 -7942.86 5103.86 3768.93 -1449.81 -6644.98 45.68 2904.73 142.68 2809.07 30.87 OSF 1.50 Pass 11900.00 3586.82 -3973.97 -8016.01 5181.58 3796.93 -1418.80 -6710.51 47.82 2877.04 144.21 2780.36 30.25 OSF 1.50 Pass 12000.00 3585.61 -3905.44 -8088.83 5241.51 3818.58 -1394.60 -6760.89 48.31 2849.92 14528 2752.52 29.74 OSF 1.50 Pass 12100.00 3584.40 -3836.92 -8161.54 5293.90 3837.59 -1372.86 -6804.60 48.75 2824.40 146.39 2726.27 29.25 OSF 1.50 Pass 12200.00 3583.19 -3768.39 -823446 5368.38 3864.60 -1341.31 -686642 49.37 2800.26 148.78 2700.53 28.52 OSF 1.50 Pass 12300.00 3581.98 -3699.86 -8307.28 5439.18 388998 -1310.95 -6025.13 49.96 2777.08 151.36 2675.63 27.80 OSF 1.50 Pass 12400.00 3580.77 -3631.34 -8380.10 5593.47 3941.99 -1243.91 -7053.97 51.20 275480 157.61 2649.18 26.47 056 1.50 Pass 12500.00 3580.04 -3563.30 -8453.38 5701.13 3977.19 -1198.89 -7145.21 50.40 2731 21 161.95 2622.70 25.54 OSF 1.50 Pass 12600.00 3581.89 -3497.93 -8529.02 5895.55 4044.54 -1122.63 -7310.86 50.11 2709 24 169.28 2595.85 24.22 OSP 1.50 Pass 12700.00 358435 -3433.21 -8605.22 5978.40 4074.34 -1091.93 -7381.80 50.80 2686.71 172.99 2570.85 23.50 OSF 1.50 Pass 12800.00 3586.81 -3368.49 -8681.41 6063.00 4105.32 -1060.58 -7454.02 51.52 2664.92 176.94 2546.42 22.79 OSF 1.50 Pass 12900.00 3589.27 -3303.77 -8757.61 6169.62 4145.46 -1021.77 -7544.85 52.47 2843.42 180.72 252240 22.13 OSF 1.50 Pass 13000.00 3591.17 -3239.01 -8833.78 6238.97 4172.12 -996.67 -7603.74 53.44 2622.70 180.25 2502.00 22.01 OSP 1.50 Pass 13100.00 3591.20 -3174 08 -8909.83 6315 44 4201.73 -968.63 -7868.42 54.31 2603.43 179.99 2482.90 21.88 OSF 1.50 Pass 13200.00 3591.20 -3109.14 -8985.87 6379.84 4227.05 -944.89 -7722.68 54.96 2585.33 179.36 248521 21.80 OSF 1.50 Pass 13300.00 3591.20 -3044.19 -9061.91 6432.44 4247.92 -924.93 -7766.64 5549 2569.10 178.38 244964 21.79 OSF 1.50 Pass 13400.00 3591.20 -297925 -9137.95 6566.02 4302.97 -875.72 -7877.94 56.90 2553.25 179.76 2432.87 21.48 OSF 1.50 Pass 13500.00 3591.20 -291430 -9213.99 6623.62 4326.86 -854.84 -7925.92 57.52 2538.21 178.90 2418.40 21.46 05F 1.50 Pass 13600.00 3590.65 -2849.36 -9290.03 6753.57 4378.09 -806.22 -8035.08 59.04 2523.76 180.27 2403.04 21.18 055 1.50 Pass 13700.00 3588.25 -2784.45 -9366.06 6811 60 4400.85 -784.61 -8083.89 59.71 2510.71 179 43 2390.55 21 17 OSF 1.50 Pass 13800.00 3585.81 -2719.54 -9442.09 8901 75 4436.12 -750.35 -8159.45 60.69 2489.17 179.57 2378.82 21 05 OSF 1.50 Pass 13900.00 3583.37 -2854.62 -9518.12 7005.05 4474.90 -710.73 -8246.62 61.80 2488.02 180.12 2367.40 20.89 OSF 1.50 Pass 14000.00 3580.93 -258971 -9594.14 7073.65 4501.49 -684.92 -8304.35 62.55 2477.74 179.55 2357.50 OSF 1.50 Pass 14100.00 3578.11 -252480 -9670.16 7169.60 4539.21 -648.49 -8384.69 63.69 2469.14 179.75 2348.77 20.78 OSF 1.50 Pass 14200.00 3574.59 -2459.89 -9746.15 7271.15 4577.31 -609.89 -8470.55 64.82 2460.72 18013 2340.10 20.66 056 1.50 Pass 14300.00 3571.07 -2394.99 -9822.15 7348.83 4606.96 -580.61 -8536.09 65.70 2453.36 179 77 2332.98 20.64 OSF 1.50 Pass 14400.00 3567 56 -2330.09 -9898.14 7424.08 4635.12 -551.47 -8599.51 66.54 2447.37 179.35 2327.2 OSF 1.50 Pass 14500.00 3564.04 -226518 -9974.14 7495.44 4861.83 -523.43 -8659.44 67 33 2442.80 178.82 2323.05 20.66 OSF 1.50 Pass 14600.00 3560.59 -2200.27 -10050.13 7600.54 4702.51 -482.78 -8747.40 68.51 2439.44 179.05 2319.54 20.61 OSP 1.50 Pass 14626.39 3559.98 -2183.14 -10070.20 7630.13 4713.90 -471.55 -8772.31 88.83 2438.36 179.10 2318.4211 20.591 OSF 1.50 Pass 14700.00 3558.59 -213534 -10126.18 7680.12 4733.04 -452.38 -8814.31 69.38 2435.70 178.51 2316.16 2054 OSF 1.50 Pass 14800.00 3556.71 -2070.41 -10202.18 7800 19 4778.49 -405.78 -8915.21 70.71 2433.11 179.08 2313.19 20.55 OSF 1.50 Pass 14900.00 3554.83 -2005.48 -10278.21 7905.63 4818.17 -366.50 -9004.65 71.89 2429.86 170.14 2309.90 20.52 OSF 1.50 Pass 15000.00 3552.95 -1940.54 -10354.24 8008.02 4856.86 -329.10 -9091.76 73.05 2427.10 179.08 2307.184 20.501 OSF 1.50 Pass 15100.00 3551.12 -1875.61 -10430.27 8100.52 4891.47 -295.42 -9170.66 74.09 2424.90 178.77 2305.18 20.52 OSF 1.50 Pass 15200.00 3550.87 -1810.67 -10506.31 8153.53 4911.45 -275.88 -9215.70 7466 ig1§M 177.5 IMMEZBE 2054 OSF 1.50 Pass 15300.00 3550.82 -1745.72 -10582.35 8205.34 4931.40 -256.30 -9259.31 75.23 2423.80 176.44 23.5.:4 20.78 OSF 1.50 Pass 15400.00 3550.77 -1680.78 -10858.39 8253.66 4950.39 -237.48 -9299.57 7575 2426.61 175.25 2309.24 20.95 OSF 1.50 Pass 15500.00 3550.72 -1615.83 -10734.43 830465 4970.78 -216.98 -9341.57 76.31 2431.75 174.13 2315.12 21.13 OSF 1.50 Pass 15600.00 3550.67 -1550.89 -10810.47 8364.24 4994.92 -192.43 -9390.21 76.95 2438.93 173.21 2322.92 21.31 OSF 1.50 Pass 15700.00 3551.89 -148595 -10886.50 8436.77 5024.44 -181.80 -9448.95 77.81 2447.11 172.45 2331.60 21.47 OSF 1.50 Pass 15800.00 355476 -1421.03 -10962.51 8515.88 5056.12 -127.43 -9512.77 78.58 2455.45 172.10 2340.19 21.59 OSF 1.50 Pass 15900.00 3557.62 -1356.12 -11038.52 8821.03 5097.03 -80.03 -9597.24 79.55 2464.85 172.32 2349.43 21.64 OSF 1.50 Pass 16000.00 3560.49 -1291.20 -11114.53 8736.05 5140.53 -28.90 -969065 80.60 2473.33 172.68 235787 21.67 OSF 1.50 Pass 16100.00 3563.35 -1226.28 .11190 54 8814.07 5169.54 6.44 -9753.86 81.29 2482.84 172.40 2367.17 21.79 OSP 1.50 Pass 16200.00 3564.95 -1161.35 .11266 57 8905.69 5203.08 49.17 -9827.64 81.94 2493.86 172.11 2378.58 21.83 0051.50 Pass 16300.00 3563.85 -1096.41 -11342.60 8071.03 5226.97 79.56 -9880.32 82.47 2507.42 170.93 2392.92 22.20 OSP 1.50 Pass 16400.00 3562.55 -1031.47 -11418.84 9030.37 5249.32 107.85 -9827.44 83.00 2523.27 169.57 2409.69 22.52 OSF 1.50 Pass 16500.00 3561.26 -986.53 -11494.67 9158.74 5296.30 169.68 -10029.66 84.12 253922 188.66 2426.24 22.79 OSF 1.50 Pass 16600.00 3559.96 -901.59 -11570.71 9319.79 5351.22 247.65 -10159.43 85.44 2553.64 168.04 2441.07 23.00 OSF 1.50 Pass 16700.00 3558.68 -836.65 -11646.74 9378.09 5371.40 275.11 -10206.73 85.95 2588.19 166.82 2456.44 23.30 OSF 1.50 Pass 16800.00 3559.21 -771.71 -11722.78 9488.73 5411.62 325.44 -10296.67 87.02 258243 165.51 2471.56 23.62 OSF 1.50 Pass 16900.00 3560.38 -706.77 -11798.82 9660.80 5474.49 398.22 -10439.33 88.56 2594.81 164.34 2484.71 23.90 OSF 1.50 Pass 17000.00 3581.55 -641.83 -11874.85 8761.91 5511.95 437.58 -10524.61 89.52 2606.21 162.95 2497.04 24.22 OSF 1.50 Pass 17100.00 3562.72 -576.89 -11950.89 9825.69 5536.11 461.82 -10578.37 90.13 2618.63 161.63 2510.34 24.53 OSF 1.50 Pass 17200.00 3563.89 -511.95 -12026.92 8909.14 5568.15 494.13 -10848.36 90.92 263243 160.29 2525.04 24.87 055 1.50 Pass 17300.00 3564.76 -447.01 -12102.96 9983.41 5596.55 523.01 -10710.63 91.58 2647.21 159.03 2540.65 25.21 OSF 1.50 Pass 17400.00 3565.18 -382.06 -12179.00 10042 38 5619.26 546.70 -10759.61 92 13 2663.93 157.91 2558.11 25.55 OSF 1.50 Pass 17500.00 3565.59 -317.12 -12255.04 10123 62 5650.53 580.34 -10826.63 92 85 2681.93 156.82 2576.85 25 91 OSF 1.50 Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 56 of 65 Trajectory:SI35-W4(P5)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 Asim Ct-Ct Distance Separation Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ff) (ft) (ft) (`) (ft) (ft) lit) 17600.00 356601 -25218 -12331.08 1021640 5685.90 618.54 -10902.92 93.65 2700.64 15576 259626 2626 OSF 1.50 Pass 17700.00 356643 -18723 -1240712 1034981 5736.56 674.56 -11013.39 94.81 2719.31 154.51 261576 26.86 OSF 1.50 Pass 17800.00 3586.84 -122.28 -1248316 10491.75 5790.80 72746 -1113349 96 11 2736.57 15280 263410 27.12 OSF 150 Pass 17900.00 356715 -57.36 -12558.21 10602.77 5832.74 766.55 -11228.48 9717 275364 15140 2652.17 27.56 OSF 1.50 Pass 18000.00 3567.46 7.58 -1263526 10700.08 586891 801.24 -11311.88 98.07 277090 150.07 267031 27.98 OSF 1.50 Pass 18100.00 3567.77 72.51 -12711.31 10787.66 590127 832.64 -11386.96 98.87 2788.71 148.88 2688.91 28.39 OSF 1.50 Pass 18200.00 3568.09 13744 -12787.36 1087427 5933.55 863.16 -11461.32 99.66 2807.22 147.72 270820 2880 OSF 1.50 Pass 18300.00 356840 202.38 -12863.41 10991.89 5977.59 902.80 -1156293 10076 2825.96 146.18 2727.97 29.31 OSF 1.50 Pass 1840000 356956 267.31 -12939.45 11064 32 6005.00 928.02 -11625.81 101.50 2844.45 144.93 2747.29 29.75 OSF 150 Pass 18500.00 3570.90 33225 -1301548 1113384 6031.86 947.85 -11688.10 102.16 2864.00 143.97 2787.48 30.18 OSF 1.50 Pass 18600.00 3572.24 39719 -13091.52 1122984 606933 977.85 -1176924 103.07 2884.62 142.89 2788.95 30.65 OSF 1.50 Pass 18700.00 3573.58 462.13 -13167.55 1134526 6113.49 101365 -11869.69 10415 2905.12 141.19 281046 31.20 OSF 1.50 Pass 1880000 357492 527.07 -1324358 11437.30 6147.87 1043.82 -1194964 104.96 2925.81 140.15 2831.83 31.66 OSF 1.50 Pass 18900.00 3576.70 592.00 -13319.61 1153180 6181.98 107651 -12031.06 105.79 294682 139.09 2853.36 32.13 OSF 1.50 Pass 19000.00 357890 65693 -1339563 1162813 6216.71 1110.80 -1211445 106.57 296740 138.26 2874.69 32.56 OSF 1.50 Pass 19100.00 3581 10 72186 -13471 66 1170840 624556 113927 -12183.74 107 20 2988.70 137 70 2896.36 32.93 OSF 1.50 Pass End of results Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SI35-W4\SI35-W4\SI35-W4(P5) 6/20/2013 2:02 PM Page 57 of 65 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 ItZ 8-1/2" Offen Hole / -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 II 6N 1 C W ci �mo � N r * - Yp' Z N a !3 D NO Y Lu Z a J N W o K d w o J li pi Q Et m W Q Y O 0 d D \. • W J y Ri > a � o 1- z d z . O• . O• O:; :Q• a ¢ � m Y U m m 1- Q N M a LO CD r gi O Z m coM 0 Q oQ a O0 '0 - L., ! 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Calculations are estimates based on providec information.All proposal&recommendations.or predictions are opinions only. ND WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTIVENESS OF MATERWI,PRODUCTS OH SUPPLIES RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual pronely rights we granted hereby Mark of Schlumberger Page 1 5135-W4.cfw;0619-2013; Loadcase 13 3/Bin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI35-W4 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 3237.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000)psi < 1 2 J — L . Frac I- - •Pore SV-4 t-, V.• • I i SV-3 • • _ SV-2 _ I B! Permafrost 1 j . N • SV-1 ` • 1 : Ugnu Top (UG4) TD - o i tr- Well Lithology Formation Press. Page 2 S135-W4.cfw;0-19-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cenr472_05 Client : Eni Petroleum Well : SI35-W4 SctIhrger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 3157.0 ft Casing/liner Shoe MD : 3237.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 3237.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 122.7 % Mean OH Equivalent Diameter: 18.724 in Total OH Volume : 1047.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1900.0 16.000 190.0 20.063 3237.0 16.000 35.0 16.822 Max. Deviation Angle : 70 deg Max. DLS : 3.788 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (Ib/gal) 771.0 11.70 8.40 SV-4 Siltstone 1160.0 11.50 8.40 SV-3 Sandstone 1482.0 11.50 8.40 SV-2 Siltstone 1900.0 11.50 8.40 B/Permafrost Shale 2240.0 12.00 8.40 SV-1 Sandstone 2736.0 12.50 8.40 Ugnu Top(UG4) Shale 3237.0 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 1749.6 32 0.7 3237.0 2453.9 50 1.2 Page 3 S135-W4.cfw;0619-2013; LoadCase 13 3/Bin Surface Casing;Version wcs-cem472_05 f f 1 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/Bin Surface Casing • Section 2: fluid sequence Job Objectives: Cement Surface Casing with Returns Seen at Surface Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty:0.48 lbf/100ft2 1 Displacement Volume 472.7 bbl Total Volume 1121.8 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Surface Lead 486.1 2732.4 0.0 10.70 k:1.23E-1 Ibf.s^n/ft2 n:0.268 Ty:1.22 lbf/100ft2 12.5ppg DeepCRETE 63.0 504.6 2732.4 12.50 k:1.68E-1 Ibf.s^n/ft2 n:0.301 Ty:0.44 lbf/100ft2 Surface Tail Mud 472.7 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 2014 psi at 3157.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 60 ton Check Valve Diff Press 170 psi ft (x 1000) psi 0 2 -Hydrostatic -Frac - -Pore 0 1 N _ i 0 I ! - ` . 1 i 0 0 0 tr- Fluid Sequence Static Well Security Page 4 SI35-W4.cfw:06-19-2013; LoadCase 13 3/8in Surface Casing Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/Bin Surface Casing Section 3: pumping schedule - Spacer/Cement Max Rate is 7-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 8.5-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 Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 0.0 0.0 80 Line Up Cement Unit Surface Lead 5.0 486.1 97.2 486.1 80 Mix/Pump Lead Slurry(3-7 BPM) 12.5ppg DeepCRETE Surface 4.0 63.0 15.8 63.0 80 Mix/Pump Tail Slurry(2-7 BPM) 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 3.0 5.0 1.7 5.0 80 Kick Out Plug with Cement Unit Mud 8.5 457.7 53.8 462.7 80 Lineup Rig Pump Mud 2.0 10.0 5.0 472.7 80 Slow Rate for Plug Bump Shut-In 0.0 0.0 3.0 0.0 80 Bleed off and Check Floats Total 03:22 1121.8 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 5 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2014 psi at 3157.0 ft Burst 4748 psi at 0.0 ft Temperature Results BHCT 80 degF Simulated Max HCT 68 degF Simulated BHCT 68 degF Max HCT Depth 3237.0 ft CT at TOC 59 degF Max HCT Time 03:22:28 hr:mn:sc Static temperatures: At Time (hr:mn) 00:03 hr:mn Geo.Temp. Top of Cement (degF) 59 degF 1 20 degF Bottom Hole (degF) 68 degF 50 degF Page 5 5135-W4.cfw;06-19-2013; LoadCase 13 3/Bin Surface Casing;Version wcs-cem472.05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing 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%2 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 SI35-W4cfw;06-19-2013; LoadCase 13 3/8in Surface Casing Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 13 3/6 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Casing Shoe during Placement o Depth= 3237 ft cri Frac ?- Fbre Hydrostatic Dynamic -.. — o - yy�yy�1•� _ t to• � :: : : =�: : : :: ------,---'— '— 111111.111111.1111111111.1101. Caly ag. __y__ __ _ . lii _ 0i11'°� �m1iiw■iili .� �, =Cal =iiy_ar_il _ y _ -- = •_ �iiymi yy��=! _r 1 , .E 5IErnm p_0 EMI III WMc 1_ _ 1___1__ �� , __ rn- r— rn -_: _-_______—�,_ — Ln 00 I I �- ! 11T-f-1 . o L + i ! i I i � �, 1 1 -- i-T! I �- 1- 1- i Iia 1 ( 7 do I r r r r r r r r r r 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 7 SI35-W4.cfw;0619-2013; LoadCase 13 3/8in Surface Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Previous shoe during Placement O Dpth= 160 ft csi Frac I, ' i i Rxe _ _�__. I w _ �_ �.._!_J__fi I._.1 € 1__l_.�_..�_.� cfl - Hydrostatic I - ynaMc - j i 7 t 1 _ as Tr 1 . m�co__ f ---' 1-1, -,-,- ' ......,_ ... . 2 a� U ` C 6- J 0) ._. �...___. 1 { ca 1 O W f r r r r r I r r r r i 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 8 SI35-W4 cfw;06-19-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : Sl35-W4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Load case : 13 3/8in Surface Casing Simulated Surface Pressures during Placement 0 O — Calc.Pump Press. Calc.CemHP 44lul O ! 1111O- 1 1111 _4 O O 1 IIIalr) �1 r u,0 I 1 I 11_ rno I M I , t--- o -_O I I I CV - - t O 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 9 SI35-W4.cfw;O6E19-2013; LoadCase 13 3/tin Surface Casing;Version wcs-cem472._05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatures during Placement -o 1— Last Sack Term First'-ck Temp. Ln CO API B T N■11111 m O 11111 _111111111111111111 1 ■■■ ■�� ■ ■ u - -E iiTN- Ina■ 111111111191191111111111111191"11 ■ -12- Rd 111 NM II I Ili J____ z;:s 'ils- i in! ipinipp i .,_ L, ,... ■ ■., ■a • 11 ----1 -::Loi dm_,,) i ■ ■■■ ■ , ■■ ■■■ ■■ ■1.1 1 _N■■■■ ■■ ■■■I.. ■ ■■ ■■ .s_ IiiIIIiiIIIIIigIIIIIiIiIIINIII1Ii!iI1 i!' ■ 1'91 ' 11u11d J■■IIN1 ' ■ _ O `( O 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 10 SI35-W4.cfw;O6-19-2013; LoadCase 13 3/8in Surface casing Versien wcs cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatures up to 24hours after Placement Lo °o - Last Sack Temp. I_O - First Sack Temp. • _LO CI. API BHCT co- __� O I . . . _Lo o Lo a � J - _ti -i ', o o O a _N O c6 0 CL Lo Ln- - N _ _N a MI .111 LA i ': : � I N A _ NO O _ O t r r r r r r t M 0 250 500 750 1000 1250 1500 1750 Time (min) Page 11 SI35-W4.cfw:06-19-2013: LoadCase 13 3/tin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 ScI��r String : 133/8 Surface Casing District : Prudhoe Bay �p Country : USA Loadcase : 13 3/8in Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo.Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.262 Ty :0.48 lbf/100ft2 Gel Strength :6.40 Ibf/100ft2 MUD Mud Type :WBM Job volume :472.7 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04Ibf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl 12.5ppg DeepCRETE Surface Tail DESIGN Fluid No:3 Density : 12.50 lb/gal Rheo.Model : HERSCHEL_B. k : 1.68E-1 Ibf.s^n/ft2 At temp. :74 degF n :0.301 Ty :0.44 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid :5.471 gal/sk Job volume :63.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity :226.05 sk Sack Weight : 100 lb Solid Fraction :53.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.471 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Page 12 S135-W4.cfw;06-19-2013; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 SMini String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Surface Lead DESIGN Fluid No:4 Density : 10.70 lb/gal Rheo.Model : HERSCHEL_B. k : 1.23E-1 Ibf.s^n/ft2 At temp. :70 degF n :0.268 Ty : 1.22 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name :ASL B439(53) Mix Fluid : 11.496 gal/sk Job volume :486.1 bbl Dry Density : 110.16 lb/ft3 Yield :2.44 ft3/sk Quantity : 1116.52 sk Sack Weight : 100 lb Solid Fraction :37.1 % BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 11.446 gal/sk Additives Code Conc. Function D185 0.050 gal/sk blend Dispers. LT Page 13 S135-W4.cfw;W19-2013; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3217.0 ft Casing Shoe :3237.0 ft NB of Cent. Used :32 NB of Floating Cent. :15 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 1877.0 15 1/3 NW-ST-13 3/8-8-ST A3B W131 0.0 1797.0 3237.0 17 1/2 NW-ST-13 3/8-8-ST A3B W131 15.3 3097.0 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 70 0 60 80 100 — Between Cent. I J} - I _+ 4At Cent. } + I ir $ ' 1 i 11 ■I i 1 0 III_ . I Pipe Standoff Page 11 5135-W4.cfw;W19-2013: LoadCase 13 3/8in Surface Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Shcllmerger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 6: WELLCLEAN II Simulator It % % o_ 0 50 100 I I 100 – Std Betw.Cent. -{ —Mud Contaminati:- 1 —Cement Coverage —Uncontaminated 5,..rry - I .P.— Ft- Ir- 0 o_ N I1 .�.. 1111111 O Cement Coverage Uncontaminated Spy 3 z 3 3 i 0 0 0 0 500 500 500 t 500 1000 1000 1000 i 1000 1500 Mr 1500 '" " 1500 - 1500 0 2000 •- -2000 0 0 2000 2000 0 2500 1 2500 2500 2500 3000 41. 1 A 3000 3000 I -3000 w ; w d ; m 13 3 3 t 0 0 Z z Page 15 SI35-W4.cfw;0619-2013: LoadCase 13 3/8in Surface Casing:Version wcs-cem47Z_05 Client : Eni Petroleum Well : SI35-W4 Sairr String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing 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 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 Surface Lead Volume:486.1 bbl Density : 10.70 lb/gal Yield :2.44 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 305.6 bbl 10.0 bbl LAS Design ASL B439(53) 111651.953 Fresh water 304.274 bbl 9.958 bbl lb D185 55.826 gal 1.827 gal 0.050 gal/sk blend Page 16 S135-W4 cfw;%-19-2013: LoadCase 13 3/ein Surface Casing:Version wcs-cem472_05 Schlumberger CerCAD E*well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : S135-W4 Country : USA State : Alaska Prepared for : Lara Occhionero Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 6/19/2013 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (9071273-1765 E-Mail Address : slauper©slb.com +;7 .�G 4UATE Disclaimer Notice: • Schlumberger submits this document with the benefit of its Judgment,experience,and good oilfield practices. This information is provided in accordance with genera ity accepted industry practice.relying on facts or information provided by others,Imitations,computer models,measurements,assumptions and inferences that are not infallible Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CON:FFNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPI IFS.RECOMMENDATIONS MADE,OF RESULTS OF THE SERVICES RENDERED Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby Mark of Schlumberger Page 1 S135-W4.clw;05-19-2013; LoadCase 9 Win Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 11347.0 ft BHST : 90 degF Bit Size : 12 1/4 in ft (x 1000) psi o_ < a0 2.5 —Siltstone— ■ 'e - [lk ) IZIMINIMMINIZI MIN 1111.=M=MMIPIINIM NM II- ZEE=III= 1. o Shale nr t . 1 • . tib_ Shale a It Shale I co SII i II • • • •Sandstone. • • • o - • • • 'Sandstone' • • • 111a 1 i CN V,/ell Lithology Formation Press Page 2 S135-W4.cfw;06-19-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlrger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/Bin Intermediate Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 3237.0 13 3/8 68.0 12.415 Landing Collar MD : 11267.0 ft Casing/liner Shoe MD : 11347.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 11347.0 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 : 1408.4 bbl (including excess) Max. Deviation Angle : 86 deg Max. DLS : 3.770 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 771.0 11.50 8.40 SV-4 Siltstone 1160.0 11.50 8.40 SV-3 Sandstone 1482.0 11.50 8.40 SV-2 Siltstone 1900.0 11.50 8.40 B/Permafrost Shale 2240.0 12.00 8.40 SV-1 Sandstone 2736.0 12.50 8.40 Ugnu Top(UG4) Shale 4544.0 12.50 8.40 UG-2 Coal Bed Shale Marke 8094.0 12.50 8.40 Lower Ugnu Shale 9254.0 12.50 8.40 Schrader Bluff Top Shale 9528.0 12.50 8.40 N Sequence Top Sandstone 9736.0 12.50 8.40 N Top Sandstone 10038.0 12.50 8.40 N Bottom Sandstone 10616.0 12.50 8.40 N Sequence Base Sandstone 11347.0 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 1900.0 1678.0 32 0.7 3610.0 2566.4 50 1.2 11347.0 3569.5 90 2.0 Page 3 SI35-W4.cfw;06-19-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 8736'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Tv:8.86 lbf/100ft2 Displacement Volume 854.3 bbl Total Volume 1179.3 bbl TOC 8730.4 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 7535.3 10.50 k:5.23E-2 lbf.s^n/ft2 n:0.324 Ty:12.92 lbf/100ft2 12.5ppg DeepCRETE 225.0 2616.6 8730.4 12.50 k:4.89E-3 Ibf.s^n/ft2 n:0.960 Ty:15.95 Ibf/100ft2 Mud 854.3 0.0 9.50 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 382 psi at 3237.0 ft Pore 140 psi at 3237.0 ft Collapse 2890 psi at 11267.0 ft Burst 5750 psi at 0.0 ft Csg.Pump out 59 ton Check Valve Diff Press 55 psi ft (x 1000) psi o_ 0 2.5 Hydrostatic —Frame Poe 0 o a' o— o � - Fluid Sequence Static Well Security Page 4 5135-W4 cfw;06.19-2013: LoadCase 9 5/tin Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI35-W4 5chihrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 3: pumping schedule - Spacer/Cement Max Rate is 7-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 8.5-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 Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Line-up Cement Unit 12.5ppg DeepCRETE 6.0 225.0 37.5 225.0 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 8.0 854.3 106.8 854.3 80 Kick Out Plug w/Cement Unit Pause 0.0 0.0 5.0 0.0 80 Line up Rig Pumps Shut-In 0.0 0.0 5.0 0.0 80 Bleed Off/Check Floats Total 03:00 1179.3 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 176 psi at 11347.0 ft Pore 140 psi at 3237.0 ft Collapse 2746 psi at 128.5 ft Burst 5307 psi at 0.0 ft Temperature Results BHCT 85 degF Simulated Max HCT 90 degF Simulated BHCT 73 degF Max HCT Depth 11347.0 ft CT at TOC 72 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time 12:00 hr:mn 24:00 hr:mn Geo.Temp. Top of Cement 76 degF 76 degF 1 78 degF ° Bottom Hole 86 degF 89 degF 90 degF Page 5 SI35-W4 ctw;06.19-2013; LoadCase 9 5/tin Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing 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%2 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 S135-W4.ctw;06-19-2013: LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Casing Shoe during Placement o Depth= 11347 ft ri I—. Frac ,- Fbre ! 1 j 1 1._.1 14 iTri._1 LIT L ; , . rr? 1 ._1-7-1-1-1- `\i — Hydrostatic Ir_ Dynamic oa -- a Iwo-111111111111 ! r n»�� onimmi�mi .. - -." aaaa aaaaaaaaaaa _ Lq __---. -aaa aaa aaaaaa-; =anal: -_ _ ___ aaaa :ia imam ___ _ aaaaaa aaaaaaaa= ;Lc) . _ a - 'sate. o- , 11111111111111111111111111111111111141111MIN w aa� a= ai aaaaaaaaaaaaaa- aaaa=� s l .. o- r �111rrr a_a_a_� .Q oo C. Co I 1 I I 1 I r 1 1 I 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 7 SI35-W4.ctw;O6-19-2013; loadCase 95/tin Intermediate Casing;Version wcs-ceni47205 Client : Eni Petroleum Well : S135-W4 Schi hrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Previous shoe during Placement o D pth= 3237 ft M — Frac Pore Lo Hydrostatic N Dynamic Lo I 1 jt w o- d p Lo cn o Lo co r 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 8 Si35-W4 ctw;Of-19-2013; LoadCase 9 5/8in intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Surface Pressures during Placement o cV --- Calc.Rtmp Press. j j ' ^ i t - Calc.CemHP { t °° _+TJ .::::____ , 111111111 .. — ■iimi i 6' III iiia _ c.„!_ _ _ 1ii- - i111111111111111111 ate_ h., I-. ._ _ 2 co -_-- t ii _ 0_o_ _ D IN __.t , CD m _ 1 v .- _ ____ . , _______ _ _ , —N O _ 7/,....7.------- i i , . 11 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 SI35-W4.cfw;06-19-2013, LoadCase 9 5/8in Intermediate Casing;Version wcs-cem412_05 Client : Eni Petroleum Well : S135-W4 SGhlumherger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures during Placement co o I— c° Last Sack Temp. { First Sack Temp. ----- — A u7 c0� All BHCT I •;a,.ewn ,«m, N __ O -- - O . allill ,._..._ �_.__ r O o us 00- -- _ i i j i o - : _._ ci) j , o = _ o _ �� •o N � . OO �o _ d v o o CDN ■ O N N O L r r r i t i t r r r M 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 10 SI35-W4.ctw:06-19-2013: LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures up to 24hours after Placement co _O W — Last Sack Temp. — First Sack Temp. -- ��M �lwtimtiIMPI.i• in � - ' _N ,z1— AR BFiCT CO 1!! .. ■ ►_� �� O 1 _rp Illiiliall_ O 111•111•11111111 III - o imommisi _0 cr> MAI 11111111 II MINS in 0 N � . Ls O __, I ::Z.' UCO 1 II �� 1 , r- N O 11111111111111 1I1IH a�- (O N _N 111111111 CO— N 0 : ..._....:::i -- "MO- N N O L 1 r r r r r i t M 0 250 500 750 1000 1250 1500 1750 Time (min) Page 11 SI35-W4.ciw;06-19-2013; LoadCase 9 578in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SI35-W4 Schlmnkrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.97E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.616 Ty :8.861bf/100ft2 Gel Strength :32.02 Ibf/100ft2 MUD Mud Type :WBM Job volume :854.3 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.23E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.324 Ty : 12.92Ibf/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 : 15.95 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid :5.471 gal/sk Job volume :225.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity :807.32 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 SI35-W4.cfw;Ot-19-2013: LoadCase 9 5/tin Intermediate Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : S135-W4 Schlumberger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/bin Intermediate Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :11327.0 ft Casing Shoe :11347.0 ft NB of Cent. Used :65 NB of Floating Cent. :65 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 8747.0 0 0/0 0.0 8765.3 11347.0 65 1/1 HYDROFORM HFD 50.0 11347.0 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) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford(1) N.A. N.A. N.A. ft 0 20 0 60 80 100 i Between Ce^1 1 f I - + .l At Cant. oO I . i� O O O C=' I 1 •_ . 1.- -_ --- _ I 1 O _ StandoffNI Pipe Page 13 5135-W4 clw;06-19-2013: LoadCase 9 5/Sin Interrnediate Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : S135-W4 ScIllierger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 6: WELLCLEAN II Simulator ft % % o– 0 20 40 60 80 100 0 20 40 60 80 100 p —Std Betw.Cent. -Mud Contamination O -Cement Coverage -Uncontaminated Slurry cg � – O O N Cement Coverage Uncontaminated Slurry z 3 3 z 8500 ) 8500 8500 8500 9000- 9000 9000 =, ' 9000 9500- 9500 9500 9500 4- 4- 4- 4- a 10000- 10000 a a 10000 10000 a a) m a) .' m o - o 0 0 10500- 10500 10500 " 10500 11000- 11000 11000 " 11000 en 3 at m 3 a) -a o - -o o -o 3 i 3 3L.. o 0 Z z MW qLw. ypcDec11T[ MNmh. N. MUDPUSH II Page 14 SI35-W4 clw:06-19-2013: loadCase 9 5/ein Intermediate Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : SI35-W4 Schi hrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume: 100.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.200 gal/bbl of spacer D182 543.750 lb 6.000 Ib/bbl of base fluid 0031 11722.021 lb 117.22 Ib/bbl of spacer 12.5ppg DeepCRETE Volume:225.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 105.2 bbl 10.0 bbl LAS Design 12.5-0.82-53 80732.016 lb Fresh water 105.159 bbl 10.001 bbl D046 161.464 lb 0.200%BWOB D065 201.830 lb 0.250%BWOB D167 201.830 lb 0.250%BWOB D153 80.732 lb 0.100%BWOB Page 15 SI35-W4 cfw:06-19-2013: LoadCase 9 5/tin Intermediate Casing:Version wcs-cem472_05 REV DATE BY (X OP : DESCRIPTION BEV DATE BY CK APP DESCRIPTION a i0/0710 is CC CC .rit,c D'ow;-g VICINITY MAP SCALE: 1" , ; V . r(._ 1 7 _ i:, 1 1.,:. 14 • , , , , „ , , p N h go 23 . 11 - 11 ...:S-- ..‘', ,4 19 2) THIS - SURVEY ;, 1 - i I I . Oc L4" 1d1 I 114N , . Ti 4NI I - - ii 3N I T13N ..habx PoIs-DAD,. OliVtr . t. 1 4 • , 0 - -•, DV Os -4- ' ‘ill s. t; ,' li".".•1S-6R •?. 1 Li l'• 1 11 \ 1' I 7 .4;• y y .\ .tc' ,i . I • - --•-/-- ra M.,-4: -' ---- ---4-144---- -1-47,-,.'---'r"-ri --' ...,N• 1 s 'i DS-30 .,_,inits-4/.=4, t*.__<:PtiDk;1 '' • - ''.1 -'0 i 1 O\ k, • (4. -* ' "") \I r \--;—• \ p Mi e Si T .. ' - , , 1. \VI 3-,,i ., c9 n i. • , io i ) "VIIP PAD OA .4 2 S 27,—730:,-7.st flit le18 L',7', .,., 30.,..'„1/4."...i -...-1(13 IrsD..)saN,..,t•L1 g7ihiN.,k,11,A,N8 tM,__e.(.i,t3p,-,1,''f'k'-I‘-i:-,3'-11\.\.. '`s•1-1/2,4,nt—. '',,..6-- "-1.,\r..i..,i'PyIAe'3s0 t-0,7s'‘(m'...1.:?..- „,tiIIi5,„•,011..,1' 1 - ,- u -4 ,t,4k •4> DRAWING NOTES: 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NADE53. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. .3. BASIS OF LOCATION DERIVED FROM CPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT [-087 =OR COORDINATE VALUES IN NAD27. vialigilikliklos 41A4 oF .41114 ••41--............. 4.47 ‘>;.•.... ., c-,, ., ,,'........58.• .., • SURVEYOR'S CERTIFICATE 100 4/ 49 t h \* #0# 0 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED r AND 0 - , . LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 0, 1-,-Ift:::: :.:I..40,.."..tZuvgy“.. ....P ALASKA AND 77-IAT THIS PLAT REPRESENTS A SURVEY r T.,-}g. rn 1 FRANCIS 6. CORNING i fi DONE BY ME OR UNDER MY DIRECT SUPERVISION ANDOA G:1, % •••• a LP ' 6115 it THAT ALL. DIMENSIONS AND OTHER DETAILS ARE CORRECT • -." %. LS-10 e` 4- "C ' , 4 AS OF OCTOBER 0ti,%., kolIto ip 1, 2010 mo 6, *.•.............. ,t, iir kh ,9,v1.r 41 4Ess to0-,,.....• "olltrawaato'- 10* vi&o.rt -11..,, N, 01i, SPY ISLAND DRILL SITE WELL CONDUCTORS 4 . • AS—BUILT LOCATIONS Da rni[1 ',-'/.:;;;,..;1CAD FILE:EN135431:9 us operaigeng DATE10/7/20'0 DRAWING NO. PART: Eni-3543-d9 1 REV:1 OF 3 0 . REV DATE I BY CK ' APP DESCRIPTION REV' DATE BY CK APP DESCRIPTION i .1_ ;',.* /. ,i' CC CC '' r ',l N .S. Q� c.) cps `CI .r-r its i\ SP1 17 ....41 Sr \'' 5‘.'f. .9 ',.! (:''. -1.1 U, I-P+ 1 A P. NAL* . 14. .+ /,/ r CP W ' OR` CA_ bN U NN O© ' N o °' Ix CA al P. DETAIL A. SCALE: 1"=8O' 1 GRP, SNCN�E�t r \,, S .v.3 •O'..vElo Gam•off°" '`I w ey wYe DETA:L A �, �A t. SPY ISLAND DRILL SITE (SID) .l--- 1tiI 1 ` n 5tiyotytpE \ r-------__--____ DE LEGENC SCALE 2 0 C 100 200 0 = WELL CONDUCTOR AS—BUILT THIS SURVEY 1" - 200' rii,* $. � a � SPY ISLAND DRILL SITE r WELL CONDUCTORS � AS—BUILT LOCATIONS 211 11il .ht . CAD FILE:EN1354309 us D"©peratinc ;c/o jio�o DRAWING No. Eni-3543--d9 PART: RE or 3 0 REV, DAM HY CK APP _.,PCSCRIPT1ON R V . Y CK APP DESCRIPTION Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian 1 Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. 'X` atitude (N) Longitude (W F.N.1. MUM Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70033'27.209" 149°54'24.765" 797 1171 12.4 2 6053471.65 1651761.87 70033'27,194" 149'54125.000" 798 1179 12,4 3 6053420.07 1651754.10 70033127,1.79" 149°54125.229" 800 1186 12.4 4 6053418.56 1651746,17 70°33'27.164" 149°54'25.463" 801 1194 12.4 5 6053417.03 1651.738.44 70033127.149" 149°5425.692" 803 1202 12,4 6 6053415.54 1651730.54 70°33'27.134" 149°5425.925" 804 1210 12.4 7 6053412.44 1651714.77 70033127.104" 149054'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70°33'27.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70033127.074" 149054'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70°33127.060" 149054'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149054'27,318" 813 1257 12.4 12 6053404,80 1651675.51 70°33'27.029" 149054127.551" 815 1265 12.4 13 6053400,38 1651652.80 70°33'26.986" 149054128.221" 819 1288 12.4 14 6053398,83 1651644.95 70°33'26.971" 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637.12 70°33'26.956" 149054'28.685" 822 1304 12.4 16 6053395,82 1651629.26 70°33'26.942" 149054128.917" 824 1311 12.4 17 6053394.32 1651621.47 70033126.927" 149°54'29.147" 825 1319 12.4 18 6053392,78 1651613.58 %0033126.912" 149054'29.380" 827 1327 12.4 _ 19 6053389.63 1651597.90 70033'26.881" 149°54'29.843" 830 1343 12.4 20 6053388.17 1651590.00 70033126.867" 149054130.076" 831 1351 12.4 21 6053386.60 1651582.24 70033126.852" 149054130.306" 833 1358 12.4 22 6053385.19 1651574.35 70033'26.838" 149054130.538" 834 1366 12.4 23 6053383.64 1651566.41 70033'26.823" 149054130.773" 836 1374 12,4 24 6053382.12 1651558.61 70033'26.808" 149054'31.003" 837 1382 12,4 25 6053377.65 1651535.94 70033126.764" 149054'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70033126.750" 149054'31,904" 843 1413 12.4 27 6053374.53 1651520.23 70033126.734" 149054'32,137" 845 1421 12.4 28 6053373.11 1651512.46 70033126.7201 149054132.366" 846 1428 12.4_ 29 6053371,56 1651304.49 70'33'26.705" 149054132.602" 848 1436 12.4 30 6053370.06 1651496.66 70°33'26.690" 149054'32.833" 849 1444 12.4 31 6053367.05 1651480.97 70033'26.661" 149054133.296" 852 1460 12.4 32 6053365.47 1651473.16 70033126.646" 149054133.527" 854 1468 12.4 33 6053363.93 1651465.22 70°33'26.631" 149054133.762" 855 1476 12.4 34 6053362.44 1651457.37 70033'26,616" 149054'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70033'26.601" 149054'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70033126.586" 149054134,459" 860 1499 12.4 37 6053356.19 1651425.30 70033'26.555" 149054134.941" 863 1516 12.4 38 6053354.74 1651417.32 70033'26.541" 149054135.177" 864 1524 12.4 ��' �,e y.8=d , SPY ISLAND DRILL SITE R WELL CONDUCTORS �I AS-BUILT LOCATIONS nD �+ f.f SW/ CAD PILE.E1�:13543c9 ICIIIIf . rte. US *perrahin' DATE ' DRAWING NO: PART: REV: io/c1/taro _ Eni-3543-d9 3 OF 3 0 N 0 W 0 -- t® em O ,0 v o y O ',13- 1"• a > .41—a a a a a a a a a a v a a a, a a a a a a a a a a a a a N UO d _v 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 2 Q W 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 cy W . 7 0 - t0 a N O t •-• N 0o t0 N M N coin M N N. M t0 a N o0 `,•i- N M 0 a N coM N. n 00 M O N N M a 'Cr V1 t0 0o M 0 e-I N N a u1 111 t0 Nn 0o O N N N 7 4 w In N I-1 ,1 N N N N N N N N N N N M M M M M m M en M Ma a a a _1 O LL D N N N N N N N N N e-I N N N N N N N N N N N N N N N N N N 0 0• _ J C O J N 00 O N M N M O N M ul 01 N N a ul N O N M t0 N N M NtO CDZ 01 M 0 0 0 0 0 0 N N N N N N N N N N M M M N M M a a a C LL r.• N. CO 0303 00 CO CO 00 CO 00 00 CO 00 00 00 CO 00 00 CO CO CO 00 00 00 CO 00 CO 00 W n N 0 M 0 M N N u1 00 M N N a Ito Ni O a N t0 M N M N a a M t0 00 0 M lan O N er N OM1 N OMO O M IMn 1-. OM1 a t0 01 N M tt0 N IN/1 N 0C1 a NMMaaaOp ^ OO OO CO Mm MN N N O e-I .i .-1 .-1 .-I ,-1NNH ,1 .-1eie4NN ,1 .-iNNN .i .-I 7 U Y v "a a a a a 'a 'a a "a v "a "a "a 'a 'a 'a 'a a 'a "a a a a 'a "a 'a r 'oeo ul 0 N In N 0 0 0 N an o ul o o M o en pn In in ul o o In en o M a s o e e e e . o . o 0 0 0 0 @ v v v v.v .1 v v v v .4 v v v v v v v v et v v v v et v ct v u N N N N N N N N N N N . . . . . . N N N N . . . . . . . 0 C N 0 Z a m e�-I o cocn a to .N-1 O^i ONO t^O N O m N t� a .M-1 O coMin to `an o W N CO1/1 4 -- N N N N N N N N N O O O O O M M M M M M 00 co co 00 co N N N Z a) 00 00 00 co 00 00 00 00 00 00 00 00 co 00 n n N N N N N N N N N N N N "a 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 M In in M M en in in M in in m M en in in en in en M M in M M in in in in 47, 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 J o o e e e o o e o e o 0 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 NNNNNNNNNNNNNNNNNNNNNNNNNNNNI- N a a I""'1 a EE o o m m t0 N O^1 .4'1 m ItpN/01 lO0 tt0 O .--I m a to N eN'1 N v 1111 tto CNo .M-I m a t^o �//�� Z U N N N N N tto to ttoo tto tD ttc to tto c tto IMn uu11 °V1° iN uM1 n 1a11 IMn INn M v a .7 V! N _Y 1.. X W N J = o e4 4 ei ei ei ei 4 e-1 ei e1 ei ei ei ei .4 ..i . ei ei ei (h Q 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 J = CO z ul V1 ul V1 ul ul o ul o o V1 M to ul ul In u1 o M o u1 ul ul V1 V1 ul ul In Amo ci 1 Q N c _ Qc Q Z 00 M u) N N a 0 00 M N N to N 0 e-I N N N to M 00 M N a M M .-I N O ul M V 0a1 Ma M W N 00 N W N 1.- N N N to V1 O a O In O In O .1O Q @ N t0 tO t0 lO tO ttO Vl u1 V1 L in 0a0 t- N Ma N O M M enn en In en N N N N O Z () o } t0 t0 t0 tO t0 LC) t0 t0 tO t0 40 0 t0 tW PD ID t� tD tO t0 t0 t0 t0 1/40 t0 t0 t0 t0 N 0 a N f11 r fn1 en fit I'nI en en 1 en Ie1 fit NM1 1Y1 en' Nri en fn1 en IeI n') I'll fit er eY) en e ul in In to i u1 it to V1 1n V1 to in to In ul In ul u1 Vl In to in ul to ul In u1 0000000000000000000000000000 _ �; Q tD us t0 t0 e e t0' t0 t0 t0 t0 tD t0 us t0 a t0 b tp us t0 tp tp t0' a t0' tO us U LC 01 N 00pp aa p Y - L.0 O N a t0 M M W ONO O M O N a t0 M ea-I M 00 O M M N 0 t0 001 N M U) (6 a ut ut u1 u1 ut tD l0 lD N: N: N-Z CO CO a0 CO M M M O O O O ea N N 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 M Q •= aaa 'a "a "a "aaaaaa 'a 'a 'a "av "aaav 'a "a 'ai "a L 00 M N ul ut en ul u1 u1 O a/1 0 len 0 0 M en ul 0 0 0 u1 M len len len M u1 u1 Q C M 01 M Cl M O 01 01 M M M M M M M M Ol M M M Ol M M M M M 01 Gl i o a a a a a a a a a a a a a a a a v a a a a a a a a a a a N N N N N N N N N N N . . . . . . N N N N N N N N N N N no0 m m a pp M a N M M O OMO N o N CO N ul a N s-I 0O t^0 u1 en N 0 to O N N dap CCCCCC < — c.1 .--o .--1 ,1 ,1 ,--o ,--1000^ OMMMMMMOIWWWWWNNNN Z v N N N N N N N N N N N N lG tG tC t0 tC tC tG tC tC tG tG tC tG tC tG u) 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 M M M M M M M M M M M MMMMMM M M M M M M M M M M M .l 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 o o O O O 0 0 0 0 o o o 0 0 0 0 0 o 0 o o o o 0 0 0 0 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 0 N N O N a s N t0 .-I .-I M .-I 0 Vl N t0 N OO O O a ul ."I N a M M t0 2 00 00 N N V1 n M H M M In 00 M N N a ul Ol pop N M a to M .-I N a .xn (_n to t0 in a m en .a-I 0 M M CO n in as en N N IM-i 011 01 co N t0 innM N N .N-I X M X N N N N N N N N t0 t0 t0 t0 to lD t0 to t0 tO N In u1 V1 V1 V1 in u1 u1 it co M N o ei ei e4 ei ei ei ey eiei ei ei ei ei .-1 -1. ei ey ey ei ei ei ey ei ei e-1 ei ei a V1 ul V1 to In V1 u1 u1 u1 u1 ul ul V1 V1 o to of u1 in ul In In u1 N V1 ul V1 i Q 4 to to to to to to t0 t0 t0 t0 t0 t0 to to to t0 to tO tO o t0 to t0 to to tp to t0 z .-i .-1 .-i .-i .-i .-i .-i .-i r? ei .-i ei .-i .-i .-i , ei e♦ .-i .-i ei .-i ei .-i ei .-i .-i .-i 21 Oi N c _ N as a d a O ul N to a g N M a en N 0 00 M N N N CO en N 0 M aN t0 N VN u1 a en 5-I Z Y N t0 O N O V1 M M m M 00 M 00 M 00 M N� t0N t0 N1 N to 4 0 00 N in N 0 M N to a O 00 � 11 N1 a N M 00 to V1 M N Ns0 a M t .-= In M a- in N N N N N N N N 0 0 0 0 M M M M M CO CO CO CO CO CO N N N N, C ra j- .7 .7 .7a a a a .7 .7a s .7a M M M M M M M M M M M M M M M M M M M M Cr! M M M M M' M M e a nl'1 CA M M' M' M' M M' ct M M M M Q ul in in u1 to u) in ut ul N u1 ul M u1 ut u1 N M u1 in In ut in N u1 M N u1 2 0000000000000000000000000000 Q us tD t0 t0' t0 to ui tD t0' t0' t0' t0 t0 t0 t0' t0 tC t0' to to to t0 t0 t0 t0 ui t0 ui 0 to C S .....1 ., O ,1 O N M O m O m O U N O 0 , N NNy o0N NNNNNN N N N N N N N N N 0 y u I,' w V N CO V U000 -.._-_ - I 0 00- NO - - — 0 .6' .0OO O O -V w eeN -a > vavvaa, a, a, av y N N N N N N NNNN Q Z O N w e-1•.I e-1 '-I ei ee-I _I ei Nr-1 c-i- w 0 4 HJ M t00 l00 N CO C1 C1 .H-1 N C 40 i 30 �vww J O w c-1 ei i l N ei eCr aai .a-1 ea-1 .Ni ,1 0) C _ J C 0 J Z CO a � 'Itin In ini In W W W In L.L 00 00 00 00 CO CO CO 00 00 00 — Z71N e-I-I a n epi a n m m N 01 ei m t0 00 0 in n v ,-i .-1 ,-i N N N N M fn m _0 N N N N N N N N N N Y va "a 'a "ain LE Enarl in in er1 vA oinoinin oin.in a 1 rn m m rn rn m m o, a a a a a a a a a a ,t, N ei ei ei ei eq e•1 ei ei i-I 0 0 N N — N 00 00 M 00 M 00 M N O0 < z a r... 4.0 M0 4 t0 IA 40 t0 t0 in I/, z 'Jh n n n n n n n n 1: N N N N N N N N N N m m m min 7n min m m y m m m m m m m m m m l O O O O O o O O O-O n n n n n n n n n n N- N w o Q _ 0 n n n m 00 M m c-1 a N n 00 ei M a M n co N II) N Z u M IA O N a l0 W O a 10 X 1` l0 in a M N .-1 I-i Q1 00 00 0 a a a a a a Cr a MIM J 4 N .ti ,- .-1*ei ei ei ee ,-Z •-i' .--iI e-i M < .-i ei ei ei ei ei ei .1 ei - J '= co z LilmulInlnlnL mmv, —a, m o _ 1 Q C N ti ❑ < Z E Y a v, l0 IA n M M ei M Q1,a N 01 O1 M W M W N 0 t0 m m n a In e-i O CO N: C NO ❑ O C1-11-1ei - ,1 1-1 0 0 0 0 N Z (' ca 5- 40 ID l0 40 t0 l0 l0 l0 l0 l0 QJn mMMMMMMMMm Vl lA 07 1A M lA NA M IIA I0 0 0 0 0 0 0 0 0 0 O J c ...., Q- 40 40 (0 (0 40 (0 40' 40' 40 0 (13 m N m t0 n N M N Q1 h D l00 CON in n C1 N a Cal .N-, �/� N a a a V/ M "d M m Imn cn Imn M M M M It'1 — av 'acv "vvvav L 'p0 Vl IA ten eA aA IA vA to U1 eA I4 -' aaaaN ai aaaaa b 0 v — _ N m 000 ei 40 ei l0 ei 10 to c1 o I a Z On (M0 400 400 4to a 40 (00 40 in in in 2N t0 to to t0 t0 it; it; it; iii tO -O N N N N N N N N N N +-. M M M M M M M M M In m m m /n m In m m m m o 0 o o o o o 0 0 0 n n n n n n n n n n OV 110 Onl -I N m 4NA 440 OM m x in Ur a t0 O M IA n C1 .-1IA 1� X m x in cr a ct Q a .7 a CO m W 0 0 in iri eti ei ei in ei en ei ei in in 0 a (00 400 IM0 400 400 l(0 400 Iin N0 4001 400 Z Z t t ey ei eti ei ei ei _1 ei ZI aiN C N m 0 E Q Z -. V1 O O V Q1 C1 M eli N In 10 ei O n IA M N O 01 t0 a Y in N N t0 l0 t0 l0 l0 v1 IA in 7 y M M M M M M M M M M JO 01 -_ M M M' M' M' M' M M M M 4N in in m 01 in M in N to to ra 0 0 0 0 0 0 0 0 0 0 a t0' 10 (0 (0 (0 (0 10 (0 (0 (0 2 V O 0 O C T M 0 momo a 0 y 0 'O O Z 01 0 N N M a N t0 N 00 00 .-i 0) N NMMMMMMMMIIn O Q Y C V w C ao (C 0/ w V 0 0 0 0 — 0 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 m E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of`Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW — Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. 111* ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 • Eno E&P Division REVISION STAP-P-1-M-6140 0 1 [f/A) LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 MudT}pe: FWGELS Rig type: J.UPs Hole Dameter(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): 13'3/8 P.V.(cps): 19Pumps: 12.P•160 Grade: .155 Y.P.Qb/100le): 5 , Liners(in): 6.6" Weight Obit): 61 : Gels(lb/100 t': 2/8 Flow Rate(bp l): 0.25 Mao.Burst pres(psi): 3103 W (con min): 10.6 Litholog y Shale • Expected EMVV 1.68 Kg/cm2110 m I Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bd) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 _ 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 1DO 300 10.5 2 483 5 125 400 11 2 455 6 _ 150 500 11.5 2 450 7 _ 1.75 570 12 2 _ 445 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Nd e: Pumped with a constant low rate of(bbl): \.blume pumped(bbl): Volume returned(bbl): (pd) 1000 900 • 800 - • - • dop pump F r 700 `-•-...,,,,r - e 600 - Slut in curve S 7. 500 + . • S . -•-• U 400 - r - 8minutes e 300 - 200 100 • 0 . . . . . . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume MIN) II I lo. Time mins RESULTS:(Press.,,,,,+Press.uo.)x10sD epth=((1.3 x 797 110)+(430 x 0.07)]x10 1797=1.68(Kg/cmZ/1 O m) ._Note: I CompanyRepresentatite I Figure 15-1 - Leak-Off Test Report String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Surface Casing 13 3/8",68.000 ppf,L-80 N/A 0.0-3237.0 12.259 2.33 1.86 4.22 Burst Design(13 3/8"Surface Casing) Collapse Design(13 3/8"Surface Casing) Axial Design(13 3/8"Surface Casing) e I 850 850 i- - - 850- _ v) I ren I 1700 . 1700 --- t 1700- 6) 0 0 0 -o - 1 1 N D 2550 --- - = 2550 - - = 2550- co 2 I 2 2 _ 3400 - 3400 -- --- l 3400- - -7-- Design.Load Line - Design Load Line I _ - Design Load Line - Pi.e Patin. Pipe Rating - Pipe Rating [ Him I IIiiiiiiiiii 2250 3000 3750 4500 0 700 1400 2100 400000 800000 1200000 160000C Burst Rating (psi) Collapse Rating (psi) Axial Force (lbf) Minimum Safety Factors(13 3/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(13 3/8"Surface Casing) 0 13 3/8",68.000 ppf,L-80 N/A 2.52 B5 +100.00 Cl 8.21 A5 3.17 B5 39 2.51 B5 +100.00 Cl 8.32 A5 3.17 B5 Drilling Load: Pressure Test 120 2.51 B5 38.15 Cl 8.58 A5 3.16 B5 Test Pressure: 1990.00 psi 120 2.51 B5 38.14 Cl 8.58 A5 3.16 B5 Mud Weight: 9.50 ppg 200 2.50 B5 22.89 Cl 8.85 A5 3.15 B5 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 200 2.50 B5 22.88 Cl 5.95 A5 3.04 B5 398 2.48 B5 11.51 Cl 4.99 A5 2.87 B5 Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 432 2.48 B5 10.61 Cl 4.85 A5 2.85 B5 Surface Pressure(1/3'BHP): 521.08 psi 600 2.47 B5 7.65 Cl 4.22 B5 2.72 B5 Shoe Depth,MD: 3237.0 usft 709 2.46 B5 6.49 Cl 4.26 B5 2.71 B5 Fracture Pressure at Shoe: 1598.38 psi 800 2.45 B5 5.78 Cl 4.30 B5 2.69 B5 Fracture Margin of Error: 0.00 ppg 900 2.45 B5 5.16 Cl 4.34 B5 2.68 B5 1000 2.44 65 4.68 Cl 4.38 BS 2.67 B5 External Pressure: Fluid Gradients(w/Pore Pressure) 1160 2.43 B5 4.09 Cl 4.43 B5 2.64 B5 TOC,MD: 0.0 usft 1160 2.43 BS 4.09 Cl 4.45 BS 2.65 B5 Prior Shoe,MD: 120.0 usft 1300 2.42 135 3.71 Cl 4.48 135 2.63 B5 Mud Weight Above TOC: 9.50 ppg 1300 2.42 B5 3.71 Cl 4.49 B5 2.63 B5 Fluid Gradient Below TOC: 8.60 ppg 1400 2.41 B5 3.49 Cl 4.52 B5 2.62 B5 Pore Pressure In Open Hole: Yes 1431 2.41 B5 3.43 Cl 4.81 B5 2.65 B5 1482 2.41 65 3.33 Cl 5.34 Al 2.70 B5 1482 2.41 B5 3.33 Cl 5.35 Al 2.70 B5 1700 2.40 B5 2.98 Cl 5.51 Al 2.93 B5 Collapse Load Data(13 3/8"Surface Casing) 2100 2.37 B5 2.51 Cl 5.86 Al 2.89 B5 2232 2.37 B5 2.39 Cl 5.99 B5 2.64 B5 Drilling Load: Full/Partial Evacuation 2233 2.37 B5 2.39 Cl 5.97 B5 2.64 65 Mud Weight: 9.50 ppg 2286 2.37 B5 2.35 Cl 5.03 B5 2.55 65 Mud Level,MD: 3237.0 usft 2300 2.36 B5 2.34 Cl 4.83 B5 2.53 BS Assigned External Pressure:Fluid Gradients(w/Pore Pressure) 2300 2.36 65 2.34 Cl 4.84 B5 2.53 B5 2400 2.36 B5 2.26 Cl 4.88 B5 2.52 65 External Pressure: Fluid Gradients(w/Pore Pressure) 2400 2.36 B5 2.26 Cl 4.87 B5 2.52 65 TOC,MD: 0.0 usft 2500 2.35 B5 2.19 Cl 4.90 135 2.51 B5 Prior Shoe,MD: 120.0 usft 2500 2.35 135 2.19 Cl 4.91 65 2.51 65 Fluid Gradient Above TOC: 9.50 ppg 2600 2.35 B5 2.13 Cl 4.94 B5 2.50 B5 Fluid Gradient Below TOC: 9.50 ppg 2736 2.34 B5 2.05 Cl 4.97 65 2.49 65 Pore Pressure In Open Hole Below TOC: No 2736 2.34 135 2.05 Cl 4.99 65 2.49 B5 2800 2.34 B5 2.02 Cl 5.01 135 2.49 B5 2800 2.34 B5 2.02 Cl 5.00 65 2.49 B5 2900 2.34 B5 1.98 Cl 5.03 B5 2.48 135 2900 2.34 B5 1.98 Cl 5.02 B5 2.48 B5 Axial Load Data(13 3/8"Surface Casing) 3000 2.34 B5 1.94 Cl 5.05 B5 2.47 B5 3000 2.34 B5 1.94 Cl 5.06 B5 2.47 B5 Running in Hole-Avg.Speed: 0.0 11/s 3100 2.33 B5 1.90 Cl 5.08 B5 2.47 B5 3236 2.33 B5 1.86 Cl 5.10 65 2.46 65 Overpull Force: 0 lbf 3237 2.33 B5 1.86 Cl 5.10 135 2.46 65 Pre-Cement Static Load: B5 Pressure Test Pickup Force: 0 lbf Cl Full/Partial Evacuation Al Running in Hole-Avg.Speed Green Cement Pressure Test: 1300.00 psi A5 Green Cement Pressure Test(Axial) String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Production Casing 9 5/8",40.000 ppf,L-80 Series 500 Type 563(TC) 32.0-11795.0 8.750 A 3.74 1.69 3.13 Burst Design(9 5/8"Production Casing) Collapse Design(9 5/8"Production Casing) Axial Design(9 5/8"Production Casing) I 2500--- - 2500 - 2500 - ?- - = - y 5000- -- t 5000- - - - y 5000 -- n - n - a - . a - a a - N 7500- --- -- = 7500- ._-T-- , 7500 -F -- - m m (8 - I 2 - 10000--- jr 10000 - -- 10000 - - - - Design Load Line -- Design Load Linz - - Design Load Line i- Pipe Ratfq12500_, Pipe R4ting_ - Ppe Rating 12500-1 1111 l IIIII iii 1500 3000 4500 6000 0 1000 2000 3000 250000 500000 750000 Burst Rating (psi) Collapse Rating (psi) Axial Force (lbf) Minimum Safety Factors(9 5/8"Production Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(9 5/8"Production Casing) 32 9 5/8",40.000 ptibitefft500 Type 563(TC) 3.82 B6 +100.00 Cl 3.96 A4 3.96 A4 41 3.82 136 +100.00 Cl 3.96 A4 3.95 A4 Production Load: Tubing Leak 200 3.84 B6 30.64 Cl 3.96 A4 3.95 A4 Packer Fluid Density: 8.60 ppg 200 3.84 66 30.63 Cl 3.52 A4 3.51 A4 Packer Depth,MD: 21283.0 usft 600 3.88 B6 10.29 Cl 3.13 A4 3.10 A4 Perforation Depth,MD: 21283.5 usft 800 3.91 B6 7.79 Cl 3.14 A4 3.09 A4 Gas Gravity: 0.70 900 3.92 B6 6.97 Cl 3.14 A4 3.09 A4 Reservoir Pressure: 1648.01 psi 1000 3.93 B6 6.31 Cl 3.14 A4 3.08 A4 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 1159 3.94 B6 5.53 Cl 3.15 A4 3.08 A4 1300 3.96 B6 5.00 Cl 3.15 A4 3.08 A4 External Pressure: Fluid Gradients(w/Pore Pressure) 1441 3.97 B6 4.59 Cl 3.15 A4 3.07 A4 TOC,MD: 9489.0 usft 1800 4.00 B6 3.83 Cl 3.17 A4 3.07 A4 Prior Shoe,MD: 3610.0 usft 2101 4.03 B6 3.37 Cl 3.19 A4 3.08 A4 Mud Weight Above TOC: 9.40 ppg 2206 4.04 B6 3.24 Cl 3.20 A4 3.08 A4 Fluid Gradient Below TOC: 8.60 ppg 2300 4.05 B6 3.14 Cl 3.20 A4 3.08 A4 Pore Pressure In Open Hole: Yes 2400 4.05 B6 3.04 Cl 3.21 A4 3.08 A4 2500 4.06 B6 2.96 Cl 3.22 A4 3.09 A4 2600 4.07 136 2.89 Cl 3.22 A4 3.09 A4 2700 4.07 B6 2.82 Cl 3.23 A4 3.09 A4 2800 4.08 B6 2.77 Cl 3.24 A4 3.10 A4 2900 4.08 B6 2.72 Cl 3.24 A4 3.10 A4 3000 4.09 B6 2.69 Cl 3.25 A4 3.10 A4 3100 4.09 B6 2.66 Cl 3.26 A4 3.11 A4 3200 4.09 136 2.64 Cl 3.26 A4 3.11 A4 3610 4.10 66 2.56 Cl 3.29 A4 3.13 A4 Collapse Load Data(9 5/8"Production Casing) 3832 4.11 B6 2.52 Cl 3.31 A4 3.15 A4 9489 4.23 B6 1.82 Cl 3.78 A4 3.49 A4 Drilling Load: Full/Partial Evacuation 9489 3.74 B6 1.82 Cl 3.78 A4 3.49 A4 Mud Weight: 9.40 ppg 10521 3.74 B6 1.74 Cl 4.15 A4 3.20 Cl Mud Level,MD: 11795.0 usft 10733 3.74 B6 1.73 Cl 4.25 A4 3.18 Cl Assigned External Pressure:Fluid Gradients(w/Pore Pressure' 10900 3.74 B6 1.72 C1 4.34 A4 3.17 C1 10900 3.74 B6 1.72 Cl 4.34 A4 3.16 Cl External Pressure:Fluid Gradients(w/Pore Pressure) 11100 3.74 136 1.71 Cl 4.46 A4 3.16 Cl TOC,MD: 9489.0 usft 11100 3.74 B6 1.71 Cl 4.46 A4 3.15 Cl Prior Shoe,MD: 3610.0 usft 11200 3.74 66 1.71 Cl 4.53 A4 3.66 Cl Fluid Gradient Above TOC: 9.40 ppg 11794 3.74 136 1.69 Cl 5.00 A4 3.62 Cl Fluid Gradient Below TOC: 8.30 ppg 11795 3.74 B6 1.69 Cl 5.00 A4 3.62 Cl Pore Pressure In Open Hole Below TOC: No Axial Load Data(9 5/8"Production Casing) Running in Hole-Avg.Speed: 0.7 ft/s Overpull Force: 100000 lbf Green Cement Pressure Test: 1000.00 psi Schwartz, Guy L (DOA) From: Occhionero Lara <Lara.Occhionero@enipetroleum.com> Sent: Wednesday,July 24, 2013 11:43 AM To: Schwartz, Guy L(DOA) Subject: RE:SI35-W4 (PTD 213-101) Attachments: SI35-W4(P6) SLB AC 3D quarter mile scan.pdf;SI35-W4(P6) SLB quarter mile plot.pdf Guy good afternoon, Attached you find the quarter mile plot, sorry I forgot to attach it in the permit request. Yes we're going to register a sonic bong log in the intermediate casing. Diverter sketch: The plan is to have a 10 days of rig shut down for summer maintenance after the SP36-W5 L1 and on that time we're going to modify the diverter sketch into 45 deg. If you have any other question, don't hesitate to ask. Thanks Lora Occhionero Drilling Engineer Eni Petroleum Alaska Office : (907) 865-3323 Cell: (907) 947-4100 Email: lara occh or eroOerupetroleum.corn From: Schwartz, Guy L(DOA) [mailto_guy.schwartzaalaska.gov] Sent: Tuesday, July 23, 2013 2:01 PM To: Occhionero Lara Subject: SI35-W4 (PTD 213-101) Lara, Can you provide the''/.mile AOR scan document that is supposed to be attachment#8 in the application. There is no mention of a CBL(Cement log over intermediate casing). The diverter sketch shows two targeted T's... have those been modified since last well? They were 90 deg before. Thank you, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 411, ,r Bettis, Patricia K (DOA) From: Occhionero Lara [Lara.Occhionero@enipetroleum.com] Sent: Thursday, July 11, 2013 3:46 PM To: Bettis, Patricia K(DOA) Subject: RE: Nikaitchuq: Proposed Well S135-W4 Hello Patricia. Nice to hear from you. No Eni do not plan any pre-produce in this well. Thanks regards Lora Occhionero Drilling Engineer Eni Petroleum Alaska Office : (907) 865-3323 Cell: (907) 947-4100 Email: Zara.occhionero@enipetroleum.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, July 11, 2013 3:43 PM To: Occhionero Lara Subject: Nikaitchuq: Proposed Well SI35-W4 Good afternoon Lara, I started the review of the Permit to Drill Application for the proposed SI35-W4 well. Does ENI planned to pre-produce the well and if so, for how long? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 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. 2 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 02)Z/Of Development /Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: POOL: &, /U f Cc. ]-tl•`� &,11d-j& Zi,,W Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no an ' sample from below the afrost or ls Dry Ditch Sample wherersampl s0are first caughtaand 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well 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. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well Well Logging logs are also required for this well: Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 5/2013 0oCo a a( m- rq •a ( ' � o D o wp cn a0 w v 3• I- - cnt cn r 3 m CT) v Av a:2 v = o 0. J D ° 0 3 c a O 0 O a D co co W —I co co co co co co co co co co N N N N N N N N N N -s -s -s -s -s -� -, co W J 0) 01 A W N 3 (0 co V 0) 01 A W N — 0 (0 00 V 0) 01 A CO N — O (0 W V O 01 A W N — 0 m O cn co p m c7, * O w w O �. D �. 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(p "0 co 3 a, c0-'i, O 0 n (n 0' a .Zl 2 2 N (D 3 a m rn 3 m m y 3 3 ° c C C co 0 (D O 0 m 0 < m au v, °�_ m ° o ° o- a c m 0 3 m 0 O c^) D O `m 2 m * m - °'_ -o . 0 0 a 0- = o m ° CL (i cn O o' 0 m C•O cn cn v p o' Q N o_ �'- co 0 3- cn o m a m ° 0 vi) < m w 0- CD 0 O Z O cwi, Z cn 3 • (n * O cn v a 7 0 c *. 03 <W m 3 n = 0 2 (- w "0 (D () (O• 6 11 (n D l CD D a cD 0" O (D O O < W 8 O •' O D A 0 O = N O O 3 O- 0 iG d W O 3' N p N (n c N (^ A co N 01 N 3 O' O N 01 .0. 7m1 _ I 6 5rs, O0 C a a N. 0 •a Ow O m a n m m o m x a v, 0 o 0 co O q CD ° C o r m 0) 0 z 0 13 0 00 0- Oz 0- 0 C' O_ < - m 0_ z 'moo N N' w o b o -- CD ,z c) o m _ 0 0 0 (° z c o -0 cn c ?. ° 0 3 3 m < - m A (n m Q 'v(i) O 01 Co (D n 0) 3 7 CD 7 < i K ca* Q) §. - m Z a v ° c- m x �, 0 D s 3 o N -co p __ 0 * o N m 0- v () o o D °) () a- m 0 0 -o co co 3 N = c Z 0 3 o. (0 co O. N n n n C R N 0 < (l A •0• N a N v * o y o �. -0 ( o o N 0 A — Z m m Q 5. c co (" n * `< 0 m n m (0 N v W 0 CSD 30 n 0 3O 0 3 ° CO Co (D A a- N C (D gyp) 0 p) O (D "0 j 0 S `< CD O 0 3 co (0 0" 0 C 0 0 N n 3 3 (n 3 0 w n) 3 O -0 CD 3 3 = 7 (° Co (D 7 w co a N 0 3 3 > o c 0 7 0 0 (D •a a r 0 o a co 0m 7 c co co cno o, Fri 3 A o (n a o D : N 3 (D 7 3 = o c v07 0 5- p a co c7i. cn , 0o 0 0 0) Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: October 3, 2013 Surface Data Logging End of Well Report SI35-W4 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 GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Doyon 15 Well: SI35-W4 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23494-00-00 Sperry Job Number: AK-AM-0900702266 Job Start Date: 27 August 2013 Spud Date: 28 August 2013 Total Depth: 19932’ MD, 3620’ TVD North Reference: True North Declination: 19.735° Dip Angle: 81.047° Total Field Strength: 57634.368 nT Date Of Magnetic Data: 28 Aug 2013 Wellhead Coordinates N: North 70° 33’ 27.63824” Wellhead Coordinates W: West 149° 54’ 22.84145“ Drill Floor Elevation 53.67’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Alexander Kalenuik, Kori Jo Plowman, Martin Nnaji SDL Sample Catchers: Jade Miller, Grant Trowbridge Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY 08/27/2013 SDL arrived on location. Spot and set mudlogging shack. Wait on the unit to warm up before rigging up. Rig up mudlogging shack. Run gas line to the unit. Rig up network connection with MWD and WITS to Canrig. 08/28/2013 Pick up 5” drill pipe. Pick up BHA #1 to clean out conductor pipe. Pick up BHA #2. Spud well and continued to drill ahead to 182’ MD. Gas: The max gas was 5 units at 252’ MD and the average drilling background gas was 1unit. Fluids: There was 48 barrels of water based mud lost down hole. Geology: No samples collected during surface section 08/29/2013 Continue to drill ahead in 16” surface hole from 182’ MD to 728’ MD. Gas: The max gas was 8 units at 706’ MD Geology: No samples collected during surface section 08/30/2013 Continue to drill ahead in 16” surface hole from 728’ MD to 2328’ MD. Gas: The max gas was 590 units at 2205’ MD Geology: No samples collected during surface section 08/31/2013 Drill ahead from 2328’ MD to surface section TD at 3175’ MD. Back ream out of hole to 816’ MD. Gas: The max gas was 293 units at 2391’ MD Geology: No samples collected during surface section 09/01/2013 Back ream out of hole from 816’ MD to surface. Run 13 3/8” casing, landing casing shoe at 3160’ MD. Circulate and condition mud for cement. Fluids: There was 10 barrels lost while running casing. 09/02/2013 Rig up cement tools. Pump surface cement. Rig down cement tools. 09/03/2013 BOP psi testing. Rig down test equipment. Pick up 5” drill pipe. 09/04/2013 Trip in hole to 2865’ MD. Slip and cut drill line. Test casing to 2500 psi. Drill casing shoe and cement. Drill 20’ of new hole. Perform leak off test. Drill ahead in 12.25” intermediate hole to 3521’ MD. Gas: The max gas was 81 units at 3301’ MD Geology: Cuttings consist mainly of sandstone with some local silts 09/05/2013 Continue to drill 12.25” intermediate hole from 3521’ MD to 5441’ MD Gas: The max gas was 71 units at 5332’ MD Geology: Cuttings consist mainly of sandstone with some local silts. There were several hard streaks 09/06/2013 Continue to drill 12.25” intermediate hole from 5441’ MD to 7457’ MD Gas: The max gas was 19 units at 7302’ MD Geology: Cuttings consist mainly of clean sandstone 09/07/2013 Continue to drill 12.25” intermediate hole from 7457’ MD to 8379’ MD Gas: The max gas was 22 units at 8148’ MD Geology: Cuttings consist mainly of clean sandstone 09/08/2013 Continue to drill 12.25” intermediate hole from 8379’ MD to 9314’ MD Gas: The max gas was 117 units at 8815’ MD Geology: Cuttings consist mainly of sandstone with some local silts. There were several hard streaks 09/09/2013 Continue to drill 12.25” intermediate hole from 9314’ MD to 9567’ MD. Circulate bottoms up and begin to back ream out of hole. Pull out of the hole to pick up new bit. Gas: The max gas was 52 units at 9500’ MD Geology: The last samples were very silty with 30% Sandstone and 70% Siltstone. 09/10/2013 Continue to back ream out of hole. Service top drive, draw works and traveling equipment. Pick up BHA #4 and run in hole to 4361’ MD Geology: No new samples 09/11/2013 Continue to run in hole from 4361’ MD. Drill from 9567’ to 11250’ MD to complete intermediate hole section Gas: The max gas was 660 units at 10300’ MD Geology: Samples predominately Sandstone with minor Siltstone 09/12/2013 Back ream out of hole to 3149’ MD 09/13/2013 Run in hole with 9 5/8” casing. 09/14/2013 Rig down cement head. Prepare to nipple down BOP stack. Calibrate gas equipment. 09/15/2013 Nipple down BOP stack. Set 9 5/8” emergency slips. Cut 9 5/8” casing. Install packoff and test. Change upper rams to variables. Pick up stands of 4.5” drill pipe and rack in derrick. 09/16/2013 Pick up 90 stands of 4.5” drill pipe. Pick up BHA #5 and 8.75” drill bit. Run in hole and measure after drilling to 11066’ MD. Circulate and balance mud 09/17/2013 Test 9 5/8” casing. Displace to oil-based mud. Clean surface equipment. Cut and slip drill line. Drill cement to shoe at 11250’ MD and 20’ of new hole to 11270’ MD. Perform formation integrity test. Drill 8.75” production hole to 12557’ MD. Gas: The max gas was 1584 units at 11675’ MD Geology: Samples are predominantly very fine to fine grained unconsolidated Sandstone 09/18/2013 Continue to drill 8.75” production hole from 12557’ MD to 14039’ MD Gas: The max gas was 2968 units at 13638’ MD Geology: Samples are predominantly very fine to fine grained unconsolidated Sandstone 09/19/2013 Continue to drill 8.75” production hole from 14039’ MD to 16293’ MD Gas: The max gas was 2375 units at 15932’ MD Geology: Samples are predominantly very fine to fine grained unconsolidated Sandstone 09/20/2013 Continue to drill 8.75” production hole from 16293’ MD to 18160’ MD Gas: The max gas was 2286 units at 17907’ MD Geology: Samples are predominantly very fine to fine grained unconsolidated Sandstone 09/21/2013 Continue to drill 8.75” production hole from 18160’ MD to 19932’ MD TD. Begin to backream out of hole Gas: The max gas was 2186 units at 19276’ MD Geology: Samples are predominantly very fine to fine grained unconsolidated Sandstone 09/22/2013 Continue to backream out of hole Gas: The max trip gas was 156 units 09/23/2013 Pull out of hole and lay down BHA #5. Service the rig. Run in hole with hole opener. Cut and slip drill line, service drawworks brakes and top drive. Run in hole and tag bottom at 19932’ MD. Circulate and condition hole. Gas: The max trip gas was 63 units 09/24/2013 Continue to circulate at 19932’ MD. Pull out of hole on elevators to 11006’ MD. Pump LVT spacer and displace mud to Brine. 09/25/2013 Continue to displace to Brine. Clean surface equipment. Pull out of hole and lay down BHA #6. Rig up casing equipment and run 4.5” liner. 09/26/2013 Continue to run in hole with 4.5” liner. Run to 8892’ MD. Rig down casing equipment and rig up to run in hole with 5” drill pipe. Run in hole with 4.5” liner on 5” drill pipe. 09/27/2013 Continue to run in hole with 4.5” liner on 5” drill pipe. Test packer. Rig down test equipment. Cut and slip drill line. Pull out of hole and lay down 5” drill pipe. Continue to pull out of hole and lay down liner running tool. Rig up 4.5” elevators. Run in hole with 4.5” drill pipe from surface to 6262’ MD, pull out of hole and lay down 4.5” drill pipe. 09/28/2013 Continue to pull out of the hole and lay down 4.5” drill pipe. Pull wear ring and set test plug. Rig up and test BOP’s. Rig down test equipment. Rig up running tool and run 4.5” completion tubing. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 0 5 10 15 20 25 30 35 Me a s u r e d D e p t h Rig Days Prognosed Actual Days vs. Depth 27 Aug 2013 Sperry SDL Arrived on location WELL NAME: SI35-W4 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-AM-0900702266 LOCATION: Spy Island AREA: North Slope STATE: Alaska SPUD: 28 Aug 2013 TD: 21 Sept 2013 Commenced 16" Surface Hole Section On Bot: 18:00 28 Aug 2013 TD Surface Hole Section 3175' MD, 2410' TVD Off Bot: 13:40 31 Aug 2013 Landed 13 3/8" Casing 3160' MD, 2404' TVD 01 Sept 2013 Commenced 12.25" Intermediate Hole Section On Bot: 20:00 04 Sept 2013 Drill 12.25" Hole to 9567' MD POOH to pick up new Bit 9 Sept 2013 TD Intermediate Hole Section 11250' MD, 3550' TVD Off Bot: 22:58 11 Sep 2013 Landed 9 5/8" Casing 11323' MD, 3541' TVD 13 Sept 2013 Commenced 8.75" Production Hole Section On Bot: 10:35 17 Sep 2013 TD Production Hole Section 19932' MD, 3620' TVD Off Bot: 19:10 21 Sep 2013 WELL NAME:LOCATION:Spy Island OPERATOR:AREA:North Slope SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION Surface EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 ENI Petroleum AK-AM-0900702266 Kori Jo Plowman 1-Aug-2013 SI35-W4 What went as, or better than, planned: The only issue with INSITE was that the pumps and flows were not calculating correctly when the pumps were first turned on. This was corrected by going into the INSITE program on the Iris computer and reconfiguring the pumps. Recommendations: Innovations and/or cost savings: Surface section was completed with no major issues. Difficulties experienced: Make sure to check all INSITE configurations after creating a new well or run. N/A Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION:Spy Island OPERATOR:AREA:North Slope SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION Intermediate EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 ENI Petroleum AK-AM-0900702266 Kori Jo Plowman 15-Sep-2013 SI35-W4 What went as, or better than, planned: No major difficulties were experienced. The bit depth was thrown off a few times during connections and the weight on bit was not always tracking accurately on Canrig. Recommendations: Innovations and/or cost savings: Intermediate section was completed with no major problems. Difficulties experienced: Check bit depth during each connection and call driller if weight on bit is reading zero, they will fix it. N/A Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION:Spy Island OPERATOR:AREA:North Slope SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 ENI Petroleum AK-AM-0900702266 Kori Jo Plowman 23-Sep-2013 SI35-W4 What went as, or better than, planned: No major difficulties were experienced. The bit depth was thrown off a few times during connections and the weight on bit was not always tracking accurately on Canrig. Recommendations: Innovations and/or cost savings: Production section was completed with no major problems. Difficulties experienced: Check bit depth during each connection and call driller if weight on bit is reading zero, they will fix it. N/A Surface Data Logging After Action Review Surface Data Logging WELL NAME:SI35-W4 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:28-Aug-2013 SPERRY JOB:AK-AM-0900702266 TD:21-Sep-2013 Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.0 0.2 264.8 160.0 -106.3 SV-4 763.0 12.2 182.5 759.6 -706.0 SV-3 1,151.5 32.0 190.6 1,116.4 -1,062.7 SV-2 1,461.0 43.1 184.3 1,365.0 -1,311.3 Permafrost Base 1,990.0 42.4 184.8 1,750.7 -1,697.0 SV-1 2,221.0 50.5 191.4 1,910.5 -1,856.8 Ugnu Top (UG4)2,770.0 58.6 209.2 2,220.8 -2,167.1 13 3/8" Casing Shoe 3,160.0 66.3 226.2 2,404.1 -2,356.4 TD 16" Borehole 3,175.0 66.7 226.7 2,410.1 -2,356.4 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 4,375.0 82.3 240.6 2,680.2 -2,626.5 Lower Ugnu 8,165.0 82.4 238.3 3,170.7 -3,117.0 Schrader Bluff Top 9,267.0 80.5 247.2 3,353.6 -3,299.9 N Sequence Top 9,588.0 81.2 254.5 3,408.0 -3,354.3 N Sand Top 9,960.0 84.4 272.9 3,450.9 -3,397.2 N-2 Top 9,980.0 84.5 273.7 3,452.8 -3,399.1 N-3 Top 9,994.0 84.5 274.2 3,454.2 -3,400.5 N Sand Bottom 10,072.0 84.0 277.4 3,461.8 -3,408.2 N-Sequence Base 10,470.0 85.8 290.2 3,505.2 -3,451.6 9 5/8" Intermed. Casing 11,232.0 85.1 304.0 3,548.4 -3,494.8 TD 12 1/4" Borehole 11,250.0 85.1 304.0 3,550.0 -3,496.3 8 3/4" Production Borehole OA-1 11,344.0 85.5 304.6 3,557.7 -3,504.0 OA-2 12,554.0 89.6 312.3 3,558.1 -3,504.4 OA-3 12,750.0 88.5 311.0 3,561.8 -3,508.1 OA-3 13,990.0 92.2 311.5 3,555.3 -3,501.6 OA-2 14,142.0 92.0 309.8 3,549.9 -3,496.2 Fault A 14,940.0 89.6 308.5 3,539.9 -3,486.2 OA-2 15,310.0 92.2 310.3 3,534.6 -3,481.0 Fault B 15,640.0 90.2 311.3 3,531.8 -3,478.2 OA-1 15,827.0 85.3 310.1 3,537.6 -3,483.9 OA-2 15,885.0 84.6 309.6 3,543.0 -3,489.4 OA-3 15,908.0 84.7 309.2 3,545.2 -3,491.5 OA-4 16,500.0 89.9 310.3 3,552.6 -3,498.9 OA-4 16,715.0 91.6 309.1 3,548.4 -3,494.7 Fault C 16,954.0 91.9 308.6 3,539.5 -3,485.8 OA-1 17,067.0 90.9 308.6 3,536.7 -3,483.1 OA-1 17,207.0 87.8 310.6 3,537.7 -3,484.0 OA-2 17,445.0 89.2 315.0 3,542.4 -3,488.8 OA-3 17,845.0 88.7 312.9 3,547.5 -3,493.8 OA-3 18,145.0 91.8 311.5 3,549.5 -3,495.8 OA-2 18,210.0 92.4 311.2 3,546.9 -3,493.2 OA-1 18,280.0 91.9 311.6 3,544.2 -3,490.6 OA-1 18,564.0 86.1 308.6 3,556.0 -3,502.3 OA-2 18,670.0 86.3 308.5 3,563.2 -3,509.5 OA-3 18,765.0 86.9 308.8 3,568.7 -3,515.0 OA-4 19,740.0 85.8 308.9 3,611.4 -3,557.8 TD 8 3/4" Lateral 19,932.0 88.1 307.4 3,620.9 -3,567.2 Formation Tops Show Report Report # 1 Show Report Report # 1 Well Name: Depth (MD) to ft Location: (TVD) to ft 12100' 3559 11350' 3558 SI35-W4 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 3559 3558 OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 25-Sep-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 89000 11356 1154 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 89000 11356 1154 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =125307 117 116937 8370 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 125307 117 998 717 28 689 1042 44 116937 170 224 8370 NPH C4 - =C1/C5 = C5 - =0 156 156 750 521 717 28 689 530 9 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 89000 11572 1294 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 5077 118 167 1203 138845 133768 1135 68 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 61 802 327 27 863 300 167 446 1203 1135 68 389 Oil C4 C1/C5 = C5 - = Production 346 2 344 327 27 300 389 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 1584 11675 89000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 1584 11675 89000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =168086 7640 160446 122 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =1031 890 141 1451 131 1320 168086 7640 160446 180 509 122 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 1031 890 387 141 410 72 315 382 28 509 420 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 410 382 28 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 1294 12017 89000 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 135552 9724 1265 217 1048 125828 175 120 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =401 160 241 1265 217 1048 980 259 721 175 522 323 NPH C4 -=C1/C5 = C5 - = Production 438 48 390 401 160 241 0.00 323 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 2 Show Report Report # 2 Well Name: Depth (MD) to ft Location: (TVD) to ft 12900' 3566' 12100' 3559' SI35-W4 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 3566'3559' OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 25-Sep-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 89000 12121 1463 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 89000 12121 1463 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =155638 123 147160 8478 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 155638 123 1198 998 153 845 1340 142 147160 174 197 8478 NPH C4 - =C1/C5 = C5 - =3 282 285 522 746 998 153 845 833 87 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 89000 12308 1244 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 34694 118 161 1188 131748 97054 824 364 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 351 604 411 219 955 192 161 505 1188 824 364 249 Oil C4 C1/C5 = C5 - = Production 459 70 389 411 219 192 249 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 1243 12585 89000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 1243 12585 89000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =128670 1556 127114 109 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =945 900 45 1196 31 1165 128670 1556 127114 141 328 109 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 945 900 422 45 479 34 388 464 15 328 274 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 479 464 15 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 1283 12856 81000 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 137254 11347 1090 165 925 125907 235 136 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =341 187 154 1090 165 925 750 214 536 235 818 413 NPH C4 -=C1/C5 = C5 - = Production 379 74 305 341 187 154 0.00 413 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 3 Show Report Report # 3 Well Name: Depth (MD) to ft Location: (TVD) to ft 13800' 3560' 13200' 3567' SI35-W4 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 3560'3567' OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 25-Sep-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 77000 13218 1433 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 77000 13218 1433 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =150527 152 137950 12577 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 150527 152 908 719 180 539 1073 165 137950 256 240 12577 NPH C4 - =C1/C5 = C5 - =66 247 313 559 574 719 180 539 723 149 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 77000 13408 2056 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 7486 182 290 1206 213190 205704 1128 78 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 88 710 396 62 798 334 290 616 1206 1128 78 561 Oil C4 C1/C5 = C5 - = Production 436 69 367 396 62 334 561 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 2968 13637 74000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 2968 13637 74000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =289366 10489 278877 256 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =805 592 213 1275 186 1089 289366 10489 278877 471 1207 256 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 805 592 421 213 469 190 231 387 82 1207 721 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 469 387 82 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 2776 13728 74000 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 279517 13643 1204 193 1011 265874 470 263 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =409 161 248 1204 193 1011 771 205 566 470 1072 703 NPH C4 -=C1/C5 = C5 - = Production 467 89 378 409 161 248 0.00 703 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 4 Show Report Report # 4 Well Name: Depth (MD) to ft Location: (TVD) to ft 15600' 3532' 14200' 3548' SI35-W4 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 3532'3548' OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 25-Sep-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 69000 14251 1394 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 69000 14251 1394 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =146761 143 138580 8181 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 146761 143 967 694 94 600 1069 102 138580 231 226 8181 NPH C4 - =C1/C5 = C5 - =24 260 284 533 612 694 94 600 676 64 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 65000 14627 1243 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 5623 119 177 1122 129987 124364 1047 75 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 83 701 349 84 784 265 177 469 1122 1047 75 368 Oil C4 C1/C5 = C5 - = Production 381 43 338 349 84 265 368 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 1544 15381 68000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 1544 15381 68000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =156526 11511 145015 110 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =1165 973 192 1486 173 1313 156526 11511 145015 149 407 110 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 1165 973 502 192 573 146 356 511 62 407 284 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 573 511 62 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 1424 15582 67500 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 143786 16003 1441 288 1153 127783 154 111 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =494 167 327 1441 288 1153 1148 316 832 154 391 242 NPH C4 -=C1/C5 = C5 - = Production 561 33 528 494 167 327 0.00 242 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 5 Show Report Report # 5 Well Name: Depth (MD) to ft Location: (TVD) to ft 17300' 3542' 15900' 3545' SI35-W4 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 3542'3545' OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 25-Sep-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 67500 15932 2375 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 67500 15932 2375 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =232426 140 225758 6668 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 232426 140 1611 1318 205 1113 1756 145 225758 203 226 6668 NPH C4 - =C1/C5 = C5 - =64 388 452 582 999 1318 205 1113 1167 168 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 64000 16117 1565 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 6205 149 218 1177 159805 153600 1032 145 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 192 704 368 162 896 206 218 746 1177 1032 145 435 Oil C4 C1/C5 = C5 - = Production 421 68 353 368 162 206 435 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 1867 16809 67000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 1867 16809 67000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =182901 14083 168818 140 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =1024 844 180 1374 171 1203 182901 14083 168818 200 612 140 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 1024 844 409 180 471 133 276 415 56 612 407 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 471 415 56 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 1635 17300 70000 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 163394 15228 1301 150 1151 148166 181 129 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =406 132 274 1301 150 1151 990 170 820 181 541 362 NPH C4 -=C1/C5 = C5 - = Production 462 53 409 406 132 274 0.00 362 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 6 Show Report Report # 6 Well Name: Depth (MD) to ft Location: (TVD) to ft 19300' 3590 17900' 3549' SI35-W4 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 3590 3549' OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 25-Sep-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 68000 17906 2286 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 68000 17906 2286 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =222738 146 213216 9522 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 222738 146 1463 1239 239 1000 1656 193 213216 213 236 9522 NPH C4 - =C1/C5 = C5 - =69 336 405 635 903 1239 239 1000 1085 182 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 68000 18140 2086 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 64864 191 301 1479 204147 139283 731 748 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 627 462 449 296 1089 153 301 910 1479 731 748 371 Oil C4 C1/C5 = C5 - = Production 509 134 375 449 296 153 371 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 2016 19073 67500 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 2016 19073 67500 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =201140 8569 192571 146 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =975 813 162 1469 150 1319 201140 8569 192571 237 693 146 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 975 813 398 162 439 120 278 386 53 693 499 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 439 386 53 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 2186 19272 67500 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 212352 94200 1561 787 774 118152 247 153 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =430 266 164 1561 787 774 1027 549 478 247 720 305 NPH C4 -=C1/C5 = C5 - = Production 461 73 388 430 266 164 0.00 305 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons SI35-W4 ENI Petroleum MI Swaco Doyon 15 AK-AM-0900702266 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec cP lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 28-Aug 181 8.70 180 42 52 27/46/58 5.5 136/94/78/58/27/26 1/-1.0 1/99 0.05 0.10 9.8 17.5 .10/.25 1100 -P/U BHA 29-Aug 412 8.90 73 22 31 14/33/40 5.5 75/53/45/35/15/13 1/-1.5 1/98 0.25 0.10 9.4 20.0 .05/.25 1800 120 Drilling 16" Surface 30-Aug 2027 9.40 94 32 34 21/45/54 5.0 98/66/54/39/19/17 1/-5.0 2/93 0.40 0.10 9.4 22.5 .05/30 1600 100 Drilling 16" Surface 31-Aug 3175 9.50 90 30 31 20/52/63 5.4 91/61/50/36/18/16 2/-5.0 2/93 0.25 0.15 10.0 22.5 .10/.35 1200 40 TD 16" Surface 1-Sep 3175 9.50 56 25 13 5/18/22 5.5 63/38/29/17/4/3 2/-7.0 2/91 0.25 0.10 8.8 22.5 .05/.30 1450 60 Run Casing, Cement Job 2-Sep 3175 9.20 36 8 5 --21/13/9/7/2/1 ----7.4 ----N/U BOP 3-Sep 3175 9.20 36 8 5 --21/13/9/7/2/1 -----7.4 ----BOP Testing 4-Sep 3242 9.30 46 10 21 10/12/13 6.4 41/31/27/21/9/8 1/-3.0 2/95 0.20 0.20 9.9 7.5 .15/1.10 900 60 Drilling 12.25" Intermediate 5-Sep 5391 9.20 56 12 34 14/24/28 5.4 58/46/40/32/15/13 1/-4.5 2/95 0.10 0.20 9.7 13.0 .10/.80 1100 80 Drilling 12.25" Intermediate 6-Sep 7303 9.20 49 12 26 13/26/30 5.6 50/38/32/25/13/12 1/-4.8 2/93 0.10 0.28 9.8 19.0 .10/65 1300 80 Drilling 12.25" Intermediate 7-Sep 8104 9.20 49 13 26 13/23/28 5.5 52/39/34/27/13/12 1/-5.1 2/93 0.10 0.20 9.8 20.0 .05/.65 1500 80 Drilling 12.25" Intermediate 8-Sep 9219 9.20 45 11 24 11/21/24 5.6 46/35/30/24/12/11 1/-4.5 2/94 0.10 0.20 10.0 15.0 .04/.65 1400 80 Drilling 12.25" Intermediate 9-Sep 9567 9.30 47 11 25 12/22/24 5.0 47/36/31/25/12/11 1/-6.0 2/92 0.10 0.15 9.8 17.5 .05/.65 1400 80 BROOH 10-Sep 9567 9.20 46 11 22 11/19/23 5.2 44/33/27/22/12/10 1/-6.0 2/92 0.10 0.20 9.8 15.0 .05/.70 1500 80 RIH BHA #4 11-Sep 11084 9.30 48 11 24 12/23/27 4.6 46/35/30/24/12/11 1/-5.8 3/91.2 0.10 0.15 9.8 19.5 .05/.65 1200 80 TD 12.25 Intermediate 12-Sep 11250 9.20 44 11 21 11/22/27 4.6 43/32/28/21/12/10 1/-6.0 3/91 0.10 0.15 9.6 17.5 .05/.65 900 60 BROOH 13-Sep 1125 9.15 45 10 20 10/19/22 5.0 40/30/25/19/11/10 1/-6.0 3/91 0.00 0.20 9.8 17.5 .05/.60 900 60 Float 9 5/8" Casing 14-Sep 11250 9.20 44 10 17 9/17/21 5.2 37/27/24/18/9/8 1/-5.8 3/91.2 0.00 0.15 9.7 17.5 .04/.60 1000 60 N/D BOP Stack 15-Sep 11250 9.15 44 10 17 9/17/21 5.2 37/27/24/18/9/8 1/-5.8 3/91.2 0.00 0.15 9.7 17.5 .04/.60 1000 60 P/U 4.5" DP Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec cP lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 16-Sep 11250 9.25 46 14 13 7/7/8 4.0 41/27/22/16/7/6 -5.86 64/36 2.75 3.58 400 32.4 ---Circulating 17-Sep 12106 9.2 45 14 18 8/8/9 4.0 46/32/26/19/8/7 -/2 6.24 66/34 2.7 3.51 615 31 -3.41/57.95 -Drilling 8.75" Production 18-Sep 13936 9.25 45 14 20 8/9/9 4.0 48/34/28/21/9/8 -/2 7.72 68/32 2 2.6 625 27.13 -13.43/61.21 -Drilling 8.75" Production 19-Sep 16105 9.25 45 14 19 8/8/9 4.4 47/33/27/20/9/8 -/2 8.44 69/31 3 3.9 600 26.17 -26.45/54.24 Drilling 8.75" Hole 20-Sep 17945 9.2 45 13 18 7/8/8 4.6 44/31/26/20/8/7 -/2 7.75 69/31 1.95 2.54 605 27.9 -18.82/55.6 -Monitor Well 21-Sep 19932 9.25 46 14 21 8/8/9 4.6 49/35/29/22/9/8 -/2 7.94 69/31 3 3.9 605 26.35 -22.49/53.61 -BROOH 22-Sep 19932 9.2 47 14 21 8/8/9 -49/35/29/22/9/8 -7.85 69/31 3.05 3.97 635 26.95 -24.64/50.36 -POOH BHA #5 23-Sep 19932 9.2 47 14 21 8/8/9 -49/35/28/22/9/8 -7.85 69/31 3.05 3.97 610 26.95 -27.37/47.42 -Circ on Bottom 24-Sep 19932 9.2 47 14 21 8/8/9 -49/35/28/22/9/8 -7.85 69/31 3.05 3.97 610 26.95 -27.37/47.42 -Displace to Brine 25-Sep 19932 9.10 27 -------------93000 -Run 4.5" Liner 26-Sep 19932 9.10 27 -------------87500 -Run 4.5" Liner 27-Sep 19932 9.10 27 -------------92500 -L/D 4.5" DP 28-Sep 19932 9.10 27 -------------92500 -RIH 4.5" Tubing Casing Record 13.375" Casing @ 3160' MD, 2404'TVD 28-Aug-2013 SPERRY JOB:TD:21-Sep-2013 Remarks 16" Conductor @ 160' MD, 160'TVD 9.625" Casing @ 11323' MD, 3541'TVD WELL NAME:LOCATION:Spy Island OPERATOR:AREA:North Slope MUD CO:STATE:Alaska RIG:SPUD: W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 1 Hughes MX-1 Milltooth 16"160'3175'2994'25.80 1.117 179.0 20.2 42 2254 874 0-1-WT-G-E-In-No-TD Surface TD 3 200 2 Hycalog SKFX716D PDC 12.25"3175'9567'6391'76.50 0.969 83.5 15 180 2000 900 7-5-WT-A-X-In-BT-BHA Bit Trip 4 300 3 Hycalog SKHI716D-E8C PDC 12.25"9567'11250'1684'7.40 0.969 227.6 10 160 2170 860 1-1-CT-G-X-In-No-TD Intermediate TD 5 400 4 Hycalog SHK616M PDC 8.75"11250'19932'8682'58.00 0.902 149.7 10 160 3250 550 0-1-CT-S-X-In-No-TD Production TD WELL NAME:SI35-W4 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO: SPERRY JOB:AK-AM-0900702266 TD:21-Sep-2013 MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:28-Aug-2013 B i t R e c o r d . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1100.00 0 28-Aug-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: SI35-W4 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: ConditionBit # 1 16MX-1 8.70 Size 100% Gas In Air=10,000 Units0Connection 0 Tools API FL Chromatograph (ppm) 0' WOB Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 0 Mud Type Lst Type Spud Mud 5.5182'52 Depth in / out YP (lb/100ft2) 9.80 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0900702266 P/U BHA PV Footage M. Ross/ O. Amend ShClyst TuffGvlCoal cP 42 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 182' 182' 0' Max @ ft Current 0'0.0 Date: Time: 0 in 0Minimum Depth C-5n 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 17.5180 MBT 0' pH 1.117 0 0 0 Siltst 0 0 Units* Casing Summary Lithology (%) 00 0 Unit Phone: 0 Paul Kalenuik Maximum Report By:Logging Engineers:Paul Kalenuik/ Kori Plowman Set AtSize Grade (max)(current) 0 0 Cly 0 . . * 24 hr Recap:Continuing to drill ahead in 16" surface. Slide/rotate from 406' MD to 700' MD. Slide and Rotate at time of report Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1800.00 0 29-Aug-2013 12:00 AM Current Pump & Flow Data: 885 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: SI35-W4 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: ConditionBit # 1 1.8 16MX-1 8.90 Size 100% Gas In Air=10,000 Units0Connection 0 Tools API FL Chromatograph (ppm) 0' WOB Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 0 Mud Type Lst Type Spud Mud 5.5412'31 Depth in / out YP (lb/100ft2) 9.80 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0900702266 P/U BHA PV Footage M. Ross/ O. Amend ShClyst TuffGvlCoal cP 22 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 332.0 Flow In (gpm) Flow In (spm) 182' 728' 546' Max @ ft Current 500'55.0 Date: Time: 4 in 2Minimum Depth C-5n 706' 10.0 C-2 8 SPP (psi) Gallons/stroke TFABit Type Depth 20.073 MBT 0' pH 1.117 0 0 0 Siltst 620 Units* Casing Summary Lithology (%) 078 0 Unit Phone: 0 Paul kalenuik Maximum Report By:Logging Engineers:Paul Kalenuik/ Kori Plowman Set AtSize Grade (max)(current) 0 0 Cly 650 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 1350 ROP ROP (ft/hr) M. Ross/ O. Amend 24 hr Max Morning Report Report # 3 Customer: Well: Area: Location: Rig: SI35-W4 30-Aug-2013 12:00 AM AK-AM-0900702266ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 285.0 Cor Solids Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 2027'1600.0 Mud Type Spud Mud 5.0 Ratio Mud Data Depth 2/93 Size 9.40 WOB MX-1 TFA Condition Slide/Rotate at time of report. Continuing to drill 16" surface. Trip 100% Gas In Air=10,000 UnitsConnection6Background(max) 0Average Mud (lb/bbl)ml/30min 0.109.40 Type 34 Casing Summary 1 16 0' C-3 Bit # 0 Lst 00 C-4i Chromatograph (ppm) 4 0 0 Cement C-1 C-5i ShSiltst Drilling 16" Surface PV cP Weight Flow In (gpm) Flow In (spm) Oil / Water Lithology (%) 1.117 3294 Footage Depth in / out ClystSsChtSilt C-4n Depth 0' Avg to0' Current 66.042.0 MWD Summary Max @ ft 2290' Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) (lb/100ft2) Comments 728' 2328' 1600' Lime TuffGvl 96% % 737 Alkal Coal Gallons/stroke 84 2205' 0 0 0 0Minimum Depth Maximum in 3 0 9045 0 0 0 0 74588 018 C-2 Gas Summary 590 Unit Phone: 0 Paul Kalenuik Set AtSize Grade Bit Type RPM Hours (current) Units* Cly Report By:Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) . . * 24 hr Recap: Cly Report By:Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) Bit Type RPM Hours Unit Phone: 0 Paul Kalenuik Set AtSize Grade 14 C-2 Gas Summary 293 0 0 0 0 28634 0 0 7310 Minimum Depth Maximum in 3 2391' 0 0 0 66 841 Alkal Coal Gallons/stroke 0 2328' 3175' 847' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft 3120' Date: Time: API FL Depth 0' Avg to0' Current 51.00.0 (current) Units* ClystSsChtSilt Lithology (%) 1.117 3090 Footage Depth in / out BROOH PV cP Weight Flow In (gpm) Flow In (spm) Oil / Water 0 Cement C-1 C-5i ShSiltst C-4n Chromatograph (ppm) 0 0 00 C-4iC-3 Bit # 0 Lst (lb/100ft2) 9.50 Type 31 Casing Summary Mud (lb/bbl)ml/30min 22.500.15 (max) 0Average Comments 0Background Trip 100% Gas In Air=10,000 UnitsConnection 1 16 0' Size 9.50 WOB MX-1 TFA Condition MWD Summary 96% %Mud Type Spud Mud 5.0 Ratio Mud Data Depth 2/93 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 3175'1200.0 Cor Solids Avg Min YP MaxECD (ppg)Tools ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 471.0 Morning Report Report # 4 Customer: Well: Area: Location: Rig: SI35-W4 31-Aug-2013 12:00 AM AK-AM-0900702266 1872 ROP ROP (ft/hr) M. Ross/ O. Amend 24 hr Max BROOH to 816' MD at time of report. Monitoring well flows , SPP, Pit Volumes and Gases. Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 ROP ROP (ft/hr) M. Ross/ O. Amend 24 hr Max Morning Report Report # 5 Customer: Well: Area: Location: Rig: SI35-W4 1-Sep-2013 12:00 AM AK-AM-0900702266ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 0.0 Cor Solids Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 3175'1450.0 Mud Type Spud Mud 5.5 Ratio Mud Data Depth 2/91 Size 9.50 3175' WOB MX-1 TFA Condition 29.00 0-1-WT-G-E-In-No-TD BROOH F/1156' T/415' MD @ 850gpm. Run Casing F/161' T/3120' MD. Lost 10bbls while running casing. Trip traces of coal, Pyrite and Glauconite. 100% Gas In Air=10,000 UnitsConnection0Background(max) 0Average Mud (lb/bbl)ml/30min 22.500.109.50 Type 13 Casing Summary 1 16 160' C-3 Bit # 0 Lst 00 C-4i Chromatograph (ppm) 0 0 0 Cement C-1 C-5i ShSiltst BROOH PV cP Weight Flow In (gpm) Flow In (spm) Oil / Water Lithology (%) 1.117 2556 2994' Footage Depth in / out ClystSsChtSilt C-4n Depth 0' Avg to0' Current 0.00.0 MWD Summary Max @ ft 0' Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 20.0 (lb/100ft2) Comments 3175' 3175' 0' Lime TuffGvl 96% % 0 Alkal Coal Gallons/stroke Circulate/Condition Mud for Cement @ Report Time. Caught bottoms up sample which consisted 90% Sandstone, 10% Siltstone with 0 0' 0 0 0 0Minimum Depth Maximum in 0 0 0 0 0 0 0 0 00 C-2 Gas Summary 0 Unit Phone: 0 Paul Kalenuik Set AtSize Grade Bit Type RPM 42.0 Hours (current) Units* Cly Report By:Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 0 12:00 AM AK-AM-0900702266 0 ROP ROP (ft/hr) M. Ross/ O. Amend 24 hr Max Max @ ft 0'0.0 Morning Report Report # 6 Customer: Well: Area: Location: Rig: SI35-W4 2-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 3175' Mud Type Spud Mud Ratio Mud Data Depth 9.20 Oil / Water (lb/100ft2) 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD20.0 Size R/U Cement Tools. Pump Surface Cement- 111bbls MudPush Spcr, Drop Btm Plug, 478bbls Lead (10.7), 64bbls Trip Calibrate gas equipment. 2 3175' 100% Gas In Air=10,000 UnitsConnection C-3 0Background (max) 0Average Mud (lb/bbl)ml/30min 5 Hycalog Casing Summary 1 16 160' Bit # Chromatograph (ppm) 0 0 0 C-4i 0 0 0 0 Cement C-1 C-5i ShSiltst Lst N/U BOP-Clean pits PV cP Weight Flow In (gpm) Flow In (spm) Type Lithology (%) 1.117 836 2994' 12.25 Footage Depth in / out ClystSsChtSilt 0' Avg to0' Current 0.00.0 MWD Summary Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Comments 3175' 3175' 0' Lime TuffGvl 96% % 0 Alkal Coal Gallons/stroke Checked Floats (held). R/D Cement Tools. Wash-up post cement. Prepare unit for sample program for intermediate section. 0 0' 0 0 0 Minimum Depth Maximum in 0 Depth 0 0 0 0 00 C-2 0 C-4n Gas Summary 0 (current) Units* Unit Phone: 0 Paul Kalenuik Set AtSize Grade Bit Type RPM 42.0 Hours 29.00 Cly Report By: Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0900702266 1086 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 3780'308.0 Morning Report Report # 8 Customer: Well: Area: Location: Rig: SI35-W4 4-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 3242'900.0 Mud Type LSND 6.4 Ratio Mud Data Depth 2/959.30 Oil / Water (lb/100ft2) 9.30 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 21 RPM 20.0 Size 3160'BTC Hycalog Casing Summary TIH T/1003' MD & perform MWD shallow hole test @ 650gpm. TIH T/2865' MD. Slip/Cut 68' DL. Trip Drilling Ahead @ time of report. 2 3175' 100% Gas In Air=10,000 UnitsConnection Average 2Background Mud (lb/bbl)ml/30min 0.20 (max) 0 C-3 Bit Type Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i $2,810.00 $14,050.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type 46 2994' 12.25 Footage Depth in / out 16 160' Ss Cht Silt 60 Avg to0' Current 242.00.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 3175' 3521' 346' Lime TuffGvl 96% Date: % 793 Alkal Coal Gallons/stroke PSI Test Casing T/2500psi. Drilled Shoe Track-Cmt@3062', Plug@3075', Shoe@3160' MD. Drilled 20' NF. 45 3250' 0 0 0 Minimum Depth Maximum in 0 Lithology (%) 1 Bit # 4292 0 Depth 0' 1.117 10 0 C-2 0 C-4n 0 Gas Summary 292 40(current) Units* Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade 42.0 Hours 29.00 Cly Comments Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 9496 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0900702266 1086 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 3780'308.0 Morning Report Report # 8 Customer: Well: Area: Location: Rig: SI35-W4 4-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 3242'900.0 Mud Type LSND 6.4 Ratio Mud Data Depth 2/959.30 Oil / Water (lb/100ft2) 9.30 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 21 RPM 20.0 Size 3160'BTC Hycalog Casing Summary TIH T/1003' MD & perform MWD shallow hole test @ 650gpm. TIH T/2865' MD. Slip/Cut 68' DL. Trip Drilling Ahead @ time of report. 2 3175' 100% Gas In Air=10,000 UnitsConnection Average 2Background Mud (lb/bbl)ml/30min 0.20 (max) 0 C-3 Bit Type Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i $2,810.00 $14,050.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type 46 2994' 12.25 Footage Depth in / out 16 160' Ss Cht Silt 60 Avg to0' Current 242.00.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 3175' 3521' 346' Lime TuffGvl 96% Date: % 793 Alkal Coal Gallons/stroke PSI Test Casing T/2500psi. Drilled Shoe Track-Cmt@3062', Plug@3075', Shoe@3160' MD. Drilled 20' NF. 45 3250' 0 0 0 Minimum Depth Maximum in 0 Lithology (%) 1 Bit # 4292 0 Depth 0' 1.117 10 0 C-2 0 C-4n 0 Gas Summary 292 40(current) Units* Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade 42.0 Hours 29.00 Cly Comments Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 9496 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0900702266 1711 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 7449'477.0 Morning Report Report # 10 Customer: Well: Area: Location: Rig: SI35-W4 6-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids 9.92 Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 7303'1300.0 Mud Type LSND 5.6 Ratio Mud Data Depth 2/939.20 Oil / Water (lb/100ft2) 9.30 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 26 RPM 49 20.0 Size 3160'BTC Hycalog Casing Summary Drill 12.25" hole F/5441' T/6724' @ 800 to 848 gpm,Monitor well. Static. Trip 2 3175' 100% Gas In Air=10,000 UnitsConnection Average 2Background Mud (lb/bbl)ml/30min 0.28 (max) 0 C-3 Bit Type Chromatograph (ppm) 10 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i $2,810.00 $19,660.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type 12.25 Footage Depth in / out 16 160' Ss Cht Silt 100 Avg to0' Current 90.048.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 5441' 7460' 2019' Lime TuffGvl 96% Date: % 846 Alkal Coal Gallons/stroke Continuing to drill ahead. Currently at a depth of 7459' MD. Experiencing hard streaks. 5 7302' 0 0 0 Minimum Depth Maximum in 2 Lithology (%) 1 Bit # 317 0 Depth 0' 1.117 12 0 C-2 0 C-4n 0 Gas Summary 19 (current) Units* Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade 42.0 Hours 29.00 Cly Comments 2994' Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 2002 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0900702266 1711 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 7449'477.0 Morning Report Report # 10 Customer: Well: Area: Location: Rig: SI35-W4 6-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids 9.92 Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 7303'1300.0 Mud Type LSND 5.6 Ratio Mud Data Depth 2/939.20 Oil / Water (lb/100ft2) 9.30 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 26 RPM 49 20.0 Size 3160'BTC Hycalog Casing Summary Drill 12.25" hole F/5441' T/6724' @ 800 to 848 gpm,Monitor well. Static. Trip 2 3175' 100% Gas In Air=10,000 UnitsConnection Average 2Background Mud (lb/bbl)ml/30min 0.28 (max) 0 C-3 Bit Type Chromatograph (ppm) 10 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i $2,810.00 $19,660.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type 12.25 Footage Depth in / out 16 160' Ss Cht Silt 100 Avg to0' Current 90.048.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 5441' 7460' 2019' Lime TuffGvl 96% Date: % 846 Alkal Coal Gallons/stroke Continuing to drill ahead. Currently at a depth of 7459' MD. Experiencing hard streaks. 5 7302' 0 0 0 Minimum Depth Maximum in 2 Lithology (%) 1 Bit # 317 0 Depth 0' 1.117 12 0 C-2 0 C-4n 0 Gas Summary 19 (current) Units* Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade 42.0 Hours 29.00 Cly Comments 2994' Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 2002 0 . . * 24 hr Recap: Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 2240 0 42.0 Hours 29.00 Cly Comments 2994' Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade Gas Summary 22 (current) Units*C-2 0 C-4n 0 579 0 Depth 0' 1.117 13 6Minimum Depth Maximum in 2 Lithology (%) 1 Bit # 8148' 0 0 0 PM ECD:9.99-10.07ppg. Monitor well. Static. Continuing to drill ahead to a depth of 8396' MD at time of report. 7 % 846 Alkal Coal Gallons/stroke 7460' 8379' 919' Lime TuffGvl 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to0' Current 43.0223.0 MWD Summary Ss Cht Silt 100 12.25 Footage Depth in / out 16 160' $2,810.00 $22,470.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 0 0 0 0 Chromatograph (ppm) 10 0 Mud (lb/bbl)ml/30min 0.20 (max) 0 C-3 Average 2Background 100% Gas In Air=10,000 UnitsConnection Drill 12.25" hole F/7460' T/7635' @ 850 to 900 gpm, AM ECD: 9.85ppg. Monitor well. Static. Trip 2 3175' 20.0 Size 3160'BTC Hycalog Casing Summary Bit Type 9.20 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 26 RPM 49 Mud Type LSND 5.5 Ratio Mud Data Depth 2/939.20 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 8104'1500.0 Cor Solids 10.06 Avg Min YP MaxECD (ppg)Tools ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 401.0 Morning Report Report # 11 Customer: Well: Area: Location: Rig: SI35-W4 7-Sep-2013 12:00 AM AK-AM-0900702266 2051 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 7742' 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0900702266 1316 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 9218'424.0 Morning Report Report # 12 Customer: Well: Area: Location: Rig: SI35-W4 8-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids 9.81 Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 9219'1400.0 Mud Type LSND 4.5 Ratio Mud Data Depth 2/949.20 Oil / Water (lb/100ft2) 9.20 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 24 RPM 45 20.0 Size 3160'BTC Hycalog Casing Summary Bit Type Continuing to drill ahead to a depth of 9360' MD at time of report. Experiencing hard streaks which is slowing Trip 2 3175' 100% Gas In Air=10,000 UnitsConnection Average 2Background Mud (lb/bbl)ml/30min 0.20 (max) 0 C-3 Chromatograph (ppm) 7 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i $2,810.00 $25,280.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type 12.25 Footage Depth in / out 16 160' Ss Cht Silt 80 Avg to0' Current 47.00.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 8379' 9307' 928' Lime TuffGvl 96% Date: % 692 Alkal Coal Gallons/stroke progress. When not experiencing hard steaks drilling progresses smoothly. Current sampling shows 80% SST and 20% Sltst. 12 8815' 0 0 0 Minimum Depth Maximum in 2 Lithology (%) 1 Bit # 1167 0 Depth 0' 1.117 11 0 C-2 0 C-4n 0 Gas Summary 117 20(current) Units* Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade 42.0 Hours 29.00 Cly Comments 2994' Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 13693 0 . . * 24 hr Recap: Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 5470 0 42.0 Hours 29.00 Cly Comments 2994' Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 Grade Gas Summary 52 70(current) Units*C-2 0 C-4n 0 1519 0 Depth 0' 1.117 11 12Minimum Depth Maximum in 3 Lithology (%) 1 Bit # 9500' 0 0 0 Circ btms up x4's while rack back 6 stds F/9566' T/9036. Con't BROOH F/9036' T/4642. Coming out to pick up new bit. 15 % 892 Alkal Coal Gallons/stroke 9307' 9567' 260' Lime TuffGvl 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to0' Current 28.00.0 MWD Summary Ss Cht Silt 30 12.25 Footage Depth in / out 16 160' Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 0 0 0 0 Chromatograph (ppm) 22 3 Mud (lb/bbl)ml/30min 0.15 (max) 2 C-3 Average 6Background 100% Gas In Air=10,000 UnitsConnection Drill 12.25" hole F/9307' T/9566' AM ECD: 9.89 ppg Monitor well. Static. Trip The last sample caught was very silty. It contained 70% Siltstone and 30% Sandstone. Gas was low. 2 3175' 20.0 Size 3160'BTC Hycalog Casing Summary Bit Type 9.30 3175' WOB MX-1 TFA Condition 0-1-WT-G-E-In-No-TD 25 RPM 47 Mud Type LSND 5.0 Ratio Mud Data Depth 2/929.30 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 9567'1400.0 Cor Solids 9.92 Avg Min YP MaxECD (ppg)Tools ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 223.0 Morning Report Report # 13 Customer: Well: Area: Location: Rig: SI35-W4 9-Sep-2013 12:00 AM AK-AM-0900702266 1528 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 9408' 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0900702266 795 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft Morning Report Report # 14 Customer: Well: Area: Location: Rig: SI35-W4 10-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids 11.20 Avg Min YP MaxECD (ppg) Tools 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 9567'1500.0 Mud Data Depth 2/929.20 Oil / Water (lb/100ft2) Condition 0-1-WT-G-E-In-No-TD 22 RPM 46 Mud Type LSND 5.2 Ratio Bit Type 9.20 3175' WOB MX-1 TFA Con't BROOH f/4642' to 3151' at 900 gpm, 130 rpm & 1300 psi.Service top drive, draw works & travelling equip. Trip 2 3175' 76.40 100% Gas In Air=10,000 UnitsConnection Average 0Background 0.20 (max) 0 C-3 11 20.0 6392' Chromatograph (ppm) 0 3 0 0 0 0 C-5i ShSiltst LstClyst C-4i $2,810.00 $30,900.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type Footage Depth in / out 16 160' 9567' Size 3160' 30 12.25 0.969 BTC Hycalog Casing Summary Avg to0' Current MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Gvl 7-5-WT-A-X-In-BT-BHA 96% Date: Time: Cement Mud (lb/bbl)ml/30min 640 Alkal Coal Gallons/stroke 9567' 9567' 0' Lime Tuff % 0 Tag obstruction at 3157'. Pull up to 3150'. Work thru at 650 gpm & 710 psi. Continue to RIH to 4361' MD at time of report. 0 in 0 Lithology (%) 1 Bit # 0' 0 0 0Minimum Depth Maximum Ss Cht Silt C-1 0 0 Depth 0' 1.117 11 Units*C-2 0 C-4n 0 Grade Gas Summary 0 70(current) 2994' Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 0 143 42.0 Hours 29.00 Cly Comments 3176' Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 0 0.96912.25SKH1716D-E8C3 . . * 24 hr Recap: 0.96912.25SKH1716D-E8C3 Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 65755 143 42.0 Hours 29.00 Cly Comments 3176' Unit Phone: 19 Paul Kalenuik Set AtSize 68.0 L-80 0 660 70(current) 0 C-4n 0 72 Depth 0' 1.117 11 Units*Depth Maximum Ss Cht Silt C-1 Gas Summary 1 Bit # 10300' 0 202 14Minimum Drill f/9885' MD to TD at 11250' MD / ' TVD at 11250' MD / 3550' TVD at 850 gpm, 2200 psi . Monitor well. Static. 100 Sample Discription- wh-gry-brn-blk, uncons, med-v fn gr, sb-and-sb rnd, mod srt, v slty, tr pyr, 10% sh, SHOW- lt brn stn 2 8880 % 582 Alkal Coal Gallons/stroke 9567' 11250' 1683' Lime Tuff Grade 7-5-WT-A-X-In-BT-BHA 96% Date: Time: Cement Mud (lb/bbl)ml/30min 854 API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to0' Current 107.00.0 MWD Summary 30 12.25 0.969 BTC Hycalog Casing Summary Lithology (%) Depth in / out 16 160' 9567' Size 3160' 2994' $2,810.00 $33,710.00 Drilling Ahead PV cP Weight Flow In (gpm) Flow In (spm) Type ShSiltst LstClyst C-4i Gvl C-2 0 C-5i 6392' Chromatograph (ppm) 1040 570 84 (max) 127 C-3 11 647 0 Average 2Background 100% Gas In Air=10,000 UnitsConnection 20% dl yel flour, dl yel ct flour. Cont RIH f/3520' & conduct SLB check shots at 3519', 3800' & 4360'. Fill pipe every 20 stds & survey. Trip 2 3175' 76.40 Bit Type 9.20 3175' WOB MX-1 TFA 0.15 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 24 RPM 48 Mud Type LSND 4.6 Ratio Mud Data Depth 3/91.29.30 Oil / Water (lb/100ft2)in 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 11084'1200.0 Cor Solids 10.26 Avg Min YP MaxECD (ppg) Tools ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 354.0 Morning Report Report # 15 Customer: Well: Area: Location: Rig: SI35-W4 11-Sep-2013 12:00 AM AK-AM-0900702266 2212 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 10152' 87 233 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 00 12:00 AM AK-AM-0900702266 2165 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 0'0.0 Morning Report Report # 16 Customer: Well: Area: Location: Rig: SI35-W4 11-Sep-2013 ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids 10.26 Avg Min YP MaxECD (ppg) Tools in 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: Mud Type LSND 4.6 Ratio Mud Data Depth 3/919.20 Oil / Water 0.15 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 21 RPM 900.0 Bit Type 9.20 3175' WOB MX-1 TFA 4411250' BROOH f/8289' to 3149' MD at 850 gpm, 1200 psi & 130 rpm. Monitor well. Static. Total Mud losses were 57 bbls. Trip 2 3175' 76.40 100% Gas In Air=10,000 UnitsConnection Average 0Background 11 0 0 0 (max) Chromatograph (ppm) 0 0 C-3 C-5i 6392' 00 Type ShSiltst LstClyst C-4iC-2 2994' $2,810.00 $36,520.00 BROOH PV cP Flow In (gpm) Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' Size 3160' Weight 1580 12.25 0.969 BTC Hycalog Casing Summary Lithology (%) Avg to0' Current 0.00.0 MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 7-5-WT-A-X-In-BT-BHA 96% Date: Time: Cement Mud (lb/bbl)ml/30min 821 Gvl Alkal Coal Gallons/stroke 11250' 11250' 0' Lime Tuff Grade % 0 0 Sample Discription- 0 0 1 Bit # 0' 0 0 0Minimum Maximum Ss Cht Silt C-1 Gas Summary 0 Depth 0' 1.117 11 Units*Depth 0 C-4n 0 0 0 5(current) Unit Phone: 0 Paul Kalenuik Set AtSize 68.0 L-80 0 143 42.0 Hours 29.00 Cly Comments 3176' Report By: 13-3/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) 0 0.96912.25SKH1716D-E8C3 . . * 24 hr Recap: (max)(current) 0 0.96912.25SKH1716D-E8C3 143 42.0 Hours 29.00 Cly Comments 3176' Unit Phone: 0 Paul Kalenuik 0 Report By:Logging Engineers:Paul Kalenuik/Kori Plowman 0 0 Depth 0' 1.117 10 Units*Depth 5(current) C-1 Gas Summary 0 0 C-4n Minimum 9-5/8" Maximum Ss Cht 0' 0 0 0 0 Calculated disp observed. No Daily LSND. Total LSND loss: 57 bbls. 0 Sample Discription- 0 0 % 0 Coal Gallons/stroke 11250' 11250' 0' Lime Tuff Grade L-80 7-5-WT-A-X-In-BT-BHA 96% Date: Time: Cement Mud (lb/bbl)ml/30min 0 Gvl API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to0' Current 0.00.0 MWD Summary 12.25 0.969 BTC Hycalog Casing Summary Lithology (%)Silt Set AtSize 13-3/8"3160' Weight 1580 68.0 Flow In (gpm) Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' Size C-4iC-2 2994' $2,810.00 $39,330.00 BROOH PV cP 6392' 00 Type ShSiltst Lst (max) Chromatograph (ppm) 0 0 C-3 0 11 0 0 C-5i Clyst 0Background 100% Gas In Air=10,000 UnitsConnection 2 3175' 76.40 Bit Type 3175' WOB MX-1 TFA 4511250' 1 Bit # 0.20 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 20 RPM 900.0 Mud Type LSND 5.0 Ratio Mud Data Depth 3/919.15 Oil / Water in 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: Cor Solids 9.26 Avg Min YP MaxECD (ppg) Tools Alkal ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 0.0 Morning Report Report # 17 Customer: Well: Area: Location: Rig: SI35-W4 11-Sep-2013 12:00 AM AK-AM-0900702266 0 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 0' Trip Average 0 Running in hole with 9-5/8" casing. Begin rotate csg at 40 to 50 rpm to 8145' at report time. Density (ppg) out (sec/qt) Viscosity 0 . . * 24 hr Recap: 0 41683'11250' (max) 0 0 (current) H563 0 16.000.96912.25SKH1716D-E8C3 Hours 29.00 Cly L-80 Comments 9567' 1-1-CT-G-X-In-No-TD99 Unit Phone: 0 Paul Kalenuik 0 Report By:Logging Engineers:Paul Kalenuik/Kori Plowman 0 Depth 0' 1.117 Gas Summary C-4n 143 Units*Depth 5(current) C-1 Minimum 9-5/8" Maximum Ss Cht 0' 0 0 0 0 stack. No Daily Losses. Total LSND Loss: 57 bbls. Prepping for BHA#5 . Calibrating gas equipment. 0 Sample Discription- 0 0 % 0 Coal Gallons/stroke 11250' 11250' 0' Lime Tuff Grade L-80 7-5-WT-A-X-In-BT-BHA 96% Date: Time: Cement Mud (lb/bbl)ml/30min 0 Gvl API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to0' Current 0.00.0 MWD Summary Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 40.0 Weight 1580 68.0BTC Flow In (gpm) Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size C-4iC-2 2994' $3,120.00 $42,440.00 cementing PV cP 6392' 00 Type ShSiltst Lst (max) Chromatograph (ppm) 0 0 C-3 Clyst 00 11 0 0 C-5i 0Background 100% Gas In Air=10,000 UnitsConnection 2 3175' 76.40 3160' 12.25 0.969Hycalog Bit Type 3175' WOB MX-1 TFA 4411250' 1 Bit # 0.15 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 17 RPM 1000.010 42.0 Mud Type LSND 5.2 Ratio Mud Data Depth 3/91.29.20 Oil / Water in 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: Cor Solids 9.26 Avg Min YP MaxECD (ppg) Tools Alkal ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 0.0 Morning Report Report # 18 Customer: Well: Area: Location: Rig: SI35-W4 11-Sep-2013 12:00 AM AK-AM-0900702266 0 ROP ROP (ft/hr) M. Ross/ R.Wimmer 24 hr Max Max @ ft 0' Trip Average Inject 20 bbls mud down annulus.R/D cmt head. Drain stack.Change bails.Prep to N/D BOP s. Density (ppg) out (sec/qt) Viscosity 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 Nipple down BOPE. Set 9-5/8" emergency slips. Cut 9-5/8" casing. Install packoff and test. Change upper rams to Trip Average 12:00 AM AK-AM-0900702266 0 ROP ROP (ft/hr) J. Keener/ R.Wimmer 24 hr Max Max @ ft 0'0.0 Morning Report Report # 19 Customer: Well: Area: Location: Rig: SI35-W4 15-Sep-2013 Tools Alkal ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: in 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: Mud Type LSND 5.2 Ratio Mud Data Depth 3/91.29.15 Oil / Water Bit # 0.15 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 17 RPM 5.810 Hycalog Bit Type 3175' WOB MX-1 TFA 4411250' 1 2 3175' 76.40 3160' 12.25 0.969 =10,000 UnitsConnection0Background 11 0 0 C-5i 00 100% Gas In Air(max) Chromatograph (ppm) 0 0 C-3 00 Type ShSiltst LstClyst C-2 2994' $4,120.00 $46,560.00 Picking Up Pipe PV cP 6392' YP Flow In (gpm) Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size 40.0 Weight 68.0BTCCasing Summary Lithology (%)Silt Set AtSize 13-3/8" Avg to0' Current 0.00.0 MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Time: Cement Mud (lb/bbl)ml/30min 0 Gvl 42.0 Cor Solids 9.26 11250' 11250' 0' Lime Tuff Grade L-80 7-5-WT-A-X-In-BT-BHA 96% Date: Coal Gallons/stroke Avg Min MaxECD (ppg) % 0 variables. Nipple up BOPE. Pick up stands of 4.5" drill pipe and rack in derrick. Set test plug. Test BOPE 0 Sample Discription- 0 0 0' 0 0 0 0Minimum 9-5/8" Maximum Ss Cht Units*Depth (current) C-1 C-4i 0 Depth 0' 1.117 Gas Summary C-4n 143 Unit Phone: 0 Kori Jo Plowman 0 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji Hours 29.00 Cly L-80 Comments 9567' 1-1-CT-G-X-In-No-TD99 (current) H563 0 16.000.96912.25SKH1716D-E8C3 0 41683'11250' (max) 0 0 . . * 24 hr Recap: 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD3SKH1716D-E8C 12.25 0.969 16.00 0 Density (ppg) out (sec/qt) Viscosity in Mud Type P/U 90 stnds 4.5" drill pipe. Changed saver sub. P/U BHA #5 and 8.75" bit. RIH and shallow test. MAD pass to 10,000 UnitsTrip Average 12:00 AM AK-AM-0900702266 0 ROP ROP (ft/hr) J. Keener/ R.Wimmer 24 hr Max Max @ ft 0'0.0 Morning Report Report # 20 Customer: Well: Area: Location: Rig: SI35-W4 16-Sep-2013 Tools Alkal ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) FAZEPRO Ratio 3.58 Mud Data Depth 1.89.25 Oil / Water YP Bit # 2.75 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 13 RPM 5.914 Hycalog Bit Type 3175' WOB MX-1 TFA 4611250' 1 2 3175' 76.40 3160' 12.25 0.969 =0Background Connection 11 0 0 C-5i 00 100% Gas In Air(max) Chromatograph (ppm) 0 0 C-3 00 Type ShSiltst LstClyst Weight C-2 2994' $3,110.00 $59,960.00 Testing Casing PV cP 6392' Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size 40.0 68.0BTCCasing Summary Lithology (%)Silt Set AtSize 13-3/8" Avg to0' Current 0.00.0 MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Time: Cement Mud (lb/bbl)ml/30min 0 Gvl 42.0 Cor Solids 9.26 11250' 11250' 0' Lime Tuff Grade L-80 7-5-WT-A-X-In-BT-BHA 96% Date: Coal Gallons/stroke Avg Min MaxECD (ppg) % 0 11066' MD. Circulate and balance mud. 0 Sample Discription- 0 0 0' 0 0 0 0Minimum 9-5/8" Maximum Ss Cht Units*Depth (current) C-1 C-4i 0 Depth 0' 1.117 Gas Summary C-4n 143 Unit Phone: 0 Kori Jo Plowman 0 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji Hours 29.00 Cly L-80 Comments 11250' (current) H563 0 0.9028.75SHK616M PDC4 0 (max) 0 0 . . * 24 hr Recap: 0 (max) 0 458 11306' (current) H563 168086 0.9028.75SHK616M PDC4 L-80 Comments 11250' Unit Phone: 90 Kori Jo Plowman 0 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji Depth 0' 1.117 Gas Summary C-4n 143 Hours 29.00 Cly (current) C-1 C-4i 1584 Units*Depth Minimum 9-5/8" Maximum Ss Cht 46280 11675' 0 410 240 160 MD and 20' new hole to 11270' MD. FIT. Drill 8.75" production hole to 12557' MD 454 Sample Discription- SST: trnsp-trnsl-wh-lt gry-dk gry-brn-grn-blk, f-vf gr, sb ang-sb rnd, w srt, sli slty, uncons, r mic, r pyr, SHOW: 5 Coal Gallons/stroke Avg Min MaxECD (ppg) % 11250' 12557' 1307' Lime Tuff Grade L-80 7-5-WT-A-X-In-BT-BHA 96% Date: Cement Mud (lb/bbl)ml/30min 502 Gvl 42.0 Cor Solids 11.04 API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 113 SPP (psi) Time: Avg to0' Current 300.0283.0 MWD Summary Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 40.0 68.0BTC 20 6392' Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size C-2 2994' $3,110.00 $63,070.00 Drill 8.75" Production PV cP 228495 Type ShSiltst LstClyst Weight Chromatograph (ppm) 1451 1031 C-3 3 136277 100% Gas In Air 11 387 0 C-5i Background Connection132 (max) = 2 3175' 76.40 3160' 12.25 0.969 80 Hycalog Bit Type 3175' WOB MX-1 TFA 4512106' 1 Bit # 2.70 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 18 RPM 6.214FAZEPRO Ratio 3.51 Mud Data Depth 66/349.20 Oil / Water YP 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools Alkal ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 485.0 Morning Report Report # 21 Customer: Well: Area: Location: Rig: SI35-W4 17-Sep-2013 12:00 AM AK-AM-0900702266 2566 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ft 12093' Trip Average Test 9 5/8" casing. Displace to OBM. Clean surface equipment. Cut and slip drill line. Drill cement to shoe at 11250' tr lt brn stn, 40% even fnt wh-yel fluor, fnt wh ct fluor. 10,000 Units Density (ppg) out (sec/qt) Viscosity in Mud Type 3 SKH1716D-E8C 12.25 0.969 16.00 85 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD . . * 24 hr Recap: 8.75SHK616M PDC4 03412492' 11250' 40.0 (current) H563 290763 0.902 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 205 143 Hours 29.00 Cly Unit Phone: 140 Kori Jo Plowman 31 Depth 0' 1.117 Gas Summary C-4nUnits*Depth C-1 2968Maximum Ss Cht Coal (current) C-4i 13638' 15 459 15568 33278 Minimum Grade L-80 Mud 236 711 Sample Discription- SST: trnsp-trnsl-wh-lt gry-brn-grn-blk, uncons, f-vf gr, sb ang-sb rnd, w srt, sli slt, tr mic, SHOW: brn stn, 70% Gallons/stroke Avg Min MaxECD (ppg) % 12557' 14039' 1482' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: Cement (lb/bbl)ml/30min 548 Gvl 42.0 Cor Solids 11.32 4.23 API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 131 SPP (psi) Time: 0' Current 103.082.0 MWD Summary Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 68.0BTC 10 Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to C-2 2994' $3,110.00 $66,180.00 Drill 8.75" Production PV cP 116392' 119260 Type ShSiltst LstClyst Weight Chromatograph (ppm) 1275 803 C-3 45 98150 100% Gas In Air 420 27 C-5i Background Connection50 (max) = 2 3175' 76.40 3160' 12.25 0.969 90 Hycalog Bit Type 3175' WOB MX-1 TFA 4513936' 1 Bit # 2.00 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 20 RPM 7.714FAZEPRO Ratio 2.60 Mud Data Depth 68/329.25 Oil / Water YP @ Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools Alkal ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 455.0 Morning Report Report # 22 Customer: Well: Area: Location: Rig: SI35-W4 18-Sep-2013 12:00 AM AK-AM-0900702266 3020 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ft 13683' Avg Trip Average Drill 8.75" production hole from 12557' MD to 14039' MD. The max gas in the last 24 hours was 2968 units even brt wh-yel fluor, dull wh-yel ct fluor. 10,000 Units Density (ppg) out (sec/qt) Viscosity in Mud Type 3 SKH1716D-E8C 12.25 0.969 16.00 66 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD . . * 24 hr Recap: 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD3SKH1716D-E8C 12.25 0.969 16.00 92 Density (ppg) out (sec/qt) Viscosity in Mud Type Drill 8.75" production hole from 14039' MD to 16293' MD. The max gas in the last 24 hours was 2375 units even brt wh-yel fluor, dull wh ct fluor. 10,000 UnitsTrip Average AK-AM-0900702266 3068 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ft 15922' Avg Morning Report Report # 23 Customer: Well: Area: Location: Rig: SI35-W4 19-Sep-2013 12:00 AM ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools 499.0 FAZEPRO Ratio 3.90 Mud Data Depth 69/319.25 Oil / Water YP Bit # 3.00 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 19 RPM 8.414 Hycalog Bit Type 3175' WOB MX-1 TFA 4516105' 1 2 3175' 76.40 3160' 12.25 0.969 90 =59 (max)Background Connection C-5i 153293 100% Gas In Air Chromatograph (ppm) 1756 1318 C-3 0 264747 Type ShSiltst LstClyst Weight C-2 2994' $3,110.00 $69,290.00 Drill 8.75" Production PV cP 116392' Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to 68.0BTC 10 Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 0' Current 256.00.0 MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 126 SPP (psi) Time: 527 Gvl 42.0 Cor Solids 11.60 4.23 @ 14039' 16293' 2254' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: Cement Gallons/stroke Avg Min MaxECD (ppg) %(lb/bbl)ml/30min Alkal Grade L-80 Mud 279 727 Sample Discription- SST: trnsp-trnsl-wh-lt gry-dk gry-brn-grn-blk, uncons, f-vf gr, sb rnd-rnd, w srt, slty, abd mic, SHOW: brn stn, 70% 11 77143 Minimum 15932' 0 627 98 540 0 Maximum Ss Cht Coal (current) C-4iUnits*Depth C-1 2375 Depth 0' 1.117 Gas Summary C-4n 143 Hours 29.00 Cly Unit Phone: 173 Kori Jo Plowman 0 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 576 11250' 40.0 (current) H563 232426 0.9028.75SHK616M PDC4 0014661' . . * 24 hr Recap: 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD3SKH1716D-E8C 12.25 0.969 16.00 90 Density (ppg) out (sec/qt) Viscosity in Mud Type Drill 8.75" production hole from 16293' MD to 18160' MD. The max gas in the last 24 hours was 2286 units. 80% even brt wh-yel fluor, dull wh ct fluor. 10,000 UnitsTrip Average AK-AM-0900702266 2917 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ft 17416' Avg Morning Report Report # 24 Customer: Well: Area: Location: Rig: SI35-W4 20-Sep-2013 12:00 AM ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools 545.0 FAZEPRO Ratio 2.54 Mud Data Depth 69/319.20 Oil / Water YP Bit # 1.95 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 18 RPM 7.813 Hycalog Bit Type 3175' WOB MX-1 TFA 4517945' 1 2 3175' 76.40 3160' 12.25 0.969 85 =70 (max)Background Connection C-5i 144270 100% Gas In Air Chromatograph (ppm) 1656 1239 C-3 0 240738 Type ShSiltst LstClyst Weight C-2 2994' $3,410.00 $72,700.00 Monitor Well PV cP 116392' Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to 68.0BTC 15 Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 0' Current 273.00.0 MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 117 SPP (psi) Time: 490 Gvl 42.0 Cor Solids 11.80 4.23 @ 16293' 18160' 1867' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: Cement Gallons/stroke Avg Min MaxECD (ppg) %(lb/bbl)ml/30min Alkal Grade L-80 Mud 256 Average mud loss rate of 20-40 bph. 852 Sample Discription- SST: trnsp-trnsl-wh-gry-brn-grn-blk-tn, uncons, m-vf gr, sb ang-sb rnd, mod srt, slty, abd mic, SHOW: brn stn, 11 89355 Minimum 17907' 0 580 71 505 0 Maximum Ss Cht Coal (current) C-4iUnits*Depth C-1 2286 Depth 0' 1.117 Gas Summary C-4n 143 Hours 29.00 Cly Unit Phone: 149 Kori Jo Plowman 0 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 501 11250' 40.0 (current) H563 222738 0.9028.75SHK616M PDC4 0016651' . . * 24 hr Recap: 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD3SKH1716D-E8C 12.25 0.969 16.00 88 Density (ppg) out (sec/qt) Viscosity in Mud Type Drill 8.75" production hole from 18160' MD to 19932' MD TD. The max gas in the last 24 hours was 2186 units. brn stn, 60% even brt wh fluor, brt wh-yel ct fluor. 10,000 UnitsTrip Average AK-AM-0900702266 2509 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ft 19191' Avg Morning Report Report # 25 Customer: Well: Area: Location: Rig: SI35-W4 21-Sep-2013 12:00 AM ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools 534.0 FAZEPRO Ratio 3.90 Mud Data Depth 69/319.25 Oil / Water YP Bit # 3.00 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 21 RPM 7.914 Hycalog Bit Type 3175' WOB MX-1 TFA 4619932' 1 2 3175' 76.40 3160' 12.25 0.969 100 =(max)Background Connection C-5i 152290 100% Gas In Air Chromatograph (ppm) 1137 771 C-3 0 260739 Type ShSiltst LstClyst Weight C-2 2994' $3,410.00 $76,110.00 BROOH PV cP 116392' Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to 68.0BTCCasing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 0' Current 249.00.0 MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 107 SPP (psi) Time: 448 Gvl 42.0 Cor Solids 11.76 4.23 @ 18160' 19932' 1772' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: Cement Gallons/stroke Avg Min MaxECD (ppg) %(lb/bbl)ml/30min Alkal Grade L-80 Mud 174 Currently BROOH. 828 Sample Discription- SST: trnsp-trnsl-wh-gry-dk gry-brn-grn-blk, uncons, m-vf gr, sb ang-sb rnd, mod srt, sli slty, abd mic, SHOW: 11 84874 Minimum 19276' 0 357 55 331 0 Maximum Ss Cht Coal (current) C-4iUnits*Depth C-1 2186 Depth 0' 1.117 Gas Summary C-4n 143 Hours 29.00 Cly Unit Phone: 98 Kori Jo Plowman 0 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 541 11250' 40.0 (current) H563 155158 0.9028.75SHK616M PDC4 0019027' . . * 24 hr Recap: 8.75SHK616M PDC4 11250' 40.0 (current) H563 0.902 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 143 Hours 29.00 Cly Unit Phone:Kori Jo Plowman Depth 0' 1.117 Gas Summary C-4nUnits*Depth C-1 Maximum Ss Cht Coal (current) C-4i Minimum Grade L-80 Mud Gallons/stroke Avg Min MaxECD (ppg) %(lb/bbl)ml/30min Alkal 19932' 19932' 1772' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: CementGvl 42.0 Cor Solids 10.65 4.23 @ API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Time: 0' Current MWD Summary Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 68.0BTC Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to C-2 2994' $3,410.00 $79,520.00 POOH BHA #5 PV cP 116392' Type ShSiltst LstClyst Weight Chromatograph (ppm) C-3 100% Gas In Air C-5i Background 156 Connection (max) = 2 3175' 76.40 3160' 12.25 0.969Hycalog Bit Type 3175' WOB MX-1 TFA 4719932' 1 Bit # 3.05 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 21 RPM 7.914FAZEPRO Ratio 3.97 Mud Data Depth 69/319.20 Oil / Water YP Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 26 Customer: Well: Area: Location: Rig: SI35-W4 22-Sep-2013 12:00 AM AK-AM-0900702266 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ftAvg Trip Average BROOH to 8917' MD. POOH at time of report. The max trip gas observed was 156 units. 10,000 Units Density (ppg) out (sec/qt) Viscosity in Mud Type 3 SKH1716D-E8C 12.25 0.969 16.00 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD . . * 24 hr Recap: 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD3SKH1716D-E8C 12.25 0.969 16.00 Density (ppg) out (sec/qt) Viscosity in Mud Type POOH. L/D BHA #5. Service rig. RIH w/hole opener. Cut and slip drill line, service drawworks brakes and top drive. observed was 63 units. 10,000 UnitsTrip Average AK-AM-0900702266 662 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ftAvg Morning Report Report # 27 Customer: Well: Area: Location: Rig: SI35-W4 23-Sep-2013 12:00 AM ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools FAZEPRO Ratio 3.97 Mud Data Depth 69/319.20 Oil / Water YP Bit # 3.05 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 21 RPM 7.914 Hycalog Bit Type 3175' WOB MX-1 TFA 4719932' 1 2 3175' 76.40 3160' 12.25 0.969 =(max)Background 63 Connection C-5i 100% Gas In Air Chromatograph (ppm) C-3 Type ShSiltst LstClyst Weight C-2 2994' $3,410.00 $82,930.00 Circ on Bottom PV cP 116392' Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to 68.0BTCCasing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 0' Current MWD Summary API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 34 SPP (psi) Time: 142 Gvl 42.0 Cor Solids 10.65 4.23 @ 19932' 19932' 0' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: Cement Gallons/stroke Avg Min MaxECD (ppg) %(lb/bbl)ml/30min Alkal Grade L-80 Mud RIH, excessive drag at 17137' MD. Work through twice. Tag bottom at 19932' MD. Circulate and condition hole. The max trip gas Minimum Maximum Ss Cht Coal (current) C-4iUnits*Depth C-1 Depth 0' 1.117 Gas Summary C-4n 143 Hours 29.00 Cly Unit Phone:Kori Jo PlowmanReport By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 11250'0-1-CT-S-X-In-No-TD160 40.0 (current) H563 58.000.9028.75SHK616M PDC4 108682'19932' . . * 24 hr Recap: 8.75SHK616M PDC4 108682'19932'11250'0-1-CT-S-X-In-No-TD160 40.0 (current) H563 58.000.902 Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji L-80 Comments (max) 143 Hours 29.00 Cly Unit Phone:Kori Jo Plowman Depth 0' 1.117 Gas Summary C-4nUnits*Depth C-1 Maximum Ss Cht Coal (current) C-4i Minimum Grade L-80 Mud Gallons/stroke Avg Min MaxECD (ppg) %(lb/bbl)ml/30min Alkal 19932' 19932' 0' Lime Tuff 7-5-WT-A-X-In-BT-BHA 96% Date: Cement 142 Gvl 42.0 Cor Solids 10.65 4.23 @ API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 34 SPP (psi) Time: 0' Current MWD Summary Casing Summary Lithology (%)Silt Set AtSize 13-3/8" 9-5/8" 68.0BTC Flow In (spm) (lb/100ft2) Depth in / out 16 160' 9567' 11239' Size to C-2 2994' $2,937.80 $85,867.80 Displace to Brine PV cP 116392' Type ShSiltst LstClyst Weight Chromatograph (ppm) C-3 100% Gas In Air C-5i Background 19 Connection (max) = 2 3175' 76.40 3160' 12.25 0.969Hycalog Bit Type 3175' WOB MX-1 TFA 4719932' 1 Bit # 3.05 20.0 Footage Condition 0-1-WT-G-E-In-No-TD 21 RPM 7.914FAZEPRO Ratio 3.97 Mud Data Depth 69/319.20 Oil / Water YP Current Pump & Flow Data: Doyon 15 Report For: Flow In (gpm) Tools ENI Petroleum Spy Island North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 28 Customer: Well: Area: Location: Rig: SI35-W4 24-Sep-2013 12:00 AM AK-AM-0900702266 662 ROP ROP (ft/hr) J. Keener/ O. Amend 24 hr Max Max @ ftAvg Trip Average Continue to circulate at 19932' MD. POOH on elevators to 11006' MD. Pump LVT spacer, displace to Brine. 10,000 Units Density (ppg) out (sec/qt) Viscosity in Mud Type 3 SKH1716D-E8C 12.25 0.969 16.00 9567' 11250' 1683'4 99 1-1-CT-G-X-In-No-TD . . * 24 hr Recap: (max)(current) H563 0 0 Cly 0 Set AtSize 68.0 L-80 Grade 13 3/8" Unit Phone: 0 Kori Jo Plowman Maximum Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji 0 0 Siltst 9 5/8" Units* Casing Summary Lithology (%) 0 SPP (psi) Gallons/stroke TFABit Type Depth MBT 0' C-5nC-2 in Minimum Depth transportation off island in case of emergency. R/U casing equipment. Run 4.5" liner Date: Time: to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Max @ ft Current Gas Summary 0 0 0 (current) TuffGvlCoal cP L-80 Ss (ppb Eq) C-1 C-5i PV Footage ShClyst Weight 0 Hours C-3 0 0 0 CementChtSilt C-4i C-4n 000 00 12.25Hycalog 3 SKH1716D-E8C 12.25 Depth in / out Mud Type Lst Type Average Background (max) Trip Comments RPM ECD (ppg) ml/30min pH 1683'4 99 1-1-CT-G-X-In-No-TD 10.65 YP (lb/100ft2) 76.400.969 0.969 16.00 9567' 11250' 0 Tools API FL Chromatograph (ppm) WOB BTC 0-1-CT-S-X-In-No-TD16058.000.902 100% Gas In Air=10,000 UnitsConnection 11239' 3160' 8.75SHK616M PDC4 108682'19932'11250' 40.0 ConditionBit #Size MWD Summary 96% Rig Activity: Report For: Avg Min 24 hr MaxAvg $2,810.00 $88,677.80 19932' 19932' 0' Job No.: Daily Charges: Total Charges: Morning Report Report # 29 Customer: Well: Area: Location: Rig: ENI Petroleum SI35-W4 Spy Island AK-AM-0900702266 1 20.0 0-1-WT-G-E-In-No-TD 143 7-5-WT-A-X-In-BT-BHA9567' 116392'2 3175' 4.23 @ Mud Data Depth 16 160'2994'3175' MX-1 North Slope Doyon 15 Run 4.5" Liner J. Keener/ O. Amend 25-Sep-2013 29.001.117 42.0 ROP ROP (ft/hr) 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 93000.0019932'Brine 9.10 27 Continue to displace to Brine. Clean surface equipment. POOH and L/D BHA #6. Safety stand down due to no Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: % Continue to RIH 4.5" liner. Run to 8892' MD. R/D casing equipment. R/U to RIH w/5" DP. RIH w/4.5" liner on 5" DP Density (ppg) out (sec/qt) Viscosity Cor Solids 87500.0019932'Brine 9.10 27 Chlorides mg/l 0 ROP (ft/hr) 12:00 AM Current Pump & Flow Data: Max MX-1 North Slope Doyon 15 Run 4.5" Liner B. Perry / O. Amend 26-Sep-2013 29.001.117 42.0 ROP 2 3175' 4.23 @ Mud Data Depth 16 160'2994'0-1-WT-G-E-In-No-TD 143 7-5-WT-A-X-In-BT-BHA9567' 116392' 3175' Morning Report Report # 30 Customer: Well: Area: Location: Rig: ENI Petroleum SI35-W4 Spy Island AK-AM-0900702266 $2,810.00 $91,487.80 19932' 19932' 0' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Report For: Avg Min 24 hr MaxAvg Bit #Size 1 11239' 3160' 8.75SHK616M PDC4 108682'19932'11250' 40.0 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) WOB BTC 0-1-CT-S-X-In-No-TD160 1-1-CT-G-X-In-No-TD 10.65 YP (lb/100ft2) 76.40 16.00 9567' 11250' ConditionRPM ECD (ppg) ml/30min pH 1683'4 99 20.0 Background (max) Trip Average Mud Type Lst Type 0.969Hycalog 3 SKH1716D-E8C 12.25 Depth in / out 0.969 0 58.000.902 000 00 0 0 CementChtSilt C-4i C-4n 0 Hours C-3 0 (ppb Eq) C-1 C-5i PV Footage ShClyst Weight TuffGvlCoal cP L-80 Comments Gas Summary 0 0 0 (current) to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Max @ ft Current Date: Time: in Minimum Depth Ss 12.25 C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth MBT 0' Siltst 9 5/8" Units* Casing Summary Lithology (%) 00 0 Unit Phone: 0 Kori Jo Plowman Maximum Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji Set AtSize 68.0 L-80 Grade 13 3/8" (max)(current) H563 0 0 Cly 0 . . * 24 hr Recap: Cly 0 13 3/8" (max)(current) H563 0 0 Unit Phone: 0 Kori Jo Plowman Maximum Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji 00 0 9 5/8" Units* Casing Summary Lithology (%) Set AtSize TFABit Type Depth MBT 0' Siltst 68.0 L-80 Grade C-2 in Minimum Depth Ss 12.25 Continue to POOH L/D liner running tool. R/U 4.5" elevator, RIH w/4.5" DP from surface to 6262' MD. POOH L/D 4.5" DP. Date: Time: SPP (psi) Gallons/stroke to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Max @ ft Current 0 (current) C-5n GvlCoal cP L-80 Comments (ppb Eq) C-1 C-5i PV Footage ShClyst Weight 0 Hours C-3 0 Gas Summary 0 0 0 CementChtSilt C-4i C-4n Tuff 000 00 Hycalog 3 SKH1716D-E8C 12.25 Depth in / out 0.969 0 58.000.902 Mud Type Lst Type 0.969 Average Background (max) Trip ECD (ppg) ml/30min pH 1683'4 99 20.0 10.65 YP (lb/100ft2) 76.40 16.00 9567' 11250' ConditionRPM Tools API FL Chromatograph (ppm) WOB BTC 0-1-CT-S-X-In-No-TD160 1-1-CT-G-X-In-No-TD 100% Gas In Air=10,000 UnitsConnection 0 11239' 3160' 8.75SHK616M PDC4 108682'19932'11250' 40.0 Bit #Size 1 MWD Summary 96% Rig Activity: Report For: Avg Min 24 hr MaxAvg $2,810.00 $94,297.80 19932' 19932' 0' Job No.: Daily Charges: Total Charges: Morning Report Report # 31 Customer: Well: Area: Location: Rig: ENI Petroleum SI35-W4 Spy Island AK-AM-0900702266 2994'0-1-WT-G-E-In-No-TD 143 7-5-WT-A-X-In-BT-BHA9567' 116392' 3175' North Slope Doyon 15 L/D 4.5" DP B. Perry / R. Wimmer 27-Sep-2013 29.001.117 42.0 ROP 4.23 12:00 AM Current Pump & Flow Data: Max MX-1 3175' @ Mud Data Depth 0 ROP (ft/hr) 2 16 160' 27 Chlorides mg/l Density (ppg) out (sec/qt) Viscosity Cor Solids 92500.00 % Continue to RIH 4.5" liner on 5" DP. Test packer. R/D test equipment. Cut and slip drill line. POOH L/D 5" DP. 19932'Brine 9.10 . . * 24 hr Recap:Continue to POOH L/D 4.5" DP. Pull wear ring, set test plug. R/U to test BOP's. Test BOP's. R/D test equipment. 19932'Brine 9.10 out (sec/qt) Viscosity Cor Solids 92500.00 % Chlorides mg/l Density (ppg) 0 ROP (ft/hr) 2 16 160' Current Pump & Flow Data: Max MX-1 3175' @ Mud Data Depth 27 Doyon 15 RIH 4.5" Tubing B. Perry / R. Wimmer 28-Sep-2013 29.001.117 42.0 ROP 4.23 12:00 AM 143 7-5-WT-A-X-In-BT-BHA9567' 116392' 3175' Morning Report Report # 32 Customer: Well: Area: Location: Rig: ENI Petroleum SI35-W4 Spy Island AK-AM-0900702266 Avg $2,810.00 $97,107.80 19932' 19932' 0' Job No.: Daily Charges: Total Charges: North Slope 1 MWD Summary 96% Rig Activity: Report For: Avg Min 24 hr Max 40.0 Bit #Size 3160' 8.75SHK616M PDC4 108682'19932'11250' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) WOB BTC 0-1-CT-S-X-In-No-TD160 1-1-CT-G-X-In-No-TD (lb/100ft2) 76.40 16.00 9567' 11250' ConditionRPM 2994'0-1-WT-G-E-In-No-TD ECD (ppg) ml/30min pH 1683'4 99 20.0 10.65 YP Background (max) Trip Average Mud Type Lst Type 0.969Hycalog 3 SKH1716D-E8C 12.25 Depth in / out 0.969 0 58.000.902 000 00 CementChtSilt C-4i C-4n Tuff Hours C-3 0 Gas Summary 0 0 0 (ppb Eq) C-1 C-5i PV Footage ShClyst Weight GvlCoal cP L-80 Comments 0 (current) C-5n to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Max @ ft Current Date: Time: SPP (psi) Gallons/stroke R/U Volant running tool. Run 4.5" completion tubing. in Minimum Depth Ss 12.25 C-2 TFABit Type Depth MBT 0' Siltst 68.0 L-80 Grade 9 5/8" Units* Casing Summary Lithology (%) Set AtSize 11239' 00 0 Unit Phone: 0 Kori Jo Plowman Maximum Report By:Logging Engineers:Kori Jo Plowman/Martin Nnaji 13 3/8" (max)(current) H563 0 0 0 Cly 0 WELL INFORMATION Customer :ENI Petroleum Well Name :SI35-W4 Job Number :AK-XX-0900702266 Platform :Spy Island Field Name :Nikaitchuq Country :USA Survey Report DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 180.00 0.00 0.00 N 0.00 E 0.00 0.00 40.57 0.00 180.00 40.57 0.00 N 0.00 E 0.00 0.00 117.20 0.15 286.15 117.20 0.03 N 0.10 W 0.03 0.20 169.15 0.17 260.82 169.15 0.03 N 0.24 W 0.03 0.14 199.56 0.51 176.33 199.56 0.11 S 0.27 W -0.11 1.72 261.90 2.92 170.18 261.87 1.95 S 0.01 E -1.95 3.87 327.97 4.37 173.88 327.80 6.11 S 0.57 E -6.11 2.22 360.27 4.48 178.25 360.01 8.60 S 0.74 E -8.60 1.10 453.02 5.37 183.30 452.41 16.55 S 0.60 E -16.55 1.07 545.84 5.89 174.47 544.79 25.63 S 0.81 E -25.63 1.09 638.57 7.04 181.12 636.93 36.04 S 1.16 E -36.04 1.48 731.72 10.54 183.43 728.97 50.26 S 0.54 E -50.26 3.78 824.40 15.43 181.16 819.25 71.06 S 0.22 W -71.06 5.30 918.35 20.72 186.45 908.54 100.09 S 2.34 W -100.09 5.89 1011.58 25.71 187.48 994.19 136.55 S 6.83 W -136.55 5.37 1067.71 28.74 188.34 1,044.10 161.98 S 10.37 W -161.98 5.44 1161.86 32.44 190.90 1,125.14 209.19 S 18.44 W -209.19 4.17 1255.15 33.08 190.41 1,203.59 258.81 S 27.77 W -258.81 0.74 1348.49 37.69 186.81 1,279.67 312.23 S 35.76 W -312.23 5.42 1441.26 42.74 184.56 1,350.50 371.81 S 41.63 W -371.81 5.66 1534.91 44.45 183.45 1,418.32 436.22 S 46.13 W -436.22 2.00 1628.19 43.04 184.26 1,485.71 500.57 S 50.46 W -500.57 1.63 1721.47 43.31 183.59 1,553.73 564.25 S 54.83 W -564.25 0.57 1814.45 43.59 182.98 1,621.23 628.09 S 58.49 W -628.09 0.54 1907.66 41.96 184.15 1,689.65 691.26 S 62.42 W -691.26 1.95 2000.89 42.44 184.91 1,758.72 753.69 S 67.36 W -753.69 0.75 2094.28 45.52 187.78 1,825.92 818.12 S 74.57 W -818.12 3.93 2187.51 49.43 190.99 1,888.93 885.86 S 85.83 W -885.86 4.90 2280.73 52.27 192.05 1,947.78 956.69 S 100.28 W -956.69 3.17 2374.35 55.76 193.64 2,002.78 1,030.53 S 117.14 W -1030.53 3.97 2467.30 55.44 194.81 2,055.30 1,104.87 S 135.98 W -1104.87 1.09 2560.65 55.96 197.68 2,107.91 1,178.89 S 157.56 W -1178.89 2.60 INSITE V7.4.20 Page 1Job No:AK-XX-0900702266 Well Name:SI35-W4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2653.89 57.25 203.12 2,159.25 1,251.80 S 184.70 W -1251.80 5.06 2747.17 58.49 208.00 2,208.89 1,323.02 S 218.79 W -1323.02 4.62 2840.35 58.86 213.00 2,257.35 1,391.56 S 259.17 W -1391.56 4.60 2933.73 61.13 217.39 2,304.06 1,457.60 S 305.79 W -1457.60 4.74 3026.91 63.94 220.82 2,347.04 1,521.71 S 357.95 W -1521.71 4.44 3087.02 64.03 224.09 2,373.41 1,561.56 S 394.40 W -1561.56 4.89 3175.00 66.20 228.20 2,410.45 1,616.82 S 451.95 W -1616.82 4.90 3197.00 67.59 226.09 2,419.08 1,630.58 S 466.78 W -1630.58 10.85 3290.42 69.36 227.18 2,453.36 1,690.25 S 529.96 W -1690.25 2.18 3383.81 71.68 231.26 2,484.51 1,747.72 S 596.63 W -1747.72 4.81 3477.15 73.98 234.15 2,512.07 1,801.73 S 667.57 W -1801.73 3.85 3570.53 75.60 236.60 2,536.57 1,852.92 S 741.71 W -1852.92 3.07 3663.96 76.87 238.82 2,558.80 1,901.39 S 818.42 W -1901.39 2.68 3757.30 77.57 240.46 2,579.45 1,947.40 S 896.96 W -1947.40 1.87 3850.71 78.67 241.34 2,598.68 1,991.85 S 976.83 W -1991.85 1.50 3944.04 79.57 241.54 2,616.30 2,035.67 S 1,057.33 W -2035.67 0.99 4037.38 80.29 241.07 2,632.62 2,079.79 S 1,137.94 W -2079.79 0.92 4130.91 81.87 241.51 2,647.12 2,124.18 S 1,218.98 W -2124.18 1.75 4224.28 81.95 241.76 2,660.26 2,168.09 S 1,300.32 W -2168.09 0.28 4317.76 82.38 241.46 2,673.00 2,212.13 S 1,381.79 W -2212.13 0.56 4410.58 82.29 239.98 2,685.38 2,257.11 S 1,462.03 W -2257.12 1.58 4504.39 82.74 240.69 2,697.60 2,303.15 S 1,542.85 W -2303.15 0.89 4597.81 82.31 240.64 2,709.76 2,348.53 S 1,623.60 W -2348.53 0.46 4691.25 82.79 241.06 2,721.87 2,393.66 S 1,704.51 W -2393.66 0.68 4784.62 82.46 240.93 2,733.86 2,438.56 S 1,785.50 W -2438.56 0.38 4878.04 83.99 240.60 2,744.88 2,483.86 S 1,866.44 W -2483.86 1.67 4971.43 83.15 241.17 2,755.34 2,529.02 S 1,947.52 W -2529.02 1.08 5064.94 82.90 241.66 2,766.69 2,573.43 S 2,029.02 W -2573.43 0.58 5158.35 82.79 241.77 2,778.33 2,617.34 S 2,110.64 W -2617.34 0.17 5251.70 82.95 241.13 2,789.91 2,661.61 S 2,192.00 W -2661.61 0.70 5345.08 82.68 239.45 2,801.59 2,707.53 S 2,272.47 W -2707.53 1.81 5438.40 82.64 238.80 2,813.52 2,755.02 S 2,351.91 W -2755.02 0.69 5531.79 82.92 238.96 2,825.25 2,802.91 S 2,431.22 W -2802.91 0.34 5625.15 82.91 237.87 2,836.77 2,851.43 S 2,510.15 W -2851.43 1.16 5718.65 82.88 237.48 2,848.34 2,901.05 S 2,588.55 W -2901.05 0.42 5811.98 82.85 236.92 2,859.93 2,951.21 S 2,666.39 W -2951.21 0.60 5905.40 83.07 236.73 2,871.38 3,001.95 S 2,743.99 W -3001.95 0.31 5998.82 82.68 236.61 2,882.96 3,052.88 S 2,821.45 W -3052.88 0.44 6092.30 82.32 236.78 2,895.17 3,103.77 S 2,898.90 W -3103.77 0.43 6185.79 82.55 237.09 2,907.47 3,154.33 S 2,976.57 W -3154.33 0.41 6279.20 82.36 237.40 2,919.74 3,204.43 S 3,054.45 W -3204.43 0.39 6372.62 82.37 237.00 2,932.15 3,254.59 S 3,132.28 W -3254.59 0.42 6466.07 82.26 237.64 2,944.65 3,304.60 S 3,210.23 W -3304.60 0.69 6559.51 81.79 237.15 2,957.61 3,354.46 S 3,288.18 W -3354.46 0.72 6652.92 82.36 239.40 2,970.49 3,403.10 S 3,366.87 W -3403.10 2.46 INSITE V7.4.20 Page 2Job No:AK-XX-0900702266 Well Name:SI35-W4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6746.32 82.34 240.25 2,982.93 3,449.63 S 3,446.89 W -3449.63 0.90 6839.71 82.30 240.74 2,995.41 3,495.21 S 3,527.44 W -3495.22 0.52 6933.15 82.58 240.90 3,007.70 3,540.38 S 3,608.31 W -3540.38 0.34 7026.59 82.45 240.63 3,019.87 3,585.62 S 3,689.16 W -3585.62 0.32 7119.97 82.25 240.49 3,032.30 3,631.11 S 3,769.76 W -3631.11 0.26 7213.22 82.89 241.16 3,044.36 3,676.19 S 3,850.49 W -3676.19 0.99 7306.89 82.31 240.93 3,056.43 3,721.16 S 3,931.77 W -3721.16 0.67 7400.27 82.61 241.11 3,068.68 3,766.01 S 4,012.75 W -3766.01 0.37 7493.73 82.52 240.69 3,080.77 3,811.08 S 4,093.73 W -3811.08 0.46 7587.08 82.97 242.25 3,092.56 3,855.31 S 4,175.08 W -3855.31 1.73 7680.45 82.47 241.03 3,104.40 3,899.30 S 4,256.58 W -3899.30 1.40 7773.91 81.12 242.88 3,117.73 3,942.79 S 4,338.22 W -3942.79 2.43 7867.35 81.64 241.14 3,131.74 3,986.15 S 4,419.79 W -3986.15 1.92 7960.75 82.44 239.93 3,144.68 4,031.65 S 4,500.32 W -4031.65 1.54 8054.14 82.76 239.49 3,156.70 4,078.36 S 4,580.29 W -4078.36 0.58 8147.55 82.35 238.49 3,168.81 4,126.07 S 4,659.68 W -4126.07 1.15 8240.84 82.36 237.50 3,181.22 4,175.08 S 4,738.08 W -4175.08 1.05 8334.23 82.51 236.23 3,193.51 4,225.68 S 4,815.60 W -4225.68 1.36 8427.91 80.47 237.37 3,207.38 4,276.41 S 4,893.12 W -4276.41 2.49 8521.01 78.56 237.18 3,224.32 4,325.90 S 4,970.13 W -4325.90 2.06 8614.36 77.66 237.70 3,243.55 4,375.06 S 5,047.12 W -4375.06 1.11 8707.78 78.81 238.78 3,262.60 4,423.19 S 5,124.88 W -4423.20 1.67 8801.19 79.61 240.38 3,280.09 4,469.65 S 5,204.01 W -4469.65 1.89 8894.60 80.67 241.92 3,296.08 4,514.05 S 5,284.61 W -4514.06 1.98 8987.97 81.85 243.57 3,310.27 4,556.31 S 5,366.65 W -4556.31 2.16 9081.16 82.00 244.46 3,323.36 4,596.74 S 5,449.59 W -4596.74 0.96 9174.39 79.72 245.77 3,338.17 4,635.47 S 5,533.08 W -4635.47 2.81 9267.75 80.54 247.25 3,354.18 4,672.13 S 5,617.43 W -4672.13 1.79 9360.98 80.63 249.48 3,369.43 4,706.04 S 5,702.92 W -4706.04 2.36 9454.65 79.76 251.65 3,385.38 4,736.75 S 5,789.95 W -4736.75 2.46 9520.53 79.90 253.43 3,397.02 4,756.20 S 5,851.81 W -4756.20 2.67 9548.51 79.80 253.33 3,401.91 4,763.91 S 5,878.26 W -4763.91 2.33 9566.00 80.00 254.50 3,404.95 4,768.57 S 5,894.84 W -4768.57 2.33 9641.80 83.12 256.07 3,416.08 4,787.61 S 5,967.35 W -4787.61 4.60 9735.14 82.95 262.06 3,427.40 4,805.18 S 6,058.27 W -4805.18 6.37 9828.41 83.89 267.39 3,438.10 4,813.69 S 6,150.50 W -4813.69 5.77 9921.56 84.21 271.31 3,447.76 4,814.74 S 6,243.13 W -4814.74 4.20 10014.84 84.60 275.07 3,456.86 4,809.57 S 6,335.80 W -4809.57 4.03 10108.12 83.54 278.88 3,466.50 4,798.31 S 6,427.88 W -4798.31 4.22 10201.10 82.68 282.88 3,477.66 4,780.89 S 6,518.51 W -4780.89 4.37 10294.31 82.96 285.01 3,489.31 4,758.61 S 6,608.26 W -4758.61 2.29 10388.12 84.85 288.01 3,499.27 4,732.10 S 6,697.67 W -4732.10 3.76 10480.93 85.91 290.46 3,506.75 4,701.63 S 6,785.01 W -4701.63 2.87 10574.54 86.12 290.75 3,513.25 4,668.76 S 6,872.42 W -4668.76 0.38 10667.38 86.97 291.75 3,518.85 4,635.17 S 6,958.79 W -4635.17 1.41 INSITE V7.4.20 Page 3Job No:AK-XX-0900702266 Well Name:SI35-W4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10760.73 86.61 292.58 3,524.07 4,600.01 S 7,045.10 W -4600.01 0.97 10853.95 86.57 293.26 3,529.62 4,563.77 S 7,130.81 W -4563.77 0.73 10947.60 87.19 295.28 3,534.72 4,525.34 S 7,216.05 W -4525.34 2.25 11040.54 87.95 300.66 3,538.66 4,481.80 S 7,298.03 W -4481.80 5.84 11133.82 87.55 303.04 3,542.32 4,432.62 S 7,377.20 W -4432.62 2.59 11205.18 85.12 304.05 3,546.88 4,393.27 S 7,436.55 W -4393.27 3.69 11250.00 85.12 304.05 3,550.70 4,368.27 S 7,473.55 W -4368.27 0.00 11369.17 85.65 304.78 3,560.29 4,301.13 S 7,571.54 W -4301.13 0.76 11462.50 89.49 306.28 3,564.24 4,246.96 S 7,647.41 W -4246.96 4.42 11555.88 91.76 309.03 3,563.22 4,189.92 S 7,721.32 W -4189.92 3.82 11649.29 90.94 309.94 3,561.02 4,130.54 S 7,793.39 W -4130.54 1.31 11742.64 90.12 308.99 3,560.16 4,071.21 S 7,865.45 W -4071.21 1.34 11836.06 90.10 310.40 3,559.98 4,011.55 S 7,937.34 W -4011.55 1.51 11929.45 90.25 310.86 3,559.69 3,950.74 S 8,008.21 W -3950.74 0.52 12022.80 90.04 310.28 3,559.46 3,890.02 S 8,079.12 W -3890.02 0.66 12116.17 90.08 310.54 3,559.36 3,829.50 S 8,150.21 W -3829.50 0.28 12209.60 90.02 310.49 3,559.28 3,768.80 S 8,221.24 W -3768.80 0.08 12302.94 89.92 310.31 3,559.33 3,708.30 S 8,292.33 W -3708.30 0.22 12396.35 90.40 310.29 3,559.07 3,647.89 S 8,363.57 W -3647.89 0.51 12489.68 90.18 311.22 3,558.59 3,586.96 S 8,434.26 W -3586.96 1.02 12583.12 89.36 312.74 3,558.97 3,524.46 S 8,503.72 W -3524.47 1.85 12676.55 88.67 312.62 3,560.58 3,461.14 S 8,572.40 W -3461.14 0.75 12769.92 88.42 310.58 3,562.95 3,399.17 S 8,642.19 W -3399.17 2.20 12863.95 88.04 308.40 3,565.85 3,339.40 S 8,714.72 W -3339.41 2.35 12956.75 89.13 309.71 3,568.14 3,280.95 S 8,786.76 W -3280.96 1.84 13050.32 90.10 310.05 3,568.77 3,220.96 S 8,858.56 W -3220.96 1.10 13143.45 90.89 309.04 3,567.97 3,161.67 S 8,930.37 W -3161.67 1.38 13236.89 90.56 311.39 3,566.79 3,101.35 S 9,001.71 W -3101.35 2.54 13330.26 90.42 313.04 3,565.99 3,038.62 S 9,070.86 W -3038.62 1.77 13423.68 90.30 313.11 3,565.40 2,974.82 S 9,139.10 W -2974.82 0.15 13517.07 90.54 311.45 3,564.72 2,911.99 S 9,208.19 W -2911.99 1.80 13610.58 90.19 310.66 3,564.12 2,850.58 S 9,278.70 W -2850.58 0.92 13703.99 91.19 311.45 3,562.99 2,789.23 S 9,349.13 W -2789.23 1.36 13797.34 91.89 311.69 3,560.49 2,727.32 S 9,418.95 W -2727.32 0.79 13890.72 90.59 312.79 3,558.47 2,664.56 S 9,488.06 W -2664.56 1.82 13984.04 92.25 311.51 3,556.15 2,601.96 S 9,557.22 W -2601.96 2.25 14077.43 91.92 310.53 3,552.75 2,540.70 S 9,627.64 W -2540.71 1.11 14170.79 92.09 309.43 3,549.49 2,480.76 S 9,699.13 W -2480.76 1.19 14264.29 90.15 308.72 3,547.66 2,421.84 S 9,771.70 W -2421.84 2.21 14357.62 90.47 309.99 3,547.16 2,362.65 S 9,843.86 W -2362.66 1.40 14451.04 90.97 311.22 3,545.98 2,301.86 S 9,914.78 W -2301.86 1.42 14544.46 90.89 312.44 3,544.47 2,239.56 S 9,984.38 W -2239.57 1.31 14638.24 91.28 312.89 3,542.69 2,176.02 S 10,053.33 W -2176.02 0.63 14731.43 91.19 311.08 3,540.68 2,113.70 S 10,122.58 W -2113.70 1.94 14824.84 89.92 309.66 3,539.78 2,053.20 S 10,193.74 W -2053.20 2.04 INSITE V7.4.20 Page 4Job No:AK-XX-0900702266 Well Name:SI35-W4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14918.26 89.42 308.42 3,540.31 1,994.36 S 10,266.29 W -1994.36 1.43 15011.71 90.13 308.93 3,540.68 1,935.97 S 10,339.25 W -1935.97 0.94 15105.15 90.74 309.02 3,539.97 1,877.20 S 10,411.89 W -1877.20 0.66 15198.56 90.81 308.74 3,538.71 1,818.57 S 10,484.60 W -1818.57 0.31 15291.96 92.51 310.04 3,536.00 1,759.33 S 10,556.75 W -1759.33 2.29 15385.35 91.11 311.15 3,533.05 1,698.59 S 10,627.62 W -1698.59 1.91 15478.79 89.98 311.79 3,532.16 1,636.72 S 10,697.63 W -1636.72 1.39 15572.23 89.72 312.40 3,532.41 1,574.08 S 10,766.97 W -1574.08 0.71 15665.61 90.32 310.91 3,532.38 1,512.02 S 10,836.74 W -1512.02 1.72 15759.05 87.64 310.14 3,534.04 1,451.32 S 10,907.74 W -1451.32 2.98 15852.53 84.37 310.13 3,540.55 1,391.21 S 10,979.03 W -1391.21 3.50 15945.91 85.00 308.59 3,549.20 1,332.25 S 11,050.92 W -1332.25 1.78 16039.37 87.48 309.35 3,555.33 1,273.60 S 11,123.42 W -1273.60 2.77 16133.82 90.54 310.90 3,556.96 1,212.75 S 11,195.61 W -1212.75 3.63 16226.49 91.23 310.58 3,555.53 1,152.28 S 11,265.82 W -1152.28 0.82 16319.89 91.22 310.37 3,553.53 1,091.67 S 11,336.85 W -1091.67 0.23 16413.35 89.61 310.53 3,552.86 1,031.03 S 11,407.97 W -1031.04 1.73 16506.39 89.96 310.33 3,553.21 970.70 S 11,478.79 W -970.70 0.43 16599.89 91.50 309.17 3,552.02 910.92 S 11,550.67 W -910.92 2.06 16693.19 91.49 308.88 3,549.58 852.19 S 11,623.12 W -852.19 0.31 16786.48 92.08 309.67 3,546.68 793.16 S 11,695.30 W -793.16 1.06 16879.87 92.47 309.81 3,542.97 733.51 S 11,767.06 W -733.51 0.44 16973.26 91.77 308.31 3,539.51 674.70 S 11,839.52 W -674.70 1.77 17066.65 90.87 308.63 3,537.36 616.62 S 11,912.62 W -616.62 1.02 17160.00 89.37 310.12 3,537.17 557.40 S 11,984.78 W -557.40 2.26 17253.42 86.29 311.06 3,540.70 496.67 S 12,055.66 W -496.67 3.45 17346.83 90.88 313.97 3,543.01 433.59 S 12,124.47 W -433.59 5.82 17440.24 89.12 314.89 3,543.01 368.20 S 12,191.17 W -368.20 2.13 17533.61 89.64 316.31 3,544.02 301.49 S 12,256.49 W -301.49 1.62 17626.76 89.09 315.61 3,545.05 234.54 S 12,321.24 W -234.54 0.96 17720.22 89.53 315.00 3,546.18 168.11 S 12,386.97 W -168.11 0.80 17813.89 88.88 313.21 3,547.48 102.92 S 12,454.22 W -102.92 2.03 17907.12 88.27 312.25 3,549.80 39.68 S 12,522.68 W -39.68 1.22 18000.40 89.56 311.21 3,551.56 22.39 N 12,592.28 W 22.39 1.78 18093.42 90.77 312.03 3,551.29 84.17 N 12,661.81 W 84.17 1.57 18186.38 92.58 311.08 3,548.58 145.81 N 12,731.34 W 145.81 2.20 18280.41 91.94 311.55 3,544.87 207.84 N 12,801.91 W 207.84 0.84 18373.65 88.30 310.43 3,544.67 268.98 N 12,872.28 W 268.98 4.08 18466.53 85.65 310.07 3,549.58 328.91 N 12,943.06 W 328.91 2.88 18559.42 86.05 308.62 3,556.30 387.64 N 13,014.71 W 387.64 1.62 18652.70 86.14 308.36 3,562.65 445.56 N 13,087.55 W 445.56 0.29 18745.68 86.89 309.13 3,568.30 503.65 N 13,159.94 W 503.65 1.15 18838.89 86.78 307.43 3,573.45 561.30 N 13,232.99 W 561.30 1.82 18932.12 88.40 309.03 3,577.37 618.94 N 13,306.16 W 618.94 2.44 19025.51 87.65 308.49 3,580.59 677.37 N 13,378.94 W 677.37 0.99 INSITE V7.4.20 Page 5Job No:AK-XX-0900702266 Well Name:SI35-W4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 19118.74 88.17 310.15 3,583.99 736.40 N 13,451.01 W 736.40 1.86 19211.96 88.10 310.22 3,587.02 796.52 N 13,522.19 W 796.52 0.11 19305.31 88.01 310.68 3,590.19 857.05 N 13,593.18 W 857.05 0.50 19398.53 88.11 310.94 3,593.35 917.94 N 13,663.70 W 917.94 0.30 19491.88 87.99 310.13 3,596.52 978.58 N 13,734.61 W 978.58 0.88 19585.12 86.46 310.05 3,601.04 1,038.55 N 13,805.85 W 1038.55 1.64 19678.40 85.65 309.20 3,607.46 1,097.90 N 13,877.53 W 1097.90 1.26 19771.58 85.83 308.67 3,614.38 1,156.29 N 13,949.81 W 1156.29 0.60 19865.55 88.11 307.44 3,619.34 1,214.13 N 14,023.69 W 1214.13 2.76 19932.00 88.11 307.44 3,621.54 1,254.51 N 14,076.42 W 1254.51 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 19.74 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 19,932.00 feet is 14,132.21 feet along 275.09 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V7.4.20 Page 6Job No:AK-XX-0900702266 Well Name:SI35-W4 Survey Report