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210-187
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. tQj Q - _I 37 Well History File Identifier Organizing(done) Two-sided III OhIlIlIHI Iliii ❑ Rescan Needed III IIIIII II((III III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: /s/ IV Project"ect Proofin II I II II II lID I 11111 Proofing i BY: 42131tb Date: 0 /s! u Scanning Preparation (p x 30 = l 0 0 + 13 = TOTAL PAGES 1 q3 OEM (Count does not include cover sheet) BY: Date: /6 / ��. /s/ r Production Scanning 11111 II 1111111 IIIII Stage 1 Page Count from Scanned File: F ` 1+ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ///10 /[ , /s! 04 F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. III I III ReScanned I IllIllIllI 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIIIIIM 12/22/2011 Well History File Cover Page.doc 1i o U 9 F 0 0 0o m cop w w � � 1; r„) M > p �0 N co v7 w 1 N — ca 6 X .� •N .y N ' il O li d C 0 X c c c c o w? E 'rnm.S o 'N o N 1 ) 1 m E Jr 0 > > > > Z o U imp o > 0 p> i F. O rnU 2 F- 2 F- 1 a L Q o O N N N N N c 72 d O O D. •t1 N N N N N I N N d 0) p O N ._..> O 7 _2 — c c c c c N r? C = = c) C . a a E O U Q O O O O O E ea O N Y U CeU O c as co O Z as 0 0 o 0 o m m Z Z CL U v)1 y E 0 o • W/ uJ :: � Z Ii/ a0 c o c°o o CO° o N '_ C.' W V Z ce a) w c CL a Qo Jis '1 cn I o on 0 0 0 o c ? E � � c ZI J2 UUUU p O 0 a I y • ON a ! N 10 N N In In N a ' Jf) UM 0 E J CJ) Q0 H 0 N N Z y 0 2/ a CO W (�J N c a (/) ~ p U) Q 1 c Z o m Q c Z� w w w w• z 3 N U O N N N N 41 10 J ar N (0 N VI N Z d' Q' CC Et W 2 C C C C C 1 —y 0 O O O O O in 3 co > > > > O O CO l ' c Z c c V V V '+r 1 I a z O ti > I 0 J w w a o = m Q v 74 2 c d N Y >- �i o z r p W O Z y 0 ai_ p ` 11 6 Q �. A w a d Z u. i � i V a a li J O u c 5)v y z Q °m d m Z v c co Z W O \ o O U w > 11 G E p 1 pr �. a J rn o ; m� rn O ° m y E �i E a j j o I- 3 J0 �jw J J o J 3 < 0 <a 0 10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Gas ❑ SPLUG n Other 0 Abandoned ❑ Suspended 1b.Well Class: G•e-•t t� (J,4 �E 20AAC 25.105 20AAC 25.110 Development ✓ Exploratory ❑ GINJ ❑ WINJ❑ WO AG ❑ WDSPL❑ N�43ttompletions: gM G'24 Service ❑ Stratigraphic Test n 2.Operator Name: 5.Date Comp.,Sugar 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 422012 210-187 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 3/16/2012 50-029-23438-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3137.6 FSL 1689.3 FEL S5 T13N R9EUM 4/14/2012 OP21-WW01 Top of Productive Horizon: 8.KB(ft above MSL): • 53.62 15.Field/Pool(s): 1827 FSL 4469 FEL 33 T14N R9EUM GL(ft above MSL): - 12.2 Nikaitchuq/Schrader Bluff Oil Pool Total Depth: 9.Plug Back Depth(MD+TVD): 1972 FSL 4404 FEL 33 T14N R9EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 516590.97 y- 6036490.59 Zone- 4 11037 MD/9357 TVD ADL355024,373301,390616,390615 TPI: x- 519070.3013 y- 6040465.246 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 519133.73 y- 604610.72 Zone- 4 2288 MD/2253 TVD ADL 417493 18.Directional Survey: Yes U No H 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1775'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 SURFACE 160 SURFACE 154 Driven Cement to Surface N/A SURFACE 2040 SURFACE 3771 390 bbls 10.7#ASL,82 bbls 12.5#Crete 13.375 68 L80 16 N/A 9.625 47 13Cr SURFACE 8093 SURFACE 6615 12.25 240 bbls 15.8#Class G N/A 7" 26 13Cr 7843 11034 6461 9549 8.75 95 bbls 15.8#Class G N/A 24.Open to production or injection? Yes 0 No If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 10456-10468 MD,8798-8810 TVD 5spf 4.5 7843 N/A 10504-10521 MD,8844-8861 TVD 5spf RECEIVED 10545-10562 MD,8884-8900 TVD 5spf 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10604-10666 MD,8940-9000 TVD 5spf JUN 2 0 2012 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10681-10702 MD,9014-9034TVD 5spf 10742-10854 MD,9073-9181 TVD 5spf AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Flowina Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No E Sidewall Cores Acquired? Yes ❑ No El 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. 'r,-.0 tOD "e" : RBDMS JUN 2 0 2012A9f441 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE U Submit original only �6/16//L 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? H Yes 'Lilo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1802 1775 OA sand top 3884 3570 Formation at total depth: Ivishak 10461 8815 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michele Cesari(907)865-3338 Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: /`�� ( Phone: (907)865-3320 Date: 6/18/2012 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 if* OP21 -WW01 2no 4-�/2" 13Cr 12.6 ppf Vam Top Production Tubing nerrC�eQJr Wellhead, 13-3/8" x 4-W, CR Flow-wetted 5,000 psi / - -�� �``� Conductor, 20" Uninsulated set at 160 ft - e RKB to Wellhead — 32.28 ft Water Source Well Vacuum Insulated Tubing (VIT), As romp 4/26/12 , I 4-Y2" x 6", approx 102' 2288' MD, 2253' TVD - TRMAXX SSSV, 3.81" 'X' Profile, '/4" SS hyd. Control line 3523' MD, 3299' TVD, 41° Inc - GLM, 4-'/2" x 1", KBG with DCK-2 Ann- to-Tubing shear valve 1931-1934' MD —Surf Casing Pert Interval 4-'/" cable clamps, (1) 3/8" Chem Inj Line Surf. Casing \' Single 3/8" SS Chem Injection Line 13-3/8" 68# \ 2040' MD, 2011' TVD 7812' MD, 6505' TVD, 41.5° Inc- Nipple, 3.81" 'X' Profile 7824' MD, 6514' TVD - Chemical Injection Mandrel Dual Stage Collar—3827' `, 7830' MD - No-Go -Tieback Seal Stem MD, 3527' TtD-, ` 7,833' MD—TOL - Flex Lock Liner L` � t Hanger and ZXP Packer Assy �� ,'ii . a �, Perf Intervals �" 1) 10456-10468' MD, 8798-8810'TVD 2) 10504-10521' MD, 8844-8861'TVD Interm. 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O bO E N Hill IPM t LT, O O O _ 0 D C Ti = N P a ti a 8 rQ o c wa T T C E C.) N- O)0 ❑ lift* Eni E&P Division I Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/12/2012 - Report#: 1 APIIUIM:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° 'Operator ENI Share(%) Well Configuration type Oliktok Point I ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) •RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB)!Target Depth(TVD..J Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) I DFS(days) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 -3.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg ROP(mlhr) POB Temperature(°C) Weather 'Wind 0.00 83.0 -30.6 Light Snow WC-32' SSW @ 6.9 MPH Daily summary operation 24h Summary Set mats and Herculite for rig move-P/U surface annular and set in cellar-Move Drill and utility modules over well OP21-WW01. Operation at 07.00 Connect interconnect and electrical lines between rig modules. 24h Forecast Finish to move rig over well OP21-WW01-N/U Vetco Gray starter Head-R/U Diverter and test as per AOGCC-P/U 5"DPs. Lithology Shows MAASP(kgflcm') 'Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 14:00 2.00- 2.00 MOB A 2 P Rig accepted to Well OP21-WW01 03/12/2012 @ 12:00.Move rig and utility modules off OP14-S3. 14:00 21.00 7.00' 9.00 MOB A 1 P P/U mats and herculite from well OP14-S3.P/U surface annular and set in cellar.Level pad,set new herculite and mats to move rig over well OP21-WW01. 21:00 23.30 2.50 11.50 MOB A 2 P Move utility module back 40'.Spot Drill module over well OP21-WW01.Pull crib blocks.level w/plywood 8.jack down. 23:30 00.00 0.50 12.00 MOB A 2 P Many up utility module to drill module. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamanna @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm.) 1. _ID Eni E&P Division I Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/13/2012 - Report#: 2 API/UWI:029-23438-00-00 II 2't ° page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° 'Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) I DFS(days) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 -2.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg ROP(mlhr) I POB Temperature(°C) Weather Wind 0.00 86.0 -37.8 Clear WC-57° NNE @ 7 MPH Daily summary operation 24h Summary Finish to move rig over well OP21-WW01-N/U Vetco Gray starter Head-N/U Diverter system. Operation at 07.00 N/U Diverter system in progress. 24h Forecast -4/41.DweGGI. -r and test as per AOGCC-Chuck Scheve waived to witness the test on 3/13/2012 @ 21:30 hrs-P/U 5"DPs. Lithology IShows n MAASP(kgflcm') Mud Weight(gIL) 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 MOB A 2 P Jack down&shim/level complex. 01:00 05:00 4.00 5.00 MOB A 1 P R/U&M/U interconnect lines throughout rig.Fold down&secure walkways throughout rig.M/U&connect flow/de-gasser lines.Install wellbay roof panels.Roll down&secure Lampson curtains around rig.Berm&secure stairs/walkways around rig. 05.00 12:00 7.00 12.00 DRILL C 5 P Vetco Gray installed starter head and pressure test to 500 psi x 10 min:Ok.N/U drilling riser.Install&M/U Diverter Knife Valve.Measurements:37.2'to load shoulder and 41.42'to ground level. 12.00 16:00 4.00 16.00 DRILL C 5 P Continue R/U Diverter System,set flange adapter on riser and test seal to 500 psi for 10 minutes:Ok.Replace short bolts all along Diverter Line to longer tighten.MI Swaco R/U CCB and berm around. 16:00 00:00 8.00 24.00 DRILL C 5 P N/U Diverter System.Place last section al Diverter on well bay roof,slide into position and Nipple up to knife valve.Load 5" DP in the shed.Finish to R/U CCB and cuttings tank. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) 1P Surf Applied(kgflcm°) I Eq.Mud Weight(gIL) IP Lea kOff(kgflcm°) En/E&P Division I Well Name:OP21-WWO1 011* ENI Petroleum Co.Inc. Daily Report` Well Code:26259 Field Name:Nikaitchuq • Date:3114/2012 - Report#: 3 APIIINA:029-23438-00-00 ei° page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° I Operator ENI Share)%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase .Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mfhr) I DFS(days) WW OP21- 01 DRILLING 3/16/2012 3,397.61 2880.89 4.117.24 145.12 28.4 -1.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather (Wind 0.00 84.0 -42.2 Clear WC-61" South @ 5 MPH Daily summary operation 24h Summary Finish to N/U Diverter system and test as per AOGCC-Chuck Scheve waived to witness the test on 3/13/2012 @ 21:30 hrs-P/U 55 stands of 5"DPs. Operation at 07.00 P/U,M/U&R/B stands of 5 DP. 24h Forecast P/U,M/U&R/B stands of 5"DP-Repeat Diverter Test-M/U BHA and spud well OP21-WW01-Drill Surface section as per well plan. Lithology 'Shows MAASP(kgflcm') I Mud Weight(gIL) 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 5 P Finish flanging/bolting up diverter spool. 01:00 07:00 6.00 7.00 DRILL C 5 P P/U and set 20"Hydrill bag preventer.N/U and torque bolts and nuts.R/U Koomey lines/hoses to knife valve&bag.Set and N/U bell nipple,center up with rotary hole. 07:00 10:30 3.50 10.50 DRILL C 5 P R/U and install Katch Kan assembly.N/U bleeder&hole fill lines.Insulate cellar box and clean up cellar area. 10:30 13:30 3.00 13.50 DRILL C .12 P P/U joint of 5"drill pipe and function test Bag and Knife Valve.Work several times:knife valve not operating correctly. Troubleshoot problem the knife valve does not open completly,probably due to cold temperature.Set drip pans around riser and try to warm up area around knife valve.The test will be repeated after P/U DP 5". AOGCC representative Chuck Scheve waived to witness the test on 3/13/2012 @ 2130 hrs. 13:30 00:00 10.50 24.00 DRILL E 5 P Pull bushings and set mouse hole in rotary table.P/U,M/U&R/B stands of 5"DPs(55 stands @ midnight). Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum 'Sr.Dog.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Ddg Spvr. angelo.lamahna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division 'Well Name:OP21-WW01 $141 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/15/2012 - Report#: 4 API/UWI:029-23438-00-00 2 r' i page 1 of 1 Wellbore name OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point I ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 -0.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 84.0 -43.9 Clear WC-65° South @ 5 MPH Daily summary operation 24h Summary P/U,M/U&R/B a total of 351 joint of 5"DP-Function test Diverter(Test waived by AOGCC rep Chuck Scheve)-Service TDS-Held Pre-Spud Safety Meeting-Fill hole with mud and check for leaks:Ok -P/U&M/U BHA#1-Start washing 20"C.P.down to 160'. Operation at 07.00 P/U&M/U BHA#2 and spud well. 24h Forecast Wash 20"C.P.down to 160'-M/U BHA#2 and spud well OP21-WW01-Drill Surface section as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1042.5 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 5 P P/U,M/U&R/B stands of 5"DPs. 03:30 06:30 3.00 6.50 DRILL E 1 P Load 142 joints of 5"DP in the shed&strap/tally. 06:30 10:30 4.00 10.50 DRILL E 5 P Continue P/U,M/U&R/B stands of 5"DPs. 10:30 11:30 ' 1.00 11.50 DRILL E 12 P Perform function test Diverter:Bag(27 sec)/Knife Valve(25 sec).Test Koomey:1850 psi-39 sec Air-133 sec total- 2450 psi avg bottles.AOGCC representative Chuck Scheve waived to witness the test on 3/13/2012 @ 21:30 hrs. 11:30 15:00 3.50 15.00 DRILL E 5 P Continue P/U,M/U&R/B stands of 5"DPs.Total=351 joints. yy44 15:00 17:00 2.00 17.00 DRILL E 5 P P/U 4 stands of 5"HWDP and 1 stand with 2x 5"HWDP+8"Smith Hydraulic Jar.Rack back in derrick. 17:00 19:00 2.00 19.00 DRILL E 25 P Rig Service:change oil and filter in Top Drive and change out M/U line on Drawv°orks. 19:00 20:00 1.00 20.00 DRILL E 1 P Held Pre-Spud Safety Meeting with all parts involved:discussed of safe area,well program,spill prevention,spill response equipment,well control procedures.Fill out pre-spud check list:Ok. 20:00 21:30 1.50 21.50 DRILL E 12 P Fill hole with-56 bbls of spud mud.Check all lines and Diverter system for leaks:Ok.Circulate with all pumps and pressure test mud lines:Ok. 21 30 23:30 2.00 23.50 DRILL E 5 P P/U and M/U BHA#1:0 16"MT bit Hughes(s/n 5201975)with 3020/32"&1016/32"nozzles(TFA=1.116)+PDM with 1.83 bend(s/n 962-7102)+NM Stabilizer+XO.Total length=40.48'. 23.30 00:00 0.50 24.00 DRILL E 3 P RIH BHA#1 and tag @ 111'.Break circulation @ 400 gpm/190 psi and start washing 20"C.P.down to 160'. Daily Contacts Position _ Contact Name Company Title E-mail _ Office Mobile Eni representative Rodney McCoy 'Eni Petroleum •Sr.Dig.Spvr, 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamadna @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson :Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) IP Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division (Well Name:0P21-WW01 PI* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • Date:3/16/2012 - Report#: 5 APIIIJWI:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) !Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(mKB) Target Depth(TVD..J Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) I DFS(days) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 0.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) !Drilling Hours(hr) Avg ROP(mlhr) I POB 'Temperature(°C) Weather 'Wind 217.93 216.58 169.16 6.76 25.0 84.0 -44.4 Clear WC-74' South @ 7 MPH Daily summary operation 24h Summary Wash and ream 20"C.P.down to 160'-P/U BHA#2-Spud well @ 05:30 hrs-Rotary/Slide Drilling 16"section to 715'(712'TVD). Operation at 07.00 Drill 16"section as per well plan.Report time @ 968'. 24h Forecast Drill 16"section as per well plan to planned TD @ 4,075'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1042.5 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 6 P Wash and ream 20"C.P.from surface to 160'@ 400 gpm/250 psi/40 rpm/1-2K TO.POOH BHA#1 racking back 2 stands 5"DP. 01:00 04:30 3.50 4.50 DRILL E 5 'P Held PJSM.P/U BHA#2 with new 0 16"MT bit Hughes s/n 5201975,3x 20/32"+10 16/32"nozzles(TFA=1.116)+PDM 1.83 bend(s/n 962-7102)+NM stabilizer+2x NMXO+Gyro Pulse collar(s/n 24709)+8"PowerPulse MWD(s/n YP45)+ ARC 825(s/n E5556)+NM Stabilizer+NMDC+XO.Orient motor and Gyro tools. 04:30 05:30 1.00 5.50 DRILL E 12 'P RIH BHA#2 and perform shallow test 300-500 gpm/200-450 psi:Ok.Check Gyro survey:Ok.Set Depth. 05:30 09:30 4.00 9.50'DRILL E '3 'P Spud well OP21-WW01 @ 05:30 hrs.Drilling Rotary/Sliding with mud motor f/160'-9287'-Pump 500 gpm/520 psi/ WOB=4-10 K/40 rpm/1-2K TO/Up wt 70K/Dn wt 70K/Rot wt 70K/Mud wt=8.8 ppg.Record Survey Gyro Data as needed.Monitor for leaks 8 conductor breaching:Ok. 09:30 10:00 0.50 10.00 DRILL E 7 'P Circulate hole clean @ 500 gym/550 psi/30 rpm/2K TO. 10:00 12:00 2.00 12.00'DRILL E '5 'P P/U and R/B x2 St HWDP-P/U and M/U x2 NM Flex DCs+Sever sub+Jar(Smith s/n 07111C)+XO. 12:00 18:00 6.00 18.00'DRILL E 3 P Dolling Rotary/Sliding 0 16"section f/287'9520'\500 gpm @ 650 psi\40 rpm @ 2+3k R'Ibs\WOB=10-20k lb\Up wt 80k lb-Dw ml=60k lb-Rot wt=70k lb\Mud wt=8.95 ppg-Take Gyro/MWD survey as needed. 18:00 00:00 6.00 24.00 DRILL E 3 P Dolling Rotary/Sliding 0 16"section f/520'1/715'(712'TVD)/500 gpm/900 psi/40 rpm/3+4k fHbs/WOB=15-25k lb/ Up wt=90k lb-Dw wt=60k lb-Rot wl=80k lb/Mud w4=8.9 ppg-Take Gyro/MWD survey as needed. Daily ADT=6.76 hrs[ART=1.87 hrs-AST=4.89 hrs].Jars=6.8 hrs. Daily Contacts - Position Contact Name Company _ Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamanna @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Em representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) ITVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1* Eni E&P Division Name:0P21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/17/2012 - Report#: 6 API/UWI:029-23438-00-00• 2'r i page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM _ 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) -RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E _LAND RIG Job Information Wellbore Job Phase Spud Date [Target Depth(mKB) Target Depth(ND..J Depth Dr.(MD)(m) Drilling Hours(hr) 'Avg ROP(mlhr) I DFS(days) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 1.77 Daily information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) !Avg ROP(mlhr) I POB Temperature(°C) Weather Wind 616.31 607.42 398.37 14.161 28.1 83.0 -41.1 Overcast WC-61° SSW @ 6 MPH Daily summary operation 24h Summary Drill ahead 0 16"section as per well plan 8/715'1/2022'(1993'TVD). Operation at 07.00 Drill 16"section as per well plan.Report time©2250'. 24h Forecast Drill 16"section as per well plan to planned TD @ 4,075'. Lithology !Shows MAASP(kgflcm') I Mud Weight(giL) 1078.4 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 Drilling Rotary/Sliding 0 16"section 8/715'V1063'/550 gpm/960 psi/40 rpm/2.3k ft'lbs/WOB=15-20k lb/Up wt=86k lb-Dw wt=83k lb-Rot wt=86k lb/Mud wt=8.9 ppg-Take Gyro/MWD survey as needed. 06.00 12:00 6.00 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section 8/1063'1/1448'/600 gpm/1100 psi/40 rpm/3+4k fflbs/WOB=15-25k lb/Up wt= 95k lb-Dwwt=95k lb-Rot wt=95k lb/Mud wt=9.0 ppg-Take Gyro/MWD survey as needed. 12.00 18:00 6.00' 18.00 DRILL E 3 P Dolling Rotary/Sliding 0 16"section 8/1448'1/1740'/600 gpm/1050 psi/40 rpm/3+4k fobs/WOB=15-25k lb/Up wt= 102k lb-Dw wt=98k lb-Rot wt=100k lb/Mud wt=9.0 ppg-Take Gyro/MWD survey as needed. 18.00 00:00 6.00. 24.00 DRILL E 3 P Dolling Rotary/Sliding 0 16"section 8/1740'V2022'(1993'ND)/600 gpm/1100 psi/40 rpm/3+4k 8-lbs/WOB=10-20k lb/Up wt=115k lb-Dw wt=105k lb-Rot wt=105k lb/Mud wt=9.2 ppg-Take Gyro/MWD survey as needed. Daily ADT=14.16 hrs[ART=5.18 hrs-AST=8.98 hrs].Jars=20.9 hrs. - Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum 'Sr.Dig.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) ITVD(mKB) Fluid Type 'Fluid Density(giL) I P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division Well Name:0P21-WW01 Pi* EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3118/2012 - Report#: 7 APIIUWI:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) 'Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E '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) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 2.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(Er) Avg ROP(rnlhr) •POB Temperature(°C) Weather Wind 879.04, 853.59 262.74 12.72 20.7 84.0 -36.1 Overcast WC-48° South @ 5 MPH Daily summary operation 24h Summary Drill ahead 0 16"section as per well plan 1/2022'1/2884'(2801'TVD). Operation at 07.00 Drill 16"section as per well plan.Report time @ 3,077'. 24h Forecast Drill 16"section as per well plan to planned TD @ 4,075'-Circulate until shakers clean-BROOH. Lithology 'Shows MAASP(kgflcm') I Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(Er) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 - 6.00' 6.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/2020'1/2374'/600 gpm/1150 psi/40 rpm/4+5k ft'lbs/WOB=0-20k lb/Up wt= 120k lb-Dw w1=110k lb-Rot wt=120k lb/Mud wt=9.2 ppg-Take MWD survey as needed. 06:00 12:00 ' 6.00 12.00'DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/2374'1/2622'/600 gpm/1280 psi/40 rpm/3.4k ft'lbs/WOB=0-25k lb/Up wt= 130k lb-Dw w1=110k lb-Rot wt=120k lb I Mud wt=9.2 ppg-Take MWD survey as needed. /„ 12:00 18:00 6.00 18.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section 1/2622'1/2752'/650 gpm/1350 psi/40 rpm/5'6k Nibs/WOB=10-20k lb/Up wt= 140k lb-Dw wt=110k lb-Rot wt=115k lb/Mud wt=9.2 ppg-Take MWD survey as needed. 18:00 00:00 6.00' 24.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section 1/2752'5/2884'(2801'TVD).Drill through very hard spot/650-700 gpm/1450 psi/40 rpm/5-6k Nibs/WOB=10-30k lb/Up wt=142k lb-Ow w1=110k lb-Rot w1=115k lb/Mud wt=9.2 ppg-Take MWD survey as needed. Daily ADT=12.72 hrs[ART=4.94 hrs-AST=7.78 hrs].Jars=33.6 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Dig.Spvr. .907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR ' 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) I TVD(mKB) 'Fluid Type Fluid Density(gIL) IP Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division (Well Name:0P21-WW01 Iff* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/19/2012 - Report#: 8 API/UWI:029-23438-00-00 �" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° !Operator ENI Share(%) Well Configuration type Oliktak Point I ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E I 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) I DFS(days) 0P21-//W01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.41 3.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) !Drilling Hours(hr) Avg ROP(m/hr) I POB Temperature(°C) Weather I Wind 1,193.29 1,094.89 314.25 14.05 22.4 86.0 -37.8 Overcast WC-56° South @ 7 MPH Daily summary operation 24h Summary Drill ahead 0 16"section as per well plan 02884'113915'(3593'TVD). Operation at 07.00 Drill 16"section as per well plan.Report time @ 4,091'. 24h Forecast Drill 16"section as per well plan to TD @ 4,127'-Circulate until shakers clean-BROOH. Lithology 'Shows MAASP(kgf/cm') I Mud Weight(gIL) 1114.4 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 Drilling Rotary/Sliding 0 16"section(/2884'1/3172'/650 gpm/1400 psi/40 rpm/4+5k 01los/WOB=2-30k lb/Up w1= 142k lb-Dw wt=110k lb-Rot wt=121k lb/Mud wt=9.2 ppg.Tightspot @ 3052':work/ream through.Take MWD survey as needed. 06:00 12:00 6.00 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/3172'1/3413'/650 gpm/1600 psi/40 rpm/6+7k h:lbs/WOB=2-20k lb/Up wt= 148k lb-Dw wt=110k lb-Rot wt=125k lb/Mud wt=9.2 ppg-Take MWD survey as needed. 12:00 18:00 6.00 18.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/3413'1/3647'/700 gpm/1650 psi/40 rpm/6+7k nibs/WOB=10-20k lb/Up w1= 155k lb-Dw wt=110k lb-Rot wt=125k lb/Mud wt=9.3 ppg-Take MWD survey as needed. 18:00 00:00 6.00 24.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section(/3647'1/3915'(3593'TVD)/650-700 gpm/1750 psi/40 rpm/5+8k ftdbs/WOB=10- 30k lb/Up w1=162k lb-Dw wt=108k lb-Rot wt=130k lb/Mud wt=9.3 ppg-Take MWD survey as needed. Daily ADT=14.05 hrs[ART=9.5 hrs-AST=4.55 hrs].Jars=47.6 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) IP Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm°) I Eni E&P Division `Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3120/2012 - Report#: 9 APIIUWI:029-23438-00-00 ( I rr n page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 DRILLING 3/16/2012 3,397.611 2,880.89 4,117.24 145.12 28.4 4.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(mlhr) 'POB Temperature(°C) Weather Wind 1,257.91 1,143.23 64.62 3.53 18.3 87.0 -37.2 Clear WC-53° North©6 MPH Daily summary operation 24h Summary Drill ahead 0 16"section as per well plan 1/3915'to TD @ 4127'(3751'TVD)-BROOH-L/D BHA#2. Operation at 07.00 Prepare and RIH 13 3/8"68#L-80 BTC casing. 24h Forecast Finish to L/D BHA#2-Dummy run with casing hanger-13 3/8"casing job-Perform cement job-N/D Diverter. Lithology 'Shows MAASP(kgflcm') 'Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase_ Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 DRILL E 3 P 'Drilling Rotary/Sliding 0 16"section f/3915'to TD @ 4127'(3751'TVD)/700 gpm/1860 psi/40 rpm/5.7k ttlbs/WOB= 4-30k lb/Up wl=158k lb-Dwwt=118k lb-Rot wt=135k lb/Mud wt=9.3 ppg-Take MWD survey as needed. Daily ADT=3.53 hrs[ART=3.15 hrs-AST=0.38 hrs].Jars=51.1 hrs. 04:30 0730 3.00 7.50 DRILL E 7 P 'Circulate 3x B/U while backreaming and R/B one stand every bottom up @ 800 gpm/2150 psi/80 rpm/6*7k tt:lbs. 07:30 20:30 13.00- 20.50 DRILL -E 6 P 'BROOH to 662'(top of 5"HWDP(@ 800 gpm/2150-1200 psi/40-80 rpm/2+6k ft:lbs. 20:30 22:00 ' 1.50 22.00 DRILL E 7 P 'Circulate 2x B/U.Backream 8,R/B 1 stand of 5"HWDP every B/U @ 800 gpm/1200 psi/40 rpm/1.1k#113s. _j 22:00 00:00 2.00" 24.00 DRILL E 5 P 'POOH and R/B 2x stands 5"HWDP(with Jar)+1 stands with 2x NM Flex DC and 1x NMDC.Continue to UD BHA#2 as per DD and MWD:L/D NM stabilizer 16"(full gauge)+ARC 825+8"PowerPulse+Gyro Collar+2x NMXO. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907.670-8601 907-575-9427 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 3/13/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • Eni E&P Division Well Name:0P21-WWO1 VII* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/21/2012 - Report#: 10 APIIUWI:029-23438-00-00 2 r' rr page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(%) !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) I Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mfhr) DFS(days) W OP21- W01 DRILLING 3/16/2012 1 3,397.61 2,880.89 4,117.24 145.12 28.4 5.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) Avg ROP(m/hr) !POB Temperature(°C) !Weather Weather Wind 1,257.91 1,143.23 0.00 84.0 -36.7 Clear WC-50° NNE @ 4.6 MPH Daily summary operation 24h Summary L/D BHA#2-R/U to run 13 3/8"csg-RIH with 13 3/8"csg 680 L80 BTC down to 1976'-CBU-RIH to 2050'and stuck csg-Working on to try get it free and re-establish the circulation. Operation at 07.00 Working on the csg to try re-establish circulation.Max pull on csg 500k lbs. 24h Forecast Work to csg free and re-establish circulation. 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 02:00 2.00 2.00 DRILL E 5 P 'Finish to L/D BHA#2:NM Stabilizer 0 12.13(full gauge)+Motor+bit 0 16".Bit Dull 3-2-WT-A-E-2-RG-TD. 02:00 103:00 ' ' 1.00 3.00 DRILL E 1 P 'Clean Drill floor.Clear pipe shed of BHA tools and prepare to run casing. 03:00 03:30 0.50 3.50 DRILL G 11 P 'Perform 13 3/8"csg hanger dummy run per Vetco rep:Ok.L/D csg hanger. 0330 06:30 3.00 6.50 DRILL G 5 P Load pipeshed with 13 3/8"GBR csg handling equipment.R/U GBR casing tools and power tongue.R/U Franks casing fill up tool. 0630 12:00 5.50 12.00 DRILL G 4 P P/U,M/U Shoe track w/Baker Lock-Check float equipment:Ok-P/U,M/U 8 RIH Casing 13 3/8"680 L80 BTC(5.7k fl'lbs M/U torque)1/1,976'.NO tightspots,proper displacement.Top off every 10 jts.Down weight 130k lbs. 12:00 12:30 0.50 12.50 DRILL G 7 P Circulate 1x B/U @ 1,907'.Break circulation at 250 gpm/270 psi. 12:30 13.00 0.50 13.00 DRILL G 4 P Continue to Run 13 3/8"Casing 1/1,976'112,060'.Taking weight.Try to P/U to 200k lbs negative.Gradually pull to 270 k lbs and finally came free. 1300 1700 4.00 17.00 DRILL G 13 TP02 "POOH and L/D joint 53.Attempt to POOH next joint:No Up,No down.Could not pump @ 2040.Work casing up to 340k lbs and attempt to regain circulation'finally got circulation with 60 gpm/800 psi/return flow=-30%of fluid pumped. 17:00 23:00 6.00 23.00 DRILL G 13 TP02 Stage flow rate up to 88 gpm/800 psi and work pipe from 150k lbs to 340k lbs.Work pipe from 150k lbs to 40k lbs.Return flow drop to-10%of fluid pumped.Set down to 35k lbs and attempt to wash at 86 gpm/770 psi:gradually lose circulation. 23:00 00.00 1.00 24.00 DRILL G 13 TP02 Stage up to 300k-350k-400 k-450k and slacked off fast to 358 regained circulation temporally,lossed again @ 23.40 hrs.Total mud loss for the day:907 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Rodney McCoy Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamadna @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Matti Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) 1P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOR(kgflcm') Eni E&P Division I Well Name:0P21-WW01 flY* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • Date:3/22/2012 - Report#: 11 API/UWI:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) 'RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 6.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 1,257.91 1,143.23 0.00 84.0 -38.0 Clear WC-58' NE@ 8.1 MPH Daily summary operation 24h Summary Working on stuck casing(csg shoe @ 2,040')and attempt to establish circulation:NO movement,NO return-UD Franks tool-R/U scaffolding-B/O bad 13 3/8"csg collar and install new one-R/U cement head-Circulate to csg volume(300 bbls)-R/U Halliburton E-line-RIH and set 13 3/8"Cement Retainer @ 1,943'. Operation at 07.00 Circulating through perferations. Checking for flow. 24h Forecast Perforate casing and try to establish a good circulation for cement job-Perform Cement Job of 13 3/8"surface casing-W.O.C.-N/D Diverter and set emergency slips-Cut and recover casing. 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 G 13 TP02 Working on stuck pipe W 2040' staaina up o Q0k-350k-49QJs-.450k-5QRk and slacked off fast to 35k:negative.Attempt to establish circulation @ 1-6 bpm:negative.NO csg moviment,NO return. 06:00 12:00 6.00 12.00 DRILL G 23 TP02 Working on stuck casing.Break circulation every 10 minutes to prevent slant pipe freezing-No retums. Work pipe F/40K T/340K @ 1.5 bpm:NO movements,NO return.Decision is made to perforate 13 3/8"casing 15'above float collar and try to get a good circulation for cement job.Wart on Halliburton Wireline,perforation guns and cement retainer. Note:13 3/8"csg shoe @ 2,040'-Flot Collar @ 1,958'. 12:00 15:30 3.50 15.50 DRILL G 5 U Break out Franks tool,UD and clean same.L/D spider elevators,R/U scaffolding(csg stick up-15'above RKB). 15:30 18.30 3.00 18.50 DRILL G 5 U R/U tongs,slings,cumalong to break bad collar on top of 13 3/8"csg joint.Remove bad one and install new one.Make up swedge for cement head, 18:30 19:30 1.00 19.50 DRILL G 5 U R/U Schlumberger Cement Head,hoses and lines.Test lines:Ok. 19:30 21:00 1.50 21.00 DRILL G 9 U Break circulation and pump 10 casing volume(-300 bbls)of mud @ 4 bpm/700 psi:NO return. 21:00 22:30 1.50 22.50 DRILL G 5 U R/U Halliburton E-Line equipments.R/U sheaves and tools to RIH and set Cement Retainer. 22:30 00:00 1.50 24.00 DRILL G 17 U 13,)l ,0h,13 3/8"U pan] cva.CementRelai ler..(5/0.102053202).tag Float Collar.@ 1,958:,pull 15:,and seLCemen(, Retainer(81 1,943':Ok..._ Daily Contacts Position Contact Name Company Title 1 E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) 'TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1� Eni E&P Division I Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Report L Well Code:26259 Field Name:Nikaitchuq • Date:3/23/2012 - Report#: 12 APIIUWI:029-23438-00-00 2" "� page 1 of 1 Wellbore name: OP21-WW01 Well Header Oliktok Point Permit/Concession N° I ENI PETROLEUM [ENI Share(°/.4 100.001 DIRECTIONAL Configuration type Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 7.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) J'Avg ROP(m/hr) IPOB Temperature(°C) Weather 'Wind 1,257.91 1.143.23 0.00 82.0 -30.0 Clear WC-49` NE @ 17 MPH Daily summary operation 24h Summary RIH and perforate casing from 1.931'to 1,934'-Pressure test 13 3/8"casing and cement retainer to 2500 psi:Ok-R/D Halliburton Wireline equipment-Circulate and condition mud for cement job-Spot Schlumberger cement unit and equipments and prepare to perform surface cement job-Perform 13 3/8"Cement job-W.O.C.and check for returns:NO flow @ Midnight. Operation at 07.00 R/D cement head and scaffolding.Prepare to cut 13 3/8"casing. 24h Forecast Lift Diverter and set emergency slips-Cut and Recover 13 3/8"csg-N/D Diverter Assy-N/U Vetco Gray Wellhead and test-N/U BOP and Test as per AOGCC requirements. 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 00:30 0.50 0.50 DRILL G 17 U POOH Wireline and check running tool:Ok. 00.30 02:00 1.50 2.00 DRILL G 12 U M/U lines to pump down 13 3/8"casing.Perform pressure test of 13 3/8"casing and cement retainer staging up pressure to 500-2500 psi and hold for 30 minutes:Ok(charted).R/D 8 B/D lines. 02:00 04:00 2.00 4.00 DRILL G 16 U Held PJSM.P/U 3'3-3/8"Millenium perforation guns 18 shots-6 spf-60 DEG phasing-25 gm HMX and RIH with Wireline.Tag Cement Retainer,pull 5'and perforate casing f/1,931'1/1,934'.POOH:all shots fired(100%). ..JJ 04:00 0500 1.00 5.00 DRILL G 7 U Break circulation slowly @ 1 bpm and check for return:Ok.Stage up to 5 bpm/200 psi:Full Retum,No losses. (1/" 05:00 07,00 2.00 7.00 DRILL G 5 U R/D Halliburton Wireline equipment.Continue to circulate @ 5 bpm/200 psi.Start offload mud to Vac Truck and prepare ` �rn� 1 pits to condition mud for cement job. , 07:00 11:30 4.50 11.50 DRILL H 1 U Circulate and condition mud @ 5 bpm/188 psi.Final VP=15-18:Ok.Meanwhile spot Schlumberger cement equipments `r�,(Al l on short side,connect lines and get ready to perform cement job.Retum 544 bbls of new mud to Spy Island.At 10.00 received Vac Truck with Cement Contam Pill.Add 40 bbls of cement contam pill to 3 trucks and 2 buckets of D-110 to each truck.Spot trucks in position and finish to R/U Schlumberger lines and pressure test with water to 250-3500 psi.Ok. 11:30 13:30 2.00 13.50 DRILL H 1 XS03 Change air hose on cementing unit.Start to mix 100 bbls of spacer.Having problems with bulk feed.troubleshoot same and continue to mix spacer in batch mixer. 1330 1730 4.00 17.50 DRILL H 9 U Cement 13 3/8"surface casing.SLB pump 5 bbls Mudpush II and test lines to 2500 psi-SLB pump 95 bbl Mudpush II @ 10.1 ppg(5 bpm @ 150 psi)-SLB mix and pump 390 bbls Lead Slurry @ 10.7 ppg[Class Artic Sea Lite 879 sacks,2.49 5j Yield,mix fluid 11.928 gal/sk]-Followed by 82 bbls Tail Slurry @ 12.5 ppg)DeepCRETE 297 sacks,1.55 Yield,mix fluid 5.198 gal/sk]-Break cap connection of cement head and Drop Top Plug-SLB pump 10 bbls water-Switch to Rig Pump and Displace with 275 bbls of mud(6 bpm @ 50--c550 psi)-[Cement in place©17:301-Top of cement inside 13 3/8"csg -100'above perforations(1,931'-1,934').Shut down pump and hold FCP:pressure drops to 200 psi.Recovered 7 264 bbls lead slurry on surface-40 bbls losses during cement job. 17:30 21:30 4.00 21.50 DRILL H 21 U W.O.C.Pressure drop from 200 psi to 80 psi in 4 hours. 21'.30 00'.00 2.50 24.00 DRILL H 21 U Attempt to bleed off casing pressure(80 psi):recovered 20 gallons of mud and fluid kept coming fast.Decided to shut in well and wait 2 more hours.Check again at midnight Ok,No flow. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile - Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Ca s.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') f Eni E&P Division 'Well Name:OP21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/24/2012 - Report#: 13 APIIUWI:029-23438-00-00 2 rr r'o page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(mKB) Target Depth(TVD...I Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) WW OP21- 01 DRILLING 3/16/2012 3.397.61 2,880.891 4,117.24 145.12 28.4 8.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) !Drilling Hours(hr) 'Avg ROP(mlhr) I POB Temperature(°C) !Weather Wind 1,257.91 1,143.23 0.001 83.0 -29.4 Overcast WC-41° NE @ 9 MPH Daily summary operation 24h Summary Lift Diverter and install emergency slips-Make final cut on 13 3/8"csg-L/D Diverter System-Install Vetco Wellhead and test-N/U BOP stack. Operation at 07.00 Test BOP as per AOGCC requirements.Jeff Jones waived to witness the test 3/23/2012 @ 09:00 hrs. 24h Forecast Finish to N/U BOP-Perform pressure test BOP stack as per AOGCC requirements-P/U 12 1/4"BHA-Perform FIT/LOT for perforation interval-Ream cement+retainer+shoe track-RIH to 4127'and check hole condition. 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 02:00 2.00 2.00 DRILL C 5 U Held PJSM.Remove Knife valve,unscrew bolts,raise surface Annular Preventer and put secondary tie-off on stack.Pull casing in tension 200k lbs on MD and set emergency slips as per Vetco.Lower stack. 02.00 07:00 5.00 7.00 DRILL C 1 U Rig down casing cement head and change elevators.Rig down and lay down scaffolding.P/U 9-5/8"csg shoe track and RIH into 13 3/8"csg to displace mud from the top to the rig floor Ok. 07:00 09:00 2.00 9.00 DRILL C 18 U 'Cut 13 3/8"csg joint @ rig floor and L/D cut off joint.P/U 9 5/8"csg shoe track and RIH into 13 3/8"csg to displace mud. Ok. 09:00 11:00 2.00 11.00'DRILL C 18 U Raise stack and put secondary tie-off on.Rig up lifting device on 13 3/8"csg and make second CSG cut at cellar level. Recover cut off joint. 11:00 16:00 5.00 16.00 DRILL C 5 P N/D Bell Nipple,R/D flow line,remove bag preventer and move to pedistal.UD Vetco starling head. 16:00 '19:00 3.00 19.00 DRILL C 5 P N/U Wellhead and valves-Pressure test Wellhead 5k psi x 10 minutes:Ok. , 19,00 00:00 '' 5.00 24.00 DRILL C 5 'P -N/U 13 5/8"Riser and BOP Stack,install Bell nipple 8,Flow line.Install choke lines,kill line and N/U Katch Kan. Daily Contacts - Position Contact Name Company Title E-mail Office Mobile • Eni representative Rodney McCoy Eni Petroleum Sr.Orig.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drip Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HOE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1 Eni E&P Division 'Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/25/2012 - Report#: 14 API/l1Wl:029-23438-00-SO err page 1 of 1 Wel lbore name OP21-WWO1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E ILAND 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) I DFS(days) OP21-WW01 DRILLING 3/16/2012 3,397.61 2880.891 4,117.24 145.12 28.4 9.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(mlhr) POB Temperature(°C) Weather Wind 1,257.91 1,143.23 0.00 83.0 -31.1 Overcast WC-40° NNE©6MPH Daily summary operation 24h Summary Finish to N/U BOP stack and Test as per AOGCC requirements-Jeff Jones waived to witness the test 3/23/2012 @ 09:00 hrs-P/U,M/U and RIH BHA#3-Tag top of cement @ 1,695'-Circulate B/U- Slip and cut drilling line. Operation at 07.00 Reamed cement To 1,728'. 24h Forecast RIH to top of cement.Driil cement to below the perfs.preform LOT/FIT on perfs.Drill out shoe track,wash to 4,027'in previously drilled hole.Swap out mud system.POOH,Lay down BHA,P/U directional BHA,TIH. Lithology 'Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL C 5 P Finish to N/U 13 5/8"Riser and BOP Stack.Hook up lines and N/U Katch Kan. 03:00 04:00 1.00 4.00 DRILL C 1 P P/U,M/U test joint.Install test plug.Fill Stack and lines w/water and check for leaks:Ok.Purge air out of system and R/U BOP test equipments. 04:00 15:30 11.50 15.50 DRILL C 12 P Test BOP as per AOGCC requirements w/5"test Joint-Annular©250-2500 psi-Rams,choke manifold,floor and top drive valves @ 250-5000 psi-Chart record-BOP test witness waived by AOGCC rep.Jeff Jones 3/23/2012 @ 09:00 hrs. Note:Experienced 4(four)failures while testing BOP: #1)Stem packing adjustment gland on Annular Valve @ Wellhead.Tighten&retest:Ok,passed test. #2)13 5/8"Gray Lock Clamp @ Wellhead.Tighten&retest:Ok,passed test. r'� #3)Ram door seal top pipe rams.Open,clean and install new door gasket&retest'.Ok,passed test. '' #4)Ram door seal blind(center)rams.Open,clean and install new door gasket&retest:Ok,passed test. f'::,;:,..; 17f 15:30 18:00 2.50 18.00 DRILL C 5 P Blow down choke,POOH test plug.Install Wear Bushing ID 12 5/16".UD 5"test joint. `P° 18:00 20:30 2.50 20.50 DRILL E 5 U P/U,M/U and RIH BHA#3:0 12 1/4"MT bir Hughes VMD-3(s/n 5208406)+bit sub+NM stabilizer+NMDC+2x NM Flex DC+sub with float valve+8"Hydraulic Jar Smith(07111C)+XO+14 jts 5"HWDP. • 20:30 22:30 2.00 22.50 DRILL E 4 U RIH BHA#3 with stands of 5"DP and tag top of cement @ 1,695'with 20k lbs.RIH and wash down from 1,120'. 22:30 00:00 1.50 24.00 DRILL E 25 P Slip and cut 75'of Drilling Line.In progress. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum 'Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HOE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mats Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P Lea kOff(kgflcm') f D Eni E&P Division I Well Name:OP21-WW01 EN/Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • Date:3/26/2012 - Report#: 15 APIIUWI:029-23438-00-00• e rn page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator 'ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 10.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(mlhr) 'P" Temperature(°C) Weather Wind 1,257.91 1,143.23 0.00 83.0 -36.1 Clear WC-33` Winds Calm Daily summary operation 24h Summary Slip and cut 75'drilling line adn rig maintenance-Ream cement to 1783'-Circulate for cement contaminated mud-Ream cement down to 1932'-Perform LOT @ 1,932'(1,904'TVD)-EMW=12.6 ppg- Attempt to ream cement retainer:no progress. Operation at 07.00 L/D BHA#3. 24h Forecast POOH and check BHA condition-RIH to top of cement retainer-Ream cement retainer and drill out shoe track-Wash to 4.027'in previously drilled hole-Swap out mud system-POOH&L/D BHA-P/U directional BHA&TIH. 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 02.00 2.00 2.00 DRILL E 25 P Finish to slip and cut 75'of dolling line.Adjust breaks,pump up wt indicator.set crown saver.Greased Top Drive and blocks. 02:00 1 04:30 2.50 4.50 DRILL E 6 U Vjtash and ream cement FI1624'TL1Z83_with 650 gpm/750 psi/60 rpm/2-3k Ibs'h TO/WOE 5K/Up Wt 100k/Dw WI 90k/Rot Wt 98k. 04:30 09:30 5.00 9.50 DRILL E 7 U See noticable contaminated mud"returns"at shakers.Circulate&condition cement contaminated mud,thin mud in pits. Dump 227 bbls of contaminated mud to cuttings box and On-load 140 bbls of new Spud mud stored on Contract Vac truck. 0930 1230 3.00 12.50 DRILL E 6 U Ream cement V1,783'5/1,932'with 650 gpm/840 psi/60 rpm/2-3k Ibs'ft TO/WOB 5-10K/Up Wt 100k/Dw Wt 90k/t Wt 105k. 12:30 13:00 0.50 13.00 DRILL E 7 U Circulate and condition mud for FIT/LOT.Mud Wt in/out=9.1* ,` `., -,/ 13:00 13:30 0.50 13.50 DRILL E 5 U R/U head pin'TtW-and.linee-Ior-FITLLIIL__ -� i j . 13:30 14:30 1.00 14.50 DRILL E 9 U Perform LOT @ 1.932'(1.904').Max Pressure 480 psi.EMW=12.6 ppg. _,.,./ V j 14:30 00:00 9.50 24.00 DRILL E 19 XP99 reaming cement retainer with 650 gpm/850 psi/45 rpm/23k Ibsit TO/WOB 25K to 1,958':rubber recovered @ the sha ontinue to ream down without makirgany-other progress.Attempt to ream down changing parameters:no progress.Max /M,TOr-46KWIbs/Max 100 rpm/Max FR=650 gpm/P=400-580 psi.POOH 30'and check TQ off bottom:with 70 rpm torque stable to 10k Ibs'ft.Tried to move BHA up and down,increase flow rate and pump 2 sweep to free bit&stabilizer from cement retainer junks:small pieces of cement retainer slips @ shakers.Check off bottom TO again:70 rpm/max TQ 19k Ibs'ft(stable).Decided to POOH and check BHA conditions. - Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Dug.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Dug Spur. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) 'Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') f Eni E&P Division 'Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:3/27/2012 - Report#: 16 APIIUWI:029-23438-00-00 2'r i 11 page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° I Operator ENI Share)%) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) DES(days) 0P21-WW01 DRILLING 3/16/2012 1 3,397.61 2,880.89 4,117.24 145.12 28.4 11.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(mlhr) IPOB Temperature(°C) Weather 'Wind 1,261.87 1,146.23 662.03 1 83.0 -36.1 Clear WC-48° NNE @5MPH Daily summary operation 24h Summary POOH BHA#3-Change bit with 0 12 1/4"PDC-RIH with BHA#4-Ream cement retainer,float collar and shoe-Wash down to 4,127'-Circulate and condition mud for displacement-Displace well with 9.2 LSND mud. Operation at 07.00 POOH BHA#4 on elevators.@ 2021' 24h Forecast Finish to displace well with 9.2 ppg LSND mud-POOH BHA#4-M/U and RIH Directional BHA#5-Drill 0 12 1/4"section to planned TD @ 8,048'. 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 XP99 POOH BHA#3 f/1,958 to surface.L/D 0 12 1/4"bit.Bit Dull:1-1-BT-C-E-1-CT-TO. 04.00 04:30 0.50 4.50 DRILL E 25 XP99 Service Top Drive and grease blocks. 04.30 05.00 0.50 5.00 DRILL E 5 XP99 P/U,M/U and RIH BHA#4 0 12 1/4"PDC bit Smith MDSi616(s/n JE3720)+bit sub+NM stabilizer+NMDC+2x NM Flex DC+sub with float valve+8"Hydraulic Jar Smith(07111C)+XO+14 jts 5"H W DP. 05.00 08:00 - 3.00 8.00 DRILL E 4 XP99 RIH BHA#4 with stands of 5"DP and tag top of cement retainer @ 1,958'. 08:00 10:00 2.00 10.00 DRILL E '6 P Reaming/Washing to 1960',drill float collar 1960'-1962',wash to 2,040'and drill through shoe @ 2,041'with 508 gpm/493 psi/50-60 rpm/TO 3-12.7k ftlbs/WOB 0-30K/Dn Wt 92k/Rot Wt 100k. 10.00 19:00 9.00 19.00 DRILL E °6 P Continue RIH BHA#4 and wash 16"hole f/2,041'to 4,127'with 500 oor0/600-700 psi/50 rpm/TO 3-4 k ftlbs/Up Wt 140k/Dn Wt 120k/Rot Wt 118k.Pump Hi-Vis sweep every 500 ft and backream @ 75 rpm till sweep to surface. 19:00 22:00 3.00 22.00 DRILL E '7 P At 4,127'pumped 40 bbls of Hi-Vis sweep and circulate conditioning mud for displacement with 600 gpm/850 psi/65 rpm/TO 5-7 k ft`Ibs. 22:00 23:00 1.00 23.00 DRILL E '1 P Shut down pumps and offload all Spud Mud from active pits to Vac Tracks.Prepare Hi-Vis Spacer pill with LSND mud into pill tank.Held PJSM for displacement. 23.00 00.00 1.00 24.00 DRILL E 7 P Pump 50 bbls of Hi-Vis Sweep Spacer and displace well with 9.2 ppg LSND mud with 330 gpm/250 psi/40 rpm/TO 5-7 k fibs.In progress. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Dulling Tour Pusher 907-670-1492 - Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 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:0P21-WW01 PI* EN!Petroleum Co.Inc. Daily Report` Well Code:26259 Field Name:Nikaitchuq • APIUWI:029-23438-00-00 3/28/2012 - Repo #: 17 page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.3411 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E I 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) OP21-WW01 DRILLING 3/16/2012 3.397.61 2,880.89 4,117.24 145.12 28.4 12.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(m/hr) 'POB Temperature(°C) Weather (Wind 1,313.08 1,185.11 55.17 2.54 21.7 83.0 -33.9 Clear WC-29° Winds Calm Daily summary operation 24h Summary POOH BHA#4-M/U and RIH BHA#5 to 4127-Drilling 12 1/4"section to 4403' Operation at 07.00 Drilling 12 1/4"section to 4593' 24h Forecast Drilling 12 1/4"section as per wellplan to 8048' Lithology Shows MAASP(kgflcm") Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00:00 01:00 1.00 1.00 DRILL E 7 P Complete to displace well with 9.2 ppg LSND mud(330 gpm @ 250 psi-40 rpm @ TO 5+7k fl'lbs)\ 01:00 06:00 5.00 6.00 DRILL E 4 P POOH(/4127'to surface 0600 07:00 1.00 7.00 DRILL E 5 P POOH and UD BHA#4(Bit Dull.0-0-WT-A-X-1-NO-BHA) 07.00 15:00 + 8.00 15.00 DRILL E 5 P Remove wear bushing to allow motor to ft through wellhead-P/U,M/U and RIH BHA#5(Bit 12'A"Smith MDSI616 TFA: 0.978(s/n JE3720)+PDM(1.5 bend)+NM pony+NM Stab+NM XO+ARC 825+PowerPulse+NM Stab+NM DC+x2 fr, NM Flex DC+Float Sub+8"Jar(s/n 07111C)+XO+x14 5"HWDP+x9 5"DP+12''/."Gost Reamer)-Set wear bushing with string on DP 15:00 1800 3.00 18.00 DRILL E 4 P RIH 1/4127' 18:00 00:00 600 24.00 DRILL E 3 P Drilling Rotary/Sliding 0 12'/."section 1/4127'84403'18407900 gpm @ 1700?2100 psi 170 rpm @ 7+12k fldbs\WOB= 5.t0k lb 1 Up wl=170k lb-Dw wt=125k lb-Rot wt=145k lb\Mud wt=9.3 ppg-Take survey as needed Daily ADT=3.2 hrs (ART=2,88-AST=0.32 hrs-Jar=54.31 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Dug.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Dug Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Dnlling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 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 ., I Well Name:OP21-WW01 011* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq •" Date:3/29/2012 - Report#: 18 API/t1Wl:029-23438-00-00 2" page 1 of 1 Wellbore name: OP21-WW01 ' Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.001 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) IDFS (days) W OP21- W01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 13.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,692.86 1.468.25 379.78 9.39 40.4 83.0 -37.8 Partly Cloudy WC- SSW @ 7 MPH 56' Daily summary operation 2411 Summary Drilling 12 1/4"section as per well plan from 4403'10 5553'-Back ream to top of 12 W hole each 500'drilled Operation at 07.00 Short trip-RIH on elevator @ 4200' 24h Forecast Drilling 12 1/4"section as per well plan to 8048' Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1120.4 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 3 P Drilling Rotary 0 12 W section(/4403't/4595'\850?900 gpm @ 1800?2150 psi 170 rpm @ 8+14k ftlbs\WOB=20,25k lb \Up wt=170k lb-Dw wt=125k lb-Rot w1=145k lb\Mud wt=9.3 ppg-Take survey as needed-Ream 30'each Std drilled 01:30 03:30 2.00 '' 3.50 DRILL E 6 P BROOH 8/4595'54127'(900 gpm @ 2000?1950 psi-70 rpm @ 8=11k ftdbs)-Pump 40 bbl HiVis sweep-Circulate B/U 03:30 04:00 0.50 4.00 DRILL E 6 P RIH on elevator 1/4127'1/4595' 04:00 08:30 4.50 8.50 DRILL E 3 P Drilling Rotary 0 12'/."section 8/4595'V5070'1900 gpm @ 2150?2200 psi\70 rpm @ 8.15k(fibs\WOB=20025k lb\Up wt=180k lb-Dw wt=130k lb-Rot wl=150k lb\Mud wt=9.4 ppg-Take survey as needed-Ream 30'each Std drilled 08:30 10:30 2.00 10.50 DRILL E 25 TRO3 Maintenance Rig power generator-Pump 40 bbl HiVis sweep and circulate B/U 10:30 14:00 3.50 14.00 DRILL E 6 P BROOH 9/5070'54116'(900 gpm @ 2150?1950 psi-70 rpm @ 7.11k fobs) 14:00 '15:00 1.00 15.00 DRILL E 6 P RIH on elevator f/4116'1/5070' 15:00 23:00 8.00 23.00 DRILL E '3 P Drilling Rotary 0 12 W section 1/5070'55553'\900 gpm @ 2200?2350 psi\70 rpm @ 8=16k ft-Ibs\WOB=20,25k lb\Up wt=190k lb-Dw wt=138k lb-Rot wt-160k lb\Mud wt=9.4 ppg-Take survey as needed-Ream 30'each Std drilled Daily ADT=8.73 hrs [ART=8.73-AST=0 hrs-Jar=63] 23:00 00:00 1.00 24.00 DRILL E 6 P Pump 40 bbl HiVis sweep-BROOH f/5553'55433'(900 gpm @ 2350?2250 psi-70 rpm @13,9k Albs) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Rodney McCoy Eni Petroleum Sr.Ng.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter •907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(g/L) I P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') Eni E&P Division I Well Name:0P21-WW01 PI* ENI Petroleum Co.Inc. Daily Report` Well Code:26259 Field Name:Nikaitchuq Date:3130/2012 - Report#: 19 APIIUWI:029-23438-00-00 2" "� page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° !Operator I ENI Share(%) Well Configuration type Oliktok Point IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type -- - , NABORS ALASKA NABORS 245 E 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) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 14.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) !Avg ROP(m/hr) POB Temperature(°C) Weather 'Wind 1,838.86 1,576.65 146.00 5.67 25.7 83.0 -33.3 Clear WC-47" North©7 MPH Daily summary operation 24h Summary Drilling 12 1/4"section as per well plan from 5553'to 6031'-Back ream to top of 12'/."hole each 500'drilled Operation at 07.00 Short trip-BROOH @ 4800' 24h Forecast BR to top of 12'/."hole-Pump HiVis sweep and circulate B/U-BR to 13 3/8"shoe and circulate hole clean-TIH w/elevator-Drilling 12 1/4"section as per well plan to 8048' Lithology 'Shows MAASP(kgflcm') I 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 03:00 3.00 3.00 DRILL E 6 P BROOH V5433'1/4116'(900 gpm @ 2250?2000 psi-70 rpm @ 7.10k bibs) 03.00 04:00 1.00' 4.00'DRILL E 25 P TOO-Change gripper dies in TO 04:00 05:00 1.00' 5.00'DRILL E 9 P Pump 40 bbl HiVis sweep-Circulate B/U 05:00 07:00 2.00' 7.00 DRILL E 6 P 'RIH on elevator f/4116'115553' 07:00 15:00 8.00 15.00 DRILL E 3 P 'Drilling Rotary 0 12 V. section f/5553'1/6031\900 gpm @ 2350?2550 psi\70 rpm @ 12.23k fobs\WOB=5.20k lb\Up wt=210k lb-Dw wt=144k lb-Rot wt=166k lb\Mud w4=9.4 ppg-Take survey as needed-Ream 30'each Std drilled Daily ADT=5.67 hrs [ART=5.67-AST=0 hrs-Jar=68.671 1500 17:30 2.50 17.50'DRILL E 6 P Pump 40 bbl HiVis sweep-BROOH f/6031'1/5750'(900 gpm @ 255072350 psi-70 rpm @ 12=29k fklbs) 17.30 18:30 1.00 18.50 DRILL E 9 P Pump 40 bbl HiVis+lube sweep and circulate B/U 18.30 '00:00 5.50' 24.00 DRILL E 6 P BROOH f/5750'1/5263'(900 gpm @ 2350?2250 psi-70 rpm @ 12.29k fflbs) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Ben Perry Eni Petroleum Sr.Orig.Spvr. -907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 1.1 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dnlling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) ITVD(mKB) Fluid Type Fluid Density(g/L) I P Surf Applied(kgticm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') I Eni E&P Division I Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • API/UWI:029-23438-00-00 page 1 of 1 2 n ri Date:3/31/2012 - Report#: 20 - II " Wellbore name: OP 21 WW01 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) I DFS(days) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 15.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) I POB Temperature(°C) Weather Wind 1,838.86 1,576.65 0.00 83.0 -25.6 Over Cast WC-34' NE @ 10 MPH Daily summary operation 24h Summary BR to top of 12'G"hole(4127')-C/O TD encoder(causing improper torque reading)-BR to 13 3/8"shoe(2040')and circulate hole clean-TIH on elevator$14748' Operation at 07.00 Drilling 12 1/4"section to 6,224' 24h Forecast TIH on elevator to the bottom(6031')-Drilling 12 1/4"section as per well plan to 8048'-Short trip to top of 12'/."hole each 500'drilled Lithology Shows MAASP(kgflcm°) I Mud Weight(gIL) • 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -10:00 10.00 10.00 DRILL E 6 P BROOH(/5263'1/3920'(900 gpm @ 2250?2050 psi-70 rpm @ 9.29k ftlbs) 10:00 11:00 1.00 11.00 DRILL E 25 TRO4 Rig Maintenance:C/O encoder on TD-Encoder found to be bad causing improper torque readings-Circulate(350 gpm @ 400 psi)meanwhile 11:00 19:00 8.00 19.00 DRILL E 6 P 'BROOH(/3920'5/2203'(900 gpm @ 2050?1700 psi-70 rpm @ 4.5?2.5k Ribs) 19:00 20:30 1.50 20.50 DRILL E 7 P Pump 40 bbl HiVis sweep and circulate hole clean(x4 B/U-1150 gpm @ 2700 psi-70 rpm @ 2.5k R'lbs) 20:30 21:00 0.50 21.00 DRILL E 25 P TDS and draw works-Calibrate blocks 21:00 00:00 3.00' 24.00 DRILL E 6 P RIH on elevator f/2203'1/4780'filling pipe every 2000' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Man Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) ITVD(mKB) Fluid Type Fluid Density(gIL) IP Surf Applied(kgflcm') Eq.Mud Weight(gIL) 1P LeakOff(kgf/cm') f Eni E&P Division 'Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • Date:4/1/2012 - Report#: 21 APIIUWI:029-23438-00-00 2"no page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° 'Operator ENI Share(%) I Well Configuration type Oliktok Point JENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.3411 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 16.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) I POB Temperature(°C) 'Weather Wind 2,159.81 1,816.01 320.95 7.58 42.3 83.0 -24.4 Over Cast WC-33° NE @ 13 MPH Daily summary operation 24h Summary TIH on elevator to the bottom(6031')-Drilling 12 1/4"section(/6031'1/6512'-Back ream 500'-Drilling 12 1/4"section(/6512'1/7085'-Short top to top of 12'/."hole(4127') Operation at 07.00 TIH on elevator @ 5,840' 24h Forecast Continue BR to top 0112%°hole(4127')-Pump HiVis sweep and circulate hole clean-TIH on elevator to bottom(7085)-Drilling 12 1/4"section as per well plan to 8048'-Back ream drilled section every 500' Lithology Shows I MAASP(kgflcm') I Mud Weight(gIL) 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 6 P RIH on elevator 1/4780'1/6031'filling pipe every 2000' 01:00 02:00 1.00 2.00 DRILL E 7 P Circulate BU to condition mud 02:00 07:00 5.00 7.00 DRILL E 3 P Drilling Rotary/Sliding 0 12 Z-section f/6031'V6512'1900 gpm©2550?2650 psi\100 rpm©11+15k fibs\WOB= 10+25k lb I Up wt=210k lb-Dw wt=140k lb-Rot wt=165k lb I Mud wt=9.4 ppg-Take survey as needed-Ream 30'each Std drilled 07:00 09:00 2.00 9.00 DRILL E 6 P BROOH 1/6512'8/6000'(900 gpm @ 2450 psi-100 rpm @ 9?10k ftlbs)-RIH on elevators 09:00 14:30 5.50 14.50 DRILL E 3 P Drilling Rotary 0 12 W section V6512'1/7085'1900 gpm @ 2650?2950 psi\100 rpm @ 12015k ftlbs\WOB=10+25k lb I Up wt=210k lb-Dw wt=145k lb-Rot wt=177k lb\Mud w1=9.5 ppg-Take survey as needed-Ream 30'each Std drilled- Pump HiVis sweep every 200'drilled Daily ADT=7.58 hrs [ART=7.15-AST=0.45 hrs-Jar=76.28] 14.30 00:00 9.50 24.00 DRILL E 6 P BROOH(/7085'1/4500'(900 gpm @ 2700?2150 psi-100 rpm©13?8.5k ft'lbs) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr, 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) I P LeakOff(kgflcm') Eni E&P Division I Well Name:0P21-WW01 101* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/2/2012 - Report#: 22 APIIUWI:029-23438-00-00 2" "� page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB)'Target Depth(TVD...I Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) I DFS(days) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2.880.89 4,117.24 145.12 28.4 17.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(m/hr) POB Temperature(°C) Weather !Wind 2,471.32 2,050.78 311.51 8.03 38.8 82.0 -23.3 Over Cast WC-33' I NE @ 16 MPH Daily summary operation 24h Summary BR to top of 12'/."hole(4127')-Pump HiVis sweep and circulate hole clean-TIH on elevator to bottom(7085)-Drilling 12 1/4"section to TD 8107'MD,6725'ND-Clean up cycle-BROOH Operation at 07.00 BROOH @ 6,760 24h Forecast BROOH to 13 3/8"shoe-Circulate hole clean-POOH on elevator-LID BHA#5-R/U casing running tools Lithology 'Shows MAASP(kgflcm°) I Mud Weight(gIL) 1174.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 02:00 2.00 2.00 DRILL E 6 P BROOH 1/4500'114020'(900 gpm @ 215072050 psi-100 rpm @ 9k fflbs)-Pump 40 bbl HiVis sweep and circulate hole clean 02:00 05:00 3.00 5.00 DRILL E 6 P RIH on elevator f/4020'1/7085'filling pipe every 1000'(30'fill on bottom) 05:00 12:00 7.00 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 12''/°"section(/7085'U7564'\900 gpm @ 295073050 psi\100 rpm @ 12.19k Ribs\WOB= 10=25k lb\Up wt=230k lb-Dw wt=180k lb-Rot wt=155k lb\Mud wt=9.4 ppg-Take survey as needed-Ream 30'each Std drilled 12:00 14:30 2.50 14.50 DRILL E 6 P BROOH(/7564'17000'(900 gpm @ 2800 psi-100 rpm @ 14.15k fobs)-RIH on elevator f/7000'07564'(no excess drag, no fill) 14:30 21:00 6.50 21.00 DRILL E 3 P Drilling Rotary/Sliding 0 12 1/4"section(/7564'U/TD(8107'MD-6725'ND)'\900 gpm @ 3050?3300 psi\100 rpm @ 17.20k ft lbs\WOB=20+25k lb\Up wt=250k lb-Dw wt=162k lb-Rot wt=195k lb\Mud wt=9.8 ppg-Take survey as needed-Ream 30'each Std drilled Daily ADT=8.03 hrs [ART=6.82-AST=1.21 hrs-Jar=84.34] 21:00 23:30 2.50 23.50 DRILL E 7 P Clean up cycle:Circulate 3x BU(900 gpm @ 3000 psi-100 rpm @ 15?18k fflbs)rack back 01 Std every BU 1/8107'1/7860' 23:30 00:00 0.50 24.00 DRILL E 6 P BROOH 117860'U7760'(900 gpm @ 3000 psi-100 rpm @ 15?18k ft'tbs-20 min/St) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 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 Report/ I Well Name:OP21-WW01 Or* ENI Petroleum Co,Inc. Daily Repor Well Code:26259 Field Name:Nikaitchuq • API/UW:029-23438-00-00 Date:4/312012 - Repo #: 23 z ii page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) !Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E 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) IDES(days) W OP21- W01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.41 18.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg ROP(mlhr) POB Temperature(°C) Weather (Wind 2,471.32 2,050.78 0.00 85.0 -25.0 Clear WC-23° NNE @ 4 MPH Daily summary operation 24h Summary Continue to BROOH to 13 3/8"shoe-Circulate hole clean-POOH on elevator 1/1341' Operation at 07.00 L/D BHA#5 24h Forecast Continue to POOH on elevator-Remove wear bushing-POOH and L/D BHA#5-CIO rams to 9 5/8"and pressure test-Csg hanger dummy run-R/U 9 5/8"Csg running tools-9 5/8"Csg Job Lithology !Shows MAASP(kgf/cm') I Mud Weight(g/L) 1174.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 13:00 13.00 13.00 DRILL E 6 P BROOH 1/7760'54110'(900 gpm @ 300072100 psi-100 rpm @ 15710k fflbs-20?10 min/St) 13:00 21:30 8.50 21.50 DRILL E 6 P Pump 40 bbl HiVis sweep-Circulate 01 BU-BROOH 1/4110'02276'(1100 gpm @ 3100?2750 psi-60 rpm @ 9.5?3.5k nibs-20 min/St) 21:30 22:30 1.00 22.50 DRILL E 7 P Circulate hole clean(x3 BU-1100 gpm @ 2750 psi-60 rpm @ 3.5k ft'lbs) 22:30 00:00 1.50 24.00 DRILL E 4 P Pump weighted pill-BD TDS-POOH on elevator t/2276'51341' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry 'Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Em representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 l Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 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') 1 Eni E&P Division I Well Name:0P21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq Date:4/4/2012 - Report#: 24 APIIl1Wl:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) IRKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 24.5E 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) 1DFS(days) W OP21- W01 DRILLING 3/16/2012 3,397.611 2,880.89 4,117.24 145.12 28.41 19.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) !Drilling Hours(hr) !Avg ROP(mlhr) POB Temperature(°C) Weather !Wind 2,471.32 2,050.78 0.00 85,0 -28.9 Clear W @C-35° ENE @ 6 MPH Daily summary operation 24h Summary Continue to POOH on elevator-Remove wear bushing-POOH and L/D BHA#5-Troubleshoot on pipe skate-C/O rams to 9 5/8"and pressure test-Csg hanger dummy run-R/U 9 5/8"Csg running tools-RIH 9 5/8"Cog 51162'-Troubleshoot on TDS Operation at 07.00 Running 9 5/8"Casing.Depth @ report time 1,420 24h Forecast Complete to C/O IBOP-9 5/8"Csg Job-R/D running equipment-Circulate to condition mud-R/U for cement job-9 5/8"dual stage cement job Lithology !Shows MAASP(kgflcm') Mud Weight(gIL) 1174.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P Pull wear bushing-POOH on elevator f/1341'5670'-B/O and L/D Ghost Reamer 03:00 04:00 1.00 4.00 DRILL E 5 P PJSM-POOH and UD BHA#5 in progress 04:00 '06:00 2.00 6.00 DRILL E 25 TR99 Troubleshoot on pipe skate:Fix kicker motor seals out 06:00 10:00 4.00 10.00 DRILL E 5 P Complete to POOH and L/D BHA#5(Bit Dull:1-4-BT-S-X-I-WT-TD)-Download MWD tools 10:00 14:00 4.00 14.00 DRILL C 5 P Install test plug-C/O top rams f/4%"x 7"variable 5 9 5/8"-Fill BOP stack-Test 9 5/8"top rams 250/3500 psi 10 min on chart-Pull test plug-UD testing tool 14:00 15:00 1.00 15.00 DRILL C 19 P 95/8"Csg hanger dummy run 15:00 '17:30 2.50 17.50 DRILL G '5 P R/U Tesco casing running tools-Function test equipment 17:30 18.30 1.00 18.50 DRILL G 5 P PJSM-P/U,M/U and RIH 9 5/8":Float Shoe+x2 Jt(47#/BTC/L-80/Av.MUT 16k fblbs)+Float Collar+x1 Jt(47#/ BTC/L-80/Av.MUT 8k R'Ibs)-Fill shoe track and check float equipment 18:30 '19:00 0.50 19.00 DRILL G 5 P P/U,M/U and RIH 9 5/8"csg x5 Jt(47#/13Cr/VAM TOP/Av.MUT 15k B lbs)5340' 19:00 .20.30 1.50 20.50 DRILL G 5 P P/U,M/U and RIH 9 5/8"csg(40#/L-80/Hydril 563/Special drift 8.75")51162'(1/1.5 min/Jt-Av.MUT 14k fobs)-Fill every jt while running and top-off every 10 jets. 20:30 00:00 3.50 24.00 DRILL G 25 TRO4 Troubleshoot on TDS:R/D Tesco tool and C/O broken IBOP-In progress Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) I TVD(mKB) Fluid Type 'Fluid Density(g/L) IP Surf Applied(kgf/cm') I Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:OP21-WW01 fill* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • APIIUWI:029-23438-00-00 Date:4/5/2012 - Repo #: 25 page 1 of 1 Wellbore name: OP21-WW01 Well Header Oliktok Point Permit/Concession N° 'Operator ENI PETROLEUM I ENI Share(°/.) 100.00'DIRECTIONAL lion type Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2.880.89 4.117.24 145.12 28.4 20.77 Daily Information End Depth(mKB) End Depth(TVD)(...'Depth Progress(m) 'Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) 'Weather Wind 2,471.32 2,050.78 0.00 85.0 -20.0 Overcast WC-28° E @ 21 MPH Daily summary operation 24h Summary Complete to C/O IBOP-9 5/8"Csg Job-R/D running equipment-Circulate to condition mud Operation at 07.00 Cementing 9 5/8"Casing 24h Forecast Circulate to condition mud-9 5/8'dual stage cement job-R/D cement equipment-Injectivity test-C/O top rams-BOP Test Lithology Shows MAASP(kgflcm') 'Mud Weight(gIL) 1174.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02.30 2.50 2.50 DRILL 'E 1 TR99 Troubleshoot on TDS:C/O broken IBOP and R/U Tesco tool 02:30 1930 17.00 19.50 DRILL G 1 P P/U,M/U and RIH 9 5/8"csg(400/L-80 I Hydril 563/Special drift 8.75")1/1162'118053'(1/1.5 min/Jt-Av.MUT 14k Ribs)- Fill every Jt while running and top-off each 10 Jt. Break circulation and circulate BU @ 2036'(4 bpm,100 psi)@ 4127'(5.5 bpm,160 psi)@ 6000'(4 bpm,190 psi) 19:30 20:00 0.50 20.00 DRILL G 1 P P/U,M/U and RIH Csg hanger w/Landing Joint-Land hanger on seat-Attempt to reciprocate up/dw failed(Hanger stuck on wellhead) 20:00 21:00 1.00 21.00 DRILL G 1 P Break circulation and circulate stage up to 8 bpm @ 370 psi with no losses 21:00 22:00 1.00 22.00 DRILL 'G 1 P R/D 9 5/8"csg running tools-R/U cement head and lines ✓ 22:00 00:00 2.00 24.00 DRILL 'G 8 P Circulate to condition mud(7 bpm @ 500 psi) Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) 'TVD(mKB) Fluid Type Fluid Density(gIL) 'P Surf Applied(kgflcm') Eq.Mud Weight(gIL) I P LeakOff(kgflcm') Eni E&P Division 'Well Name:OP21-WW01 ft* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • API/UW1:029-23438-00-00 2^n Date:4/6/2012 - Report#: 26 II 'I II page 1 of 1 Wellbore name OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34_ 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 24.5E I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(mKB)'Target Depth(TVD..1Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP21-WW01 DRILLING 3/16/2012 3,397.611 2,880.89 4,117.24 145.12 28.4 21.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) Avg ROP(mlhr) 'POB Temperature(°C) Weather rind 2,471.32 2,050,78 0.00 85.0 -19.4 Clear WC-20° WSW @ 10 MPH Daily summary operation 24h Summary Circulate to condition mud-9 5/8"dual stage cement job-R/D cement equipment-injectivity test-C/O top rams-Freeze Protect well-BOP Test Operation at 07.00 BOP test 24h Forecast BOP test-Pull test plug and install wear ring-P/U,M/U and RIH BHA#6-Record CBL(memory mode)f/2000'1/3800'-Drill out Stage tool and cement-RIH to baffle plate-Displace to FazePro-Drill out cement,plugs and float equipment Lithology 'Shows MAASP(kgflcm') Mud Weight(gIL) 1174.3 Time Log Start End Cum 4'i . Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. IC, 00:00 '01:30 1.50 1.50 DRILL H 7 "P Circulate to condition mud(7 bpm @ 500 psi-YP 18-no losses-9.8 ppg) 01:30 "06:00 4.50 6.00 DRILL H 9 "P Held PJSM for 1st stage Cement Job-SLB pump 5 bbl Mud Push @ 12 ppg and test lines to 500/3500 psi+75 bbl Mud ��- Push @ 12 ppg(5 bpm @ 550 psi)-Drop Bypass Plug-SLB mix and pump 65 bbl LiteCrete @ 12.5 ppg[LiteCrete 232 4,+µ sacks,1.58 Yield,mix fluid 5.426 gal/ski+50 bbl Tail Slurry @ 15.8 ppg[G cement 242 sacks,1.16 Yield,mix fluid 5.062 gal/sk]-Drop Shutoff Plug-SLB pump 10 bbl water-Switch to Rig Pump and Displace with 594 bbl mud @ 9.8 ppg(7?2.5 bpm @ 350?400 psi)[Bump plug @ 05:40]-No losses during job / [Shoe @ 8093'-Collar @ 8006'-Baffle Plate @ 7960'-Dual Stage Tool @ 3826'] V 06:00 09.00 ' 3.00 9.00 DRILL H 19 7P W.O.C.-Pressure up casing to 900 psi(500 psi over FCP)-Release pressure and check float equipment-Pressure up to 2000 psi to shear dual stage collar Failed-Cycled several times pressure up to 3800 psi Failed-Pressure up to 4100 psi with Slb cmt unit and sheared Dual Stage Tool 09:00 10'00 ' 1.00 10.00 DRILL H 7 "P Circulate to condition mud(2?5 bpm @ 110?280 psi-YP 18-no losses-9.8 ppg) 10:00 '12.30 2.50 12.50 DRILL H 9 "P Held PJSM for 2nd stage Cement Job-SLB pump 100 bbl Mud Push @ 12 ppg+240 bbl Tail Slurry @ 15.8 ppg[G cement 1159 sacks,1.16 Yield,mix fluid 5.066 gal/sk)-Drop Closing Plug-SLB pump 10 bbl water-Switch to Rig Pump and Displace with 280 bbl mud @ 9.8 ppg(7?3 bpm @ 250?500 psi)[Bump plug©12:20]-No losses during job .0a] 12:30 '15.30 ' 3.00 15.50 DRILL H 20 "P W.O.C.-Pressure up to 1700 psi to close Dual Stage Tool-Release pressure and check float equipment-R/D Cmt head- C/�,,,t R/U lines to 9 5/8"x 13 3/8"and attempt injectivity test-Failed,flow back up to 9 5/8"csg-R/U Cmt head-Pressure up 9 .S'-"7 5/8"csg up to 2300 psi(pressure drop to 1600 psi)-Release pressure and check flow back-Perform 15 bbl Injectivity test down to 9 5/8"x 13 3/8"(1/2/3 bpm @ 330/400/475 psi-9.8 ppg mud) 15:30 18.00 - 2.50 18.00 DRILL C 5 •P W.O.C.-R/D Cmt equipment-BIO Landing Joint Failed-Attempt several times-8/0 Landing Joint working back/forth with rig tongs-LJD landing joint-Set mouse hole 18:00 '20:00 2.00 20.00 DRILL C 5 P Install 9 5/8"pack off assembly and test 2500 psi 15 min 20:00 21:00 1.00 21.00 DRILL G 9 "P P/U,M/U and Set test plug w/safety vale-Freeze protect well 4150 bbls diesel(max pressure 1200 psi) 21:00 22:00 1.00 22.00 DRILL C 5 "P C/O Top rams from 9 5/8"fixed to 4'''A"x 7"variable-Fill Stack and manifold w/water 22:00 00:00 2.00 24.00 DRILL C 12 "P Test BOP as per AOGCC requirements-Rams,choke manifold,floor and top drive valves @ 250?5000 psi-Chart record- BOP test waived by AOGCC rep.Lou Grimaldi-Leak during 1st test(Valve#1)-Valve inspection in progress Daily Contacts %2t) Position Contact Name Company Title E-mail Office Mobile / Eni representative Ben Perry Eni Petroleum "Sr.Ddg.Spur. 907-685-1493 /' Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 -0.02 621.79 3/21/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') ' Eni E&P Division 'Well Name:OP21-WW01 0111* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq Date:417/2012 - Report#: 27 APIIUWI:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) IRKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 22.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg ROP(m/hr) POB Temperature(°C) Weather (Wind 2,471.32 2,050.78 0.00 83.0 -20.6 Clear WC-16' NE @ 10 MPH Daily summary operation 24h Summary BOP test-Pull test plug and install wear ring-P/U,M/U and RIH BHA#6-Record CBL(memory mode)f/2000'V3800'-Drill out Stage tool and cement-RIH to baffle plate Operation at 07.00 Reciprocating up/down and rotate to clean BHA hanging off 24h Forecast RIH to baffle plate-Drill out plugs and cement to float collar-Circulate BU-Casing pressure test 3000 psi-Drill out shoe track-Displace to FazePro-Drill shoe and 20'new hole-Circulate BU- Perform LOT-Drill 8%"section as per well plan Lithology 'Shows MAASP(kgflcm') 'Mud Weight(gIL) 1168.3 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 12 P Test BOP as per AOGCC requirements-Valve#1 leaking-Grease and tighten flange-Body test choke manifold 5000 psi 01 30 06:00 4.50 6.00 DRILL C 12 P Test BOP as per AOGCC requirements-Annular @ 250?2500 psi-Rams,floor and top drive valves @ 250?5000 psi- Chart record-BOP test waived by AOGCC rep.Lou Grimaldi 06:00 08:00 2.00 8.00 DRILL C 5 P Pull test plug-L/D testing equipment-Set wear ring-LID Wear ring running tool-Blow down choke manifold and kill lines 08:00 13:30 5.50 13.50 DRILL E 5 P P/U,M/U BHA#6(Bit 8%"Hycalog DTX619M TFA'0.778(s/n A146987)+PDM(1.15 bend)+NM stab+NM XO+ARC+ Telescope+ILS NM stab+Sonic+nm STAB+x3 NM Flex DC+Float Sub+6'/:"Jar WTF(s/n 1416-1573)+014 HWDP 5"]and RIH w/5"DPs 01897' 13:30 16:00 2.50 16.00 DRILL E 25 P Slip and cut drilling line-TDS service,change oil and fitters-Adjust brakes-Service Draw works and Crown Sheaves 16:00 20:30 4.50 20.50 DRILL J 11 P RIH BHA#6 1/1897'V3795'Recording CBL log in memory @ 850 fph-Ta•cement••3795' ' 20:30 22.30 2.00 22.50 DRILL E 19 P Drill out cement and Closing Plug on Dual Stage Tool 1/3795'113828'(450 gpm @ 1100 psi-60 rpm @ 6+7 flibs)-Ream up/dw x3 times-Dual Stage Collar integrity test Close rams and pressure up to 3000 psi 5 min monitoring OA pressure 22:30 00:00 1.50 24.00 DRILL E 4 P RIH BHA#6 1/3795'1/4100'Recording CBL log in memory @ 850 fph-Blow down TDS-Send downlink and continue TIH f/4100'5/4592' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2.466.75 4/7/2012 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:OP21-WW01 fff* EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/8/2012 - Report#: 28 APIIUWI:029-23438-00-00 2'r i page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%( 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E 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) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 23.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) I POB Temperature(°C) Weather Wind 2,471.32 2,050.78 0.00 83.0 -17.8 Overcast WC-30° ENE @ 16 MPH Daily summary operation 24h Summary Casing integnty test-Displace to FazePro OBM-Evaluation friction factor-Drill out shoe track-Drill shoe and 20'new hole-Circulate BU-Perform LOT-Drill 8%"section as per well plan Operation at 07.00 Displace to FazePro OBM 24h Forecast POOH BHA#6-Inspect BHA-Download MWD data-RIH BHA#6 to 7700'-Circulate to condition mud Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1156.3 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 4 P RIH BHA#61/4100'1/7950'Tag cement-Fill pipe every 200' 02.00 I 06:00 4.00 6.00 DRILL E 19 U Attempt to wash and ream(/7950'(High Torque 18k fobs-50k over pull-20k slack off)-Likely trash between drill string and casing-POOH f/7950'1/7700'(above Cr casing)and work pipe at different rotary speeds,pumps on,pumps off,fast, slow-Not solved 06:00 12:00 6.00 12.00 DRILL E 4 U POOH on elevators f/7700'to surface-No junks on BHA,no grooves or damaged areas 12:00 16:30 ' 4.50 16.50 DRILL E 5 U Attempt to download MWD data on rig floor failed-UD BHA-Download MWD data-Program tools for next run-P/U BHA 16:30 23:00 6.50 23.00 DRILL E 4 U M/U BHA#7[Bit 8 14"Hycalog DTX619M TFA:0.778(s/n A146987)+PDM(1.15 bend)+NM stab+NM XO+ARC+ Telescope+ILS NM stab+Sonic+nm STAB+x3 NM Flex DC+Float Sub+6'A"Jar WTF(s/n 1416-1573)+x14 HWDP 5")and RIH w/5"DPs 1/7700'(Check torque,weight up/down and pump pressure every 1000'until 6000'than every 500')- FF 0.5(0.2 expected)/Rotary torque 18k fl'lbs(limit set @ 18k)/Up wl 320k lbs/Dwwt 130k Ibs) 23:00 00:00 1.00 24.00 DRILL E 7 P Circulate to condition mud for casing integrity test-Preparation to displace to FazePro OBM Daily Contacts Position _ Contact Name Company _ Title E-mail ! Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dig Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Man Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date - CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 'Last Leakoff Test Depth(mKB) I TVD(mKB) I Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') I Eq.Mud Weight(gIL) P LeakOff(kgflcm') ffi#1 Eni E&P Division .. (Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/9/2012 - Report#: 29 APIIUWI:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(14) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E _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) 0P21-WW01 DRILLING 3/16/2012 3,397.61_ 2,880.89 4,117.24 145.12 28.4 24.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,471.32 2,050.78 0.00 85.0 -16.1 Mostly Cloudy WC- ENE @ 15 MPH 15" Daily summary operation 24h Summary !I Circulate to condition mud-Casing integrity test Failed-Displace to OBM-Safety stand down Operation at 07.00 Drill out baffle plate and cement to float collar 24h Forecast Casing pressure test with new mud Failed-Drill out baffle plate and cement to float collar-POOH BHA#7-P/U,M/U and RIH Test packer to find csg leak Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1258.2 • Time Log Start End Cum <_S.4-a—t Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. L 00.00 01:00 1.00 1.00 DRILL E 7 P Continue circulation to condition mud for casing integrity test and prepare to displace to FazePro OBM / ✓-L f r 01:00 04:30 3.50 4.50 DRILL E 19 U Attempt to obtain casing test on chart with 9.5 ppg WBM-Pressured up to 3000 psi and bled down to 2000 psi in 10 . minutes-Made several attempts-Working out possible air 0,430 08:00 3.50 8.00 DRILL E 7 P Displace well to new FazePro 10.5 ppg OBM reciprocating and rotating string up/dw f/7900'U7940'(280 gpm @ 900 psi,35 rpm @ 18k?ek fflbs)-Clean shakers and trough pits 08:00 09:00 1.00 9.00 DRILL E 5 P POOH f/7940'1/7690'-R/U casing test equipment 09:00 00:00 15.00 24.00 DRILL E 20 U Safety stand down-Operations suspended until further notice Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. -907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum i Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling •Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2.466.75 4/7/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') lifY*1 Eni E&P Division Well Name:0P21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:411012012 - Report#: 30 APIIUWI:029-23438-00-00 ( i rr o page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) W OP21- W01 DRILLING 3/16/2012 l 3,397.61 2,880.891 4,117.24 145.12 28.4 25.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) I Weather (Wind 2,471.32 2.050.78 0.00 84.0 -16.1 OverCast WC-12° ENE @ 10 MPH Daily summary operation 24h Summary Casing pressure test with new mud-Drill out baffle plate and cement 1/7975'-POOH BHA#7-P/U,M/U and RIH Test packer to found csg leak-Selective pressure test 5 5/8"csg with test packer- POOH Test packer Operation at 07.00 P/U and RIH BHA#7 24h Forecast POOH and L/D Test packer-RIH BHA#7-Drill out cement and float equipment-Drill out 20'new formation-Perform LOT-Drill 8 W section as per wellplan Lithology Shows MAASP(kgflcm') I Mud Weight(gIL) 1222.2 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 19 P Attempt to test 9 5/8"casing to 3000 psi-No success.pressure bleeding down-Check surface equipment-Re-test with no success 01 30 05:00 3.50 5.00 DRILL E 6 P Drill out cement 1/7955'to baffle plate at 7958'-Continue drilling cement to 7975'(450 gpm @ 2500 psi.50 rpm @ 9-13k ft'lbs) 05.00 06:00 1.00 6.00 DRILL E 7 P Circulate hole clean(450 gpm @ 2100 psi,60 rpm @ 10k ft'lbs)-Got back aluminum,steel cuttings,rubber and cement 06:00 13:00 7.00 13.00 DRILL E 4 P POOH on elevators t/7975'7/451'and L/D BHA#6(Bit Dull:0-2-CT-G-X-I-NO-BHA) 13:00 15:00 2.00 15.00'DRILL E 25 P Test stand pipe manifold and surface equipment 3000 psi-Blow down TD-Service rig 15:00 15:30 0.50 15.50 DRILL E 19 P Pressure test 9 5/8"csg against blind rams-Failed 15:30 17:30 2.00 17.50 DRILL E 5 U M/U and RIH Test Paker+x5 Std HWDP 1/460'-Pressure test 9 5/8"csg 3000 psi on chart(3055?980 psi/30 min) 7C401./fJ 17:30 21:00 3.50 21.00 DRILL E 4 U RIH Test Paker w/5"DP5 1/460'1/3726' 21:00 23:00 2.00 23.00 DRILL E 11 U Test packer set @ 3726'(center pkr)-Pressure test above Pkr:3020?2970 psi/5 minutes-Pressure test below Pkr: 3050?2010 p s i!2 minutes-Release tool-RIH and set Test packer @ 4020'(center pkr)-Pressure test above Pkr:3087? 1660 psi/5 minutes-Pressure test below Pkr:3180?3130 psi/5 minutes-Release tool 23:00 00:00 1.00 24.00 DRILL E 4 U POOH Test Packer BHA 1/4020'1/3450'-In progress + Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum -Sr.Drtg.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Ng Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Man Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2.466.75 4/7/2012 Last Leakoff Test Depth(mKB) I TVD(mKB) Fluid Type Fluid Density(gIL) IP Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') ft* Eni E&P Division (wen Name:oP21-wwo, ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • APIIIJWI:029-23438-00-00 2�, Date:4/11/2012 - Report#: 31 If II page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share)%) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA _ NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date (Target Depth(mKB) Target Depth(TVD..JDepth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) ' OP21-WW01 DRILLING 3/16/2012 1 3,397.61 2.880.89 4,117.24 145.12 28.4 26.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) !Drilling Hours(hr) 'Avg ROP(m/hr) IPOB Temperature(°C) Weather Wind 2,599.33 2,149.96 128.02 4.12 31.1 85.0 -15.0 Overcast WC-7' NE @ 7 MPH Daily summary operation 24h Summary POOH and L/D Test packer-RIH BHA#8-Drill out cement and float equipment-Drill out 20'new formation-Perform LOT-Drill 8'A section to 8545' Operation at 07.00 Drill 8'''/"section as per well plan.Report time @ 8,816' 24h Forecast Drilling 8'A"section as per well plan to 11148' Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1258.2 Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P POOH Test Packer BHA 53450'to surface-B/O and UD Test packer 02:30 03:00 - 0.50 3.00 DRILL E 25 P C/O Iron roughneck dies 03:00 10:00 ' 7.00 10.00 DRILL E 5 P iP/U,M/U BHA#8[Bit 8''A"Hycalog DTX619M TFA:0.778(s/n 125286)+PDM(1.15 bend)+NM stab+NM XO+ARC+ ' Telescope+ILS NM stab+Sonic+NM stab+x3 NM Flex DC+Float Sub+6'''A"Jar WTF(s/n 1416-1573)+x14 HWDP 5")-Shallow test-RIH w/5"DPs 1/7975'filling pipe every 2500' 10:00 13:30 3.50 13.50 DRILL E 19 P _Drill out plug,float equipment,shoe and cement t/7975'5/8107'(440 gpm @ 2050 psi,60 rpm @ 10+11k ft'lbs.WOB= 2+10k Ibs,MW=10.2 ppg)-Drill rotary 0 8''A"new hole 1/8107'1/8127'(450 gpm @ 2200 psi,40 rpm©9+10k fibs, WOB=2+5k Ibs,MW=10.2 ppg) 13:30 14:30 1.00 14.50'DRILL E 7 P POOH into shoe-Circulate BU MW 10.2 ppg in/out(450 gpm @ 2100 psi,50 rpm @ 9+10k fibs) 14:30 16:30 2.00 16.50 DRILL E 11 P B/D TD-1'• .• ',e and•erform FIT with 10 ••• ••;,,- ..)ce pressure,of 1043 psi-BMW=13.2 ppg-R/D to.. Z I test equipment 16:30 00:00 ' 7.50 24.00 DRILL E 3 P 'Drilling Rotary/Sliding 0 8'A"section f/8127'1/8545'\550 gpm @ 3200?3300 psi 160780 rpm @ 12+15k fibs\WOE= ,r^ 7+10k lb\Up wt=240k lb-Dn w1=165k lb-Rot wt=185k lb\Mud wt=10.5 ppg\ECD 11.48711.84 ppg [ [ADT=4.12 Hrs I Daily Contacts Position _ Contact Name Company Title - E-mail _ Office Mobile _ j Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push _Matti Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat - Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Report L Well Code:26259 Field Name: Nikaitchuq • Date:4/12/2012 - Report#: 32 APIIUWI:029-23438-00-00 2" "ii page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliklok Point _ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) 'Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.341 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 1LAND 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) W OP21- W01 DRILLING 3/16/2012 3,397.611 2,880.89 4,117.24 145.12 28.4 27.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,006.55 2,511.41 407.21 15.96 25.5 85.0 -20.6 Partky Cloudy WC- NE @ 10MPH 22` Daily summary operation 24h Summary Drill 8 W section to 9833' Operation at 07.00 Drill 81/."section as per well plan.Report time @ 10,006' 24h Forecast Drilling 8 1/2"Section as per well plan to 11,148' Lithology I Shows MAASP(kgflcm°) Mud Weight(gIL) 1258.2 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 Drilling Rotary/Sliding 0 8 W section 1/8545'1/8940'1575 gpm @ 3250?3350 psi\80 rpm @ 13+17k ft/lbs\WOB=4+10k lb\Up wl=280k lb-Dn wt=150k lb-Rot wt=187k lb\Mud wt=10.5 ppg-Ream 30'each Std 06.00 12:00 6.00 12.00*DRILL E 3 P Drilling Rotary/Sliding 0 8/1'section 1/8940'1/9294'\575 gpm @ 3350?3450 psi\80 rpm @ 16+19k ftlbs\WOB=4+10k lb\Up wt=310k lb-Dn wl=148k lb-Rot wt=195k lb\Mud wt=10.5 ppg-Ream 30'+90'each Std 12.00 18:00 6.00 18.00 DRILL E 3 P Dolling Rotary/Sliding 0 8''/1'section 1/9294'1/9680'\575?570 gpm @ 3450?3400 psi\80 rpm @ 16+22k fhlbs\WOB= 8+12k lb\Up wt=330k lb-Dn wt=155k lb-Rot wt=205k lb\Mud wt=10.5 ppg-Ream 30'+90'each Std 18.00 00:00 6.00 24.00*DRILL E 3 P Drilling Rotary/Sliding 0 8'/1'section 1/9680'1/9833'\570?565 gpm @ 3400?3350 psi\80 rpm @ 14*21k ft.lbs\WOB= 8+12k lb\Up wt=345k lb-Dn wt=160k lb-Rot wt=210k lb\Mud w1=10.5 ppg-Ream 30'+90'each Std [ART=11.52-AST=3.08-ADT=14.6 Hrs] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dog.Spur. 907-685-1493 Eni representative Metro Musumeci Eni Petroleum Ddg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 Last Leakoff Test Depth(mKB) 'TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) 'P LeakOff(kgflcm') • lf 51* Eni E&P Division �weu Name:0P21-wwol EN/Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • API/UWI:029-23438-00-00 2^„ Date:4/13/2012 - Report#: 33 1 111 page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share)%) [Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) 0P21-WW01 DRILLING 3/16/2012 3,397.611 2,880.891 4,117.24 145.12 28.4 28.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) !Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,241.85 2,734.37 254.20 17.221 14.8 94.0 -21.7 Clear WC-7' Winds Calm Daily summary operation 24h Summary Drill 8'/::"section to 10635' Operation at 07.00 Drill 8 W section as per well plan.Report time @ 10,758' 24h Forecast Drilling 8''A"section as per well plan to 11148'-Circulate hole clean-POOH on elevator-Rabbit DPs-L/D BHA#8 Lithology Shows I MAASP(kgflcm') Mud Weight(gIL) 1258.2 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 Drilling Rotary/Sliding 0 8'''A"section(/9833'5110150'\5657550 gpm @ 3350?3450 psi\80 rpm @ 18.23k Ribs\WOB= 4.10k lb\Up wt=350k lb-Dn wt=160k lb-Rot wt=210k lb\Mud wt=10.7 ppg-Back ream stand every connection 06:00 13:00 7.00 13.00'DRILL E 3 P Drilling Rotary/Sliding 0 8''A"section(/10150'010346'\550?600 gpm @ 3450?3650 psi 180 rpm @ 16.24k 0-lbs\WOB= 4.15k lb\Up wt=350k lb-Dn wt=165k lb-Rot wt=220k lb\Mud wt=10.6 ppg-Back ream stand every connection 13.00 14:00 1.00 14.00'DRILL E 7 P Pump 35 bbl HiVis sweep(550 gpm @ 3170 psi,100 rpm @ 14.17k ft-Ibs) 14.00 18:00 4.00 18.00 DRILL E 3 P Drilling Rotary/Sliding 0 8'G"section 1/10346't/10450'\600?590 gpm @ 365073600 psi\80?100 rpm @ 14v23k ft lbs\ WOB=8.12k lb\Up wt=360k lb-Dn wt=170k lb-Rot wt=240k lb\Mud wt=10.6 ppg-Back ream stand every connection 18.00 00:00 6.00 24.00'DRILL E 3 P Drilling Rotary/Sliding 0 8'''A"section(/10405'V10635'\570?565 gpm @ 3400?3350 psi\80 rpm @ 18.28k ft'lbs\WOO= 10.15k lb\Up wt=375k lb-Dn wt=170k lb-Rot wt=260k lb\Mud wt=10.6 ppg-Back ream stand every connection [ART=13.93-AST=2.39-ADT=16.32 Hrs] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Jim Thompson ENI Petroleum Sr.DrIg.Spvr. 907-685-1493 Em representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Em representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Em representative Steve Abbott Eni Petroleum Material Coordinator Em representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mam Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 Last Leakoff Test Depth(mKB) !TVD(mKB) Fluid Type 'Fluid Density(gIL) IP Surf Applied(kgflcm') I Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division Well Name:0P21-WW01 iff* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq ii• Date:411412012 - Report#: 34 APIIWJI:029-23438-00-00• 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.001 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 1 Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name IRig Type NABORS ALASKA NABORS 245E I 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) W OP21- W01 DRILLING 3/16/2012 I 3,397.61 2,880.89 4,117.24 145.12 28.4 29.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,341.22 71.93 8.91 8.1 94.0 -20.0 Scattered Clouds WC SE @ 4 MPH -12' Daily summary operation 24h Summary Doll 8 W section to 10959'-POOH BHA#8 due to low ROP Operation at 07.00 L/D BHA#8 24h Forecast Complete to POOH BHA#8 due to low ROP-P/U,M/U and RIH BHA#9-Drill 8'A"section as per well plan to 11148' Lithology !Shows MAASP(kgflcm') 'Mud Weight(gIL) 1258.2 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 Drilling Rotary/Sliding 0 8'W section f/10635'1/10828'\565?600 gpm @ 3350?3750 psi\80=100 rpm @ 17*24k ft-lbs\ WOB=10+156 lb\Up wt=375k lb-Dn wt=165k lb-Rot wt=230k lb\Mud wt=10.6 ppg-Back ream stand every connection 06:30 09:30 3.00 9.50 DRILL E 6 P BROOH 1/10828'1/10348'(600 gpm @ 2300 psi,110 rpm @ 17.20k fobs)-Ream back to bottom(600 gpm @ 3550 psi, 110 rpm @ 14.18k ftlbs)-No tight spot 09:30 17:30 8.00 17.50 DRILL E 3 P Drilling Rotary/Sliding 0 8%"section(/10828'1/10959'1 590 gpm @ 3500 psi\80 rpm @ 17.28k ft'lbs\WOB=10.20k lb\ Up wt=375k lb-Dn wt=165k lb-Rot wt=230k lb\Mud wt=10.7 ppg-Back ream stand every connection NOTES: Decision to POOH due to low ROP,High torque and possible PDM faillure 17:30 00:00 6.50 24.00 DRILL E 4 U POOH on elevator(/10959't/4985' (P/U F.F.0.3)-Proper displacement Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum -Sr.Dig.Spvr. -907-685-1493 Eni representative Jim Thompson ENI Petroleum Sr.Dig.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dig Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 Last Leakoff Test Depth(mKB) 1TVD(mKB) 'Fluid Type Fluid Density(gIL) 1P Surf Applied(kgticm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division VWeh1 Name:0P21-WW01 1 r* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/15/2012 - Report#: 35 APIIUWI:029-23438-00-00 zi "i page 1 of 1 Wellbore name: OP21-WW01 Well Header PermiVConcession N° Operator ENI Share(14) !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.721 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB)'Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP)Mhr) DFS(days) W OP21- W01 DRILLING 3/16/2012 3,397.611 2,880.89 4,117.24 145.12 28.4 30.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg ROP(mlhr) I POB Temperature(°C) Weather Wind 3,341.22 0.00 94.0 -11.1 Mist WC 4° NNW @ 5 MPH Daily summary operation 24h Summary Complete to POOH BHA#8 due to low ROP-P/U,M/U and RIH BHA#9-Drill 8%"section to 10985' Operation at 07.00 Drill 8''/:"section as per well plan.Report time @ 11,004' 24h Forecast Drill 8'A"section as per well plan to 11148'-Clean up cycle-POOH on elevator Lithology 'Shows MAASP(kgflcm°) I Mud Weight(gIL) 1258.2 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 DRILL E 4 U POOH on elevator 1/4985 t/679' (P/U F.F.0.3)and L/D BHA#8(Bit Dull:3-4-BT-A-NO-2-CT-PR) 04:30 07.30 3.00 7.50 DRILL E 25 TRO4 Troubleshoot Diamatic brake on draw works and encoder on TDS 0730 15.30 8.00 15.50 DRILL E 5 P P/U,M/U BHA#9)Bit 8%"Baker RC216 TFA:0.92(s/n 5202998)+Bit Sub+NM stab+ARC+Telescope+NM XO+NM stab+x3 NM Flex DC+Float Sub+6''A"Jar WTF(s/n 1416-1549)+014 HWDP 5")-Shallow test-RIH w/5"DPs 1/10920'filling pipe every 2500'-NO tight spot 15:30 17:30 2.00 17.50 DRILL E 6 P Ream down 1/10920'910959'(580 gpm @ 2750 psi,100 rpm @ 14+18k Ribs) 17:30 00:00 6.50 24.00 DRILL E 3 P Drilling Rotary 0 8'A"section 1/10959'910985'\580 gpm @ 2750 psi\110 rpm @ 12+18k Ribs\WOB=10+20k lb\Up wt=320k lb-Dn wt=165k lb-Rot wt=240k lb\Mud wt=10.6 ppg- NOTES: Vaned all possible parameters,reamed last 120'.no success in speeding up drilling-Non to slightly calcareous silty sandy layers(Hard shale spot) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry 'Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Jim Thompson ENI Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spur. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator Z Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mast Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 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:0P21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq •"ii Date:4/16/2012 - Report#: 36 API/t1Wl:029-23438-00-00 2" page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° 'Operator ENI Share(%) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) 'RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name IRig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 DRILLING 3/16/2012 3,397.61 2,880.89 4,117.24 145.12 28.4 31.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) I POB •Temperature(°C) Weather 'Wind 3,346.40 22.86 13.97 1.6 94.0 -11.7 Overcast WC-4° Eat 13 MPH Daily summary operation 24h Summary Drill 8 1/2"section as per well plan to TD(11037')-Clean up cycle POOH on elevator-LID HWDP and BHA#9 Operation at 07.00 R/U to Run 7"Liner. 24h Forecast Pull wear ring-Test upper variable rams wl 7"test Jt-Set wear ring-R/U GBR-7"Liner Job Lithology -I Shows I MAASP(kgf/cm') Mud Weight(gIL) 1258.2 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 11:30 ' 11.50 11.50 DRILL E 3 P Drilling Rotary 0 8 04"section 1/10985'to TD 11037'1550+580 gpm @ 2500+2700 psi\60+110 rpm @ 12+18k ft'lbs\ WOB=4+25k lb\Up wt=350k lb-Dn wt=165k lb-Rot wt=230k lb 1 Mud wt=10.6 ppg-Attempt to increase ROP changing parameters failled [ADT=10.23 Hrs] 11:30 13:00 1.50 13.00 DRILL E 7 P Circulate hole clean(570 gpm©2600 psi,100 rpm @ 14*20k fibs) 13:00 23:30 10.50 23.50 DRILL E 4 P POOH on elevator f/11037 V623'-B/O and L/D HWDP-L/D BHA#9(Bit Dull:5-4-WT-A-E-I-ER-TD/Upper and lower Stab 1/16"Under gauge) 23:30 00:00 0.50 24.00 DRILL C 5 P Pull wear ring-In progress Daily Contacts Position Contact Name Company Title • E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drig.Spvr. 907-685-1493 Eni representative Jim Thompson ENI Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 Last Leakoff Test Depth(mKB) 'TVD(mKB) Fluid Type Fluid Density(gIL) I P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgf/cm') ri* Eni E&P Division (Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/17/2012 - Report#: 37 APIIUWI:029-23438-00-00 2"no page 1 of 1 Wellbore name: OP21-WW01 Well Header Oliktok Point PermitIConcession N° 1 EENI PETROLEUM !ENI Share CV.) 100.001 DIRECT OINAL tion type Rotary Table Elevation(m) Ground Level(m) 'Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date l Target Depth(mKB) Target Depth(TVD..J Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) WW OP21- 01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 32.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) !Drilling Hours(hr) lAvg ROP(m/hr) l POB Temperature(°C) Weather Wind 3,364.08 0.001 93.0 -11.7 Overcast WC 11° Winds Calm Daily summary operation 24h Summary 7"Liner Job Operation at 07.00 7"Liner cement job 24h Forecast R/U cement head-Circulate to condition mud-R/U cement equipment-7"Liner cement job-Set liner hanger-Circulate to clean hole-Pressure test liner and hanger-POOH and L/D running tool Lithology Shows MAASP(kgflc m') Mud Weight(gIL) 1258.2 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL C 5 P Pull wear ring-P/U,M/U and set test plug w/7"test Jt-Fluid pack-Pressure test upper variable rams 250/5000 psi 5 min -Pull test plug-R/D testing equipment-Install wear ring 02.30 05:30 3.00 5.50 DRILL G 2 P R/U Cr 7"Liner running equipment 05:30 14.00 8.50 14.00 DRILL G 5 P PJSM-P/U.M/U and RIH Liner T 26/299 13Cr-L80 Vam Top(M/U torque 8.3k ttdbs)V3160'-Top fill every 10 Jt 14:00 15.30 1.50 15.50 DRILL G 5 P C/O Elevator-P/U&M/U ZXP liner hanger-Fill Tieback sleeve with"pal mix°(wait 30'to set up)-R/D GBR equipment- M/U 5"DPs Std and circulate string volume 15:30 16:30 1.00 16.50 DRILL G 4 P RIH T Liner w/5"DPs 114155'on elevator-Fill up every 10 Std 16:30 17:30 1.00 17.50 DRILL G 25 P TDS services:C/O gripper dies and one head i r''. 17:30 20:00 2.50 20.00 DRILL G 4 P RIH 7"Liner w/5"DPs f/4155'98080'on elevator-Fill up every 10 Std 20:00 21:00 1.00 21.00 DRILL G 7 P Circulate string volume @ 8080'(9 5/8"Shoe)(250 gpm @ 400 psi) 21:00 00:00 3.00 24.00 DRILL G 4 P RIH 7"Liner wl 5"DPs f/8080'911036'on elevator[Shoe @ 11036'-TOL @ 7843']-Fill up every 10 Std-R/U cement head and hose in progress Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 L80 -0.19 2,466.75 4/7/2012 Last Leakoff Test Depth(mKB) ITVD(mKB) Fluid Type Fluid Density(g/L) !P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 11Y* Eni E&P Division Well Name:0P21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq 11• Date:4/18/2012 - Report#: 38 APIIl1Wl:029-23436-00-00 2rr rr page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 10000 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name •Rig Type NABORS ALASKA NABORS 245 E 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) I DFS(days) 0P21-WW01 DRILLING 3/16/2012 3,397.61 2,880.891 4,117.24 145.12 28.4 33.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg'Avg ROP(mlhr) POE Temperature(°C) Weather l Wind 3,364.08 0.00 91.0 -10.0 Overcast WC 5° N @ 6MPH Daily summary operation 24h Summary R/U cement head-Circulate to condition mud-R/U cement equipment-7"Liner cement job-Set liner hanger-Circulate to clean hole-Pressure test liner and hanger-POOH and UD running tool-UD 110 Jt 5"DPs-BOP test Operation at 07.00 BOP test.FINAL DRILLING REPORT. 24h Forecast BOP test-P/U 4"DPs-RIH test paker @ 3900'-Pressure test liner and hanger-POOH test paker.7-TIH to btm and displace to NaCI brine-POOH Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1258.2 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL H 5 'P R/U cement head and lines-Space out as per tally 01 00 05:00 4.00 5.00 DRILL H 8 P Circulate(7 bpm @ 1200 psi,Up wt 290k Ibs)-Spot cement units and R/U cement equipment NOTES: CH2 Truck broke(gauge don't work)transfer fluid to another truck and swap same Water line to cement mixing unit frozen,swap to backup line / 05:00 06:30 1.50 6.50 DRILL H 9 'P PJSM-SLB pump:5 bbl Water and test lines to 500/5500 psi+30 bbl Citric Pill @ 11.1 ppg(5 bpm @ 580 psi)+30 bbl Mud Push @ 13 ppg-SLB mix and pump 95 bbl Tail Slurry @ 15.8 ppg[Class G cement 510 sacks/1.17 Yield/mix fluid 5.217 gal/sk](5 bpm @ 5007410/Start mixing©05:40)-Drop Dart-SLB pump:5 bbl Water-Switch to Rig Pump and Displace with 240 bbl mud @ 10.5 ppg(7.5?3 bpm @ 400?1600 psi)[Bump plug @ 07:00]-No losses during job 06:30 07:30 1.00 7.50 DRILL G 19 P W.O.C.-Pressure up to 3000 psi to set liner hanger-Slack off 120k lbs-Pressure up to 4000 psi to release running tool- Bleed off pressure and check flow back-Up wt 190k lbs-Slak off 50k lbs to top of liner rotating 10 rpm 07:30 08:30 1.00 8.50 DRILL H 7 P W.O.C.-Sting out and circulate down DPs to wash he back sleeve-Circulate out citric pill,mud push and 24 bbl cement to surface(15 bpm @ 1600 psi) 08:30 09:00 0.50 9.00 DRILL G 11 P W.O.C.-Attempt to test liner FAILLED(1200?850 psi/15 min) 09:00 10:00 1.00 10.00 DRILL H 2 P W.O.C.-B/D cement head and R/D cement equipment 10:00 12:30 2.50 12.50 DRILL G 25 P W.O.C.-Slip and cut 120'DL 12.30 17:00 4.50 17.00 DRILL G 4 P W.O.C.-POOH t/7947'1/4499'and UD 110 Jt 5"DPs 17:00 19:00 2.00 19.00 DRILL G 4 P POOH 1/4499'to surface-Inspect and L/D Liner Hanger Running Tool 19:00 22:00 3.00 22.00 DRILL C 5 P Pull wear ring-Set test plug-Swap lower rams(4%"-7")with upper rams(3'A"-6")-C/O door seals 22.00 00:00 2.00 24.00 DRILL C 12 P P/U 5"test Jt and fill BOP stack and lines with water-Test BOP as per AOGCC requirements wl 5",4''A"and 4"test Jt- Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 250?5000 psi-Chart record-BOP test witnessed by AOGCC rep.Matt Herrera-In progress Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Drig.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3.363.16 4/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(giL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division (Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/19/2012 - Report#: 1 APIIUWI:029-23438-00-00 e r'ii page 1 of 1 Wellbore name: OP21-WW01 Well Header PermitlConcession N° Operator ENI Share(%) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) !Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...I Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP21-WW01 COMPLETION I 34.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) 'Avg ROP(m/hr) I POB Temperature(°C) 'Weather Wind 0.00 91.0 -12.2 Overcast WC 10 Winds Calm Daily summary operation 24h Summary BOP test-P/U 4"DPs-RIH test packer @ 3900'-Pressure test liner and hanger-POOH test packer-P/U and RIH 4"DPs 1/2300' Operation at 07.00 TIH w/%"DPs-Prepare to displace 9.5 ppg Brine 3%KCI 24h Forecast P/U 4"Jt and RIH 113440'-Continue TIH U bottom w/5"DPs-Displace 9.5 ppg Brine 3%KCI-Spot Pert pill-POOH-R/U guns equipment-RIH guns 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 07:00 7.00 7.00 COMP -C 12 P Test BOP as per AOGCC requirements wl 5",4%"and 4"test Jt-Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 250?5000 psi-Chart record-BOP test witnessed by AOGCC rep.Matt Herrera-Test lower rams w/4 14"Test Jt FAILLED 07:00 10:00 3.00 10.00 COMP •C 5 P C/O variable lower rams(4 1/2"-7")-Fill BOP Stack-Test lower rams w/4%"Test Jt 250?5000 psi on chart-L/D test tools-Pull test plug-R/D testing equipment-Blow down choke manifold and lines 10:00 11:00 1.00 11.00 COMP K 25 P Rig maintenance:Inspecting 5"handling equipment(Slip,dog collar,elevators)-C/O iron roughneck dies 11:00 14:30 3.50 14.50 COMP G 4 P P/U Test Packer and RIH vd 5"DPs 1/3937' 14:30 15:30 1.00 15.50 COMP -G 11 P Pressure test Liner and Hanger 1500 psi 15 min on chart 15:30 18:00 2.50 18.00 COMP G 4 P POOH 1/3937'to surface-L/D Test Paker 18:00 00:00 6.00 24.00 COMP 'K 5 P P/U XO.Elevators and slip(4")-Calibrate blocks-RIH picking up 4"DP Jt 1/2300' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Jim Thompson Eni Petroleum Sr.Ddg.Spur. Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3.363.16 4/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) VY#41 Eni E&P Division I Well Name:OP21-WW01 EN/Petroleum Co.Inc. Daily Report L Well Code:26259 Field Name: Nikaitchuq � Date:4/20/2012 - Report#: 2 APIIUWI:029-23438-00-00 211 11 Wellbore name: OP21-WW01 page 1 of 1 Well Header Permit/Concession N° 'Operator ENI Share(%) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) 'RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 COMPLETION 35.77 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 94.0 -19.0 Partly Cloudy WC- NE@ 10 MPH 19" Daily summary operation 24h Summary P/U 4"Jt and RIH 1/3440'-Continue TIH U bottom w/5"DPs-Displace 9.5 ppg Brine 3%KCI-Spot Perf pill-POOH-R/U guns equipment Operation at 07.00 P/U,M/U and RIH 4 1/2"Guns 5 spf 24h Forecast R/U guns equipment-RIH guns-MWD Correlation-Displace 100 bbl Pert Pill-Fire guns-POOH guns-UD DP's Lithology 'Shows MAASP(kgflcm') 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 05:30 5.50 5.50 COMP K 4 P RIH picking up 4"DP Jt(/2300'1/3475'-M/U XO-Flush string-Blow down TDS-RIH w/5"DPs 1/3475'1110862'(tag bottom) 05:30 07:30 2.00 7.50 COMP K 8 P TDS-Off load mud-Build spacer/Pills-Prepare to displace FazePro to Brine 07:30 10:30 3.00 10.50 COMP K 9 P PJSM-Displace FazePro 10.5 ppg to 9.5 ppg KCI(3%)Brine,pumping.30 bbl LVT+80 bbl HiVis surfactant&sotvente-I- 730 bbl 9.5 ppg Brine 3%KCI(12?8 bpm @ 12007800 psi/40 rpm @ 9,15k ft'lbs) 10:30 16:30 6.00 16.50 COMP K 20 P Clear under shakers,ditch,mud pits,possum belly,pill pit-Mix Dry Job(Brine 10.5 ppg)-Spot 20 bbl Perf Pill(9.5 ppg)at bottom hole 16:30 22.30 6.00 22.50 COMP K 4 P POOH f/10862'to surface(SLM) 22.30 00:00 1.50 24.00 COMP K 5 P R/U Slb guns running equipment-In progress Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Jim Thompson Eni Petroleum Sr.Ddg.Spvr. Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) 'P LeakOff(kgf/cm') Eni E&P Division ,} Well Name:0P21-WW01 ENI Petroleum Co.Inc. Daily Repot L Well Code:26259 Field Name: Nikaitchuq • Date:4/21/2012 - Report#: 3 APIIUWI:029-23438-00-00 II 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E ILAND 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) OP21-WW01 COMPLETION _ 36.77 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 -13.9 Mostly Cloudy WC- NNE @ 9.2 MPH 7° Daily summary operation 24h Summary R/U guns equipment-RIH guns-MWD Correlation-Displace 100 bbl Perf Pill-Fire guns-POOH guns-L/D DP's Operation at 07.00 POOH,L/D 4"DP. 24h Forecast Fix pipe skate-POOH and LID DPs-Inspect guns and check for shot fired-R/U running completion equipment-Completion job Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Our(hr), Phase Opr. Act. Plan Oper.Descr. e 00:00 04:00 4.00' 4.00 COMP M 5 P R/U Slb guns running equipment-PJSM-P/U.M/U and RIH 4.75"Tbg conveyed perforating guns 5 spf ,e---e. 04:00 12:00 8.00 12.00'COMP M 4 P RIH w/tapered string 4"+5"810854'(Up ml 270k lbs/Dw wt 175k Ibs) 12:00 15:30 3.50 15.50 COMP M 11 P Record log(/10854'810794'for correlation 15:30 16:00 0.50 16.00 COMP M '9 P Displace 100 bbl Perf Pill(3%KCI 9.5 ppg) 16:00 17:00 1.00' 17.00 COMP M 16 P Cycled firing sequence(Guns fired at 17:00)-Perforated follow intervals:10742'*10854'/10681'.10702'/10604'.10666'/ 10545'"10562'/10504'110521'/10456'+10468'-Total 1164 shots 17:00 18:30 1.50' 18.50 COMP M 11 P Rack back x5 Std-Flow check well static-C/O spin on iron roughneck 18:30 19:30 1.00 19.50 COMP M 25 P Complete to C/O spin on iron roughneck 19.30 23:00 3.50' 23.00 COMP M 4 P POOH 1/10472'88771'•B/O and L/D DPs 23.00 00.00 1.00' 24.00 COMP M 25 TR99 Troubleshot Pipe skate do not work-Fixing in progress Daily Contacts Position Contact Name , Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. - 907-685-1493 Eni representative Jim Thompson Eni Petroleum Sr.Ddg.Spvr. Eni representative Mirka Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative •Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2.390.77 3.363.16 4/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') f , Eni E&P Division Well Name:Or-21-WW01 EN/Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • Date:4/22/2012 - Report#: 4 APIIUWI:029-23438-00-00 2r' r'0 page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I EM Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) IRKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) IDFS(days) OP21-WW01 COMPLETION I 37.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather r- 0.00 96.0 -15.6 Cloudy WC 4` nds Calm Daily summary operation 24h Summary Fix pipe skate-POOH and LID DP's-Inspect guns and check for shot fired-Pull wear ring-Center rig over the well-R/U running completion equipment Operation at 07.00 Fixing GBR tong-Screw test with pups Jt-CIO pup joint on Injection nipple assembly(sent to Prudhoe,only injection nipple available on the North Slope) GBR computer not operational.Waiting for replacment.from Prudhoe Bay. 24h Forecast Complete to R/U running completion equipment-Completion job(4.5"/12.68/13Cr-L80/Vam Top) Lithology Shows MAASP(kgflcm2) Mud Weight(gIL) 1138.4 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 M 25 TR99 Troubleshot:Pipe skate do not work-Fixed proximity sensor broken 01 30 14.00 12.50 14.00 COMP M 4 P POOH(/8771'11679'-BID and L/D DPs 14.00 16.30 2.50 16.50 COMP M 5 P POOH and L/D perforating guns 1157/1157 shots fired 16.30 19'.00 2.50 19.00 COMP M .5 P TIH 14 DPs Std-POOH and L/D same 19.00 21.00 2.00 21.00 COMP C 5 P Pull wear nng-Jack ng up(centered rig over the well) 21:00 00.00 3.00 24.00 COMP K '2 P R/U running completion equipment-P/U and set on rig floor CL and injection line spools Daily Contacts -Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry 'Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Jim Thompson Eni Petroleum Sr.Dig.Spvr. Eni representative Mirk°Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Steve Millea ENI Petroleum HSE 907-685-1496 Eni representative Greg Parker Em Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) I TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2)-Eq.Mud Weight(g/L) P LeakOH(kgflcm2) 1 Eni E&P Division I Well Name:0P21-WW01 EN!Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:4/23/2012 - Report#: 5 API/l1Wl:029-23438-00-00 z i "II page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° I Operator EM Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) IRKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 COMPLETION 38.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(mlhr) POB Temperature(°C) Weather [Wind 0.00 66.0 -7.8 Mostly Cloudy WC 7°I ENE @10 MPH ' Daily summary operation 24h Summary ' Complete to R/U running completion equipment-Trouble with GBR tong-R/D GBR running equipment and tong-R/U Nabors running equipment and tongs-C/O collar and PJ damaged-RIH completion string(4.5"/12.6#/13Cr-L80/Vam Top) Operation at 07.00 RIH completion string(4.5"/12.6#/13Cr-L80/Vam Top) 24h Forecast Continue to RIH completion string(4.5"/12.6#/13Cr-L80/Vam Top)-Space out-Install VIT and Tbg hanger-Set Tubing hanger-Pressure test hanger-Install BPV-N/D BOP Stack Lithology 'Shows MAASP(kgflcm') I Mud Weight(gIL) 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 COMP K 2 P Complete to R/U completion running tools(GBR torque turn,compensator,single joint elevators,and handling tools) 01:00 01 30 0.50 1.50 COMP K 5 TS03 P/U seal assembly-M/U chemical injection mandrel[Tongs crushed lower pup joint on Chemical Injection assembly]- Backed out and inspected damage 01:30 08.30 7.00 8.50 COMP K 24 TS03 Sent damaged injection mandrel to SLB shop to get spare pup bucked on-GBR sent out new computer for torque turn 08:30 11:00 2.50 11.00 COMP K 12 TS03 R/U new computer for torque turn-Check torque turn for proper functioning with spare PJ OK-Make up chemical injection assembly-Attempt to install injection line and egged bushing for flair nut-Repair egged bushing and installed injection line -Pressure test 10k psi 11:00 13:00 2.00 13.00 COMP K 5 TS03 M/U"X"nipple assembly-Tong turn over torque connection-Backed out and inspected damage-Collar and lower PJ damaged on"X"nipple assembly 13:00 18:30 5.50 18.50 COMP K 2 7503 R/D GBR equipment-Get Nabors running equipment and crews headed to rig 18:30 21:00 2.50 21.00 COMP K 2 7503 R/U Nabors running equipment and tong-Check torque turn for proper functioning with spare PJ OK-C/O collar and PJ on "X"nipple assembly 21:00 00.00 3.00 24.00 COMP K 5 P RIH Completion string w/4 R:"tubing(12.69/13Cr-L80/Vam Top/4480 Albs/Dw wt 55k lbs/Up wt 60k tbs)01616' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Mattt Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) 'TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') fl! Ent'E&P Division .} Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name: Nikaitchuq • APIIUWI:029-23438-00-00 en11 Date:4/24/2012 - Report#: 6 �f l) page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(%( !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) I Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 COMPLETION 39.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather 'Wind 0.00 86.0 -11.1 Overcast WC+1° East @8 MPH Daily summary operation 24h Summary Continue to RIH completion string(4.5"/12.6#/13Cr-L80/Vam Top)-Space out-Install VIT and Tbg hanger-Set Tubing hanger-Pressure test hanger-Install BPV Operation at 07.00 N/D BOP Stack/N/U Production Tree. 24h Forecast N/D BOP Stack-N/U Production tree and test-Pull BPV-Freeze protect well-C/O GLM sheared valve-RDMO 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 19:00 19.00 19.00 COMP K 5 P RIH Completion string w/4%"tubing(12.6#/13Cr-L80/Vam Top/4480 ft'lbs/Dwwt 100k lbs/Up wt 130k Ibs)(/1616' 1/7839'-Space out string 19:00 21:00 2.00 21.00 COMP K 5 P P/U and M/U PJ+53 VIT+PJ+Tbg Hanger-M/U dummy penetrator-Feed lines through hanger-Land hanger- Orientate hanger 21:00 22:00 1.00 22.00 COMP K 5 P Land tbg hanger(130k lbs up,100k lbs dw)-Run in all lock down screws-Test upper and lower seals 5000 psi 10 min each (Injection mandrel @ 7817'-LN'X'3.813"@ 7806'-GLM 2100 psi A?T @ 3517'-SCSSSV TRMAXX @ 2282') 22:00 00:00 2.00 24.00 COMP K 20 P L/D landing joint-Blow down all lines and TDS-Clean pits-Install BPV-Clear rig floor of all completion running tools Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Steve Abbott Eni Petroleum Material Coordinator Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Main Turcotte Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) I P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) Eni E&P Division 'Well Name:OP21-WW01 Olt* ENI Petroleum Co.Inc. Daily Repo Well Code:26259 Field Name:Nikaitchuq • APIIUWI:029-23438-00-00 2^n Date:412512012 - Report#: 7 • II '�II page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) IRKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E 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) OP21-WW01 COMPLETION 40.77 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 83.0 -10.0 Mostly Cloudy WC West @ 6 MPH +5" Daily summary operation 24h Summary N/D BOP Stack-N/U Production tree and test-Pull BPV-Freeze protect well-R/U Halliburton slick line. Operation at 07.00 Working with slick line to install new2100 psi A-->T shear valve in GLM @ 3,517'. 24h Forecast Install 2100 psi A—>T shear valve in GLM-Prepare and move the rig over well OP16-03 for workover. Lithology 'Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 COMP K 5 P 'Held PJSM.L/D Schlumberger spools from rig floor.L/D Schlumberger Tool Box. 01:00 10:30 9.50 10.50 COMP C 5 'P Blow down choke and kill lines.Pull Katch Kan,N/D Bell Nipple,choke and kill lines.N/D BOP stack and set on stump.Pull Riser to rig floor. 10:30 14:00 3.50 14.00 COMP C 5 'P Held PJSM.N/U tubing adapter and X-Tree.Pull BPV and install TWC.Perform pressure test X-Tree @ 5000 psi x 15 min, ., TV VC. (charted).Test tubing hanger void/pack-off to 5000 psi for 10 min:Ok.Pull TC. ,' 14.00 20:30 6.50 20.50 COMP K 9 P R/U LRS to pump down IA.Perform pressure test IA @ 1500 psi x 15 min:Ok.Pressured up and sheared GLM valve at 1900 psi.Freeze protect well pumping 251 bbls of Diesel @ 2 bpm/IA=1100-->1400 psi/OA=100—>450 psi.Take �'t i �1 return to mud pits and to cuttings box.Final pressure:IA=750 psi/OA=450 psi. 20:30 00:00 3.50 24.00 COMP R 5 P R/D LRS.Spot Halliburton unit and R/U slick line.R/U sheaves,5 pieces lubricator and tools.Pressure test lubricator to 2500 psi:Ok(TRSSV pressure=5200 psi—>Open).Start washing and cleaning pits and prepare for rig move. i ' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drig Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk • 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Ken Bogner Eni Petroleum Material Coordinator Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling ,Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) I TVD(mKB) Fluid Type 'Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1* Eni E&P Division Well Name:OP21-WW01 ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • APIIUWI:029-23438-00-00 4/26/2012 - Repo #: 8 page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° I Operator ENI Share(%) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(mKB)'Target Depth(TVD...I Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) I DFS(days) OP21-WW01 COMPLETION 41.27 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 82.0 -11.1 Partly Cloudy WC ENE @6 MPH +3` Daily summary operation 24h Summary Work with slick line and set new 2100 psi A—>T shear valve in GLM @ 3,517'-Prepare for rig move. Operation at 07.00 Release rig @ 12:00 hrs 04/26,2012.FINAL COMPLETION REPORT. 24h Forecast Move rig over well OP16-03 for WO.FINAL COMPLETION REPORT. Lithology 'Shows MAASP(kgflcm°) I Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 09:00 9.00 9.00 COMP R 15 P RIH with sick line and set catcher.POOH and install kick over tool.RIH and attempt to retrieve sheared valve:negative. POOH and change kick over tool.RIH and retrieve sheared valve:Ok.POOH and change tool.RIH and set new 2100 psi A —>T shear valve in GLM @ 3,517'.Retrieve catcher and R/D slick line equipment. 09:00 12:00 3.00 12.00 COMP A 1 P Prepare for rig move.Blow down steam,start Lampson,swap power,lay herculite and mats,pull walkways.Jack rig and put on crib blocks. Release rig @ 12:00 hrs 04/26/2012.FINAL COMPLETION REPORT. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spar. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spar. angelo.lamarina @enipetroleum.com 907.685-1493 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Kerr Bogner Eni Petroleum Material Coordinator Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Matt Vanhoose Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) I TVD(mKB) Fluid Type '.. I Fluid Density(gIL) I P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) Eni E&P Division Well Name:�P21-WW01 IfY* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • Date:5/6/2012 - Report#: 2 APIIIJWI:029-23438-00-00 2" " page 1 of 1 Wellbore name: OP21-WW01 Well Header PermiVConcession N° [Operator ENI Share(%) Well Configuration type Oliktok Point IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) I RKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor Rig Name IRig Type Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..JDepth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) IDFS(days) OP21-WW01 RIGLESS 5/5/2012 I 1.42 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather 'Wind 3,364.08 0.00 Daily summary operation 24h Summary Lifting Job-Flow back-R/D CTU._ Operation at 07.00 FINAL RIGLESS REPORT. 24h Forecast FINAL RIGLESS REPORT. Lithology Shows MAASP(kgflcm°) IMud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 30 1,50 1.50 COMP S 15 P Continue lifting well pumping hot water 8.4 ppg/120 F/1.5 bpm/3100 psi taking returns to the 400 bbls open top tank. While pumping,POOH coil @ 30 ft/min to 3,500'. Pressure readings with choke fully open: WHP from 133 psi to 410 psi-IA from 0 psi to 965 psi-OA from 100 psi to 300 psi. 01:30 02:00 0.50 2.00 COMP S 15 P Stop pumping with coiled tubing @ 3,500':WHP=342 psi/good retum of Fresh Water @ retum tank. 02:00 02:30 0.50 2.50 COMP S 15 P Pump 10 bbls of Diesel and displace coiled tubing with Nytrogen.POOH coiled tubing to surface and close swab valve. 02:30 06:30 4.00 6.50 COMP P 10 P OP21-WW01 flow back. 02:30 a.m.->WHP=293 psi/IA=1110 psi/Fresh Water&Diesel @ return tank. 03:00 a.m.->WHP=281 psi/IA=1149 psi/Fresh Water @ retum tank. 03:30 a.m.->WHP=300 psi/IA=1132 psi/Fresh Water @ retum tank. 04:00 a.m.->WHP=313 psi/IA=1133 psi/Fresh Water @ retum tank. 04:30 a.m.->WHP=329 psi/IA=1141 psi/Water&Gas @ return tank. 05:00 a.m.->WHP=333 psi/IA=1147 psi/Water&Gas @ return tank. Well OP21-WW01 to production plant @ 0620 a.m..580 bbls of Water+290 bbls of Brine and Diesel recovered. 06:30 10:00 3.50 10.00 COMP S 5 P R/D CTU. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. Angelo.lamarina @enipetroleum.com 907-685-1493 907-903-7269 • Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 -- 3.363.16 4/18/2012 Last Leakoff Test Depth(mKB) ITVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) • Eni E&P Division (Well Name:OP21-WW01 If* ENI Petroleum Co.Inc. Daily Report Well Code:26259 Field Name:Nikaitchuq • API/UWI:029-23438-00-00 Date:5/5/2012 - Repo #: 1 2^ page 1 of 1 Wellbore name: OP21-WW01 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) IRKB-Tubing Spool(m) 16.34 3.72 0.00 11.34 Rig Information Contractor 'Rig Name Rig Type 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) OP21-WW01 RIGLESS 5'5/2012 1.00 Daily Information End Depth(mKB) I End Depth(TVD)(... Depth Progress(m) 'Drilling Hours(hr) 'Avg ROP(mlhr) I POB Temperature(°C) Weather 'Wind 3,364.08 0.00 Daily summary operation 24h Summary R/U CTU-M/U BHA-Pressure test lubricator and function test BOP-RIH dry to 10,825'-Lifting Job. Operation at 07.00 Flow Back in Progress 24h Forecast Lifting Job-R/D CTU. 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. 00:00 00:30 0.50 0.50 COMP S 1 P Schlumberger CTU on location @ 00:00 5/5/2012.Held PJSM with Co.Man. 00:30 04:30 4.00 4.50 COMP S 2 P P/U rig mats and prepare pad to spot unit.Spot coiled tubing unit over well OP21-WW01. 04:30 19:00 14.50 19.00 COMP S -5 P R/U CTU.lubricator and BOPs.M/U BHA:connector+motorhead assembly+2.1"jet swirl nozzle.Pull test connector to 15000 lbs.Ok.Fill coiled tubing and lubricator with Diesel.Fluid pack and pressure test lubricator 4000 psi.Ok.Function test BOPS:Ok.Pressure test BHA 500 psi-low,4250 psi-high x 5 minutes each test.Ok. 19:00 19:30 0.50 19.50 COMP S 1 P Held PJSM with all parts involved in operations. Pressure readings:Tbg=0 psi/IA=0 psi/OA=100 psi/TRSSV=4500 psi. 19:30 22:30 3.00 22.50 COMP S 15 P RIH dry with coiled tubing @ 70 ft/min down to 10,825'.Weight check every 1000 ft. 22:30 00:00 1.50 24.00 COMP S 15 P Start lifting well pumping hot water 8.4 ppg/120 F/1.5 bpm/3100 psi taking returns to the 400 bbls open top tank.While pumping.,POOH coil @ 30 ft/min.In progress. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamadna @enipetroleum.com 907-685-1493 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 2,390.77 3,363.16 4/18/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) IP Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') $cblumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No OP21-WW01 Date Dispatched: 26-Apr-12 Installation/Rig NABORS 245E Dispatched By: Hector Echeto Data No Of Prints No of CDs OP21-WW01 Log /1 . # 2a 2inMD 1 2 in TVD 1 5inMD 1 ' 5 in TVD 1 Received By: lJ Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan@enipetroleum.com LWD Log Delivery V2.1,03-06-06 Flo — I8 ? Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,April 11,2012 4:51 PM j To: 'Longo Joseph' w_ Subject: RE: OP21-WW01 Intermediate FIT Joe, I agree... FIT results are very good. Drill ahead. I looked at the PTD and we didn't specify a min FIT for drilling out of the Inter. Casing. But this gives us a lot of margin. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From: Longo Joseph [mailto:joe.longo @enipetroleum.com] Sent: Wednesday,April 11, 2012 4:07 PM To: Schwartz,Guy L(DOA) Subject: OP21-WW01 Intermediate FIT Guy, 9-5/8" Intermediate Casing FIT Shoe: 8093' MD/ 6717'TVD MW: 10.2 ppg Pres: 1043 psi EMW: 13.20 We pressured up to 1043 psi (basically straight lined) which is a 13.2 ppg EWM, we shut in and after 25 min it bled down to 948 psi or 12.91 ppg EMW. Looking ahead assuming a 10.5 ppg MW we should not see anything over a -11.8 ECD (worst case - assuming 20% increase in rheology @ 300 fph). I am comfortable drilling ahead with these results. 4/11/2012 1 Page 2 of 3 Wel OP21.WWO1 Operator : EMPrholeum I1-.(1?XU1.4X;Y COWL N Depth(ft) Food Niancliro Location - Oalloh Port TVD(ft) 8000- :1 6638 Fbw rasa 500 9pm - 8200 ROP fa citigs risk 30OMr 6787 S ing dA flop(oe) Lenancaroontel 8400 To Surf 5"19 St S NC50 S13S •Vd0 481093sb'1MIOPGh HUMP • •• 4.06 Satin Su0 S135 196 78 LYIU'Ww1Y2 x k.S13 x NAIFC 5135 8P)0- ---.... ._ _... S 1 3 5.. .,__I_- 7104 . - Hole Pickle 813 8800 .............,-..._.-_.-. ..... ... ...... F .._. . Bese(R)Doman)Descnpamr..__ .-_....-._. . 1277 804800 8 681 D 9-$8'47�r r • 11148-00 8 500 6.1,t Bole - 5 • 9000 a. . . 1,1041 re 10 w mg PV'27 Yl'131bst1009� r '.4n7 u..%�l1xjs C,r4ta.',411J(k'&`7 . 9700 . . ,' :, . . . , . . . .ads,et l4 rmrd100:smrr TPA i. . .1.-. 71;49 EfIW-068591on r N.017Ryrn i WOO ; p•Ut6 9800 ,.........._... .. ._ .- t4).31 1 •• t 10000 ... .. . ... _- .. . . ..•i- . htt . 3 10200 .. ►...... . ( P.S73 10400 £•.7t R 1 10000 e.... . . . . . -.. . 8944 • a E 10800. ...._ .._ . . 1..._. ........ ...... ,.... ...._. -.. ...._..._. ...... 9130 11000 1 �..,._......_. ..-_... _ .9315 11200 , . ,......,,. ....,,..... .y .. 9501 • 11400-, . . ,`9887 9.5 10.0 105 110 11 5 120 125 130 135 140 145 150 15.5 Eq.Circ-Density(peg) -Min FG ECO.10%0300ft'1s ECOMW-10% Mud wt ........Mas FG —ECO 889e ca5e.0300a*r EGO VP Base case -----—Mar PP ECO.10%O300thr ECOOV'P•10% ----KOh risk CG —ECD 420%O300Whr ECDeW•20% -ECO-20%(43001C4r ECOOvP-201 —Snapino40TO Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 4/11/2012 Oliktok Point Nikaitchuq Field n • o 2 ° Crc�l ur��� OP21 -WW01 Alaska p� DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD _ MD I TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' o N/A Welded/Driven N/A D N r- -o GR/Res Surface Csg Dir 13-3/8" Top of Tail 1,505' 1,479' 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor L-80,BTC 9.2-9.5 Lost Circulation Base Permafrost 1,802' 1,775' Top Perforation 1,931' 1,903' Hole Cleaning Btm Perforation 1,934' 1,906' 8.9° 13-3/8"Casing Point 2,040' 2,011' TOC 2,960' 2,865' H N Sand Top 3,690' 3,425' m P. DV Stage Tool 3,826' 3,527' �''.^"7'+,y --- - � C �z�z� c� ` . te) . OA Sand Top 3,884' 3,570' I7+ B/CMT 4,020' 3,671' 41° TD 16"Hole 4,127' 3,752' 1 16" 50°F SPUD GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Mud Motor 40 lbs/ft MW(ppg) Hole Cleaning 6,788' 5,734' L-80,Hydril 563 9.4-9.8 Torque&Drag r O r-, rn mv m 01 1 7,566' 6,321' rit- 9-5/8"Casing Point 8,093' 6,717' 4 i' 40.9° 12-1/4"TD 8,108' 6,729' 12-1/4" 85°F LSND GR/RES Wellbore Stabtliry Lost Circulation Mud Motor Liner Hole Cleaning 7" Torque&Drag 26 lbs/ft MW(ppg) 13CrL80,VamTop 10.5 20.83° TD 11,147' 9,452' 7" 230°F MOBM , I. , , SEAN PARNELL,GOVERNOR ' D, L_ it n ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COM1tIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operating Manager a 0 7 ENI US Operating Co. Inc. .„--------------3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Ivishak Pool, OP21-WW01 Sundry Number: 312-110 Dear Mr. Grandi: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,- _,),74, . Cathy . Foerster -- Chair DATED this Zn day of March, 2012. Encl. 3-Y''f#*A E 4'E� 2Y2_ -��' LIAR 2 3 2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 01' & Gas Cons. Commission 20 AAC 25.280 a Anchorage 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well b---- CTiange Approved-Program-a--1 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ENI US Operating Co.Inc. Development ❑ Exploratory ❑ 210-187 3.Address: Stratigraphic ❑ Service IS 6.API Number: 3800 Centerpoint Drive Anchorage,AK 99503 50-029-23438-00-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No IS OP21—WW01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355024,373301, 390616,390615 Nikaitchuq/Ivishak 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4127 3751 2045 2015 1943'MD(Cement Retainer) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 122 20 160 160 4980 3240 Surface 2045 13-3/8" 2045 2015 5020 2260 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1936-1939 1907-1910 N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): EZ Drill SVB Cement Retainer 1943'MD/1914'TVD 12.Attachments: Description Summary of Proposal 'j 13.Well Class after proposed work: Detailed Operations Program IS BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 ' 14.Estimated Date for 3/22/2012 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 3/22/2012 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Guy Schwartz ' Water Source IS - GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joseph Longo-907-865-3323 Printed Name Maurizio Grandi Title Well Operating Manager Signature AAA Phone 907-865-3320 Date 3/23/2012 AAA COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 2:: I ( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 A 1 A re e j A t-4,-,-,..,_,..4.„ 5G�.i, r-, II�j E'C�2%�+�'J II Subsequent Form Required: 07 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 —Z2 —/2-- RSDMS A R 02:2012 "'�Z z RiGINAL � " '�� Form 10-403 Revised 1/2010 Submit in Duplicate w V ,,, ibrat } Ens troieum 120322 OP21-WW01 Sundry Approval.doc 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Maurizio Grandi Phone (907) 865-3320 Email: Maurizio.Grandi @enipetroleum.com March 23, 2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Sundry Approval for Change of Approved Program: OP21-WW01 APD# 210-187 Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a sundry approval for change of approved program for the water source well OP21-WW01 APD# 210-187. The 16" surface hole section was drilled to a total depth of 4127' MD/ 3751'TVD without issues. The section was back reamed and preparations were made to run surface casing. While running the 13-3/8" 68# L80 BTC surface casing it became stuck at 2060' MD. Attempts were made to pump the casing out of the hole resulting in the string remaining stuck at 2045' MD/ 2015'TVD. Circulation was lost shortly after. The decision was then made to perforate the casing below the permafrost and cement the casing string in place to surface. Currently a 13-3/8" cement retainer has been set 15' above the float collar and the well was perforated from 1936-1939' MD. A circulation rate of 5 bpm was achieved, and we will commence the 13-3/8" cement job this afternoon. The operations summary below outlines our previous operations, current operation and plan forward. If you have any questions or require further information, please contact Joseph Longo at 907-865-3323. Sincerely, /IAA CV"' ) Maurizio Grandi Well Operation Project Manager EnD i=i = troleum 111,1,1 120322 OP21-WW01 Sundry Approval.doc Operations Summary - 03/21/2012 to 03/23/2012 10:00 hrs: • Rig up GBR casing running equipment and TIH with 13-3/8" 68# L80 BTC casing to 2060' MD and break circulation at 250 gpm/ 270 psi. • Continue RIH to 2060' MD. Taking weight. Pull free with 270K. • Attempt to pump out of hole. Pull joint #53. Pull joint #52 15' and lose circulation. Pull 340K, regain circulation but pipe still stuck. • Attempt to maintain circulating and pull pipe free. • Circulation lost and pipe not moving. • Casing set at 2045' MD/ 2015'TVD. • Rig up Schlumberger cement head and Halliburton E-Line. • RIH on E-Line with cement retainer to top of float collar set at 1959' MD/ 1931' TVD. Get on depth and pull up to set cement retainer at 1944' MD/ 1915'ND (15' above float collar) and POOH. • Test and chart casing to 2500 psi - Good Test. • Pick up 3' 3-3/8" Millennium perforation guns. o 18 shots, 6 spf, 60° Phasing, 25 gm HMX. • TIH to perforation depth (bottom perforation 5' above cement retainer). o Perforation Interval: 1936' MD - 1939' MD • POOH perforation guns and RU to circulate through cement head. o All shots fired • Re-gain circulation. o Broke circulation at 1 bpm and staged up to 5 bpm at 40-200 psi. o 100% returns no losses. Current Operation/ Plan Forward Current ODs: • Currently conditioning mud for cement job and rigging up Schlumberger cementing. Plan Forward: • Pump cement as per Schlumberger Program. o Lead: 390 bbl ASL o Tail: 82 bbl Arctic Set 1 • Drop top plug and displace with rig pumps at 5 bpm. o Be sure to leave 100' of cement above the perforations. • Record cement to surface and estimated volume circulated to surface. • Hold FCP for at least 4 hr, then bleed off, if bleed off is more than 1 bbl or does not appear to be slowing down, shut in and repeat in 2 more hours, until cement sets. Ant Eni trole 120322 OP21-WW01 Sundry Approval.doc Post Cement Job: • ND diverter and set emergency slips. • Cut casing and NU Vetco Gray well head and test to 5000 psi for 10 min. • NU BOP and test, Notify AOGCC 24 Prior to testing: o Rams and Choke Manifold: 5000/ 250 psi o Annular Preventer: 2500/ 250 psi • PU 12-1/4" BHA and drill out cement through perforation interval. • DO NOT drill out cement retainer! • Conduct an FIT/ LOT across Perforation Interval. 0 Shut down if pressure rises past 14 ppg EWM and continue as per FIT guidelines. O If FIT/ LOT is less than 12 ppg EMW contact Drilling Superintendent and Drilling Engineer prior to moving forward. o Estimated ECD at perforation interval is estimated below 10.6 ppg assuming 10 ppg MW. • Contact Drilling superintendent of results prior to drilling out cement retainer. • Drill out shoe track and clean out to 4127' MD. • Swap spud mud to LSND and drill ahead. Attachments: • OP21-WW01 Current Schematic • OP21-WW01 Surface Surveys • OP21-WW01 P3 Surface CemCADE II OViik Oliktok Point Nikaitchuq Field • enll P trroicLm OP21 -WW01 Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD I TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A GR/Res Surface Csa Dir 13-3/8" 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor L-80,BTC 9.2-9.5 Lost Circulation Hole Cleaning Base Permafrost 1,776' 1,748' Top Perf 1,936' 1,907' INF Bottom Perf 1,939' 1,910' Cement Retainer 1.944' 1,915' cement retainer Float Collar 1,959' 1,931' FC 13-3/8"Casing Point 2.045' 2,015' . k_ 16" 16"hole TD 4,127' 3,751' 50"F SPUD N O > N O c a '10000 00000 OoOC70 <<<<< 00000 0 u 03333 3333 333 3 2M2M2 MM222 0 O C7 00000 C7C7C7C7C7 a F 0 0 0 0 • O O O O O 666 +6 + + + + + + + + + + 7 >` 3 CC CC 00 00000 0000 m 0000 0O0 00000 00000 N>}>} »>}> }»3>Z 7 7 7 0 07 0 7 7 7 7 C7 0 m m m m g g g g M c 7 O I I I I N N W m m m m m m m m m a >J J J J J J J J J J J J J J J J J J J J J J J N (jIV)CJ)CO!n toCOCO v)u) (O COcnW CO toW In Into In toto fn to co m J co OZ t CD N O n COD O'U M tWO O c O C^7 M 4 CA W O T N UD'U N N O Z N.—N co CODCCOCCOCOOCCO Onrnn CDCDNN DO'M� S. 0 W F 55 '07N2 O U Na7 8 O CO O t%K,NO)2 O2 2N O Y 0000 r N71f)I-O) -CV MNV O CU cO4 s COCDO. r r r r .-r r r Q a 3' J m N i- f, Z r O LL Q` m m C CO- m m m C m m J J m J m J J J J J J J J J N 00 F N F`-' W NMW A W7 NNCOM COOM N MC,WIP W j O N C r N 0n VN NOW 07 W OI-,CvI- COri M7e} I�OrW W '„CO OCW COW N'Uf�MCD ..)CO ODDOODC U tO N zN m CO N W W W^ OO E � 5 o 8 . 1g ^ a, E 0 O W t0O N 00 7 0 'C) W 0 CO C C C7 ^ On (7 0 N 0 M 0012 N N W c7, 1) m __2 C N 1 z ONM M 2CON W O nN CO 7 W CONGO U) D77 W O Orr 0— W 0 C)CD M K CO O O R NOD OD CO a LA N W 0 7 3 r .. 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U)U) MU) oO M OD0 U) WON ON U)7 MN CD MNN COM U)N 0 2 00)N U)N 70r0N N OCD N 00 700)U)U) N70D MM U)N COO N COMrM o)CDN CDM Oi V Oi Ui0 NCCDUim :4-0)Ui.00 Ci00'Cr CO U)U)77 MMM NN ■ 000 MM00 OON N CO CO CD U) l077N 7 U)CDN O MO.-NM 7 NOON O W00.-CV C')7 U)CON CO MOr N N N N N N N N N N N M M M MMMMM M M 7 7 C 0 O O d S O_ 0.O m r o R N U g ) N 4 0 C co F - 11)a CD o >.>, 0 E ° m E cc 0 a N V)U) 0 Schiumberger CemCAD E*well cementing recommendation for Stuck Surface Casing Contingency Operator : Eni Petroleum Well : OP21-WW01 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Joe Longo Location Oliktok Point Proposal No. : Draft v3 Service Point : Prudhoe Bay,Alaska Date Prepared : 03/22/2012 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1 @slb.com n C Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. Mark of Schlumberger Client : Eni Petroleum Well : OP21-WWO1 Schlumburgcr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 4076.0 ft BHST : 33 degF Bit Size : 16 in ft (x 1000) psi CD 7 — 0 2.5 —_ r Frac 11 Pore — o - —Siltstone— o— i=i - • • •Sandstone• • • . - --iM o— Shale °- Siltstone oo ' Shale ■ o— Q .�, ; •••'•Sandstone•',' -- L- (-4 ' o _ o Coal o— ref - F Well Lithology Formation Press. Page 2 op21-ww01 v3 p3.cfw,03-22-2012, LoadCase V2 Surface Casing Contingency,Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WWO1 Scilierger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.376 Top of Cement in Casing MD : 1858.0 ft Perforations MD : 1958.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 1958.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 180.8% Mean OH Equivalent Diameter: 17.889 in Total OH Volume : 1217.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1749.0 16.000 200.0 20.254 1958.0 16.000 35.0 16.822 1997.0 16.000 0.0 16.000 2005.0 16.000 0.0 16.000 4075.0 16.000 0.0 16.000 4076.0 16.000 0.0 15.999 Page 3 op2t-ww01 v3 p3.cfia;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 Scillikrier String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Max. Deviation Angle : 42 deg Max. DLS : 3.502 deg/100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/1OOft) 0.0 0.0 0.0 163.0 0.000 100.0 100.0 0.0 163.0 0.000 200.0 200.0 0.0 163.0 0.000 250.0 250.0 0.0 163.0 0.000 300.0 300.0 0.8 163.0 1.500 350.0 350.0 1.5 163.0 1.500 400.0 399.9 3.3 163.0 3.500 500.0 499.5 6.8 163.0 3.500 600.0 598.4 10.3 163.0 3.500 700.0 696.2 13.8 163.0 3.500 800.0 792.6 17.3 163.0 3.500 862.8 852.2 19.5 163.0 3.502 900.0 887.4 18.4 161.8 -3.015 1000.0 983.0 15.6 157.8 -2.998 1100.0 1079.9 13.0 152.1 -3.001 1200.0 1177.8 10.5 143.8 -2.993 1300.0 1276.4 8.4 130.8 -3.006 1376.5 1352.2 7.2 116.3 -2.997 1400.0 1375.5 7.1 115.9 -0.499 1500.0 1474.8 6.6 114.4 -0.503 1600.0 1574.2 6.1 112.7 -0.499 1700.0 1673.7 5.7 110.7 -0.496 1800.0 1773.2 5.2 108.3 -0.503 1879.3 1852.2 4.9 106.1 -0.504 1900.0 1872.8 5.0 99.0 3.002 2000.0 1972.3 6.4 72.1 2.999 2100.0 2071.5 8.7 57.0 3.001 2200.0 2169.9 11.3 48.4 2.998 2300.0 2267.5 14.1 43.1 3.003 2400.0 2363.8 16.9 39.5 2.996 2500.0 2458.7 19.8 36.9 3.001 2600.0 2551.9 22.7 35.0 3.002 2700.0 2643.1 25.7 33.5 3.005 2800.0 2732.1 28.6 32.3 2.992 2900.0 2818.6 31.6 31.3 3.003 3000.0 2902.4 34.5 30.4 2.996 3100.0 2983.3 37.5 29.7 3.001 3200.0 3061.0 40.5 29.0 3.007 3245.6 3095.3 41.8 28.8 2.989 3300.0 3135.9 41.8 28.8 0.000 3400.0 3210.4 41.8 28.8 0.000 3500.0 3284.9 41.8 28.8 0.000 3600.0 3359.4 41.8 28.8 0.000 3700.0 3433.9 41.8 28.8 0.000 3800.0 3508.4 41.8 28.8 0.000 3900.0 3582.9 41.8 28.8 0.000 4000.0 3657.5 41.8 28.8 0.000 4076.0 3714.1 41.8 28.8 0.000 Page 4 op21-ww01 v3 p3.cfw;03-22-2012; LoadCa se V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 Sihmihrger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 714.0 11.50 8.39 SV-4 Siltstone 975.0 11.50 8.40 SV-3 Sandstone 1240.0 11.50 8.40 SV-2 Shale 1715.0 11.70 8.42 SV-1 Siltstone 1749.0 12.00 8.43 Permafrost Base Coal 2049.0 12.30 8.44 Ugnu Top(UG4) Stuck Point 2534.0 12.60 8.45 UG-2 Coal Bed Marker Sandstone 3270.0 12.70 8.50 Lower Ugnu Coal 3545.0 12.60 8.60 Schrader Bluff Top Shale 3600.0 12.60 8.60 N Seq.Top Sandstone 3656.0 12.60 8.60 N Top Sandstone 3711.0 12.60 8.70 N Bottom Sandstone 3770.0 12.60 8.70 N Seq Base Sandstone 3865.0 12.50 8.70 OA Top Sandstone 3877.0 12.50 8.70 OA-2 Top Sandstone 3890.0 12.50 8.70 OA-3 Top Sandstone 3908.0 12.50 8.70 OA-4 Top Sandstone 3918.0 12.50 8.70 OA Bottom Sandstone 4076.0 12.50 8.70 TD Shale Page 5 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 Sc Fierier String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1872.8 32 0.6 4076.0 3714.1 50 0.8 ft degF 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 o- 1 I I 1 I 0 o Ln _ o - S- 0 - O - O - 0 N - Geoth.Profile O - -Tubular Fluids oAnnulus M C7 O - O O _ O u7 - Temp. Profile At 195 min Page 6 op21-wwO1v3p3.cfw;03-22-2012, LoadCase V2 Surface Casing Contingency,Version wcs-cem47l.02 • • Client : Eni Petroleum Well : OP21-WW01 Sc I Wrger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface,Arctic Set 1 Tail to 100 ft.above the perfs. Original fluid Mud 9.60 lb/gal k:5.41E-4 Ibf.s^n/ft2 n :0.975 Ty: 17.24 lbf/100ft2 Displacement Volume 281.2 bbl Total Volume 853.2 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) _ MUDPUSH II 100.0 0.0 10.10 k:6.58E-2 Ibf.s^n/ft2 n:0.291 Ty:6.34 lbf/100ft2 Lead Slurry 390.0 1531.5 10.70 k:1.16E-1 Ibf.s^n/ft2 n:0.254 Ty:0.48 lbf/100ft2 Arctic Set 1 82.0 426.5 1531.5 15.70 k:3.00E-3 Ibf.s^n/ft2 n:0.905 Ty:0.83 lbf/100ft2 Mud 281.2 0.0 9.60 k:5.41E-4 lbf.s^n/ft2 n:0.975 Ty:17.24 lbf/1 00ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2008 psi at 1878.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 42 ton Check Valve Diff Press 195 psi it II Page 7 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 SchIinkergcr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Section 3: pumping schedule Start Job: Circulate 5-8 BPM Minimum If unable to circulate with full returns at a minimum 5 BPM, we will need to redesign the job to adjust for lower parameters. Safety Meeting;Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead 5.0 0.0 80 Swap to Cement 5.0 0.0 80 Weight Up Tub Lead Slurry 5.0 390.0 78.0 390.0 80 Mix&Pump Lead Slurry Arctic Set 1 4.0 82.0 20.5 82.0 80 Mix&Pump Tail Slurry 5.0 0.0 80 Drop Top Plug Mud 5.0 10.0 2.0 10.0 80 Kick Out Plug Pause 0.0 0.0 5.0 0.0 80 Line Up Rig Pumps Mud 5.0 271.2 54.2 281.2 80 Displace to 100' Above Perfs Shut-In 0.0 0.0 1220.0 0.0 80 HOLD PRESSURE. Total 03:14 hr:mn 853.2 bbl End Job: HOLD FINAL PRESSURE FOR ATLEAST 4 HRS, then bleed off, if bleed off is more than 1 bbl or does not appear to be slowing down, shut in and repeat in 2 more hours, until cement sets. Dynamic Security Checks: Frac 4 psi at 160.0 ft Pore 10 psi at 160.0 ft Collapse 2008 psi at 1878.0 ft Burst 4794 psi at 0.0 ft Temperature Results BHCT 57 degF Simulated Max HCT 77 degF Simulated BHCT 76 degF Max HCT Depth 1807.4 ft CT at TOC 69 degF Max HCT Time 02:44:38 hr:mn:sc Static temperatures: At Time (hr:mn) 20:20 hr:mn Geo.Temp. Top of Cement (degF) 37 degF 20 degF Bottom Hole (degF) 61 degF 33 degF Page 8 op21-ww01 v3 p3.cfw,03-22-2012, LoadCase V2 Surface Casing Contingency.Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WWO1 ScInirger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency ECD simulated at anticipated Perforation depth: Depth= 1958 ft N �1 ^O H Hydrostatic ip Dynarric Frac aFlare CD N N o c < O) 0 ai- it � I co 0 Ca I I I 0 30 60 90 120 150 180 210 Time (min) Page 9 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 gcilrg�r String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency BHCT CementTemperature Simulation: o 0 First Sack Temp. •Last Sack Temp. M -N -M CL- a) -o0 OO r—. U Q 0 f` -1� O_ co co ■ 0 30 60 90 120 150 180 210 Time(min) Page 10 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 • Client : Eni Petroleum Well : OP21-WW01 Sekhoberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Temperature Ramp over 24 Hours: (.1 , o First Sack Terrp. •Last Sack Temp. O W I -N Co -M aT O O N U 0- N 0 -CO N N. O -Co c co —— i i Cr) 0 250 500 750 1000 1250 1500 1750 Time(min) Page 11 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 ScInkerger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Surface Pressure Model: Calc.Pump Press. •Calc.CemHP M- o- M 0 ln- N N a 0 `0 0 0 30 60 90 120 150 180 210 Time(min) Page 12 op21-ww01 v3 p3.cfw;03-22-2012, LoadCase V2 Surface Casing Contingency,Version wcs-cem471_02 Page 1 of 1 Schwartz, Guy L (DOA) From: Regg, James B (DOA) Sent: Friday, March 23, 2012 2:14 PM To: Longo Joseph Cc: Schwartz, Guy L (DOA) Subject: RE: OP21-WW01 CO 639 Administrative Approval Attachments: co639-002.pdf Admin approval attached Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Longo Joseph [mailto:joe.longo @enipetroleum.com] Sent: Friday, March 23, 2012 10:38 AM To: Regg, James B(DOA) Subject: OP21-WW01 CO 639 Administrative Approval Jim, Eni would like to request Administrative Approval, regarding the CO 639 surface casing setting requirement, to set the surface casing less than 500' below the base of the permafrost. While running the 13-3/8" surface casing string the casing became stuck and all attempts to recover were unsuccessful. If you have any questions please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo@ienipetroleum.com 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. 3/27/2012 scifEE b a SEAN PARNELL,GOVERNOR ALASKA. OIL AND GAS 3331N,7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL CONSERVATION ORDER 639.002 Mr. Joseph Longo Drilling Engineer Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage,AK 99503 RE: Request for Administrative Approval Nikaitchuq Unit OP21-WW01 (PTD 2101870) Dear Mr. Longo: In accordance with Rule 14 of Conservation Order (CO) 639.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Eni US Operating Company Inc. (Eni)'s request for administrative approval to place the surface casing shoe within 500 feet of the base of permafrost in the subject well. While running equipment into Nikaitchuq OP21-WW01 (water supply well) for the purposes of casing and cementing the surface section of the well, surface casing became stuck before reaching the bottom of the open hole section. Attempts to pull the casing free were unsuccessful, requiring the surface casing to be set at its stuck point. Conservation Order 639, Rule 4.b. requires the surface casing setting depth to be "at least 500 feet measured feet below the permafrost";the stuck depth of the casing is approximately 260 feet below permafrost. AOGCC has approved revised plans submitted by Eni to cement the surface casing in place and to establish the mechanical integrity of the surface casing before installing blowout prevention equipment and drilling ahead in Nikaitchuq OP21-WW01. Allowing the surface casing to be set at a depth less than required by Conservation Order 639 will not promote waste, will not compromise the integrity of the well or prevent the ability to continue drilling in a safe and efficient manner, will not jeopardize correlative rights, and will not increase the risk of fluid movement into fresh water. DONE at Anchorage, Alaska and dated March 23, 2012. Cathy P Foe ter DA'el T. Seamount,Jr. 0 K.No• Chair, omissioner Commissioner o - loner 0,tm oN , CO 639.002 March 23,2012 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. 7 [F Altalir\Kii: SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL CONSERVATION ORDER 639.002 Mr. Joseph Longo Drilling Engineer Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage,AK 99503 RE: Request for Administrative Approval Nikaitchuq Unit OP21-WW01 (PTD 2101870) Dear Mr. Longo: In accordance with Rule 14 of Conservation Order (CO) 639,000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Eni US Operating Company Inc. (Eni)'s request for administrative approval to place the surface casing shoe within 500 feet of the base of permafrost in the subject well. While running equipment into Nikaitchuq OP21-WW01 (water supply well) for the purposes of casing and cementing the surface section of the well, surface casing became stuck before reaching the bottom of the open hole section. Attempts to pull the casing free were unsuccessful, requiring the surface casing to be set at its stuck point. Conservation Order 639, Rule 4.b. requires the surface casing setting depth to be "at least 500 feet measured feet below the permafrost"; the stuck depth of the casing is approximately 260 feet below permafrost. AOGCC has approved revised plans submitted by Eni to cement the surface casing in place and to establish the mechanical integrity of the surface casing before installing blowout prevention equipment and drilling ahead in Nikaitchuq OP21-WW01. Allowing the surface casing to be set at a depth less than required by Conservation Order 639 will not promote waste, will not compromise the integrity of the well or prevent the ability to continue drilling in a safe and efficient manner, will not jeopardize correlative rights, and will not increase the risk of fluid movement into fresh water. DONE at Anchorage, Alaska and dated March 23,2012. on;, • Cathy P Foe ter D:r''el T. Seamount,Jr. K.K. No• n Chair, ommissioner Commissioner om loner sy frOirs "tub, I?ZON — • CO 639.002 March 23,2012 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. ,Qieziri-ci,t(Aq Oral Regg, James B (DOA) P� �i� ��7� From: Longo Joseph [joe.longo@enipetroleum.com] e4 I I 3l�� 1 v Sent: Friday, March 23, 2012 10:38 AM \ To: Regg, James B (DOA) Subject: OP21-WW01 CO 639 Administrative Approval Jim, Eni would like to request Administrative Approval, regarding the CO 639 surface casing setting requirement, to set the surface casing less than 500' below the base of the permafrost. While running the 13-3/8" surface casing string the casing became stuck and all attempts to recover were unsuccessful. If you have any questions please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo(aenipetroleum.com 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 Page l of 2 m tat Schwartz, Guy L (DOA) P-1-6 z-10 02 70 From: Schwartz, Guy L (DOA) Sent: Thursday, March 22, 2012 4:15 PM To: Schwartz, Guy L (DOA); 'Longo Joseph' Cc: 'Borri Luca'; Regg, James B (DOA); Davies, Stephen F (DOA) (steve.davies @alaska.gov) Subject: RE: OP21-WW01 Remedial Action Joe, Forgot to mention I will be out of town this weekend. Jim Regg will be my alternate for the next couple days. Had a thought since we last talked.... Make sure part of your procedure includes pressure testing the 13 3/8" casing above the pert holes. Once you drill past the perfs and before hitting the bottom retainer a LOT/FIT must be done to your new calculated minimum value. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Thursday, March 22, 2012 3:43 PM To: 'Longo Joseph' Cc: Borri Luca; Regg, James B (DOA); Davies, Stephen F(DOA) (steve.davies @alaska.gov) Subject: RE: OP21-WW01 Remedial Action Joe, Plan so far is acceptable.... Get me a full plan as soon as you can. You will need a sundry ( Change of operation)once the basic plan is outlined. I can get you a verbal once I have that in place. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Longo Joseph [mailto:joe.longo @enipetroleum.com] Sent:Thursday, March 22, 2012 3:10 PM To: Schwartz, Guy L (DOA) Cc: Borri Luca Subject: OP21-WW01 Remedial Action Guy, I have a meeting to attend but I wanted to give you an overview of our plan forward. I will follow it up with a more detailed package later today. Currently we are rigging up to set a cement retainer above the top of the float collar. We will then run in the hole with a 3-3/8" perforation gun on WL and perforate a 3 foot interval at 6 spf for 18 total shots. We will then attempt to gain circulation. If all goes well we will commence our cement job as planned bringing cement returns to surface. Below is the intervals where we plan to set and perforate. If you have any questions please do not hesitate to ask. 3/22/2012 Page 2 of 2 MD Ft below B/ Perm B/ Perm 1776 T/Jt3 1920 144 Top Perf 1938 162 Btm Perf 1941 165 CR 1944 168 B/Jt. 3 1959 183 FC 1959 183 Shoe 2040 264 Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo@ienipetroleum.com 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. 3/22/2012 /0, `�`-I c9P -t -w i zia I7o Regg, James B (DOA) From: Longo Joseph [joe.longo @enipetroleum.com] Sent: Thursday, March 22, 2012 6:16 PM To: Schwartz, Guy L (DOA) Cc: Borri Luca; Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: OP21-WW01 Remedial Action Attachments: OP21-WW01 P3 v3 Stuck Surface CADE 3-22-2012x.pdf I forgot to attach the CemCADE. Again if you have any questions please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo @enipetroleum.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, March 22, 2012 4:15 PM To: Schwartz, Guy L (DOA); Longo Joseph Cc: Boni Luca; Regg, James B (DOA); steve.davies @alaska.gov Subject: RE: OP21-WW01 Remedial Action Joe, Forgot to mention I will be out of town this weekend. Jim Regg will be my alternate for the next co • e days. Had a thought since we last talked.... Make sure part of your procedure includes pressure t- ing the 13 3/8" casing above the perf holes. Once you drill past the perfs and before hitting the bottom retainer - LOT/FIT must be done to your new calculated minimum value. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Thursday, March 22, 2012 3:43 PM To: 'Longo Joseph' Cc: Borri Luca; Regg, James B (DOA); Davies, Stephen ' (DOA) (steve.davies @alaska.gov) Subject: RE: OP21-WW01 Remedial Action Joe, Plan so far is acceptable.... Get me a full pla as soon as you can. You will need a sundry ( Change of operation) once the basic plan is outlined. I can get you a -rbal once I have that in place. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1 Schlumberger C emCAD E*well cementing recommendation for Stuck Surface Casing Contingency Operator : Eni Petroleum Well : OP21-WW01 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Joe Longo Location : Oliktok Point Proposal No. : Draft v3 Service Point : Prudhoe Bay,Alaska Date Prepared : 03/22/2012 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1©slb.com A tApV \ TE 44' Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that am not infallible. Calculations are estimates based on provided information.All proposals.recommendations,or predictions are opinions only NO WARRANTY IS MEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to he inferred and no intellectual property rights are granted hereby. Mark of Schlumberger Client : Eni Petroleum Well : OP21-WW01 Schlumburgcr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 4076.0 ft BHST : 33 degF Bit Size : 16 in ft (x 1000) psi O_ 0 2.5 - — — Frac - — — — Pore ' 111111111111111111111111 o - —SIltStOne_ -� Q_ I : u7 - — - - a - • • 'Sand st one* • • U Shale _--it ,_ . =N . amt °_ _Siltstone= , Mili MIN am o . CD ■ i CV o : Sandstone•'•'• o c-4 - CD M ' Shale Coal i co O _ — O— O C— Well Lithology Formation Press. Page 2 op21-ww01 v3 p3.cfw,03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 Schlmerger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.376 Top of Cement in Casing MD : 1858.0 ft Perforations MD : 1958.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 1958.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 180.8% Mean OH Equivalent Diameter: 17.889 in Total OH Volume : 1217.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) _ 1749.0 16.000 200.0 20.254 1958.0 16.000 35.0 16.822 1997.0 16.000 0.0 16.000 2005.0 16.000 0.0 16.000 4075.0 16.000 0.0 16.000 4076.0 16.000 0.0 15.999 Page 3 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WWO1 5ilstirger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Max. Deviation Angle : 42 deg Max. DLS : 3.502 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/10Oft) 0.0 0.0 0.0 163.0 0.000 100.0 100.0 0.0 163.0 0.000 200.0 200.0 0.0 163.0 0.000 250.0 250.0 0.0 163.0 0.000 300.0 300.0 0.8 163.0 1.500 350.0 350.0 1.5 163.0 1.500 400.0 399.9 3.3 163.0 3.500 500.0 499.5 6.8 163.0 3.500 600.0 598.4 10.3 163.0 3.500 700.0 696.2 13.8 163.0 3.500 800.0 792.6 17.3 163.0 3.500 862.8 852.2 19.5 163.0 3.502 900.0 887.4 18.4 161.8 -3.015 1000.0 983.0 15.6 157.8 -2.998 1100.0 1079.9 13.0 152.1 -3.001 1200.0 1177.8 10.5 143.8 -2.993 1300.0 1276.4 8.4 130.8 -3.006 1376.5 1352.2 7.2 116.3 -2.997 1400.0 1375.5 7.1 115.9 -0.499 1500.0 1474.8 6.6 114.4 -0.503 1600.0 1574.2 6.1 112.7 -0.499 1700.0 1673.7 5.7 110.7 -0.496 1800.0 1773.2 5.2 108.3 -0.503 1879.3 1852.2 4.9 106.1 -0.504 1900.0 1872.8 5.0 99.0 3.002 2000.0 1972.3 6.4 72.1 2.999 2100.0 2071.5 8.7 57.0 3.001 2200.0 2169.9 11.3 48.4 2.998 2300.0 2267.5 14.1 43.1 3.003 2400.0 2363.8 16.9 39.5 2.996 2500.0 2458.7 19.8 36.9 3.001 2600.0 2551.9 22.7 35.0 3.002 2700.0 2643.1 25.7 33.5 3.005 2800.0 2732.1 28.6 32.3 2.992 2900.0 2818.6 31.6 31.3 3.003 3000.0 2902.4 34.5 30.4 2.996 3100.0 2983.3 37.5 29.7 3.001 3200.0 3061.0 40.5 29.0 3.007 3245.6 3095.3 41.8 28.8 2.989 3300.0 3135.9 41.8 28.8 0.000 3400.0 3210.4 41.8 28.8 0.000 3500.0 3284.9 41.8 28.8 0.000 3600.0 3359.4 41.8 28.8 0.000 3700.0 3433.9 41.8 28.8 0.000 3800.0 3508.4 41.8 28.8 0.000 3900.0 3582.9 41.8 28.8 0.000 4000.0 3657.5 41.8 28.8 0.000 4076.0 3714.1 41.8 28.8 0.000 Page 4 op21-ww01 v3 p3.cfw;03-22-2012: LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 ScIoberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (Ib/gal) 714.0 11.50 8.39 SV-4 Siltstone 975.0 11.50 8.40 SV-3 Sandstone 1240.0 11.50 8.40 SV-2 Shale 1715.0 11.70 8.42 SV-1 Siltstone 1749.0 12.00 8.43 Permafrost Base Coal 2049.0 12.30 8.44 Ugnu Top(UG4) Stuck Point 2534.0 12.60 8.45 UG-2 Coal Bed Marker Sandstone 3270.0 12.70 8.50 Lower Ugnu Coal 3545.0 12.60 8.60 Schrader Bluff Top Shale 3600.0 12.60 8.60 N Seq.Top Sandstone 3656.0 12.60 8.60 N Top Sandstone 3711.0 12.60 8.70 N Bottom Sandstone 3770.0 12.60 8.70 N Seq Base Sandstone 3865.0 12.50 8.70 OA Top Sandstone 3877.0 12.50 8.70 OA-2 Top Sandstone 3890.0 12.50 8.70 OA-3 Top Sandstone 3908.0 12.50 8.70 OA-4 Top Sandstone 3918.0 12.50 8.70 OA Bottom Sandstone 4076.0 12.50 8.70 TD Shale Page 5 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 ScrIoberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1872.8 32 0.6 4076.0 3714.1 50 0.8 degF ft 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 o I I I I I I I I I 0 o- tn _ o- - 0 - 8- N on - Geoth.Profile o - -Tubular Fluids OAnnulus M O - O Lo- c." O - O_ mr O O _ O Ln - 'd - Temp. Profile At 195 min Page 6 op21-ww01 v3 p3.cfw;03-22-2012, LoadCase V2 Surface Casing Contingency,Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 SckIrger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface,Arctic Set 1 Tail to 100 ft.above the perfs. Original fluid Mud 9.60 lb/gal k: 5.41E-4 Ibf.s^n/ft2 n :0.975 Ty: 17.24 Ibf/100ft2 Displacement Volume 281.2 bbl Total Volume 853.2 bbl TOC 0.O ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:6.58E-2 Ibf.s^n/ft2 n:0.291 Ty:6.34 Ibf/100ft2 Lead Slurry 390.0 1531.5 10.70 k:1.16E-1 Ibf.s^n/ft2 n:0.254 Ty:0.48 Ibf/100ft2 Arctic Set 1 82.0 426.5 1531.5 15.70 k:3.00E-3 Ibf.s^n/ft2 n:0.905 Ty:0.83 Ibf/100ft2 Mud 281.2 0.0 9.60 k:5.41 E-4 Ibf.s^n/ft2 n:0.975 Ty:17.24 Ibf/100ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2008 psi at 1878.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 42 ton Check Valve Diff Press 195 psi Page 7 op21-ww01 v3 p3.cfw.03-22-2012. LoadCase V2 Surface Casing Contingency,Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 S hlumbcrgcr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Section 3: pumping schedule Start Job: Circulate 5-8 BPM Minimum If unable to circulate with full returns at a minimum 5 BPM, we will need to redesign the job to adjust for lower parameters. 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 5.0 0.0 80 Swap to Cement 5.0 0.0 80 Weight Up Tub Lead Slurry 5.0 390.0 78.0 390.0 80 Mix&Pump Lead Slurry Arctic Set 1 4.0 82.0 20.5 82.0 80 Mix&Pump Tail Slurry 5.0 0.0 80 Drop Top Plug Mud 5.0 10.0 2.0 10.0 80 Kick Out Plug Pause 0.0 0.0 5.0 0.0 80 Line Up Rig Pumps Mud 5.0 271.2 54.2 281.2 80 Displace to 100' Above Perfs Shut-In 0.0 0.0 1220.0 0.0 80 HOLD PRESSURE. Total 03:14 hr:mn 853.2 bbl End Job: HOLD FINAL PRESSURE FOR ATLEAST 4 HRS, then bleed off, if bleed off is more than 1 bbl or does not appear to be slowing down, shut in and repeat in 2 more hours, until cement sets. Dynamic Security Checks : Frac 4 psi at 160.0 ft Pore 10 psi at 160.0 ft Collapse 2008 psi at 1878.0 ft Burst 4794 psi at 0.0 ft Temperature Results BHCT 57 degF Simulated Max HCT 77 degF Simulated BHCT 76 degF Max HCT Depth 1807.4 ft CT at TOC 69 degF Max HCT Time 02:44:38 hr:mn:sc Static temperatures : At Time (hr:mn) 20:20 hr:mn Geo.Temp. Top of Cement (degF) 37 degF 20 degF Bottom Hole (degF) 61 degF 33 degF Page 8 op21-ww01 v3 p3.cfw,03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 Scklkrger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency ECD simulated at anticipated Perforation depth: Depth= 1958 ft N O ' N Hydrostatic �o Dynamic Frac 7t. 7 • Q L O O O ca t!7_ 0 30 60 90 120 150 180 210 Time (min) Page 9 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 3ekI bet it String : Surface Casing District : Prudhoe Bay,Alaska y Country : US Loadcase : V2 Surface Casing Contingency BHCT CementTemperature Simulation: 0 co First Sack Temp. Last Sack Temp. a0 -N oo f` M LL � O a (fl_ N- -dO Y N O f0 � a 1-(D r- -co co 0 30 60 90 120 150 180 210 Time(min) Page 10 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 Sekliaberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Temperature Ramp over 24 Hours: co First Sack Temp. � 0 Last Sack Terrp. r O_ co -N co _ r M LL _ N O 73 O O O Y I Ir U as N 0 as a- 1-CD N_ ir- O_ ti co co i i I T i T O 0 250 500 750 1000 1250 1500 1750 Time(min) Page 11 op21-ww01 v3 p3.cfw:03-22-2012: LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 Client : Eni Petroleum Well : OP21-WW01 SchIberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : V2 Surface Casing Contingency Surface Pressure Model: 0 Calc.Pump Ress. Calc.CemHP o1 tn- M o- M N N gCL x 0 - o 0 30 60 90 120 150 180 210 Time (min) Page 12 op21-ww01 v3 p3.cfw;03-22-2012; LoadCase V2 Surface Casing Contingency;Version wcs-cem471_02 ith'ket;f-chu.9- oPZ I -cilwa Pn Regg, James B (DOA) z-‘0107(:) From: Longo Joseph [joe.longo @enipetroleum.com] Sent: Thursday, March 22, 2012 6:07 PM To: Schwartz, Guy L (DOA) Cc: Borri Luca; Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: OP21-WW01 Remedial Action Attachments: 120322 OP21-WW01 Plan Forward.pdf; OP21-WW01 Surface Surveys.xls; 120322 OP21WW01 Schematic .pdf Guy, I have attached our plan forward along with a schematic and survey. If you have any questions please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo @enipetroleum.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, March 22, 2012 4:15 PM To: Schwartz, Guy L(DOA); Longo Joseph Cc: Borri Luca; Regg, James B (DOA); steve.davies @alaska.gov Subject: RE: OP21-WW01 Remedial Action Joe, Forgot to mention I will be out of town this weekend. Jim Regg will be my alternate for the next couple days. Had a thought since we last talked.... Make sure part of your procedure includes pressure testing the 13 3/8" casing above the pert holes. Once you drill past the perfs and before hitting the bottom retainer a LOT/FIT must be done to your new calculated minimum value. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Thursday, March 22, 2012 3:43 PM To: 'Longo Joseph' Cc: Borri Luca; Regg, James B (DOA); Davies, Stephen F (DOA) (steve.davies @alaska.gov) Subject: RE: OP21-WW01 Remedial Action Joe, Plan so far is acceptable.... Get me a full plan as soon as you can. You will need a sundry ( Change of operation) once the basic plan is outlined. I can get you a verbal once I have that in place. Guy Schwartz Senior Petroleum Engineer AOGCC 1 793-1226 (office) 444-3433 (cell) From: Longo Joseph [mailto:joe.longo(aenipetroleum.com] Sent: Thursday, March 22, 2012 3:10 PM To: Schwartz, Guy L (DOA) Cc: Borri Luca Subject: OP21-WW01 Remedial Action Guy, I have a meeting to attend but I wanted to give you an overview of our plan forward. I will follow it up with a more detailed package later today. Currently we are rigging up to set a cement retainer above the top of the float collar. We will then run in the hole with a 3-3/8" perforation gun on WL and perforate a 3 foot interval at 6 spf for 18 total shots. We will then attempt to gain circulation. If all goes well we will commence our cement job as planned bringing cement returns to surface. Below is the intervals where we plan to set and perforate. If you have any questions please do not hesitate to ask. MD Ft below B/ Perm B/ Perm 1776 T/Jt3 '1920 144 Top Perf 1938 162 Btm Perf 1941 165 CR 1944 168 B!Jt. w y ' 5 ii°IN `183!!t4 FC 1959 183 Shoe 2040 264 Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo@aienipetroleum.com 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. 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 2 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. 3 0.4.,...rioLt Oliktok Point Nikaitchuq Field eno pekrroicun OP21 -WW01 Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD I TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0a 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A GR/Res Surface Csq Dir 13-3/8" 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor L-80,BTC 9.2-9.5 Lost Circulation Hole Cleaning Base Permafrost 1,776' 1,748' Top Perf 1,936' 1,907' Bottom Perf 1,939' 1,910' Cement Retainer 1,944' 1,915' cement retainer Float Collar 1,959' 1,931' FC 13-3/8"Casing Point 2,045' 2,015' . ` 16" 16"hole TD 4,127' 3,751' 50"F SPUD Sisk 0 no ( AN) urn 120322 OP21-WW01 Plan Forward.doc Operations Summary — 03/21/2012 to 03/22/2012 17:00 hrs: • Rig up GBR casing running equipment and TIH with 13-3/8" 68# L80 BTC casing to 2060' MD and break circulation at 250 gpm/ 270 psi. • Continue RIH to 2060' MD. Taking weight. Pull free with 270K. • Attempt to pump out of hole. Pull joint #53. Pull joint #52 15' and lose circulation. Pull 340K, regain circulation but pipe still stuck. • Attempt to maintain circulating and pull pipe free. • Circulation lost and pipe not moving. • Casing set at 2045' MD/ 2015'TVD. Current Operation/ Plan Forward Current Ops: • Currently rigging up Schlumberger cement head and Halliburton E-Line. Plan Forward: • Circulate casing volume prior to RIH with cement retainer. • RIH with cement retainer on E-Line to top of float collar set at 1959' MD. Get on depth and pull up to set cement retainer at 1944' MD (15' above float collar) and POOH. • Pump down casing to verify that retainer is set. o If retainer will not hold pressure call superintendent. • Pick up 3' 3-3/8" Millennium perforation guns. o 18 shots, 6 spf, 60° Phasing, 25 gm HMX. • TIH to perforation depth (bottom perforation 5' above cement retainer). o Perforation Interval: 1936' MD - 1939' MD • POOH perforation guns and RU to circulate through cement head. • Attempt to re-gain circulation. o Previous circulation rate: 42 gpm @ —800 psi. o If circulation is not possible contact Drilling Superintendent Immediately • If it is not possible to establish 5 bpm without losses contact Superintendent immediately as cement job will need to be re-evaluated. • Pump cement as per Schlumberger Program. o Lead: 390 bbl ASL o Tail: 82 bbl Arctic Set 1 • Drop top plug and displace with rig pumps. o Be sure to leave 100' of cement above the perforations. • Record cement to surface and estimated volume circulated to surface. • Hold FCP for at least 4 hr, then bleed off, if bleed off is more than 1 bbl or does not appear to be slowing down, shut in and repeat in 2 more hours, until cement sets. ..IL ,44; • Ein 11 �• (-tir s leu11 Ii .elli 120322 OP21-WW01 Plan Forward.doc Post Cement Job: • ND diverter and set emergency slips. • Cut casing and NU Vetco Gray well head and test to 5000 psi for 10 min. • NU BOP and test, Notify AOGCC 24 Prior to testing: o Rams and Choke Manifold: 5000/ 250 psi o Annular Preventer: 2500/ 250 psi • PU 12-1/4" BHA and TIH to top of cement • Test and chart casing to 2500 psi for 30 min. • Drill out cement in casing. • DO NOT drill out cement retainer • Conduct an FIT/ LOT across Perforation Interval. o Shut down if pressure rises past 14 ppg EWM and continue as per FIT guidelines. o If FIT/ LOT is less than 12 ppg EMW contact Drilling Superintendent and Drilling Engineer prior to moving forward. • Alert Drilling superintendent of results prior to drilling out cement retainer. • Drill out shoe track and clean out to 4127' MD. • Swap spud mud to LSND and drill ahead. Sc mMr r OP21-VWVO1 Drilling Survey Report (Non-Def Survey) Report Date: March 21,2012-10:19 PM Survey/DLS Computation: Minimum Curvature/Lubinski Client: ENI Vertical Section Azimuth: 31.955°(True North) Field: Nikaitchuq Vertical Section Origin: 0.000 ft,0.000 ft Structure I Slot: Oliktok Point/OP21 TVD Reference Datum: Rotary Table Well: OP21-W W01 TVD Reference Elevation: 53.820 ft above MSL Borehole: OP21-W W01 Seabed/Ground Elevation: 12.200 ft above MSL UWI/API#: Unknown/50-029-23447-00-00 Magnetic Declination: 20.878° Survey Name: OP21-WW01 Drilling Total Field Strength: 57847.082 nT Survey Date: February 23,2012 Magnetic Dip Angle: 81.042• Tort/AHD/DDI/ERD Ratio: 87.954°/1379.141 ft/5.125/0.368 Declination Date: February 23,2012 Coordinate Reference System: NAD27 Alaska State Plane,Zone 04,US Feet Magnetic Declination Model: BGGM 2011 Location Lat/Long: N 70°30'39.17341",W 149°51'51.25142" North Reference: True North Location Grid N/E Y/X: N 6038490.590 PLUS,E 516590.970 PLUS Grid Convergence Used: 0.000° CRS Grid Convergence Angle: 0.12798494° Total Corr Mag North->True 20.676° North: Grid Scale Factor: 0.99990031 Local Coord Referenced To: Well Head MD Inc! Azim True DLS VSEC NS EW TF Tray Cyl Dist Ct.Tray Cyl Azim- Comments (ft) (°) (•) (°l1 OOft) (ft) (R) (ft) (•) Ct North Survey Tool Ift1 1.1 RTE 0.00 0.00 183.00 N/A 0.00 0.00 0.00 232.8M 0.00 N/A TYRO-MWD-Depth Only 138.18 0.12 232.80 0.09 -0.14 -0.09 -0.12 177.02M 0.14 232.80 3LB_GYRO-MWD 183.85 0.50 177.02 1.73 -0.25 -0.22 -0.13 184.53M 0.25 211.25 3LB_GYRO-MWD 196.07 1.83 164.53 4.18 -0.72 -0.85 0.01 157.46M 0.85 179.08 OLB_GYRO-MWD 208.50 2.06 157.46 3.18 -0.94 -1.19 0.13 183.51M 1.19 173.74 3LB_GYRO-MWO 238.35 2.96 163.51 2.94 -1.82 -2.50 0.58 170.21M 2.57 168.89 3LB_GYRO-MWD 267.32 3.55 170.21 2.42 -2.98 -4.10 0.95 185.91M 4.17 167.03 3LB_GYRO-MWD 294.87 3.93 165.91 1.71 -4.27 -5.88 1.32 166.5M 5.75 167.48 3LB_GYRO-MWD 325.17 4.42 168,50 1.62 -5.81 -8.00 1.85 167.08M 7.48 187.393LB_GYRO-MWD 355.60 4.58 187.08 0.55 -7.50 -10.33 2.39 169.44M 9.14 187.58 3LB_GYRO-MWD 416.10 5.56 169.44 1.66 -11.37 -15.58 3.47 2.61R 11.60 169.093LB_GYRO-MWD 477.19 6.42 169.79 1.41 -18.08 -21.83 4.62 4.92L 12.80 171.843LB_GYRO-MWD 539.25 8.07 188.78 2.67 -21.83 -29.52 8.08 67.72L 13.10 175.42 3LB_GYRO-MWD 566.19 8.48 162.75 3.58 -24.51 -33.27 7.04 23.36R 12.96 176.37;LB_MWD+GMAG 600.17 9.87 186.21 4.40 -28.18 -38.49 8.48 8.73L 12.88 177.383LB_GYRO-MWD 695.63 12.50 164.35 2.78 -40.85 -58.39 13.21 14.86R 11.57 182.44 iLB_MW0+0MAG 758.01 13.95 185.94 2.40 -50,63 -70.19 18.86 17.9L 10.21 188.511LB_MWD+GMAG 790.78 14.55 185.17 1.92 -56.19 -78,00 18.87 25.33L 9.28 193.90 iLB_MWD+GMAG 855.50 18.20 182.40 2.79 -67.61 -94.46 23.69 53.14L 6.90 209.04 lLB_MW0+0MAG 918.76 17.93 155.43 4.23 -78.71 -111.73 30.40 50.42L 4.88 215.931LB_MWD+GMAG 982.24 18.45 153.48 1.26 -89.35 -129.61 38.95 168.73L 4.60 18828 iLB_MWD+GMAG 1078.53 14.74 150.56 195 -103.19 -153.92 51.78 136.07L 6.95 180.56 lLB_MWD+GMAG 1173.82 12.21 137.56 4.13 -111.71 -171.92 64.54 175.16L 8.68 144.44 lLB_MWD+GMAG 1269.83 9.61 13624 232 -116.42 -185.20 76.94 168.57L 10.22 136.27;LB_MWD+GMAG 1386.64 8.15 134.15 1.54 -119.86 -195.82 87.45 98.85L 11.98 144.77;LB_MWD+GMAG 1462.05 8.08 120.45 2.02 -121.11 -203.93 98.09 114.78M 14.67 151.041LB_MWD+GMAG 1556.95 6.89 114,78 1.47 -120.23 -209.89 109.01 138.89L 16.35 150.01 iL6_MWO+GMAG 1653.71 8.10 107.92 1.14 -118.26 -213.71 119.17 132.99L 16.75 148.14 iLB_MWD+GMAG 1747.53 5.27 97.07 1.44 -115.23 -215.77 128.19 82.15L 15.93 144.79iLB_MWD+GMAG 1843.25 5.68 81.68 1.59 -110.32 -215.83 137.24 69.78L 14.17 135.50iLB_MWD+GMAG 1939.18 8.68 64.78 2.15 -102.56 -212.58 146.98 29.47L 12.74 118.041LB_MWD+GMAG 2038,09 8.88 57.00 2.51 -91.05 -208.09 158.36 38.45L 12.90 98.24;L9_MWD+GMAG 2132.18 10.61 49.87 2.19 -75.91 -196.35 171.34 36.3L 13.91 86.961LB_MWD+GMAG 2226.90 13.24 41.82 3.28 -56.92 -182.64 185.24 13.77L 14.62 77.901LB_MWD+GMAG 2323.25 16.29 39.17 3.24 -32.64 -163.93 201.14 41.92L 15.79 68.32■LB_MWD+GMAG 2419.28 17.71 35.10 1.93 -4.69 -141.54 218.05 1,8R 16.38 60.911LB_MWD+GMAG 2514.80 21.15 35.40 3.80 27.03 -115.60 238.39 13.63L 16.70 55.471LB_MWD+GMAG 2609,67 24.48 33,47 3,58 63.76 -85.28 257.14 6.1R 18.18 51.01;LB_MWD+GMAG 2705.75 25,89 33.82 1.50 104.61 -51.24 279.79 11.12R 19.15 49.13iLB_MWD+GMAG 1 2800.82 28.28 34.81 2.56 147.85 -15.50 304.20 11.64L 19.07 52.841LB_MWD+GMAG 2897.48 32.11 33,33 4.04 196.42 24.78 331.40 13.04L 19.79 58.12 1B_MW0+0MAG 2993,04 35.07 32.14 3.17 249.28 69.26 359.96 32.91L 21.35 61.18iLB_MW0+0MAG 3088.93 40.31 27.02 6.36 307.78 120.27 388,74 24.21R 23.56 56.13 iLB_MW0+0MAG 3185.52 40.79 27,35 0.54 370.36 176.12 417.43 140.3R 25.26 48.201LB_MWD+GMAG 3278.58 39.61 28.90 1.66 430.27 229.09 445.73 94.6R 23.15 47.93/LB_MW0+0MAG 337429 39.57 29.74 0.56 491.21 282.28 475.60 5.47L 19.88 53.081LB_MWD+GMAG 3489.47 40.04 29.67 0.50 552.10 335.20 505.79 21.25R 17,37 60.67 iLB_MWD+GMAG 3565.82 41.58 30.57 1.71 615.03 389.66 537.40 82.19L 18,83 68.12lLB_MWD+GMAG 3861,38 41.71 2923 0.94 678.49 444.71 589.05 188.49R 17.42 71.99 iLB_MWD+GMAG 3756.99 41.45 29.31 0.28 741.87 500.06 600.07 8.55L 17.50 74.26 1B_MWD+GMAG 3853.51 41.76 29.24 0.32 805.89 555.97 831.41 HS 17,85 76.44;LB_MWD+GMAG 3948.75 42.91 29.24 1.21 869.96 611.93 662.74 170.46L 18.81 75.63 1B_MWD+GMAG 4044.82 40.96 28,74 2.06 934,07 868.08 693.88 HS 18.91 75.771LB_MWD+GMAG Proj.to Bottom. 4127.00 40.96 28.74 0,00 987.88 715.32 719.76 18.06 78.62 SLB_UNKNOWN Survey Type: Non-Def Survey Survey Error Model: ISCWSA Rev 0°""3-D 95.000%Confidence 2.7955 sigma Survey Program: Description MD From MD To EOU Freq Survey Tool Type Borehole I Survey Ift1 (ft (ft) 0.000 41.420 Act Stns SLB_GYRO-MWD-Depth Only OP21-WW01/OP21-WW01 Drilling 41.420 41.420 Act Stns SLB_GYRO-MWD-Depth Only OP21-WW01/OP21-WW01 Drilling 41.420 160.000 Act Stns SLB_GYRO-MWD OP21-WW01/OP21-WW01 Drilling 160.000 539.250 Act Stns SLB_GYRO-MWD OP21-W W W01/OP21- W01 Drilling 539.250 566.190 Act Stns SLBMWD+GMAG OP21-WW01/OP21-WW01 Drilling 566.190 600.170 Act Stns SLB_GYRO-MWD OP21-WW01/OP21-WW01 Drilling ■ 800.170 4044.820 Act Stns SLB_MWD+GMAG OP21-WW01/OP21-WWO1 Drilling 4044.820 4127.000 Act Stns SLB_UNKNOWN OP21-WW01/OP21-WW01 Drilling , Drilling Office 2.5.1100.0 Nikaitchuq\Oliktok Point\OP21-VVW01\OP21-WW01\0P21-WW01 Drilling 3/23/2012 8:47 AM Page 1 of 1 'U; 14-- t . Up2 I- (4,o 001 Zing70 Regg, James B (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 22, 2012 7:50 PM 3 f 23Jty To: Longo Joseph Cc: Borri Luca; Regg, James B (DOA); Davies, Stephen F (DOA) Subject: Re: OP21-WW01 Remedial Action Joe, You have verbal approval to cement surface casing as outlined below. A 10-403 must be submitted as soon as possible. It also appears an Administrative Approval will be needed as CO 639 specifies surface casing be set at least 500 ft below permafrost. Please contact Jim in that regard tomorrow . Guy Sent from my iPhone On Mar 22, 2012, at 6:07 PM, "Longo Joseph" <joe.longo@enipetroleum.com> wrote: Guy, I have attached our plan forward along with a schematic and survey. If you have any questions please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.LongoOenipetroleum.com From: Schwartz, Guy L (DOA) [mailto:•u .schwartz ' alaska.•o Sent: Thursday, March 22, 2012 4:15 PM To: Schwartz, Guy L(DOA); Longo Joseph Cc: Boni Luca; Regg, James B (DOA); steve.davies ' . :ska.•ov Subject: RE: OP21-WW01 Remedial Action Joe, Forgot to mention I will be out of town this ' eekend. Jim Regg will be my alternate for the next couple days. Had a thought since we last talked.... Make sure part of your procedure includes pressure testing the 13 3/8" casing above the pert holes. Once you drill past the perfs and before hitting the bottom retainer a LOT/FIT must be done to your new calculated minimum value. Guy Schwartz Senior PetroleumEngineer AOGCC 793-1226 (pffice) 444-343 '(cell) 1 ..c7-AdI r 60 z 1 - kotte4-0 1. 1 24c ) 87 jzz/i z.. :1 . k3 ,,,, -',- . ,.. , ... ..- • i` . . A , i / -I - \ 1 ... 1414114 , 1 Li i ,\, Pt.co.Aou.Ar it -----1 t;'; :. 0 (..,1 - 4 it SI* c.- ■I„. .. 4' '.' X04) -- 7/ / 3 4 if L—............_4 ' '- c 4-g slit,It, ,.. o4 ? 1 c:)4) ■ il OD° Ad 111 ii\\, 'S\k/1 e I SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Crive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Undefined Pool, OP21-WW01 ENI US Operating Co. Inc. Permit No: 210-187 Surface Location: 3138' FSL, 1690' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 1758' FSL, 4426' FEL, SEC. 33, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair � DATED this `3 day of January, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) -STATE OF ALASKA EIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 2 2010 PERMIT TO DRILL 20 AAC 25.005 Maska cs i Ofis Cons Commission la.Type of Work: 1 b. Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1c.Specif jj rappposed for: Drill El Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply 0 Multiple Zone ❑ Coalbed Gas IC Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • OP21-WW01 3.Address: 6.Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 10788' • TVD: 9453' • Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3138 FSL 1690 FEL S5 T13N R9E UM ADL 355024,373301,390616,390615 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1590 FSL 4535 FEL S33 T14N R9E UM ADL 417493 2/23/2011 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 1758 FSL 4426 FEL S33 T14N R9E UM 1280 1758'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 53.2 feet 15.Distance to Nearest Well Open Surface:x- 516591. y- 6036491 . Zone- 4 GL Elevation above MSL: 12 feet to Same Pool: 3366'Nwto OP23-wwo2 16.Deviated wells: Kickoff depth: 800 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 36° degrees Downhole: 4638 psig Surface: 3711 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 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 4065 35 35 4100 3714 889 sx 10.7#ASL,228 sx 12.5#Deeperete 12.25" 9-5/8" 47 L-80 BTCM 7767 33 33 7800 6674 391 sx 15.8#Class G 8.5" 7" 26 13CrL80 Vam Top 3188 7600 6513 10788 9453 479 sx 15.8#Class G 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 is BOP Sketch el Drilling Program IN Time v.Depth Plot ❑ Shallow Hazard Analysis E Diverter Sketch 111 Seabed Report ❑ Drilling Fluid Program el 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maurizio//`Gr�andi Title Well Operation Project Manager Signature /l CL- ` Phone Date 1? '9• to Commission Use Only Permit to Drill API Number. ��� rmrt Ap oval See cover letter for other Number: Z/C' (2 50-0L. 2�JJe)" `�' � 1`�1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce albed methane,gas hydrates,or gas contained in shales: [ Other: 1""SOCO ps., /3 ° /Ls r• Samples req'd: Yes ❑ No" Mud log req'd: Yes ❑ No Re ---'�' H2S measures: Yes ❑ No 2/ Directional svy req'd: Yes [✓'No ❑ str (.✓Qi✓L1 �t. z ,44c Zs.03S" (k)CZ) I�i��r+ p AAc 25.2-GS Co) f��� APPROVED BY THE COMMISSION �"® DATE. ‘-- °''tea®-- • ,COMMISSIONER ' ) ,, (s.II �9� /0 , 1 ( . . i/. � 1> ( I ( 1i. Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(9)) Submit in Duplicate Af's D Petrolleum En11 REC4,,,�F[� 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 DEC 2 20 Maurizio Grandi Phone(907)865-3320 MSak9 Oil &Gas Corte. wGtlilTws inn Email: Maurizio.Grandi @enipetroleum.com An8419180i December 16,2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Water Source OP21-WW01 Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Permit to Drill for the onshore water source well OP21- WW01.The well will be drilled and completed using Nabors rig 245E. The planned spud date could be 2/23/2011 or could be moved later in 2011 depending on flowback testing and productivity of OP23- WW02(previously drilled and completed). Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Jason Brink at 907-865-3321. Sincerely, A / Maurizio Grandi Well Operation Project Manager toot • En8 Petroleum Oliktok Point OP21 - Nikaitchuq Field eno WW01 (P1 ) North Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO WL Logging MWD MD TVD CEMENT SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A Surface Csq Dir/PWD _ 10.7# 13-3/8" AS LITE 68 lbs/ft Wellbore Stability Mud Motor a,,, L-80,BTC 9.2-9.6 ppg Lost Circulation • `., Hole Cleaning KOP:800' 12.0# DeepCrete • • } Hole Angle / 36 13-3/8"Casing Point 4,100' 3,714' 16" 50°F SPUD , Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Motor 47 lbs/ft 9.6-10.0 ppg Hole Cleaning L-80,BTC-M /b 'c 9-5/8" /„ 47 lbs/ft vv 13Cr,Vam Top 15.8# Class G TOL 7,600' 6,513' Hole Angle <:3:■�: ∎.4 i 36 9.5/8"Casing Point 7,800' 6,674' 12-1/4" 95°F LSND Jurassic Wellbore Stability Lost Circulation Production Liner Hole Cleaning Sag D >: 15.8# !` 7" >!'Class 26 lbs/ft Motor T.i Ivishak 13Cr,Vam Top R3 10.0-10.5 ppg 6/Ivishaq 7"Liner Hole Angle 16 Proposed TD 10,788' 9,453' 8-1/2" 210"F MOBM tirosens• Enfl Petroleum Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 Application for Permit to Drill Document Water Source Well 0P21-WW01 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 6 Intermediate Hole Mud Program (LSND) 6 Production Hole Mud Program (MI VersaClean Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 10.Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 101215 OP21-WW01 PERMIT Document.doc Page 1 of 9 Printed: 17-Dec-10 • Enft Petirofleuirn Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 11.Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 7 12.Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) 7 13.Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 7 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 8 15.Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: OP21-WWO1 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item 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; 101215 OP21-WW01 PERMIT Document.doc Page 2 of 9 Printed: 17-Dec-10 • Enfl Petirolleum eni Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 Location at Surface 3138 FSL 1690 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates _ RKB Elevation 53.2'AMSL Northings 6036490.59 Eastings: 516590.97 Pad Elevation 12'AMSL Location at Top of Ivishak Sand Target 1590 FSL 4535 FEL S33 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10100 Northings: 6040227.25 Eastings:519005.27 Total Vertical Depth,_RKB: 8793 Total Vertical Depth, 55: 8740 Location at Total Depth 1758 FSL 4426 FEL 53.3 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10788 Northings: 6040395.04 Eastings: 519113.69 Total Vertical Depth, RKB: 9453 Total Vertical Depth, 55: 9400 Please see Attachment 7: Surface Platt and (D)other information required by 20 MC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (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 AAC 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 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration ✓ 4. Drilling Hazards Information Requirements of 20 AAC 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 101215 OP21-WW01 PERMIT Document.doc Page 3 of 9 Printed: 17-Dec-10 eni Petrofleuim En6 Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Sag River sand: The expected reservoir pressure is 0.55 psi/ft, or 10.5 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 formation: MPSP = (8433 ft TVD)(0.55 - 0.11 psi/ft) = 3711 psi Ivishak sand: The expected reservoir pressure is 0.51 psi/ft, or 9.8 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 formation: MPSP = (8791 ft TVD)(0.51 - 0.11 psi/ft) ,/ = 3516 psi (8)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 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 AAC 25.030(1) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; 101215 OP21-WW01 PERMIT Document.doc Page 4 of 9 Printed: 17-Dec-10 wits • Enid Petrolleurn Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 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) (1b/ft) Grade Connecti (ft) (ft) (ft) Cement Program on 20 178.89 X-65 Welded 124 36/ 36 1607 160' Cemented to surface Cemented to Surface with 889 sx 10.7#ASLite Lead Yield 4.33 cu. Ft./sk, 13-3/8 16" 68 L-80 BTC 4065' 35 / 35 4100'/ 3714' 228 sx 12.5# DeepCRETE Tail Yield 1.54 cu.ft./sk Cement Top plan @ 6800'MD Cemented w/391 sx 9-5/8 12-1/4" 47 L-80 BTCM 7767' 33 / 33 7800'/ 6674' 15.8#Class G Yield 1.16 cu.ft./sk 13 Cement Top plan @ 7600'MD 7" liner 8-1/2" 26 Chrome Vam 3188' 7600'/ 6513' 10788'/ 9453' Cemented w/479 sx 1/ L-80 Top 15.8#Class G Yield 1.16 cu.ft./sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP Configuration. / ENI requests that AOGCC waive diverter requirements per 20 MC 25.035. (h). (2). ✓ 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 101215 OP21-WW01 PERMIT Document.doc Page 5 of 9 Printed: 17-Dec-10 .___.._..... . . • Eno Petrolleum Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 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 9.6 Funnel Viscosity 250 250 150 200 (seconds) Yield Point 35 45 30 35 (lb/100 s0 Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 <6.0 <6.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Production Hole Mud Program (Ml VersaClean Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 10.0- 10.5 Density(ppg) 9.6 - 10.0 Plastic Viscostiy <23.0 Funnel Viscosity (CP) 45 - 60 (seconds) Yield Point 20 -25 Plastic Viscostiy 12 - 18 (lb/100 sf) (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 st) 200psi& 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical Stability 650-900 Chlorides (mg/I) <500 pH 9.0 - 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 101215 OP21-WW01 PERMIT Document.doc Page 6 of 9 Printed: 17-Dec-10 • EnA Petirolleum ��� Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. 2. Spud and directionally drill 16" hole to casing point at as per directional plan. Run Gyro and MWD tools as required for directional monitoring. -- W6 Di.x.- •- ( w+�je.0) 3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. Install and test wellhead to 5000 PSI. 5. Nipple up 13-5/8"5K BOP and test to 5000 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording - results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 5000 PSI. '' 11. Run and cement 9-5/8", 47# L80, BTC Mod casing. Pump cement and displace with mud, land casing hanger and bump plug. 101215 OP21-WW01 PERMIT Document.doc Page 7 of 9 Printed:17-Dec-10 • EMI PetiroHeuim enn Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 12. Install 9-5/8" packoff and test to 5000 psi. 13. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 15. PU 8-1/2" bit and directional drilling assembly including MWD, LWD, PWD. RIH, clean out cement to top of float equipment. 16. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording. fin - results. 17. Directionally drill 8-1/2" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 18. Run and cement 7", 26# 13CrL80, Vam Top Liner. 7" RA/A — :7 19. Liner hanger to be set with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. 20. Test casing and liner to 3000 psi and record. 21. Rig up E-line and perforate. 22. PU shrouded ESP completion as required and RIH to depth, before landing tubing spot corrosion inhibited IA brine throughout entire inner annulus. Land tubing seals and shrouded ESP. Pressure test IA to 1500 PSI -fo and record. Set BPV 23. Nipple down BOP, nipple up tree and test. Pull BPV. 24. Freeze protect well with diesel through shear out valve in tubing. 25. Set BPV and move rig off. 26. Rig up wire line unit. Pull BPV. • 27. Set dummy valve in mandrel. Use ESP to clean up well. • 28. Place well on production. • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). M (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 14.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: 101215 OP21-WW01 PERMIT Document.doc Page 8 of 9 Printed: 17-Dec-10 • Enft Petirolleurn Application for Permit to Drill Well OP21-WW01 Saved: 17-Dec-10 (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt • 101215 OP21-WW01 PERMIT Document.doc Page 9 of 9 Printed: 17-Dec-10 •��� OP21-WW01 (P1)Proposal Report Schlumberger (De(Plan) Report Date: October 07,2010-10:26 AM Survey I DLS Computation: Minimum Curvature/Lubinskl Client: ENI Vertical Section Azimuth: 32.995'(True North)0.000 ft,0.000 ft Structure l Slot: Oliktck Point/OP21 �'bi''tY 5 UdYTVD Refeentlt.Dau�m: Roary11abl MSL Wall: 0P21-W W 01 Borehole: DP21-W W 01 Fog Seabed I Ground Elevation: 12.2001t above MSL APM: 50020n,t000 Magnetic Declination: 25.538' Survey Name: OP21-W W e1(P1) Total Field Strength: 57476014 nT Survey Date: October 07,2010 Magnetic Dip Angle: 80836° Tort 1 AHD IDES 1 ERD Ratio: 56.863°1 4649 004 It/5 480 I 0.492 Declination Date: December 31,2001 God Coordinate System: NAD27 Alaska Slate Plane,Zone 04.US Feet Magnetic Declination Model: BGGM 2010 Location Let 1 Long: N 70°30'39.17 3411 W 149°51'51.15142" North Reference: True North Location Grid N/E WA: N 6036490.590 itUS,E 5165%070 BUS Grid Correction: 0 000° Grid Convergence Angle: 0.12798494° Total Corr Nag North->True North: 25.538° God Scala Factor: 099990031 Local Coord Referenced To: Well Heed MD Intl Azim True TV055 TVD VSEC NS EW TF DLS Directional Exclusion Zone Exclusion Zone Northing Eating Comments (ft) (') (°) (t) (t) (t) (t) (N) (°) (°noon)Dimculty Index Alert CRC (NUS) (BUS) RTE 000 000 3300 -5220 0.00 0.00 000 000 33M N/A 000 Alert 9.16 603649059 51659097 10000 000 3300 4710 10000 0.00 000 0.00 33M 000 000 Alert 9.16 603649059 51659017 20000 0.00 3100 147.80 20000 000 000 000 33M 0.00 000 Alert 9.16 6036490.59 51650097 30000 000 33.00 24760 300.00 000 000 0.00 33M 000 0.00 Alert 9.16 6036490.59 51659097 400.00 0.00 33.00 347.80 40000 0.00 0.00 000 33M 0 00 000 Alert 916 6036490.59 51659097 50000 000 3100 447.80 500.00 000 0.00 000 33M 0.00 0.00 Alert 9.16 6036490.59 51659097 60000 0.00 3100 547.80 60000 0.00 000 000 33M 000 0.00 Alen 9.16 6036490 59 518590.97 700.00 0.00 33.00 547.80 70000 000 0.00 0.00 33M 0.00 000 Alert 9.16 6036490.59 516590.97 KOP Bid 16/100 80000 0.00 3100 74710 69000 000 000 000 33M 000 000 Alert 9.16 603649069 516590.97 BId 2.5/100 900 00 150 33 00 64779 899.99 1.31 1.10 0.71 33M 1.50 0.29 Alert 7.68 603649109 51659108 100000 400 3300 94767 999.87 611 512 333 33M 2.50 119 Alert 522 603649572 51659428 1100.00 6.50 3300 1047.24 1099.44 15.26 12.80 8.31 MS 250 200 Fail 285 603650340 51659925 Gyro Pt 1200.00 0.00 3380 114632 1108.52 28.74 24.10 15.85 HS 250 2.41 Fail 1.1P 003851473 51860657 130000 1150 3300 1244.71 129691 4053 3103 25.34 MS 250 2.73 Fail 209 603652967 51661622 BId 0.5/100 1356.57 12.91 3300 130000 1352.20 58.49 4906 3115 HS 250 2.88 Fail 4.01 6036539.72 51662271 140000 1313 33.00 134212 1394.52 68.28 5727 37.18 HS 050 2.95 Fail 4.21 6036547.94 516628.02 1500.00 1363 3300 143660 149100 9142 7668 49.79 HS 0.50 3.10 Fell 4.70 8038567.37 516640.58 1600.00 14.13 33.00 153668 1588.88 11541 96.80 6285 HS 0.50 3.22 Alert 5.18 6036587.52 51665380 170000 14.63 33.00 163355 168575 14025 117.63 7638 HS 050 3.32 Alert 567 603660838 51666706 1800.00 15.13 3300 173019 178239 165.93 139.17 9016 HS 050 140 Alert 6.16 603662695 51668101 BId 2.5000 187238 1549 33.00 180000 1852.20 18505 155.20 100.77 45 050 346 Alen 651 603664600 51669138 1900 00 16 18 3100 1826.57 1878.77 192.59 161.53 104.88 HS 250 350 Alert 7.19 603665233 516895 47 200000 1868 3300 1921.97 1974.17 222.54 186.65 121.19 HS 2.50 3.62 Alert 967 603667749 516711.73 210000 21.18 3300 201597 2068.17 25663 215.24 139.75 HS 2.50 174 1215 6036706.12 516730.23 2200 00 2168 33 00 210840 2160.60 204.79 247.25 160.53 HS 2.50 365 1464 603673117 516750.94 2300.00 26.18 3300 2199.07 2251.27 33695 28260 183.49 HS 2.50 195 17.14 603677157 51677181 2400.00 2668 3100 228782 2340.02 383 02 321.24 208.58 HS 2.50 4.05 19.63 6036812 26 516798.81 250000 31.18 33.00 2374.47 242607 43291 363.09 235.75 HS 2.50 4.14 22.13 6036854.17 51682588 260000 33.68 3100 2458.87 251107 48654 408.07 264.95 HS 250 4.23 24.62 603689921 516854.98 2700.00 36.18 3300 254084 2593.04 54380 456.09 296.13 HS 2.50 4.31 27.12 6036947.30 516886.05 E.W BId 2727.19 3686 3300 2562.64 261489 55998 469.66 30465 HS 250 4.33 27.80 6036960.89 51689483 2800.00 36.86 3300 262094 2673.14 60366 506.30 328.73 HS 0.00 4.37 27.80 603699257 51691154 2900.00 36.86 33.00 270095 2753.15 663.65 556.62 36140 HS 000 441 27.80 6037047.95 516951.09 3000.00 3615 33 DO 278096 2833.16 723.64 806.93 394.07 HS 0.00 4.45 27.80 6037098.34 51698164 310000 36.86 33.00 2860.98 2913.16 783.63 657.25 426.74 HS 000 4.49 27.80 6037148.72 517016.20 3200.00 3686 33.00 294097 2993.17 84162 707.56 459.41 HS 000 452 27.80 6037199.10 51704875 3300.00 3616 33.00 302098 3073.18 90161 757.88 492.08 HS 000 4.55 27.80 603724949 51708110 3400.00 3616 33.00 310096 315118 96361 808.19 524.75 HS 000 458 2780 603729917 517113.86 3500.00 36166 3300 3180.99 3233.19 1023.60 858.51 55742 HS 000 4.61 27.80 603735025 51714641 3600.00 36.86 33.00 3261.00 3313.20 1083.59 90182 590.09 HS 000 4.64 2280 603740064 517178.96 3700.00 36.86 33.00 334100 3393.20 1143.56 95614 622.75 HS 000 4.66 2780 6037451,02 517211.52 • 3800.00 36.86 3100 342101 347121 120357 100946 655.42 HS 0.00 4.69 2710 603750140 51724407 • 3900.00 3086 3100 3501.02 3553.22 1263.56 105677 688.09 HS 0.00 4.71 2780 6037551.79 51727662 4000.00 38.86 3100 358102 3033.22 1323.55 1110.09 720.76 HS 0.00 4.73 2780 6037602.17 51730618 410000 3616 3100 3661.03 371123 1383.54 1160.40 753.43 HS 000 4.75 27.80 603765255 517341 73 420000 3686 3300 374104 379124 1443.53 121072 786.10 HS 0.00 4.77 2780 6037702.99 51737428 4300 00 36.86 33 00 382104 387324 1503.53 1261.03 818.77 HS 0.00 4.79 2780 603775132 517406.84 4400.00 3086 33.00 390105 3953.25 156352 131135 85144 HS 000 4.81 27.80 6037803.70 51743639 4500.00 36.85 33 00 398106 403126 1623.51 136168 88411 HS 000 4.82 27.80 6037854.09 517471.94 4600.00 3186 3300 4061.06 1113.28 188350 141198 916.70 HS 000 4.84 27.80 603790447 51750450 470000 36.86 3300 4141.07 4193.27 174349 146230 949.44 HS 0.00 4.86 2710 6037954.85 517537.05 480000 36.85 3300 4221.08 427128 100348 151261 982.11 HS 000 4.87 2710 603800624 51756980 490000 3686 3300 4301.08 4353.28 186347 1562.93 1014.78 HS 0.00 4.89 27.80 603805562 517602.16 500000 36.86 3300 4381.09 4433.29 1923.46 1613.24 1047.45 HS 0.00 4.90 2710 6038106.00 51763421 510000 3686 3300 4461.10 451310 198345 1663.56 1080.12 HS 0.00 4.92 27.80 603815639 517667.26 5200.00 3686 3300 4541.10 4593.30 2043.44 171387 111228 HS 0.00 4.93 2710 803820677 51769982 13-318'Gsa 520837 3686 33.00 4547.80 4800.00 204846 171888 111552 HS 0.00 4.93 27.80 003821000 517702.54 530000 3186 3300 4621.11 487131 2103.44 1764.19 114546 HS 0.00 4.94 27.80 6038257.15 51773237 5400.00 3186 33.00 4701.12 4753.32 2163.43 1014.50 1178.13 HS 000 4.96 27.80 6038307.54 517764.92 550000 36.86 3100 478112 4833.32 222342 186482 1210.80 HS 0.00 4.97 27.80 603835762 51779748 580000 3186 3300 4861.13 491333 226341 191614 124347 HS 0.00 498 27.80 603840830 51783003 5700.00 36.86 3100 4941.14 4993.34 234340 196545 127614 HS 0.00 4.99 27.80 603845169 517862.58 5800.00 3686 3300 502115 5073.35 240339 201577 1308.60 HS 000 501 2280 803850607 517895.14 • 590000 36.86 33.00 5101.15 515315 246318 2068.08 134147 HS 0.00 502 27.80 603855945 517927.69 600000 3686 3100 518116 5233.36 252337 211640 1374.14 HS 000 503 27.80 6030609.84 51795024 6100.00 3696 33.00 5261.17 5313.37 258136 2166.71 140681 65 0.00 604 27.80 603888022 51799280 620000 36.86 33.00 5341.17 539337 264315 221703 143948 05 000 5.05 27.80 6038710.60 51802635 630000 3686 3300 5421.18 5473.38 270135 226714 1472.15 HS 0.00 506 27.60 6038760.99 518057.90 640000 36.86 33.00 5501.19 5553.39 276134 2317.66 1504.82 HS 0.00 607 27.80 6038811 37 518090 46 6500.00 36.86 3300 5581.19 563319 282133 236718 153749 HS 000 508 27.81 8038861.75 518123.01 660000 36.86 33.00 - 5661.20 5713.40 2883.32 241129 157016 HS 000 609 2781 6038912.14 51815556 670000 3686 3100 5741.11 5793.41 294131 2468.61 1602.83 HS 0.00 5.10 2781 603896252 518188.12 6800.00 3686 33.00 582121 587341 3003.30 251192 1635.50 05 0.00 611 27.81 603901260 518220.67 6900.00 36.86 3300 5901.22 5953.42 306129 156924 166116 HS 0.00 5.12 2781 603906329 51825122 7000.00 3686 3300 598123 6033.43 312128 261955 170083 HS 000 5.13 2711 6039113.67 51828576 7100.00 3616 3300 6061.23 611343 318127 266987 173150 HS 0.00 5.13 2701 603916405 51831833 7200.00 36.86 3300 6141.24 619344 3243.27 2720.18 1766.17 HS 0.00 5.14 2711 603921444 51835088 730000 3186 3300 6221.25 627345 3303.26 2770.50 179884 HS 000 5.15 2781 603926482 518383 44 7400.00 3686 33.00 6301.25 6353.45 3363.25 2620.82 1831.51 HS 000 5.16 27.81 603931520 518415.99 7500.00 3686 3100 6381.26 643346 3423.24 287113 1864.18 HS 000 117 27.81 6039365.59 51844854 760000 38.86 33.00 6461.27 6513.47 3483.23 2921.45 1896.85 HS 0.00 618 27.81 603941597 518481.10 7700.00 36.86 3300 6541.27 6593.47 354122 2971.76 192652 65 000 518 27.81 603946615 51851365 780000 36.86 3300 8621.28 6673.48 360121 302208 1962.19 HS 000 5.19 27.81 603951174 51854620 790000 3686 33.00 870129 675349 3663.20 307219 1994.86 HS 000 5.20 27.81 6039567.12 518578.76 Target 796626 3686 33.00 6753.50 680670 3702.35 310523 2016.18 LS 000 5.20 27.81 6039600.00 51860000 8000.00 3600 33.00 6761.45 683365 372218 312253 2027.41 L5 2.50 622 2694 603961712 51861119 8100.00 33.50 33.00 686161 6915181 377997 317013 2058.44 LS 250 525 2444 603966619 51864212 8200.00 3100 33.00 6948.18 7000.311 383332 321507 2087.50 LS 250 5.28 2195 603970999 518671.07 8300.00 28.50 3300 7035.00 7087.20 388293 3256.68 2114.51 LS 250 5.31 19.45 603975106 518697 99 840000 2600 3300 7123.90 7176.10 392171 329508 2139.44 LS 2.50 5.34 1696 6038790.10 518722.83 8500.00 23.50 33.00 721471 7266.91 3970.56 3330.18 2162.23 LS 2.50 637 1446 603982625 51874654 860000 2100 33.00 7307.26 7359.46 4008.41 3361.93 218285 LS 2.50 539 1167 603985704 518766.08 870000 18.50 3100 740137 7453.57 404220 3390.26 2201.24 LS 2.50 642 Alert 949 603988542 51878441 8765.26 1055 33.00 7463.55 751675 4062.01 3406.88 2212 03 HS 2.50 5.43 Alert 7.87 6039902.06 518795.16 880000 16.86 3100 7496.80 7549.00 407209 3415.34 2217.52 HS 000 543 Alert 717 603991052 51880063 890000 1686 3100 7592.50 7644.70 4101.10 343167 223132 HS 0.00 543 Alert 787 6039934.89 516816.37 900000 1886 33.00 7688.20 774040 413011 3464.00 224612 HS 0.00 644 Alert 787 6039959.25 518832.12 9100.00 1686 33.00 778190 7836.10 415612 3488.33 2264.91 05 0.00 544 Alert 787 6039983.61 518847.86 920000 1686 33.00 7879.60 7931.80 4188.13 351266 2280.71 HS 000 5.44 Alen 717 604000298 518863.60 9300.00 16.88 3300 7975.29 802740 4217.14 353699 2296.51 HS 0.00 5.44 Alert 7.87 604003214 51887934 940000 1086 33.00 8070.99 8123.19 4246.15 356132 231231 HS 0.00 645 Alert 7.87 604005670 518895.08 9500.00 1616 33.00 816689 821819 4275.16 3585.65 2328.10 HS 0.00 645 Alert 717 6040081.07 51891012 960000 16.86 33.00 8282.39 8314.59 4304.16 360998 2343.90 HS 000 645 Alert 787 6040105.43 51892656 970000 1686 33.00 835809 841029 4333.17 363411 235670 HS 0.00 545 Alert 7.87 604012979 51894231 980000 1686 3100 8453.79 850599 4362.18 365864 2375.50 HS 000 546 Alert 767 6040154.16 518958.05 990000 1686 33.00 854949 860169 4391.19 368297 2391.29 HS 0.00 5.46 AIM 7.87 6040178.52 518973.79 1000000 1686 3100 8645.19 8697.39 4420.20 370730 240209 HS 000 546 Alert 7.87 6040202.88 51898953 1010000 16.86 33.00 874019 8793.09 4449.21 373163 242289 HS 0.00 546 AIM 787 6040227.25 519005.27 10200.00 1686 3300 8836.59 8888.79 4478.22 3755.96 243809 HS 000 647 Alert 717 604025161 51902101 Exclusion Zone MD Incl Azim True TVDSS TVD VSEC NS EW TF DLS Directional Exclusion Zone Northing Existing Comments (N) C) C) (N) (N) (fl) (tt) (8) C) (vt66N)Difficulty Index Alert Angle (NUS) (NUS) CI 10300 00 1686 33 00 8932 29 8984 49 4507.23 3780.29 2454 48 HS 0 00 5 47 Alert 7 87 6040275.97 519036 75 10400 00 16.86 33 00 9027.99 9080.19 4536 24 3804 62 2470 28 HS 0.00 5 47 Alert 7.87 6040300 34 519052.50 9-5/8'Cso 1042070 16.86 3300 904780 9100.00 4542.24 3809.86 2473.55 HS 0.00 5.47 Alert 787 8040305.36 51905575 1050000 1686 3300 912369 917589 4565.25 382896 248608 HS 000 547 Alen 7.87 6040324.70 519068.24 1060000 1686 3300 921939 9271.59 459426 3853.29 2501.88 HS 000 548 Alen 7.87 604034906 519083.98 1070000 1686 33.00 931509 9367.29 462327 3877.62 251767 HS 0.00 548 Alert 787 604037343 519099.72 TD 1076E 72 1686 33 00 9400 00 9452 20 464900 3899 20 2531 69 0.00 5 48 Alert 7.87 6040395.04 519113 69 N O C? 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WC O E m @2 2 c Y m c U a m t >•>• (O,) O -N0YO, VO-HJ (00)0)/) a1-F- NN ❑ If* 2 n• Schlumberger WELL FIELD STRUCTURE OP21-WW01 (P1b) Nikaitchuq Oliktok Point MagnetK Paramotors Surface Location NAD27 Alaska State Rare.Zone 04.US Feet Miscellaneous Modal BGGM2010 Dip. 80800° �.i, Apnl of LaL N 703039.173 Northing' rry.. 6036490.59 PUS Grid Co 0.12798494` Slot OP21 ND Ref Rotary Tabb(52.211 above MSL) Mag Dec'. 25.42T I.. 57486+ Lon: W1495151.251 Fasting-- 516590 97 ftUS Sub Fact:099990031 Plan'. OP21-WW01(P10) Srvy Dab.December 16 2010 -1200 0 1200 2400 3600 4800 0 RTE 0 KOP Bld 1.5/100 Bld 2.5/100 • V3 Gyro Pt 1200 Bid 0.5/100 1200 Bld 2.5/100 _._.._.._.._.._.._.._.._.._._.._ V7_.._.._.._.._.._._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._. . 2400 AM. 2400 _._.._.._.._.._.._.._.._.._. ••.er Ugnu (Mg Ugnu • • 3600 +r,1t,Li•' ss..._.._.._.,_.._.._.._.._.._.._.._.._.4_.._.._.._.._.._.._.._.._.,_.._.._.._.._.._. ase 3600 • 13-3/8"Csg O O N C II 4800 4800 a) 03 U U) 0 6000 6000 9-5/8"Csg oupaauk- 7200 7200 8400 ublik T'Lnr •Pf1-yW O1(PM) 9600 m 9600• -1200 0 1200 2400 3600 4800 Vertical Section(ft)Azim=33°,Scale=1(in):1200(ft) Origin=0 N/-S,0 E/-V If* 2n Schlumberger WELL FIELD STRUCTURE OP21-WW01 (P1b) Nikaitchuq I Oliktok Point Magnetic Parameters Surface Caution NRD27 Alaska State Rare,Zone 04.US Feet I MiscelMre000 Model acorn 2010 Dip 80940' Date'. Rpn101,2002 Lat. N 703039.173 Northing 603E490.59 PUS Grid Cons.012798494' Slot OP21 ND Re(. Ro5ry Table(52211 above l48CI Mag Dec 25.427° FS'. 57486 8n Lon W 14951 51.251 Easting'. 516590.978US Scale Fact 099990031 Plan OP21-13/W01(Ptb) Srvy Date December 18,2010 0 500 1000 1500 2000 2500 4000 ENI Lease Line.(646).2. 4000 OP21-NNVO1(P112) TD 7"Lnr N 3500 ®i y.® 3500 �f Target 9S/8"Cs• • 3000 o a 4 .P 3000 2500 n °°- 2500 A II n A Z o ENI Lease Line(615)1 ENI Lease Line(616)2 to E 2000 a ? 2000 II 0) U to CO V V V 1500 1500 13-3/8"Cs P 1000 0 7 a 1000 End Bid 500 500 Bid 2.5/100 KOP Bid 1.6 100 0 F TE Bid 0.5/100 0 BId 2.5/100 • 0 500 1000 1500 2000 2500 I «< W Scale=1(in):500(ft) E >>> Schlumberger OP21-WW01 (P1 b) Anti-Collision Summary Report Analysis Date-24hr Time: December 16,2010-09:18 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP21-WW01(P1b)(Def Plan) Field: Nikaitchuq Depth Interval' Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M Anti Collision Standard Slot: OP21 Min Pts: All local minima indicated. Well: OP21-W W01 Borehole: OP21-W W01 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 41010.5 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP23-WW02(Def Survey) • .t r1,44.4..,,,,,,, ,°',d1,e . 1 +taS *.% 1 .' jP Warning Alert - 1� 12.56 11.82 267.98 267.98 MinPts 14.96 12.28 11.55 9.41 329.00 329.00 MinPt-CtCt 15.03 I5 11.39 8.54 364.00 364.00 MinPt-O-EOU ® 11.92 10.99 7.37 414.00 414.00 MinPt-CtCt 15.06 Min 10.92 7.11 429.00 429.00 MinPt-O-EOU 14.91 10.94 9.56 4.98 579.00 579.00 OSF<5.00 Enter Alert 1 13.931 8.33 6.14 2.90 818.93 818.93 MinPt-CtCt 14.07 8.161 5.81 2.74 853.81 853.81 MinPt-0-EOU 14.37 8.22 5.771 2.67 878.72 878.72 MinPt-O-ADP 15.42 8.75 6.03 2.611 933.43 933.40 MinPt-O-SF 40.53 31.43 27.49 4.99 1229.15 1227.28 OSF>5.00 Exit Alert 369.65 353.15 345.511 24.121 2588.39 2501.39 MinPt-O-SF 435.33 415.84 406.711 23.771 2788.32 2683.80 MinPt-O-SF 2291.92 2240.90 2215.881 45.781 7176.47 6174.62 MinPt-O-SF 2548.70 2491.62 2463.571 45 421 7797.89 6671.79 MinPt-O-SF I165.3 3205.29 3175.73 55.22 10173.00 8862.95 MinPt-CtCt 3265.3 3205 281 3175.72 55.21 10177.92 8867.87 MinPt-O-EOU 3265.40 3205 28 3175 72 55.21 10182.85 8872.38 MinPt-O-ADP 3271.56 321023 3180.06 54.201 10788.72 9452.20 MinPt-O-SF 0118-07(P3)(Def Plan) Warning Alert 31,99 30.77 28.66 N/A 0.00 0.00 Surface 22.68 16.99 14.75 4.80 514.44 514.44 OSF<5.00 Enter Alert 1 19.6661 11.08 7.41 2.51 588.59 588.59 MinPt-CtCt 20.1'•11 10.651 6.51 2.29 613.18 613.18 MinPt-O-EOU 20.37 10.70 6.41 2.27 618.09 618.09 MinPt-0-ADP 20.64 10.82 6.5 2.261 623.00 623.00 MinPt-O-SF 45.03 35 02 30.63 4.99 763.85 763.85 OSF>5.00 Exit Alert 7256.45 7235.30 7225 25 361.14 2444.59 2378.92 TD r 10040 94 10012 73 9999 121 368.831 2121.10 2087.81 MinPt-O-SF I IMMIE MIMI_ 2444.58 2378.92 MinPts OP16-03(P3)(Def Plan) 1,� s4 Warning Alert 47.98 46.76 44.66 N/A 0.00 0.00 Surface 32.56 25.03 21,88 4.97 718.98 718.98 OSF<5,00 Enter Alert 1 25.971 13.27 7.54 2,16 827.31 827.31 MinPt-CtCt 26.25 12.801 6.691 2.051 846.92 846.92 MinPts 46.09 35.85 31,34 4,98 972.33 972,26 OSF>5,00 Exit Alert 8224.22 8200.90 8189.77 369.51 2561.25 2478.64 TD 9104.03 9080.45 9069.15 402.85 2540.42 2461.07 MinPt-0-SF IMEMESI 8205.8" 8194.76 369.68 2561.25 2478.64 MinPts OP17-02PB1(Def Survey) , f2 - ,.v `As5, `" . L` 4 dY' z Warning Alert MEE 34.93 33.76 15.96 343.75 343.75 MinPl-CtGI 36.30 28.01 24.48 4.97 667.79 667.79 OSF<5.00 Enter Alert 1 31.19 18.76 13.15 2.67 866.03 866.03 MinPt-CtCt 31.311 18.551 12.79 2.61 890.59 890.58 MinPt-O-EOU 31.38 18.57 12.78 2.60 895.49 895.48 MinPt-O-ADP 31.46 18.82 12.80 2.601 900.38 900.37 MinPt-0SF 55.68 43.39 37.86 4.92 1082.12 1081.66 OSF>5.00 Exit Alert 10701.43 10664.69 10646.82 299.29 3477.15 3214.91 MinPt-O-SF 10796.40 10759.36 10741 33 299.41 3500.80 3233.83 MinPt-O-8F 11951.30 11912.16 11893.08 313.19 3642.77 3347.42 TD jI 11956 27MEIMEE: 11898.05®1 3642.76 3347.41 MinPts OP17-02(Def Survey) : Warning Alert 1=1E1 35.01 33.88 16.53 343.75 343.75 MinPt-CtCt 36.30 28.02 24.49 4.97 667.79 667.79 OSF<5.00 Enter Alert 1 31 191 18.76 13.15 2.67 866.03 866.03 MinPt-CtCt 31.31 18.56 12.80 2.61 890.59 890.58 MinPt-O-EOU 31.38 18.59 12.80 2.61 895.49 895.48 MinPt-O-ADP 31.46 18.63 12.83 2.611 900.38 900.37 MinPt-O-SF 54.47 42.32 36.85 4.87 1077.47 1077.04 OSF>5.00 Exit Alert 12210.89 1217152 12152.33 318.08 3671.51 3370.41 TD II 12215 8911 12176 5211 12157.331 318 201 3671.51 3370.41 MinPts 0114-08(P2)(Def Plan) .,`,;"`:-,J.-,-•-''':,9','; x 4 q s Warning Alert 64.01 62.79 60.69 N/A 0.00 0.00 Surface 56.991 47.75 43.74 6.96 653.35 653.35 MInP1-CtCt 5828 46.471 41.18 5.39 717.18 717.18 MinPt-O-EOU 59.30 46.67 40.971 5.09 736.74 736.74 MinPt-0-ADP 59.94 46.93 41.03 4.98 746.50 746.50 OSF<5.00 Enter Alert 67,00 51.75 44.73 MMICI 814.69 814.69 MinPt-0-SF 74.57 58.56 51.16 4.96 863.60 863.60 OSF>5.00 Exit Alert 10922,49 10896.66 10884.23 439.4 2932.22 2778.93 MinPt-0-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P21-W W01\0P21-W W01\0P21-W W01(P1b) 12/16/2010 9:29 AM Page 1 of 4 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft),I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 10940.45 10914.61 10902.18 440,10 2932.27 2778.97 TD II 109454411 10919.601 10907.17 440.271 2932.27 2778.97 MinPts OP15-08(P3)(Del Plan) a _ Pass 55.97 54.75 52.64 N/A 0.00 0.00 Surface r 51.861 44.56 41.53 8.34 558.88 558.88 MinPt-CtCt 53.03 43.38 39.17 6.15 617.87 617.87 MinPt-O-EOU 53.76 43.52 39.021 5.83 632.55 632.55 MinPt-O-ADP 59.26 46.68 4099 5.11 695.78 695.78 MinPt-0-SF 9020.55 8998.06 8987.34 420.84 2637.13 2541.79 TD 0113-03(P2)(Def Plan) ,.w 1T ..M $ w`�vok '' 'ft.. "'1' i�. e °7�✓� I,e )' ",Fba" r;rr,, 72.01 70.78 68,68 N/A 0.00 0.00 Surface 6648 64.61 18.77 464.70 464.70 MinPt-CtCt 72.82=MIG 61.96 11.15 563.69 563.69 MinPt-0-EOU 74.10 65.4 61.69 9.77 593.17 593.17 MinPt-O-ADP 74.96 65.67 9.15 607.86 607.86 MinPt-O-ADP 94.08 79.27 72.47 752.75 75275 MinPt-O-SF 11570.01 11521.24 11497.35 242.11 4570.53 4089.69 TD 11575 01 11526 24 11502.34 242.21 4570.53 4089.68 MinPts OP12-01(Def Survey) ' Pass "•r 95.99 I®.-- i®I 371750.03 2.62 2 62 MinPts 94.69 89.99 88.26 26.90 432.36 432.36 MInPt-C1Cl 95.89 86.55 17.50 562.10 562.10 MinPt-O-EOU 98.00 51,, 85.62 13.00 651.60 651.60 MinPt-O-EOU 98.74 85.32 12.03 676.40 676.40 M1nP8-0-EOU 100.84 69.75'. 84.81 10.09 735.74 735.74 MinPt-O-ADP 102.03 90.07 11111111111E 9.39 760.38 760.38 MinPt-O-ADP 125.23 105.75 96.62 996.10 995.98 MinPt-O-SF 10400,98 10353.73 10330.60 224.80 5126.45 4534.46 TO 0111-01(Def Survey) _ :�ar Passr2T +, 1021.. 100.50! 215.06 138.95 138.95 MinPts 104.6 m8 100.61' 55.13 378.95 378.95 MinPt-O-EOU 105.56=ME 99.50 32.39 553.93 553.93 MinPt-0-EOU 105.80 101.17 99.47 30.69 578.91 578.91 MinPt-O-ADP 106.07 101.26 99.47 29.24 598.89 598.89 MinPt-0-ADP 117.08 106.1 ® 11.92 899.65 899.64 MinPt-O-ADP 121.30 1072 100.80 9.34 997.96 997.83 MinPt-O-ADP 123.28 107,941 100.83 8.63 1039.29 1039.03 MinPt-O-ADP 134.93 115.94 107.05® 1177.22 1176.00 MinPt-O-SF 3171.28 3129.96 3109.7`..1111MC1E1 4721.94 4210.82 MinPt-O-SF 5549.55 5505.03 5483.65 7396. 129.74q 5445.44 4789.67 TD 73 7349.76 7321.161 16358'1 5444.97 4789.30 MinPts 0111-01PB1(Def Survey) Pass ®4 10212 100.50 215.06 138.95 138.95 MinPts 104.6 ® 100.61 55.13 378.95 378.95 MinPt-0-EOU 105.56®' 99.50 32.39 553.93 553.93 MinPt-O-EOU 105.80 101.17 99 47 30.69 578.91 578.91 MinPt-O-ADP 106.07 101.26 99.47 29.24 598.89 598.89 MinPt-O-ADP 117.08 106.14® 11.92 899.65 899.64 MinPt-O-ADP 121.30 107.22 100 80 9.34 997.96 997.83 MinPt-O-ADP 123.28 107.9. 100 83 8.63 1039.29 1039.03 MinPI-0-ADP 134.93 115.94 107.05=mg 117722 1176.00 MinPt-0-SF 3171.28 3129.96 3109 79.1.1E1E 4721.94 4210.82 MinPt-O-SF 4105.50 4064.51 4044.50 102.58 5152.96 4555.67 TD OP10-09(P4)(Def Plan) ... . ; A M 'a., 9,r +.:€�`�'`w, 531 '(,ti`^,,. " <``,/ .`i;VTr//n 111.99 110.77 108.67 N/A 0.00 0.00 Surface I 111.991 109.36 108.65 78.40 250.00 250.00 M1nPt-CtCt 112.47 108.9 107.72 47.38 369.98 369.98 MinPt-O-EOU 113.61 109.11 107.47 34.27 449.87 449.87 MinPt-O-ADP 115.15 109.7 107.66 27.27 509.66 509.66 MinPt-O-ADP 178.88 158.79 149.36 9.42 1057.63 105730 MinPt-O-SF 8854.00 8801.12 8775 171 170 591 5387.68 4743.46 MinPt-O-SF 11755.39 11697.19 11668.58 205 43 5551.01 4874.14 TD ` 9 11760 311 11702 101 11673.480 205.48 5551.01 4874.13 MinPts 0106-05(P9)(Def Plan) 1r W�..E ! H,, {v, .,.+.'. Pass 151.98 150.76 148.66 N/A 0.00 0.00 Surface =B 148.95 148.05 83.49 300.00 300.00 MinPt-CICt 153.2 =OM 145.64 35.82 594.47 59447 MinPt-O-EOU 154.27=DM 144.81 27.88 649.05 649.05 MinPt-O-EOU 157.77 148.26 mogiE 18.90 747.81 747.81 MinPt-O-ADP 173.68 158.94 152.1,.® 917.14 917.12 MinPt-O-SF 335.13 320.41 313.66® 1367.69 1363.04 MinPt-O-SF 2017.95 1985.60 1969.96® 3500.11 3233.28 M1nPt-O-SF 2046.03 2013.18 1997.29 64.34 3531.60 3258.48 MinPt-0-SF 2089.96 2056.42 2040.18 w 3580.60 3297.68 MinPt-O-SF 2467.48 2427.75 2408.42 63.80 3991.55 3626.46 MinPt-O-SF 3358.93 3306.39 3280.60® 5918.35 5168.03 MinPt-O-SF 4156.66 4101.77 4074.81 Emma 7326.05 6294.28 MinPt-O-SF 4580.05 4519.64 4489.9 MIME 7705.69 6598.02 MinPt-O-SF 4607.65 4546.87 4516.98 M11'E, 7726.76 6614.88 MinPt-O-SF 7974.57 7898.30 7860.65 105.91 8427.79 7201.16 TD OP26-DSPO2(Def Survey) Pass MIEENHIMENMIIIMIN N/A 3.99 3.99 MinPts MZES 154.08 149.72 18,67 1177.19 1175.97 MinPt-CtCt 164.77=a 149.66 18.52 1186.18 1184.86 MinPt-O-EOU 164.81 154.07 149.65 18.46 1190.66 1189.29 MinPt-0-ADP 171.29 159.74 154.92® 1298.36 1295.31 MinPt-0-SF 1576.05 1544.33 1529.42- 111 3875.25 3533.41 MinP1-0-SF 2993.4"r=Ian mmEg 7340.28 6305.67 MinPts Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP21-W W01\OP21-W W01\OP21-W W01(P1 b) 12/16/2010 9:29 AM Page 2 of 4 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major Oliktok Point l-2PB1(Def Survey) Pass 184.49 183.38 181.17 N/A 0.00 0.00 Surface I 18449 103.38111111111311/1 N/A 40.00 40.00 MinPts 164.44 156.55 153.17 24.13 823.95 823.95 MinPt-CtCt 164.71 156.251 152.57 22.26 863.67 863.67 MinPt-O-EOU 165.07 156.31 152.49 21.44 883.43 883.42 MinPt-O-ADP 181.45 170.19 165.12 17,78 1079.66 1079.22 MinPt-O-SF 187.94 176,34 171.10 17.8 1112.30 1111.66 MinPt-O-SF 5053.01 502456 5010.83 183.96 3383.16 3139.71 MinPt-O-SF Oliktok Point 1-2(Def Survey) n F x -,,.r,,/ -.. r ',ply ,y,. 184.49 183.38 181.17 N/A 0.00 0.00 Surface 184.491 183-381®1 N/A 40.00 40.00 MinPts 156.55 153.17 24.13 823.95 823.95 MinPt-CtCt 164.71=IMEEI 152.57 22.26 863.67 863.67 MinPt-O-EOU 165.07 156.31 21.44 883.43 883.42 MinPt-O-ADP 181.45 170.19 165.12 MEM 1079.66 1079.22 MinPt-O-SF 187,94 176,34 171.10 OMEN 1112.30 1111.66 MinPt-O-SF 6975,72 6944,27 6929.04 228.96 3601.83 3314.66 MinPt-O-SF 10734,65 10693.50 10673.43 267.29 4314.60 3884.92 TD Oliktok Point I-2PB2(Def Survey) -� E,e¢ ':8' ` 4;�r n *ifie� Siy g"- v ' 7 184.49 18351 181.17 N/A 0.00 0.00 Surface 1 184.4 183.3:®1 N/A 40.00 40.00 MinPts • 164.44 156.57 153.19 24.19 823.95 823.95 MinPt-CtCt 164.71 156.261 152.60 22.31 863.67 863.67 MinPt-0-EOU 165.07 156,33 152.52 21.50 883.43 883.42 MinPt-0-ADP 181.45 170,21 165.14 17 811 1079.66 1079,22 MinPt-0-SF 187,94 176,35 171.12 1774 1112.30 1111.66 MinPt-O-SF 6975.72 6944.28 6929 051 229.001 3601.83 3314.66 MinPt-0-SF 7888,68 7854.19 7837.43 235.39 3808.99 3480.41 TD OP08-04PB1(Def Survey) , Pa36. 127.97 126 7 124.64 1 N/A 0.00 0.00 MinPts 1 128.28 126.09 124.95 132.76 183.90 183,90 MinPt-O-EOU 189.51 175,62 169.29 14.87 893.91 893.90 MinPt-O-SF 525,30 509,55 502.281 36.081 2331,44 2279,39 MinPt-0-SF 740.82 715,01 702.641 29.901 3338.20 3103,74 MinPt-0-SF 4849.93 4805.36 4783.56 111.25 6230.71 5417.94 TD MEM 4809 76 4787.961 111 3411 6230.69 5417,93 MinPts OP08-04(Def Survey) A. viµ . ,-, ,,- ,t f ,t t 1 127.971 126.741 124.641 N/A 0.00 0,00 MinPts 128.28 126.09 124.95 132.76 183.90 183.90 MinPt-O-EOU I 189.51 175.62 169291 14.871 893.91 893.90 MinPt-0-SF 525.30 509.55 502 28 36 08 2331.44 2279.39 MinPt-0-SF 740.82 715.01 702 641 29.901 3338.20 3103.74 MinPt-O-SF 5314.40 5268.65 5246.27 118 70 6276.48 5454.56 TD II 6556 7411 6509 251 6486 0011 140 97i1 6253.81 5436.42 MinPts OP09-503(P2)(Def Plan) 4 e<,. ., Y#-''. s -,. ;1e4 t.?5.,, m7. ,..!4` ,µ."' yr 14 z%4 z 119.98 118.76 116.66 N/A 0.00 0.00 Surface 1 119.981 116.17 114.87 45.85 400.00 400.00 MinPt-CtCt 120.19 115.91 114.47 39.67 450.00 450.00 MinPI-0-EOU 120.51 116.0 114.40 36.62 479.99 479.99 MinPt-0-ADP 209.35 190.17 181.19 11.591 1266.74 1264.27 MinPt-0-SF 532.36 509.59 498.74 2727.90 2615.46 MinPt-0-SF 5921.98 5856.78 5824.67 92.20 6858.17 5919.95 MinPt-0-SF 10980.12 10891.72 10848.01 125.59 7080.33 6097.69 TD 10984.:- 10896,4! 10852.70=Mil 7080.33 6097.69 MinPts 0107-04(P8)(Def Plan) �'"•.f5 Nfq,Y ,r„.,`fi t- '7- 135,99 134 76 132-66 N/A 0-00 0.00 Surface ="t 131.39 129.70 39.93 500.00 500.00 MinPt-CtCt 136.1.1111111111 129.47 37.42 530.00 530.00 MinPt-0-EOU 136.31 131.32=EMI 35.83 550.00 550.00 MinPt-0-ADP ,I 213.97 200.64 194.59® 1297.20 1294.16 MinPt-0-SF 378.18 361.09 353.15® 2295.40 2247.14 MinPt-0-SF 388.23 370.69 362.53® 2352.37 2297.99 MinPt-0-SF 392.86 375.26 367.00® 2380.00 2322.43 MinPt-0-SF 492.42 467.70 455.87 3406.10 3158.06 MinPt-0-SF 495.34 470.47 458.5 4.58, 3440.28 3185.41 MinPt-0-SF 1413.50 1380.90 1365.0• 44.681 5064.83 4485.16 MinPt-0-SF 7242.24 7186.00 7158.37 131 05 8181.99 6984.99 TD OP05.06(Def Survey) -,0 t .o-,,. -ty ,;ar ie Pass ,1^;"-'7 159.74 157.86 156.42 239.65 153.94 153.94 MinPts 159,81 157.81 156.48 204.16 173.94 173.94 MinPt-0-EOU 220.62 208.87 203.60 20.84 920.62 920.60 MinPt-0-SF 4100.85 4057.98 4037.04 97.8 5254.40 4636.83 MinPt-0-SF 4180.21 4136.54 4115.20 97.92 5372.55 4731.36 MinPt-0-SF 4264.48 4219.98 4198.23 97.98 5513.54 4844.15 MinPt-0-SF 4313.79 4268.81 4246.82 98 03 5609.10 4920.61 MinPt-0-SF 4373.83 4328.24 4305.93 98 03 5760.81 5041.99 MinPt-0-SF 4412.15 4365.40 4342.51 96.381, 6178.44 5376.12 MinPt-0-SF 1=131k 4345 56 4322.77 96.34 6466.34 5606.46 MinPt-C1Ct 4392.1`1 4322.74 96.27 6472.58 5611,46 MinPt-0-EOU 4392.17 4345 55 man 96.23 6475.70 5613.95 MinPt-0-ADP 4400.63 4353.50 4330 44 mffsin 6575.17 5693.53 MinPt-0-SF 5606.46 5521.92 5480.15 67.09 8110.81 6924.85 MinPt-O-SF 5710.30 5624.12 5581.53® 8134.68 6944.88 MinPt-O-SF 5882.36 5793.71 5749.88 67.09 8172.94 6977.27 MinPt-O-SF 9009.91 8903.48 8850 77 85.44 8557.57 7319.99 TD Drilling Office 2.0.930.0 Nikaitchuq\OliktokPoint\OP21-WW01\OP21-WW01\OP21-WW01(P1 b) 12/16/2010 9:29 AM Page 3 of 4 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major OP05-06P51(Def Survey) Pass 159 7.1 157.86 156.42 239,65 153.94 153.94 11in Pts 159.81 157,81 156.48 204,16 173.94 17394 M1nPt-O-EOU 220.62 208.87 203.60 MECO 920.62 920.60 MinPt-O-SF 4313.76 4269.82 4248.34 100.40 5338.36 4704.00 TD OPOS-06P02(Def Survey) x g a - -- - _ Pass 1 159.74 157.86 156 42 239.65 153.94 153.94 MinP/s 159.81 157.81 15648 204.16 173,94 173.94 MinP1-0-EOU 220.62 208.87 203.60 20.84 920.62 920.60 MinPt-O-SF 4100.85 4057.98 4037.03® 5254.40 4636.83 MinPt-O-SF 4180.21 4136.54 4115.19® 5372.55 4731.36 MinPt-O-SF 426448 4219.98 4198 221 57.971 5513.54 4844.15 MinPt-O-SF 4313.79 4268.81 4246.811 58 021 5609.10 4920.61 MinPt-O-SF 4373.83 4328.23 4305.921 58.021 5760.81 5041.99 MinPt-O-SF 4412.15 4365.39 4342.511 96 371 6178.44 5376.12 MinPt-O-SF ® 4345.56 6 4322.77 96 34 6466.34 5606.46 MinPt-CtCt 4392.1•mg=, 4322.73 96.26 6472.58 5611.46 MinPt-O-EOU 4392.17 4345.55Ik0 56.23 6475.70 5613.95 MinPt-O-ADP I 4400.63 4353.50 4330.43® 6575.17 5693.53 MinPt-O-SF 5606.46 5521.93 5480.15 67 09 8110.81 6924.85 MinPt-O-SF 5710.30 5624.13 "5581.53®i 8134.68 6944.88 MinPt-O-SF 5882.36 5793.71 5749.88®i 8172.94 697727 MinPt-O-SF 7664.42 7562.74 7512.40 76.11 8440.86 7212.99 TD OPO4-07(Def Survey) - - :0'.- -.. _ ;.'- 167.20 164.61 163.87 122.01 278.84 278.84 MinPts 167.28 164.5 163.78 109.26 313.84 313.84 MinPt-O-EOU 167.43 164.5 163.75 101.32 338.84 338.84 MinPt O ADP 270,34 259.47 254.65 27.911 1201.29 119979 MinPt-O-SF 8111.84 8054.14 8025.78 143.01 8200.25 7000.60 TD OPO4-07PB1(Def Survey) 4n'u� a„?);., Pass 11 ; 164.61 163.87 122.01 278.84 276.84 MirrPts 167.28 164.54 163.78 109.26 313.84 313.84 MinPt-O-EOU 167.43 164.5 163.75 101.32 338.84 338.84 MinPt-O-ADP 270.34 259.47 254.6 27.911 1201.29 1199.79 MinPt-O-SF 6736.94 667999 6652.01 120.37 7947.27 6791.31 TD OP03-P05PB1(Def Survey) - 't.,Cw-'s,` 4ft31' ;8'W _V n ,$' tt-, £-"f, .>141;r<.P.wa7, ,' ); mow 174.60® 2360.20 64.00 64.00 MinPts ® 173.77 MEIS 174.12 244.00 244.00 MinPts 176 1,® 172.81 135.14 299.00 299.00 MinPt-O-EOU 176.1711111111111 9 17284 132.20 304.00 304.00 MinPt-O-EOU 276.12 266.05 261.62 31.06 1269.23 1266.72 MinPt-O-SF 1633.19 1605.17 1591.65 60.37 4101.77 3714.65 MinPt-O-SF 1846.06 1815.16 1800.2 61 671 4970.11 4409.38 MinPt-O-SF 2002.86 1970.24 1954.427 63 271 5579.36 4896.82 MinPt-O-SF OP03-P05(Def Survey) 4, x `00XRt,55 k ?.'„ Pas' +i ,t}„i' 174.60® 2360.20 64.00 64.00 MinPts 176.00 173.77r..1[ 1111, 17412 244.00 244.00 MinPts 1761,=En 172.81 135.14 299.00 299.00 MinPt-O-EOU 176.17 man 172.84 132.20 304.00 304.00 MinPt-O-EOU 276.12 266.05 261.62 1269.23 1266.72 MinPt-O-SF 1633.19 1605.17 1591.6 MEM 4101.77 3714.65 MinPt-O-SF 1841.06 1810.31 1795.4r 4945.18 4389.43 MinPt-O-SF 1929.19 1896.76 1881(-i' 1 5318.00 4687.71 MinPt-O-SF 6666.05 6614.88 6589.78 132.80 8214.85 7013.14 TD OP03-P05PB2(Def Survey) .,Pass ,A 6 175.89 174 60 172 571 2360.20 84 00 64.00 MinPts 176.001 173.7 17267 17412 244.00 244.00 MinPts 176.14 172.81 135.14 299.00 299.00 MinPt-O-EOU 176.17 173.62 172.84 132.20 304.00 304.00 MinPt-O-EOU 276.12 266.05 261621 31.061 1269.23 1266.72 MinPt-O-SF 1633.19 1605.17 1591_65 60.3 j 4101.77 371465 MinPt-O-SF 1841.06 1810.31 179543 61.83 4945.18 438943 MinPt-O-SF 1929.19 1896.76 1881.04 61.3 5318.00 4687.71 MinPt-O-SF 4740.25 4694.17 4671.62 105,10 7616.11 6526.35 TD Olilr k Point I-1A-106(P5)(Def ' "" s ")j7/ / ,� 4 .y.4•). 11 Plan) v 4 g .:: r# ,...4 y """1sv,'"' 'g�, wr ., cn b'i •,?` S 04^ : 192.53 190.61 189.20 N/A 0.00 0.00 Surface 192.53 190.61 189.2 535997.28 40.10 40.10 MinPts 192.63 190.51 189.31 923.66 8420 84.20 MinPt-O-EOU 423.26 411.78 406.99 Man 1297.28 1294.24 MinPt-O-SF 1105.06 1087.83 1080.18' 2493.21 2420.86 MinPt-O-SF 1225.89 120691 1198.37® 272948 2616.72 MinPt-O-SF 1586.61 1563,61 155264® 317644 297432 MinPt-O-SF 5336.28 5280.07 5252.45 56.60 6903.30 5956.06 MinPt-O-SF MEZNE'MEGIE.® 96.64 691393 5964.57 MinPts 6794.65 6690.82 6639.39 66.06 8326.19 7110.29 MinPt-O-SF 9722.42 9595.23 9532.13 77.03 8646.73 7403.26 TD #.. - 192.53 190.61 189.20 N/A 0.00 0.00 Surface 11 192.53 190.61 189.20 535997.28 40.10 40.10 MinPts 192.63 190.51 189.31 923,67 84.20 84.20 MinPt-O-EOU 423.26 411.78 406.99 44.02 1297.28 1294.24 MinPt-O-SF 1105.06 1087.84 1080.19 72.10 2493.21 2420.86 MinPt-O-SF 1225.89 1206.94 1198.42 71 84 2729.48 2616.72 MinPt-O-SF 4995.01 4945.84 4922.14 105 33 6458.49 5600.18 MinPl-0SF 5113.30 5061.02 5035.76 101.17 7069.29 6088.86 MinPt-O-SF 5045.32 5008.06 68 71 7162.42 6163.37 MinPts Drilling Office 2.0.930.0 Nikaitchuq\OliktokPoint\OP21-WW01\OP21-WW01\OP21-WW01(P1b) 12/16/2010 9:29 AM Page 4 of 4 Schlumberger TRAVELING CYLINDER PLOT 1 • Client: ENI NoGo Region EOU's based on: Well: OP21-WW01 Oriented EOU Dimension Field: Nikaitchuq .■ NoGo Region Anti-Collision rule used: Structure: Oliktok Point Minor Risk-Separation Factor • • Date: December 16,2010 ',',. North 350 0 10 340 -1"ti�—� att. 4 20 330 \�'��y �� �•.it_30 ,ti � - 0-09(P4) 320 °, t .�— 40 310 � ' \ wl :„Zion∎� -41� r . r,��; F) 44i1 ■41V" .-- *IT%...K.1111 101 ,`� ..... \ , .,�k , SF C»\�, ilp 44111. 1 1 k ,e,;..,300 S1��`ZVti'� ..�:r�,t�,ti:"1$ 60 IV �ry 1 'i t r , ;07• 0,:i ", ,�P r .i.J i 10 04(P8). .:-,4� ; '710 0.. //III 290 (• ) ° ^ �►,` 44- � � +��-,, 9106-05(P9) 1118-07 3 / ` 280 o P+, m m ; 7141 , IUD o 80 o * 4 OP16-0' (P3); -��� .. • ;9 isell 270 .. Z fit, 90 z 260 ����� �� I ���"�e" � ����M , i -' 100� o n v 1, � Li V "i*- 4 . ,`rte,, 250�� I 1r011$ +..�- ,,° �` p§ r` 1 7 110 240 l 1 . „ 1 20 * ♦♦ 230 ,\ illtiltr ��✓. � �♦ 130 11111171t. , 220 i 140 210 / �� 150 1 I 200 •160 190 180 170 Well Ticks Type: MD on OP21-W W 01(Plb) Calculation Method: Normal Plane 1 Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP21-W W 01 Oriented EOU Dimension Field: Nikaitchuq _■( NoGo Region Anti-Collision rule used: Structure: Oliktok Point Minor Risk-Separation Factor , = Date: December 16,2010 North 350 0 10 340.40011/v 60 p2� �m9 •��,18(P2) 330 `+ 30 4 320 50 *4 40 310 ~4� �� . ��,#p,♦ 50 ♦f tom,. r i 300 �' �I%� a`� ®� ,� , 60 OIiB-DAP � ." , 30 ����, �;.,.. OP16-03 `��, 290 ; (.. 4 -ilr-7`` 70 4146,, A,^s / 0 Vt---280 _ -e • / vt ) ,. 80 61141,10i4 111__ .1 270 ._ -' 90 s 260 I �� , ---fi4( 4 \ 250 .I�� , , o / 110 ,1,..:. *4 /, 240 —�'�'I N. • I•� �r;� o03 120 `,,,41110.11tY- illrl‘ 230 } 130 ♦ •220•" 02 �/r �" 210 4.10 150 20o 160 190 180 170 Well Ticks Type: MD on OP21-W W O1(Plb) Calculation Method: Normal Plane Ring Interval: 10.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=20.00 ft Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard I Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8-1/2" Open Hole / 7" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Moderate 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 Drilling Hazards Summary.doc 12/17/2010 w ;- ma \ °aa)w z\z °m PI z u = < CO , n 0 -T m rya-- m� 0 ris _ 1 1)-";: _ _ a H - - - – _ A I I O N --) I L—J 1_–] 1 U 1 �� TI N 77 t C) _—� I i— ■■ –7 I rl II' 71 O N z m — 1 ;I – I – – I — 1I 1 • 1 w c; Q c)mS:::.. ri\ m a m < l`1) 1 t k 4 u, N w A % _ i i i < o I (./1 -c= < �' rum�z a z 1 Co oo C I ` �u' i l 11 CO If o � o �2 \ 2rn rn ;O oo, N z 03,Q m 1 �a �I ��r n 1�ti = �= � mg S q z (4 –I c) Zc_ z C_ 4 6 1 Ti 1 4 1 ill 11 J 1 IlxA /. 1 Cr) Z7J Z * C� D rn O OaD O ? co in 3 _ 7 CI m CD C _ D 1 o n c- Oa a (D W A N l� 1 1 1 ._, m CD � O ` N ^` 1 T11 1 1 Z V/ Z T! 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' | 9.. � Schlumberger CemCAD E* well cementing recommendation for Surface Casing Operator : Eni Petroleum Well : OP21-WW01 Country US Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : Oliktok Point Proposal No. : Draft v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 12-16-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1Qslb.com Q " M �L q4VAT E Disclaimer Notice: 1 his information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. *Mark of Schlumberger Client : Eni Petroleum Well : OP21-WW01 Schlemberger String Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 4100.0 ft BHST : 52 degF Bit Size : 16 in ft (x 1000) psi OD 20.in °- [@ 160ft :, < ) - 0 2.5 ■ l ,—Frac —Pore Permafrost (OD 13.4 00fin Ig4100ft ry Schrader Blurr LC ig,4020 ft OA Base o " kn- Well Lithology Formation Press. Page 2 op21-ww0l.cfw;12-16-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WWO1 Sci ie1 String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 4020.0 ft Casing/liner Shoe MD : 4100.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 4100.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 141.1 Mean OH Equivalent Diameter: 19.099 in Total OH Volume : 1396.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1901.0 16.000 275.0 21.634 4100.0 16.000 35.0 16.822 Page 3 op21-ww01.cfw;12-16-2010; LoadCase 13-3/8in Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 ScIli er String : Surface Casing District : Prudhoe Bay,Alaska Y Country : US Loadcase : 13-3/8in Surface Casing Max. Deviation Angle : 37 deg Max. DLS : 2.501 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 33.0 0.000 100.0 100.0 0.0 33.0 0.000 200.0 200.0 0.0 33.0 0.000 300.0 300.0 0.0 33.0 0.000 400.0 400.0 0.0 33.0 0.000 500.0 500.0 0.0 33.0 0.000 600.0 600.0 0.0 33.0 0.000 700.0 700.0 0.0 33.0 0.000 800.0 800.0 0.0 33.0 0.000 900.0 900.0 1.5 33.0 1.500 1000.0 999.9 4.0 33.0 2.500 1100.0 1099.4 6.5 33.0 2.500 1200.0 1198.5 9.0 33.0 2.500 1300.0 1296.9 11.5 33.0 2.500 1356.6 1352.2 12.9 33.0 2.492 1400.0 1394.5 13.1 33.0 0.507 1500.0 1491.8 13.6 33.0 0.500 1600.0 1588.9 14.1 33.0 0.500 1700.0 1685.7 14.6 33.0 0.500 1800.0 1782.4 15.1 33.0 0.500 1872.4 1852.2 15.5 33.0 0.497 1900.0 1878.8 16.2 33.0 2.498 2000.0 1974.2 18.7 33.0 2.500 2100.0 2068.2 21.2 33.0 2.500 2200.0 2160.6 23.7 33.0 2.500 2300.0 2251.3 26.2 33.0 2.500 2400.0 2340.0 28.7 33.0 2.500 2500.0 2426.7 31.2 33.0 2.500 2600.0 2511.1 33.7 33.0 2.500 2700.0 2593.1 36.2 33.0 2.500 2727.2 2614.9 36.9 33.0 2.501 2800.0 2673.2 36.9 33.0 0.000 2900.0 2753.2 36.9 33.0 0.000 3000.0 2833.2 36.9 33.0 0.000 3100.0 2913.2 36.9 33.0 0.000 3200.0 2993.2 36.9 33.0 0.000 3300.0 3073.2 36.9 33.0 0.000 3400.0 3153.2 36.9 33.0 0.000 3500.0 3233.2 36.9 33.0 0.000 3600.0 3313.3 36.9 33.0 0.000 3700.0 3393.3 36.9 33.0 0.000 3800.0 3473.3 36.9 33.0 0.000 3900.0 3553.3 36.9 33.0 0.000 4000.0 3633.3 36.9 33.0 0.000 4100.0 3713.3 36.9 33.0 0.000 Page 4 op21-ww01.cfw;12-16-2010, LoadCase 13-3/8in Surface Casing;Version wcs-cem461_06 Client : Eni Petroleum Well : OP21-WW01 ScImMerger String : Surface Casing District : Prudhoe Bay,Alaska t t Country : US Loadcase : 13-3/8in Surface Casing Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 154.0 11.20 9.00 Permafrost Siltstone 1901.0 12.00 9.00 Permafrast Siltstone 2062.0 12.50 9.00 Upper Ugnu Shale 3647.0 12.50 9.00 Schrader Blurr Sandstone 3699.0 12.50 9.00 N-Seq Top Shale 3748.0 12.50 9.00 N-Sand Sandstone 3981.0 12.50 9.00 OA Base Shale 4100.0 12.50 9.00 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1901.0 1879.7 32 0.6 4100.0 3713.3 52 0.9 ft degF 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 o- - - --t- I - 0 - 0- Ln _ 0 0 0- o - a o - O o- N - O - 0 U N O - 0 O M - - Geoth.A-ofile - Tubular Fluids - - Annulus U M - O - O- O _ O Ln - Temp. Profile At 255 min Page 5 op21-ww0l.cfw,12.16.2010, loadCase 13-3/8in Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Salk" String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface, 500' 12.0 ppg DeepCRETE Slurry Tail Original fluid Mud 9.60 lb/gal k:2.06E-3 Ibf.s^n/ft2 n :0.812 Ty: 8.74 Ibf/100ft2 Displacement Volume 601.9 bbl Total Volume 1450.0 bbl TOC 0.O ft Fluid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Lead Slurry 685.5 3600.0 0.0 10.70 k:1.46E-1 lbf.sAn/ft2 n:0.217 Ty:1.22 Ibf/100ft2 Tail Slurry 62.5 500.0 3600.0 12.50 k:7.77E-3 lbf.sAn/ft2 n:0.942 Ty:21.23 Ibf/100ft2 Mud 601.9 0.0 9.60 k:2.06E-3 lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks Frac 4 psi at 160.0 ft Pore 14 psi at 160.0 ft Collapse 1899 psi at 4020.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 91 ton - Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7-Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 685.5 137.1 685.5 80 13-Start Mixing Lead Slurry Tail Slurry 5.0 62.5 12.5 62.5 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 601.9 70.8 601.9 80 19-Start Displacement Total 04:15 hr:mn 1450.0 bbl End Job: Bump Plug; Check floats Dynamic Security Checks: Frac 1 psi at 160.0 ft Pore 5 psi at 160.0 ft Collapse 1899 psi at 4020.0 ft Burst 4639 psi at 0.0 ft Page 6 op21-ww0l.cfw.12.161010; LoadCase 133/8in Surface Casing;Version wcs-cerr461_08 Client : Eni Petroleum Well : OP21-WW01 Schlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing * CemCADE Client :Eni Petroleum Well :OP21-WW01 String :Surface Casing District :Prudhoe Bay,Alaska Country :US ft lb/gal o < 8 9 10 1l1 1i2 13 J ; L —. -Hydrostatic -Mn.Hydrostatic 0 - i - Max.Dynamic ion- -tvfn.Dynamic ------ Frac -Pore 8 o- g. .8, 0 — oo— ` N 3 > QQQ N U g_ M IL l,,. \ g_ Fluid Sequence Dynamic Well Security a o ■fvUDPUSH II 100.0 bbl 10.10 b/gal Herschel:k=2.54E-2 bf.s^n/ft2 n=0.420 Ty=13.04lbf/100f12 3 Lead Slurry 685.5 bbl 10.70 lb/gal Herschel:k=1.46E-1 Ibf.s^n/ft2 n=0.217 Ty=1.22 bf/100ft2 Tail Slurry 62.5 bbl 12.50 b/gal Herschel:k=7.77E-3 bf.s^n/1t2 n=0.942 Ty=21.23 Ibf/100ft2 ■Mid 601.9 bbl 9.60 lb/gal Herschel:k=2.06E-3 bf.s^n/ft2 n=0.812 Ty=8.74 Ibf/100ft2 Total Depth = 4100.0 11 Top of Cement= 0.0 ft 'Mark of Schlumberger Sehlumberpr Page 7 op21-wwOl.cfw:12-16-2010, LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WWO1 Seklimberpr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Temperature Results BHCT 65 degF Simulated Max HCT 67 degF Simulated BHCT 67 degF Max HCT Depth 4100.0 ft CT at TOC 59 degF Max HCT Time 04:15:25 hr:mn:sc Static temperatures: At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 52 degF lerci r 0 Iv ro 0 co ro 1 N- 1 � ao_ o0 .AN- o 0 ON 2 � v _ N u')� NL U(f) N 7. 't COp (0 a (N1•0- N CM •First Sack Depth ----- First Sack Temp. O _ •Last Sack Temp. �' th u') -Last Sack Depth ,' o O Tr tf) t V 0 30 60 90 120 150 180 210 240 270 Time(min) Page 8 op21-ww0l.cfw,12-16.2010: LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Silk" String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing ECD Profile at the shoe: — — -- _ Depth= 4100 ft co N v � o N- Hydrostatic Dynanrc _ Frac Pore N O-: O �N l i co od 0 30 60 90 120 150 180 210 240 270 Time(min) ECD Profile at the Conductor shoe: Depth= 160 ft Fluids at 4100 ft co Hydrostatic •Dynamic -Frac Ci- Pore h N - O f O Ce) ar- o7 -�- - 0 30 60 90 120 150 180 210 240 270 Time (min) Page 9 op21-wwOl.cfw;12-16-2010; LoadCase 13-3/8in Surface Casing:Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 SCIIIIIIMIPI String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Pressure Profile: p71—- 0ak.Pump Press. i Ca1c.VVHP 9t I (O 7 1 1 --/ —1 , 8- 0 30 60 90 120 150 180 210 240 270 Time (min) Fluid in vs. Fluid out: co Fluids at 4100 ft_ 0 out 7 •on O N. O 11') i •zt- 1 -.---- . ( i N I i O 0 30 60 90 120 150 180 210 240 270 Time (min) Pagel 0 op21-ww01_cfw;12-16-2010, LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 SBI1 String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.60 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.812 Ty :8.74 lbf/100ft2 Gel Strength : 38.42 Ibf/100ft2 MUD Mud Type : WBM Job volume :601.9 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No: 2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.46E-1 Ibf.s^n/ft2 At temp. :65 degF n :0.217 Ty : 1.22 lbf/100ft2 Gel Strength : 12.81 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809 Mix Fluid : 19.043 gal/sk Job volume : 685.5 bbl Dry Density : 105.47 lb/ft3 Yield :4.33 ft3/sk Quantity :889.28 sk Sack Weight : 188 lb Solid Fraction : 41.2% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 19.043 gal/sk Page 11 op21-wwO1.cfw;12-16-2010, LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Saltier String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Tail Slurry DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 7.77E-3 Ibf.s^n/ft2 At temp. : 74 degF n :0.942 Ty :21.23 lbf/100ft2 Gel Strength : 58.20 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.174 gal/sk Job volume :62.5 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :228.36 sk Sack Weight : 100 lb Solid Fraction : 55.0% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.174 gal/sk Additives Code Conc. Function D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Annulus ID: 13.375 in-OD: 16.000 in T - Tail Slurry Lead Slurry — MUDPUSH II - Mud N— 2 co - 2 0 8 t3 u_ 1 I - I I I I I I 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) Page 12 op21-ww0l.cfw,12-16-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 0 Client : Eni Petroleum Well : OP21-WW01 SCIIIIIIIIIII String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 5: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :4080.0 ft Casing Shoe :4100.0 ft NB of Cent. Used :59 NB of Floating Cent. :59 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 220.0 3 1/1 NW-TR-13 3/8-8-TR 3 W304 100.0 200.0 3500.0 41 1/2 NW-TR-13 3/8-8-TR 3 W304 0.0 1920.0 4100.0 15 1/1 NW-TR-13 3/8-8-TR 3 W304 75.8 4100.0 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-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft % 0 7 0 20 40 60 __80 100 ` Between Cent. 4 4 At Cent. , , §_ , i it _ _ CV I r 1 $ + $L..- .. r- V - Well Pipe Standoff Page 13 op21-ww0l cl w;12-16-2010: LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.3 Total Drag Force :13 ton Hook load Down Stroke :128 ton Hook load Up Stroke :155 ton ft ton 0 20 40 60 80 100 120 140 160 0- 1 - Hookload Up - Hookload Dow n O - - Weight - Drag Force O O _ � O r - O O - N O . O Lo- c.] O - O M - O . - O O O_ O - Running Forces Page 14 op21-ww0l.cfw,12-16-2010; LoadCase 13-3/8in Surface Casing;Version wcs-cem461_08 0 Client : Eni Petroleum Well : OP21-WW01 SCOW', String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 6: WELLCLEAN II Simulator ft % % 0 0 20 40 60 80 100 0 0 20 40 60 80 100 -- Std Betw.Cent. ` 1—..lt Mud Contamination Cement Coverage I Uncontaminated Slurry .)CLI , — MIM■■•—. , 1. r r SQL � N J CI Cement Coverage Uncontaminated Slurry Risk Mud on the Wall Fluids Concentrations ° 5 0 0 0 0 0 500- 500 500 500 1000- 1000 1000 1000 t 1500 1500 G 1500- 1500 ` ti 4 s 2000- '� 2000 .- f 2000 ?000 = Z. e to. li 2500- 2500 0° g 2500 - 2500 c, 3000- 3000 3000 3400 irr 3500- 3500 3500 3500 4000 1000 4000 6000 r a c a° _� o a to 0 o z IM Mud I I Lead Slurry II I High I I Low ® Tail Slurry I 1 MUDPLISH II ( I Medium I I None Page 15 op21-ww0l.cfw.12-16-2010, LoadCase 13-3/8in Surface Casing;Version wcs-cem46l_08 Schlumberger CemCAD E*well cementing recommendation for Intermediate Casing Operator : Eni Petroleum Well : OP21-WW01 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : Oliktok Point Proposal No. : Draft v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 12-16-2010 Business Phone : 907-659-2434 FAX No : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLongl@slb.com zf C FL 4UAT E Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client : Eni Petroleum Well : OP21-WW01 Schlumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 7800.0 ft BHST : 93 degF Bit Size : 12 1/4 in fi (x 1000) psi OD 20.in 0 .5 5.0 o— @ 180ft v Frac Pore Permafrast OD 13.4 in @ 4100ft E- i Schrader Blurr M OD 9.82 in @ 7800ft o HRZ Top 0 0 LC @7720 ft I rn Well Lithology Formation Press. Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 4100.0 13 3/8 68.0 12.415 Landing Collar MD : 7720.0 ft Casing/liner Shoe MD : 7800.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 7800.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Page 2 op21-ww01.ctw;12-16-2010; LoadCase 9 5/8 Intermediate(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 5cIllebrier String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Mean OH Diameter : 12.250 in Mean Annular Excess : 35.0 Mean OH Equivalent Diameter: 13.045 in Total OH Volume : 611.6 bbl (including excess) Max. Deviation Angle : 37 deg Max. DLS : 2.501 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 33.0 0.000 100.0 100.0 0.0 33.0 0.000 200.0 200.0 0.0 33.0 0.000 300.0 300.0 0.0 33.0 0.000 400.0 400.0 0.0 33.0 0.000 500.0 500.0 0.0 33.0 0.000 600.0 600.0 0.0 33.0 0.000 700.0 700.0 0.0 33.0 0.000 800.0 800.0 0.0 33.0 0.000 900.0 900.0 1.5 33.0 1.500 1000.0 999.9 4.0 33.0 2.500 1100.0 1099.4 6.5 33.0 2.500 1200.0 1198.5 9.0 33.0 2.500 1300.0 1296.9 11.5 33.0 2.500 1356.6 1352.2 12.9 33.0 2.492 1400.0 1394.5 13.1 33.0 0.507 1500.0 1491.8 13.6 33.0 0.500 1600.0 1588.9 14.1 33.0 0.500 1700.0 1685.7 14.6 33.0 0.500 1800.0 1782.4 15.1 33.0 0.500 1872.4 1852.2 15.5 33.0 0.497 1900.0 1878.8 16.2 33.0 2.498 2000.0 1974.2 18.7 33.0 2.500 2100.0 2068.2 21.2 33.0 2.500 2200.0 2160.6 23.7 33.0 2.500 2300.0 2251.3 26.2 33.0 2.500 2400.0 2340.0 28.7 33.0 2.500 2500.0 2426.7 31.2 33.0 2.500 2600.0 2511.1 33.7 33.0 2.500 2700.0 2593.1 36.2 33.0 2.500 2727.2 2614.9 36.9 33.0 2.501 2800.0 2673.2 36.9 33.0 0.000 2900.0 2753.2 36.9 33.0 0.000 3000.0 2833.2 36.9 33.0 0.000 3100.0 2913.2 36.9 33.0 0.000 3200.0 2993.2 36.9 33.0 0.000 3300.0 3073.2 36.9 33.0 0.000 3400.0 3153.2 36.9 33.0 0.000 3500.0 3233.2 36.9 33.0 0.000 3600.0 3313.3 36.9 33.0 0.000 3700.0 3393.3 36.9 33.0 0.000 3800.0 3473.3 36.9 33.0 0.000 3900.0 3553.3 36.9 33.0 0.000 4000.0 3633.3 36.9 33.0 0.000 4100.0 3713.3 36.9 33.0 0.000 4200.0 3793.3 36.9 33.0 0.000 4300.0 3873.3 36.9 33.0 0.000 4400.0 3953.3 36.9 33.0 0.000 Page 3 op21-ww01.Ow:12-16-2010; LoadCase 95/8 Intermediate(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Sdimkrier String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4500.0 4033.3 36.9 33.0 0.000 4600.0 4113.4 36.9 33.0 0.000 4700.0 4193.4 36.9 33.0 0.000 4800.0 4273.4 36.9 33.0 0.000 4900.0 4353.4 36.9 33.0 0.000 5000.0 4433.4 36.9 33.0 0.000 5100.0 4513.4 36.9 33.0 0.000 5200.0 4593.4 36.9 33.0 0.000 5208.4 4600.1 36.9 33.0 0.000 5300.0 4673.4 36.9 33.0 0.000 5400.0 4753.4 36.9 33.0 0.000 5500.0 4833.5 36.9 33.0 0.000 5600.0 4913.5 36.9 33.0 0.000 5700.0 4993.5 36.9 33.0 0.000 5800.0 5073.5 36.9 33.0 0.000 5900.0 5153.5 36.9 33.0 0.000 6000.0 5233.5 36.9 33.0 0.000 6100.0 5313.5 36.9 33.0 0.000 6200.0 5393.5 36.9 33.0 0.000 6300.0 5473.5 36.9 33.0 0.000 6400.0 5553.5 36.9 33.0 0.000 6500.0 5633.6 36.9 33.0 0.000 6600.0 5713.6 36.9 33.0 0.000 6700.0 5793.6 36.9 33.0 0.000 6800.0 5873.6 36.9 33.0 0.000 6900.0 5953.6 36.9 33.0 0.000 7000.0 6033.6 36.9 33.0 0.000 7100.0 6113.6 36.9 33.0 0.000 7200.0 6193.6 36.9 33.0 0.000 7300.0 6273.6 36.9 33.0 0.000 7400.0 6353.6 36.9 33.0 0.000 7500.0 6433.7 36.9 33.0 0.000 7600.0 6513.7 36.9 33.0 0.000 7700.0 6593.7 36.9 33.0 0.000 7800.0 6673.7 36.9 33.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 154.0 11.20 9.00 Permafrost Siltstone 1901.0 12.00 9.00 Permafrast Siltstone 2062.0 12.50 9.00 Upper Ugnu Shale 3647.0 12.50 9.00 Schrader Blurr Sandstone 3699.0 12.50 9.00 N-Seq Top Shale 3748.0 12.50 9.00 N-Sand Sandstone 3981.0 12.50 9.00 OA Base Shale 4100.0 12.50 9.00 TD 13 3/8 Shale 7487.0 12.50 9.00 HRZ Top Shale 7577.0 12.50 9.00 HRZ Base Sandstone 7800.0 12.50 9.00 TD Shale Page 4 I op21-ww01.cfw,12-16-2010, LoadCase 9 5/8 Intermediate(al:Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Sinker's' String : Intermediate Casing District : Prudhoe Bay,Alaska Y Country : US Loadcase : 9 5/8 Intermediate(a) _ _ Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1901.0 1879.7 32 0.6 4100.0 3713.3 52 0.9 7800.0 6673.7 93 1.1 ft degF 10 20 30 40 50 60 70 80 90 100 o O °O- M S_ a) — Geoth.Rof ile — Tubular Fluids — Annulus O O O 0)— Temp. Profile At 108 min • Page 5 op21-ww01.cfw;12-t6-2010; LoadCase 9 5/8 Intermediate la);Version wcs-cem461 08 Client : Eni Petroleum Well : OP21-WW01 ScIinliener String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Section 2: fluid sequence Job Objectives: Sufficient shoe strength to allow drilling ahead. Original fluid Mud 10.00 lb/gal k:2.06E-3 Ibf.s^n/ft2 n :0.812 Ty:8.74 lbf/100ft2 Displacement Volume 565.2 bbl Total Volume 696.3 bbl TOC 6800.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 50.0 664.0 6136.0 12.00 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Tail Slurry 81.2 1000.0 6800.0 15.80 k:3.34E-2 lbf.s^n/ft2 n:0.757 Ty:0.14 lbf/100ft2 Mud 565.2 0.0 10.00 k:2.06E-3 lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks: Frac 482 psi at 4100.0 ft Pore 193 psi at 4100.0 ft Collapse 4146 psi at 7720.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 123 ton Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 50.0 10.0 50.0 80 7-Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 80 4-Drop Bottom Plug Tail Slurry 5.0 81.2 16.2 81.2 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 565.2 66.5 565.2 80 19-Start Displacement Total 01:47 hr:mn 696.3 bbl End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 301 psi at 7800.0 ft Pore 193 psi at 4100.0 ft Collapse 4146 psi at 7720.0 ft Burst 6283 psi at 0.0 ft Page 6 op21-ww01 cfw:12-16-2010, LoadCase 95/8 Intermediate(a).Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Sell �rgYr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) CemCADE Client :Eni Petroleum Well :OP21-W W01 String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US lb/gal ft 8 9 10 11 12 13 — —Hydrostatic — Mn.Hydrostatic — Max.Dynamc — Mn.Dynamic _.__ Frac —Pore O ! 0 N - i or i I ' y 0 i3 O 8 l O O v o _ i OD— 3 Fluid Sequence Dynamic Well Security ° ■MUDPl1SH II 50.0 bbl 12.00 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 Tail Slurry 81.2 bbl 15.80 lb/gal Herschel:k=3.34E-2 Ibf.s^n/ft2 n=0.757 Ty=0 14 Ibf/100112 .Mud 565.2 bbl 10.00 lb/gal Herschel:k=2.06E-3 Ibf.s^n/it2 n=0.812 Ty=8.74 Ibf/100ft2 Total Depth = 7800.0 ft Top of Cement= 6800.0 ft *Mark of Schlumberger Scli i'pr Page 7 op21-ww01 clw;12-16-2010; loadCase 9 5/8 Intermediate(al:Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WWO1 YchIo ie String : Intermediate Casing District : Prudhoe Bay,Alaska �j Country : US Loadcase : 9 5/8 Intermediate(a) Temperature Results BHCT 88 degF Simulated Max HCT 93 degF Simulated BHCT 64 degF Max HCT Depth 7800.0 ft CT at TOC 65 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 1 82 degF Bottom Hole (degF) (degF) 93 degF co --r° I I c 1 Illiv\ -N �(.0 O I 1 O o f Z a) -c U o.j o_ 0_ [is)(21 cD_ u7 C° First Sack Depth First Sack Temp. •Last Sack Temp. •Last Sack Depth H �y 4 --— — , — --- , -- co 0 20 40 60 80 100 120 Time (min) Page 8 op21-ww0l.cfw,12-16-2010. LoadCase95/8 Intermediate fa).Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Sile��r��r String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) ECD Profile at shoe: co Depth= 7800 ft I N- Hydrostatic Dynamc O Frac V-- Pore r I co r O co 01- co cd ---- 0 20 40 60 80 100 120 Time (min) ECD Profile at previous shoe: co _Depth= 4100 ft Fluids at 7800 ft N N- O Hydrostatic Dynarrc Frac O Pore r- co r o d O d— cy Of- i co 0 20 40 60 80 100 120 Time (min) Page 9 op21-ww0l.ctw;12-16-2010: LaadCase 9 5/8 Intermediate(a):Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Schiokrier String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Pressure Profile: O Calc.Pump Press. ---- ------ --- - ---- Calc.WHP // fA 4�. I 0 20 40 60 80 100 120 Time(min) U-tube profile,fluid-in vs.fluid-out: Fluids at 7800 ft _ - Q out E- i 8 �,- 0 20 40 60 80 100 120 Time (min) Page 10 op21-ww01.cfw,12.16-2010: LoadCase 9 5/B Intermediate lal:Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Yc1I ie1 String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 10.00 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.812 Ty :8.74lbf/100ft2 Gel Strength : 38.42 Ibf/100ft2 MUD Mud Type : WBM Job volume : 565.2 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water : 96.0% MUDPUSH II DESIGN Fluid No: 2 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 lbf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 50.0 bbl Tail Slurry DESIGN Fluid No:4 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 3.34E-2 Ibf.s^n/ft2 At temp. : 65 degF n :0.757 Ty :0.14)bf/100ft2 Gel Strength :22.57 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.118 gal/sk Job volume :81.2 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3/sk Quantity :391.61 sk Sack Weight : 94 lb Solid Fraction :41.2% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.038 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D185 0.050 gal/sk blend Dispers. LT D167 0.500%BWOC Fluid loss D153 0.200%BWOC Antisettling D186 0.030 gal/sk blend Accelerator Page 11 op21-w 01cfw.12-16-2010, LoadCase95/8 Intermediate(a),Version wcs-cem461 08 Client : Eni Petroleum Well : OP21-WW01 Schlcmberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Section 5: centralizer placement Top of centralization :6800.0 ft Bottom Cent. MD :7780.0 ft Casing Shoe :7800.0 ft NB of Cent. Used :25 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 7800.0 25 1/1 541 -STL-9 5/8-6-36(.171") 2.8 6820.0 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) 541 -STL-9 5/8-6-36 9 5/8 13.126 9.720 No Houma 12 250 238.30 1690 56 (.171") (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft 0 20 40 60 80 100 —t- Between Cent. At Cent. O O_ O N Well Pipe Standoff Page 12 op21-ww01.cfw;12-16-2010; LoadCase 95/8 Intermediate(a):Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 ScImerier String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.3 Total Drag Force :8 ton Hook load Down Stroke :159 ton Hook load Up Stroke :174 ton ft ton 0 0 20 40 60 80 100 120 140 160 180 — Hookload t. - Hookload Dow n - Weight - Drag Force p O8_ pO O- co 00- I Running Forces Page 13 op21-ww0l.clw:12-16-2010, LoadCase95/8lntermediale(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Silinierier String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Section 6: WELLCLEAN II Simulator °,U ok ft 25 50 75 100 0 20 40 60 80 100 I — — - Std Betw.Cent. - Mud Contamination Cement Coverage — Uncontaminated Slurry -1 I Z Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 2 g g 2 g 6800 * 4 6800 6800 - 6800 6900 '1 fir'"( 6900 6900 6900 7000 7000 7000 7000 7100 7100 7100 7100 7200 V -1 7200 f 7200 7200 sy , 7300 ',rot "ba 4 7300 1 s 7300 7300 .c o ,' ; n n Ta c 7400 ` ,,,,,;0.,,,,,. 7100 d 0 7400 7400 0 7500 x^y 7500 a 7500 7600 .,'1,'24.-,;;-!,,' 7600 7600 7600 7700 7700 7700 7700 7800 ` .411 xr ri, 7800 7800 �. . _- 7800 e C W o i' O 3 B 2 2 i. Mud IIII High M Low ME Tail Slurry Medium None iii MUDPUSHII Page 14 op21-ww0l.cfw;12-15-2010; LoadCase 95/8 Intermediate(a);Version wcs-cem461_08 Schlumberger CemCADE* well cementing recommendation for Production Liner Operator : Eni Petroleum Well : OP21-WW01 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : Oliktok Point Proposal No. : Draft v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 12-16-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1 @slb.com O �c n c OLtri �9 Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. *Mark of Schlumberger Client : Eni Petroleum Well : OP21-WW01 ScIikerier String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner Cal Section 1 : well description Configuration : Liner Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 10788.0 ft BHST : 200 degF Bit Size : 8 1/2 in ft (x 1000) psi 00 20.in 0 5.0 7.5 °— @ 160ft - —Frac —Pore Permafrast 0D 13.4 in _ @ 4100ft I 1 Schrader Blurr OD 5.in I o @ 7600ft o v - OD 9.62 in !� @ 7800ft HRZ Top LH @ 7600ft o_ o 0 0D7.in @ 10788ft ` I Sag-D LLC @10708 ft o Co - o Well Lithology Formation Press. Page 2 op21-ww0l.cfw,12-16-2010; LoadCase 7 in.Liner(al;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 7800.0 9 5/8 47.0 8.681 Drill Pipe MD OD Weight ID Grade Collapse Burst (ft) (in) (lb/ft) (in) (psi) (psi) 7600.0 5 19.5 4.276 E-75 9960 9500 Liner Hanger : 7600.0 ft Landing Collar MD : 10708.0 ft Casing/liner Shoe MD : 10788.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 10788.0 7 40.0 26.0 6.276 L-80 5410 7240 LTC Page 3 op21-ww01.cfw.12-16-2010, LoadCase 7 in Liner fal,Version wts-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Wok" String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Mean OH Diameter : 8.500 in Mean Annular Excess : 35.0 Mean OH Equivalent Diameter: 8.966 in Total OH Volume : 233.3 bbl (including excess) Max. Deviation Angle : 37 deg Max. DLS : 2.513 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 33.0 0.000 100.0 100.0 0.0 33.0 0.000 200.0 200.0 0.0 33.0 0.000 300.0 300.0 0.0 33.0 0.000 400.0 400.0 0.0 33.0 0.000 500.0 500.0 0.0 33.0 0.000 600.0 600.0 0.0 33.0 0.000 700.0 700.0 0.0 33.0 0.000 800.0 800.0 0.0 33.0 0.000 900.0 900.0 1.5 33.0 1.500 1000.0 999.9 4.0 33.0 2.500 1100.0 1099.4 6.5 33.0 2.500 1200.0 1198.5 9.0 33.0 2.500 1300.0 1296.9 11.5 33.0 2.500 1356.6 1352.2 12.9 33.0 2.492 1400.0 1394.5 13.1 33.0 0.507 1500.0 1491.8 13.6 33.0 0.500 1600.0 1588.9 14.1 33.0 0.500 1700.0 1685.7 14.6 33.0 0.500 1800.0 1782.4 15.1 33.0 0.500 1872.4 1852.2 15.5 33.0 0.497 1900.0 1878.8 16.2 33.0 2.498 2000.0 1974.2 18.7 33.0 2.500 2100.0 2068.2 21.2 33.0 2.500 2200.0 2160.6 23.7 33.0 2.500 2300.0 2251.3 26.2 33.0 2.500 2400.0 2340.0 28.7 33.0 2.500 2500.0 2426.7 31.2 33.0 2.500 2600.0 2511.1 33.7 33.0 2.500 2700.0 2593.1 36.2 33.0 2.500 2727.2 2614.9 36.9 33.0 2.501 2800.0 2673.2 36.9 33.0 0.000 2900.0 2753.2 36.9 33.0 0.000 3000.0 2833.2 36.9 33.0 0.000 3100.0 2913.2 36.9 33.0 0.000 3200.0 2993.2 36.9 33.0 0.000 3300.0 3073.2 36.9 33.0 0.000 3400.0 3153.2 36.9 33.0 0.000 3500.0 3233.2 36.9 33.0 0.000 3600.0 3313.3 36.9 33.0 0.000 3700.0 3393.3 36.9 33.0 0.000 3800.0 3473.3 36.9 33.0 0.000 3900.0 3553.3 36.9 33.0 0.000 4000.0 3633.3 36.9 33.0 0.000 4100.0 3713.3 36.9 33.0 0.000 4200.0 3793.3 36.9 33.0 0.000 4300.0 3873.3 36.9 33.0 0.000 4400.0 3953.3 36.9 33.0 0.000 Page 4 op21-ww0l.cfw;12-16-2010; LoadCase 7 in.Liner(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Sc Iiii e1 String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4500.0 4033.3 36.9 33.0 0.000 4600.0 4113.4 36.9 33.0 0.000 4700.0 4193.4 36.9 33.0 0.000 4800.0 4273.4 36.9 33.0 0.000 4900.0 4353.4 36.9 33.0 0.000 5000.0 4433.4 36.9 33.0 0.000 5100.0 4513.4 36.9 33.0 0.000 5200.0 4593.4 36.9 33.0 0.000 5208.4 4600.1 36.9 33.0 0.000 5300.0 4673.4 36.9 33.0 0.000 5400.0 4753.4 36.9 33.0 0.000 5500.0 4833.5 36.9 33.0 0.000 5600.0 4913.5 36.9 33.0 0.000 5700.0 4993.5 36.9 33.0 0.000 5800.0 5073.5 36.9 33.0 0.000 5900.0 5153.5 36.9 33.0 0.000 6000.0 5233.5 36.9 33.0 0.000 6100.0 5313.5 36.9 33.0 0.000 6200.0 5393.5 36.9 33.0 0.000 6300.0 5473.5 36.9 33.0 0.000 6400.0 5553.5 36.9 33.0 0.000 6500.0 5633.6 36.9 33.0 0.000 6600.0 5713.6 36.9 33.0 0.000 6700.0 5793.6 36.9 33.0 0.000 6800.0 5873.6 36.9 33.0 0.000 6900.0 5953.6 36.9 33.0 0.000 7000.0 6033.6 36.9 33.0 0.000 7100.0 6113.6 36.9 33.0 0.000 7200.0 6193.6 36.9 33.0 0.000 7300.0 6273.6 36.9 33.0 0.000 7400.0 6353.6 36.9 33.0 0.000 7500.0 6433.7 36.9 33.0 0.000 7600.0 6513.7 36.9 33.0 0.000 7700.0 6593.7 36.9 33.0 0.000 7800.0 6673.7 36.9 33.0 0.000 7900.0 6753.7 36.9 33.0 0.000 7965.3 6805.9 36.9 33.0 0.000 8000.0 6833.9 36.0 33.0 -2.476 8100.0 6916.0 33.5 33.0 -2.500 8200.0 7000.6 31.0 33.0 -2.500 8300.0 7087.4 28.5 33.0 -2.500 8400.0 7176.3 26.0 33.0 -2.500 8500.0 7267.1 23.5 33.0 -2.500 8600.0 7359.6 21.0 33.0 -2.500 8700.0 7453.8 18.5 33.0 -2.500 8765.3 7515.9 16.9 33.0 -2.513 8800.0 7549.2 16.9 33.0 0.000 8900.0 7644.9 16.9 33.0 0.000 9000.0 7740.6 16.9 33.0 0.000 9100.0 7836.3 16.9 33.0 0.000 9200.0 7932.0 16.9 33.0 0.000 9300.0 8027.7 16.9 33.0 0.000 9400.0 8123.4 16.9 33.0 0.000 9500.0 8219.1 16.9 33.0 0.000 9600.0 8314.8 16.9 33.0 0.000 9700.0 8410.5 16.9 33.0 0.000 9800.0 8506.2 16.9 33.0 0.000 Page 5 op21-wwO1 c(w;12-16-2010; LoadCase 7 In Liner(al:Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Silmikerpr String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(al Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 9900.0 8601.9 16.9 33.0 0.000 10000.0 8697.6 16.9 33.0 0.000 10100.0 8793.3 16.9 33.0 0.000 10200.0 8889.0 16.9 33.0 0.000 10300.0 8984.7 16.9 33.0 0.000 10400.0 9080.4 16.9 33.0 0.000 10420.7 9100.2 -16.9 33.0 0.000 10500.0 9176.1 16.9 33.0 0.000 10600.0 9271.8 16.9 33.0 0.000 10700.0 9367.5 16.9 33.0 0.000 10788.0 9451.7 16.9 33.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 154.0 11.20 9.00 Permafrost Siltstone 1901.0 12.00 9.00 Permafrast Siltstone 2062.0 12.50 9.00 Upper Ugnu Shale 3647.0 12.50 9.00 Schrader Blurr Sandstone 3699.0 12.50 9.00 N-Seq Top Shale 3748.0 12.50 9.00 N-Sand Sandstone 3981.0 12.50 9.00 OA Base Shale 4100.0 12.50 9.00 TD 13 3/8 Shale 7487.0 12.50 9.00 HRZ Top Shale 7800.0 12.50 9.00 HRZ Base Sandstone 7965.0 13.00 9.00 LCU Shale 9733.0 13.50 9.00 Sag-D Sandstone 9768.0 13.50 9.00 Sag-C Sandstone 9841.0 13.50 9.00 Shublik Sandstone 10096.0 13.50 9.00 Ivishak Sandstone 10788.0 13.60 9.00 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1901.0 1880.0 32 0.6 4100.0 3713.3 52 0.9 7800.0 6673.7 93 1.1 10788.0 9451.7 200 1.9 Page 6 op21-ww01.dw;12-16-2010; LoadCase 7 in Liner(a),Version wcs-cem461_08 Client : Eni Petroleum Well : 0P21-WWO1 SINN String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Section 2: fluid sequence Job Objectives: Zonal isolation: Cement to top of liner hanger at 7600'. Original fluid Mud 10.00 lb/gal k :2.06E-3 Ibf.s^n/ft2 n :0.812 Tv: 8.74 lbf/100ft2 Displacement Volume 253.9 bbl Drill Pipe Volume 135.0 bbl Total Volume 403.2 bbl TOC 7600.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 50.0 1022.1 6577.9 13.40 k:4.62E-2 Ibf.s^n/ft2 n:0.424 Ty:15.95 lbf/100ft2 Tail Slurry 99.3 3188.0 7600.0 15.80 k:3.07E-2 lbf.s^n/ft2 n:0.717 Ty:0.02 lbf/100ft2 Mud 253.9 0.0 10.00 k:2.06E-3 lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks: Frac 674 psi at 7800.0 ft Pore 539 psi at 7800.0 ft Collapse 3900 psi at 10708.0 ft Burst 7240 psi at 10708.0 ft Csg.Pump out 69 ton Page 7 op21-ww01 cfw,12-16-2010; LoadCase 7 in.Liner(a) Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 kiliberill String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 50.0 10.0 50.0 80 7-Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 80 4-Drop Bottom Dart Tail Slurry 5.0 99.3 19.9 99.3 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Dart Mud 8.5 30.0 3.5 30.0 80 19-Start Displacement Mud . 5.0 5.0 1.0 35.0 80 Shear Bottom Plug Mud 8.5 100.0 11.8 135.0 80 Cont.Displacing Mud 5.0 4.0 0.8 139.0 80 Shear Top Plug Mud 8.5 11.0 1.3 150.0 80 Cont.Displacing Mud 5.0 4.0 0.8 154.0 80 Bottom Plug at Landing Collar Mud 4.0 80.0 20.0 234.0 80 Slow rate Mud 3.0 19.9 6.6 253.9 80 Slow rate as Slurry enters lap Total 01:30 hr:mn 403.2 bbl End Job: Bump Plug; Check floats Dynamic Security Checks: Frac 24 psi at 10788.0 ft Pore 347 psi at 7800.0 ft Collapse 3900 psi at 10708.0 ft Burst 5778 psi at 7600.0 ft Temperature Results BHCT 150 degF Simulated Max HCT 200 degF Simulated BHCT 130 degF Max HCT Depth 10788.0 ft CT at TOC 110 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 91 degF Bottom Hole (degF) (degF) 200 degF Page 8 op21-ww01.cfw,12-16-2010; LoadCase 7 in Liner(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 SCIIII brier String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) * CemCADE Client :Eni Petroleum Well :OP21-W W01 String :Production Liner District :Prudhoe Bay,Alaska Country : US ft lb/gal 8 9 10 11 12 13 14 O- <-– --- > I---- -- I I { I I —Hydrostatic -Mn.Hydrostatic • -Max.Dynastic - Mn.Dynastic 0 • --- Frac O • N_ -Fore _ I $_ 0 E l E � E ' of E 0 l l 8- C > 2 6.: 8 \\...,,,,,NN---\\\......., � _ i !!i u 00 E Irio°O l s S CV 3 — s I Fluid Sequence Dynamic Well Security ■MUDPUSH II 50.0 bbl 13.40 lb/gal Herschel:k=4.62E-2 Ibf.s^n/ft2 n=0.424 Ty=15.95 Ibf/100ft2 IITail Slurry 99.3 bbl 15.80 lb/gal Herschel:k=3.07E-2 Ibf.s^n/ft2 n=0.717 Ty=0.02 Ibf/100ft2 ■Mud 253.9 bbl 10.00 lb/gal Herschel:k=2.06E-3lbf.s^n/ft2 n=0.812 Ty=8.74 Ibf/100f12 Total Depth =10788.0 ft Top of Cement= 7600.0 ft *Mark of Schlumberger SChillib r Page 9 op21-ww0l.cfw;12-16-2010; LoadCase 7 in.Liner(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Scllikerger String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Temperature Profile: — o /. 1N - W8- First Sack Depth 1 R6 First Sack Temp. �- i ■—■—•- Last Sack Temp. v Last Sack Depth -(p C g IV‘ 1 !p 8_ 1 O O 10 20 30 40 50 60 70 80 90 100 Time(min) ECD Profile at the shoe: Depth= 10788 ft Hydrostatic -Dynamic 1 Frac -Pore CV I N 7 1 to DE • O i I 1 O 0 10 20 30 40 50 60 70 80 90 100 Time(min) Page 10 op21-ww01.cfw,12-16-2010; LoadCase 7 in Liner(a),Version wcs-cem461_08 A Client : Eni Petroleum Well : OP21-WW01 SciIohrger String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Pressure Profile: • 0 N Calc.Pump Press. 1 Calc.WHP CO I e CO / 1.4- V g N r X O d O I d d N -11 1--'. U'. 0 O 10 20 30 40 50 60 70 80 90 100 Time (min) U-tube Profile: Fluids at 10788 ft Qout Q In c co I 1 N- O 1 r T 0 10 20 30 40 50 60 70 80 90 100 Time (min) Page 11 op21-ww01.cfw,12-16-2010, LoadCase7in.Liner(al,Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 ScSImierger String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 10.00 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 lbf.sAn/ft2 At temp. :80 degF n :0.812 Ty :8.741bf/100ft2 Gel Strength : 38.42 Ibf/100ft2 MUD Mud Type : WBM Job volume :253.9 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0 Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 13.40 lb/gal Rheo. Model : HERSCHEL_B. k :4.62E-2 Ibf.s^n/ft2 At temp. : 117 degF n :0.424 Ty : 15.95 lbf/100ft2 Gel Strength : 32.02 Ibf/100ft2 Job volume : 50.0 bbl Tail Slurry DESIGN Fluid No:4 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k :3.07E-2 lbf.s^n/ft2 At temp. : 117 degF n :0.717 Ty :0.02 lbf/100ft2 Gel Strength : 10.69 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.095 gal/sk Job volume :99.3 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3/sk Quantity :479.02 sk Sack Weight : 94 lb Solid Fraction :41.5% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.065 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.300%BWOB Dispersant D167 0.500%BWOC Fluid loss D153 0.200%BWOC Antisettling D177 0.030 gal/sk blend Retarder Page 12 op21-ww0l.cfw;12.16-2010. LoadCase 7 in.Liner lal;Version wcs-cem461_06 Client : Eni Petroleum Well : OP21-WW01 ScIimlerger String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Fluid Rheological Heirarchy Profile: Annulus ID: 7.000 in (Q7 Flow Rate : 7.0 bbl/min 1` ----Tail Slurry - MUDPUSH I Mud a '- ______ . .. __ _ _... ._ . i Q- 0 t ._.. _.... ........,......_.........._ 1 6 � 8- -- 1 1 1 1 1 -h I 1 -h -1 1 i I 8.49 8.52 8.55 8.58 8.61 8.64 8.67 8.70 8.73 8.76 8.79 8.82 8.85 8.88 8.91 Annulus OD (in) QQ Annulus ID: 7.000 in-OD: 8.500 in §+ ---, Tail Slurry - MUDPUSHN 8 Mid I,- - 2. a_ e §- •c u_ 8- N 8- • 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) Page 13 op21-ww0l.cfw;12-16.2010; LoadCase 7 in.Liner tai;Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Sribpberier String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Section 5: centralizer placement Top of centralization :7600.0 ft Bottom Cent. MD :10768.0 ft Casing Shoe :10788.0 ft NB of Cent. Used :79 NB of Floating Cent. :79 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 10788.0 79 1/1 1731270-7-0-RIGID W119 31.8 8228.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 1731270-7-0-RIGID W119 7 8.252 8.252 Yes Houma N.A. N.A. N.A. (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft % o_ 30 40 50 60 70 80 90 100 I [ —Betw een Cent. o I-- _ + +At Cent. O O— co 4r ti L_ o Do- rn o - o - 00_ _ 0 0 f— Well Pipe Standoff Page 14 op21-ww01.cfw,12-16-2010, LoadCase 7 in Liner lal,Version wcs-cem461_08 Client : Eni Petroleum Well : OP21-WW01 Saltier String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) ft ton 0 20 40 60 80 100 120 140 o —Fbokload Up — Hookload Dow n - Weight — Drag Force - 0 O— O O oo S N Running Forces Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.3 Total Drag Force :9 ton Hook load Down Stroke :111 ton Hook load Up Stroke :129 ton Page 15 op21-ww0l.cfw;12-16-2010; LoadCase 7 in.Liner lal;Version wcs-cem461 O6 Client : Eni Petroleum Well : OP21-WW01 le" String : Production Liner District : Prudhoe Bay,Alaska Country : US Loadcase : 7 in.Liner(a) Section 6: WELLCLEAN II Simulator 4 % % ft 25 50 75 100 0 20 40 60 80 100 Std Betw.Cent. —Mud Contamination Cement Coverage — Uncontaminated Slurry • ai W • e pt _ l7 § .----- r — Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall ; z° '3 z° rf 8000 ! -8000 8000 . 8000 8500 -8500 8500 8500 9000 -9000 L 9000 9000 ` r c i r o°a 9500 -9500 o 8 9500 9500 �° 1D000- -10000 10000 10000 10500 . -10500 10500 10500 • 5. o F `3 0 F vo 0 O 2 2 Mud - High Lov,. Tail Slurry ME Medium r None IIIII MUDPUSHII Page 17 op2l-wwOl cfw,12-16-2010, LoadCase 7 in.Liner lal,Version wcs-cem461_08 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). S P E O IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 I/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. S IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni UP Division REVISION STAP-P-1-M-6140 _ 0 1 1 I I I I I 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. S P E O IDENTIFICATION CODE PAG 209 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 I LEAK-OFF TEST REPORT Report N° Date: WELL NPRAE: WELL CODE: I CONTRACTOR: RIG NAME: RIG CODE Open hole depth(m): 825 Mud Type: FWGELS Rig type: J.UPs Hole Ctamete r(in): 121/4 Weight(KgA): 1.3 R.K.B.elevation(m): 26 last Csg.Shoe(m): 797 Marsh Uscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter 0n): 13'3/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: 155 Y.P.Qb/100 50): 5 Liners(in): B 5" Weight 4b/t): 61 Gels(1b/100 V): 218 Flow Rate(bpi): 0.25 Max.Burst pres(psi). 3103 W.L(cc 30 min): 10.6 LRholog y Shale Expected EMW 1.68 Kg/crn2ll0 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bSl) (Psi) (min) (bbl) (Psi) (min) (bbl( (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 100 30D 10.5 2 463 5 125 400 11 2 455 6 150 50D 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 _ Nate: Pumped with a constant tow rate of(bbl): bblume pumped(bbl). yblume returned(bbl): (po) 1000 - 900 800 stop pump P 700 r e 600 • - shut in curve S 500 / --S U 400 r 18 minutes ( e 300 200 100 • 0 . . . . . . . , . . , • . • • r • • • . • • . • 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbl) 4 r Time mins RESULTS:press., +press.,n.)x101D epth=[(1.3 x 797 110)+(430 x 0.07)]x10 1797=1.68(Kg/cm2/10 m) Note. I Company Representative Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK 5 TN Point 0 INTAKE DOCK OPP THIS I MODULE RR P 5 SURVEY SI' P g N pip{ �� DS-3R O I DEW UNE r9 /le, l r 1 ITE • o i STP I 1 OUKTOK POINT MODULES I --- N DC STAGING AREA•. T13N, R9E ' DS-30 J I . 0--. y1 -1' ' 18 �• 1 �I : t ,� �f 15 SCALE: Oh ' 1" = 150' � ,,, D5-30 2iN . 19 rth ,:' (-2-6-; A,. ?-2. S TP PAD VICINITY MAP o SCALE: 1" = 1 Mile °°o -o ° \ �0-0 0-o \9-o° o, °�S O O �' 0 �o0.0 \ c\,,:\ 0 Q 0-0 -0 °,'rp 0O 37 \\\c\ OW° C- , '- '' \\\\D\ O00°'0 °Oux--> O°-o o__1 \'0 0 , �0 OOOO-0,v' , os \ Z ul O0���o / ,\ OZ ( \ OLIKTOK \ O0 POINT PAD \ 0. \ as \ \ 0 9 , / \ , SEE SHEET 3 FOR NOTES \ / LOUNSBURY....;• Existing Conductor /�' & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS J AREA: MODULE: UNIT: it= JL EnO PPt�r©II °�tu��rrii OWELLOCO CONDUCTOR RD Era ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 _ NSK 6.80-d1 1 OF 3 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 V OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 0P15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 • ! DISPOSAL WELLS AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. O. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: elm C -- BM r etroHeur POINT PAD WELL no ASBUILT LOCATIONS CAD DRAWING NO:LK680D1 10/9/08 N SK 6.80-d 1 PART: 2 OF 3 `REV: 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. .•• c OF44444444444 SURVEYOR'S CERTIFICATE e i '':: . ' h %\ .• ' ' ♦II I HEREBY CERTIFY THAT / AM PROPERLY • REGISTERED AND LICENSED TO PRACTICE • �,�� ,., g.LAND SURVEYING IN THE STATE OF j"D� J. Ro oKUS o r ALASKA AND THAT THIS PLAT REPRESENTS ♦ °.A SURVEY DONE BY ME OR UNDER MY �� s� S-803 ��"= F J DIRECT SUPERVISION AND THAT ALL �1%***•.,4 ....119,./ `' : CORRECT AND OTHER DETAILS ARE DECEMBER 23, 2008. 1�,,->t�t"s•- •• LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: ` P- - -1-- Eno P�t�rollkiu��n�n OLIKTOK POINT PAD C�� 'r WELL CONDUCTOR ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80—d1 3 OF 3 2 O O O O CO M O ..i O N • A o O O h- . ti d, re o w _ Q LL V O S O _ ci 1 11_11_ , .-3- N co _O N O `r E mi V i , 0 U O ,:t A+ W W , o �_ O O O , CD LO Cr a NO Q a o O W O O O o O O O o Co o Co O Co d' O 0 Co 0 0 O Co 0 Co O Co 0 ao LO 0 , 00 CO CO 1.0 LO LO TRANSMITTAL LETTER CHECKLIST ' WELL NAME /t-/ a C- ( - (e'�/0,�`--'' 1 PTD# 7 l; Development / Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 'J � t!,!� �' POOL: /44- /L71 C'�� - /L71 /1 / Lf`- 4 /(44-t_ Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well _ (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 El[1] o m , _o , a) c -o.. co, ; , co w , Co m. � � a '� m• , U , O , a O N co' co E O Q' Co , , o o o , 2 Q c, a �� C � C , , , � a), N, CO >, . . ' -�, - N , M. , L �, ? , <, . a, . >. y, 'O. m , �, E, 3.• a 0, . �.CO 7 a) N 01 N y tn, g 0, CD)c , O, , p, , O, 4 O, M' p , 2, , a), 4 , N j 9, Z �, •y, a, , c. c' O), , si `, N N' y, N) E,• U 3N , ° ' �, �, Md . Lt, y �, ° a) v _ Q 0 O), >, 2, , a), ) , w W, v. as > O, , ', , a), a), ti CO a) < J, 7. f` N, a N >Ca C, , �, , X X N, C, cEC) C7 o. 0, N, . y, , a> , O, N. a a >. 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