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211-139
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O • U b ° Eco ��._ z `�\ M 3 v Z i M ;i 'ji (•) ry - Co CC in c H CO i y c.) o o2 c d 2 0 a 5 E Z. 0ta E o oiH E i o RECEIVED STATE OF ALASKAN E C 2 3 2013 ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AC _r 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U ESP Change Out Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator Eni US Operating Co.Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Exploratory ❑ 211-139 b 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: >< AK 99503 50-629-23458-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0391283,0388583,0388574,0388574 . SP27-N1 4 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):ss Nikaitchuq/Schrader Bluff Oil Pool 11.Present Well Condition Summary: Total Depth measured % 14,155 feet Plugs measured feet true vertical 3,743 feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2,664 13.375 2,664 2,466 5,020 2,270 Intermediate Production 8,245 9.625 8,245 3,739 6,870 4,760 Liner 6,010 5.5 14,103 3,743 slotted slotted Perforation depth Measured depth feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) 4.5 12.6 ppf L80 7,252'MD 3,677'TVD Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS . MAY 17 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1376 110 51 242 236 Subsequent to operation: 1376 110 51 242 236 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development El • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil . ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-573 Contact Giuseppe Maugeri Email giuseppe.maugeri(C7enipetroieum.com Printed Name Marc Kuck Title Production Optimization Coordinator Signature „.72,. .,/11-----LPhone (907)865-3328 Date 12/18/2013 Form 10-404 Revised 10/2012 s---2/-,,, Submit Original Only f2"1//Y ❑ U U N W O Lai Y,,' �•_ m -0 J l • M C ice+ i 3 , o a� M a) o m � o o \ 2 o L •W N � (n O Z ~ 1- No 0 I I 's C� J c LI, Cn U) coLm L 0 ^^s- W < NC Y VII l''Wa)12 CO 0 CU \ O U Q Q N 1 3 0 co _ �. I I O 0_ 2 — ❑ a X la oX = - � 3 CO —_ _ ) 0 ' M •O I I , � Y X 0) ° d X N U al m COpCO _ �' m a) 0 M& _ ,I I ❑ � 20 2- ca o c6 as m .. I m I Ix pco 0 m O U co M ❑ N d .� p ❑ o J W •E c — H p 0) O 0E - N- WN N oo ._ C0 U M co N Q� Q > MH -EL �° U > O (0 ❑ 2 I I 0 0 o .c o 1- cn co 2 a M o H Io co as MCO r- U , U _ _ M C Q N (n �? U N- /r "' 0) 2 m ❑ .u, ^X a� o - £ `n c\i a \ 3 r` c� Z-5) o 4 a N N ` / .' / 110Z 0 F cc 1 i 1 ' \ '',/--7 \ \ ., a .4t zo -0 � N M d ci as N c cn U (0 o 1 •� M ❑ p -it 0 = M 2 v Cr I C �' U CD CO 0 N as Z I Eni E&P Division [Well Name:SP27-N1 OR ENI Petroleum Co.Inc. Daily Repo Well Code:26116 Field Name: Nikaitchuq • APIIt1Wl:50-629-23458-00-00 2 I� "�, Date:11/15/2013 - Report#: 1 page 1 of 1 wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.42 12.43 3.99 11.20 9.67 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP27-N1 WORKOVER 2,223.21 1.115.76 714.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 109.0 -13.9 Snow WC-10' NW @19 MPH Daily summary operation 24h Summary Accept rig @ 0001 hrs.R/D from well SP08.move to well SP27 and rig up. Operation at 07.00 Bring Water to Rig Pits 24h Forecast / Complete R/U procedures and inspect berming.Bring on produced water from Operations into rig pits.R/U to Tree and PT lines.Pump 165 bbls of water down tubing.Vetco to set BPV and N/D tree and N/U BOP E. 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 04-.30 4.50 4.50 W.O. A 2 P PJSA Rig accepted to SP27 @ 0001 hrs.Move pump room#3.Prep for laying herculite.Blow down water,steam and gray waterinspect moving sys.Work on suit cases. 04.30 05:30 1.00 5.50 W.O. A 2 P PJSA Skid rig floor and raise stompers.Move out Rock Washer. 05.30 12:00 6.50 12.00 W.O. A 2 'P PJSA Split pits off rig module,remove diverter pipe,move sub down pad to well SP27-N1 RWO. 12:00 14:30 2.50 14.50 W.O. A '2 'P PJSA Spot sub over well and mate up pit module. 14:30 16:00 1.50 16.00'W.O. 'A 2 P PJSA Lower stompers and skid rig floor over well.Work on interconnects.Spot Rock Washer. 16:00 00:00 8.00 24.00'W.O. -A 2 P PJSA Work on suit cases and R/U rig components.Work on berming. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener .ENI Senior Drilling Supv SIDDritling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 2,466.75 4.314.44 12/29/2011 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,513.08 1,139.65 OBM(FazePro) 1126.4 48.4 1550.8 176.7 Eni E&P DivisionWell Name: SP2?-N1 OR ft* ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^tt Date:11/16/2013 - Report#: 2 iI ('(I page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.42 12.43 3.99 11.20 9.67 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP27-N1 WORKOVER 2223.21 1,115.76 715.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 107.0 -10.0 Snow WC-4 W @ 21 MPH Daily summary operation 24h Summary Fill mud pits w/235 bbls of produced water via Production.R/U and inject 165 bbls of produce water down tubing.Vetco checkout wellhead and prep for R/D.Install BPV and N/D tree,cap control and ESP line.N/U Hi pressure riser and BOPE.Test BOPE as per AOGCC regs.Witness waived by Chuck Scheve.R/U to pull tubing. Operation at 07.00 POOH UD tubing. 24h Forecast Pull Vetco hanger to rig floor and dismantle jewelry.POOH L/D 4.5"tubing as per tally. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1006.5 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 W.O. A 12 'P PJSA Finish berming and inspected by ACS.Test all suitcase lines wl 115 psi air. 03:00 05:30 2.50 5.50 W.O. L 20 'P PJSA R/U pumping flanges and hose to choke line on SI25 and bring on 235 bbls of 146 degree produced water to mud pits @ 3 bpm,230 psi.Blow down lines. 05:30 08:00 2.50 8.00 W.O. L 9 ,P PJSA R/U injection line to SP 27 and Bullhead 165 bbls of produced water down tubing @ ICP 1 bpm @ 2100 psi and FCP 2.3 bpm @ 230 psi.Shut well in and blow down lines. 08:00 12:00 4.00 12.00 W.O. L 20 .P PJSA Bleed down IA f/13 to 0 psi.Vetco checked void and hanger seals.Install BPV and N/D Tree,cap control and ESP line.N/U Hi pressure riser. 12:00 15:00 3.00 15.00 W.O. L 20 P PJSA N/U BOPE,bell nipple and secure stack. 15:00 16:30 1.50 16.50 W.O. L 12 P PJSA R/U to test BOPE.fill stack and test mud lines to 3000 psi. 16:30 21:00 4.50 21.00 W.O. L 12 P PJSA Test BODE as per AOGCC regs w/4.5"test jt to 250/3500 psi.Witnessed waived by Chuck Scheve. 21:00 22:00 1.00 22.00 W.O. L 20 'P PJSA R/D test equipment and blow down choke and kill lines. 22:00 22:30 0.50 22.50 W.O. L 20 P PJSA Pull test dart. 22:30 00:00 1.50 24.00 W.O. L 20 P PJSA Clear and clean rig floor.Pull to rig floor casing equipment,baker tools and R/U to pull tubing. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDritling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasniko8 ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 2,466.75 4,314.44 12/29/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.513.08 1,139.65 OBM(FazePro) 1126.4 48.4 1550.8 176.7 Eni E&P Division (Well Name: SP27-N1 OR I ft* ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^o Date:11/17/2013 - Report#: 3 If II II page 1 of 1 Wellbore name: SP27-N1 • Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.42 12.43 3.99 11.20 9.67 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP27-N1 WORKOVER 2.223.21 1.115.76 716.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 0.00 119.0 -16.1 Cloudy WC-12' NNW @ 14 MPH Daily summary operation 24h Summary POOH L/D 4.5"completion string as per tally until reaching fish.PJSA w/Howco and Well Tec.Remove fish f/tubing and L/D same.Cont.to POOH L/D completion string. Operation at 07.00 Prep for new competion run. 24h Forecast Complete decompletion process,Gear and clean ng floor,prep and run new ESP 4.5"completion string as per tally. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1006.5 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 W.O. L 20 P PJSA Complete R/U of GBR casing equipment. 00:30 02:00 1.50 2.00 W.O. L 19 P PJSA Pull BPV and M/U Landing jt.,XO and TIW valve.Install GBR bail extensions.Vetco B/O LDS and unseat hanger @ 195k,Pull hanger to rig floor 145k puw,108k sow.Pump in 30 bbls water w/no retums. 02:00 06:00 4.00 6.00 W.O. L 20 P PJSA on L/D completion string w/all parties.Disconnect ESP and control line,L/D hanger and landing jt.L/D bale extension s.Baker prep.lines to run over sheaves.Had ESP cutting training with rig hands.Run rope over sheaves to spooling unit. 06:00 11:00 5.00 11.00 W.O. L 4 P PJSA POOH with 4.5"completion f/7251'-4825'spooling cables and filling hole w/10 bbls/10 jts.L/D GLM and drop 2.9" rabbit w/wire line @ it#121. 11:00 12:00 1.00 12.00 W.O. L 4 P -PJSA POOH L/D completion string f/4825'-4703',130k puw,112k sow.122 bbls.fluid loss for tour. 12:00 13:00 1.00 13.00 W.O. L 4 P PJSA POOH vS 4.5"tubing completion f/4703'-4210'. 13:00 15:00 2.00 15.00 W.O. L 9 P 'PJSA Pump 260 bbls of produced water down backside until returns.Pump 65 bbls down tubing string @ 2bpm 1420/1030 psi.Blow down lines. 15:00 20:00 5.00 20.00 W.O. L 4 P 'PJSA POOH f/4210'-211'.Fish 8'below tool joint on jt#3,1)1 above lower GLM. 20:00 21:00 1.00 21.00 W.O. L 9 P 'PJSA R/U XO and TIW.Pump 218 bbls of produced water down IA until retums.R/D same and blow down lines. 21:00 22:30 1.50 22.50 W.O. L 13 P 'PJSA PJSA w/Howco and Well Tec.R/U and retrieve E-line and Well Tec tools and L/D same.R/D Howco tools. 22:30 00:00 1.50 24.00 W.O. L 4 P PJSA POOH to MLE connector and remove and L/D.Remove capillary tube and RIH and L/D Discharge sub assy. 624 bbls fluid loss for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener .ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 2,466.75 4.31444 12/29/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,513.08 1,139.65 OBM(FazePro) 1126.4 48.4 1550.8 176.7 • '�ii# Eni E&P Division .. Iwell Name:SP27-N1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nlkaitchuq • APIIUWI:50-629-23458-00-00 2�'f II,II r, Date:11/18/2013 - Report#: 4 page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.42 1243 3.99 11.20 9.67 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB)•Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP27-N1 WORKOVER 2,223.21 1.115.76 717.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 113.0 -21.7 Snow WC-20" WNW @ 18 MPH Daily summary operation 24h Summary Finish UD of old completion equipment.Clear and clean rig floor then bring up new completion equipment.M/U Baker ESP completion as per tally. Operation at 07.00 Making Splice on ESP Cable 24h Forecast RIH w/4.5"12.68 L-80 HYD 563 ESP completion and land on Vetco hanger. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1006.5 Time Log StartEnd Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dascr. 00.00 02.00 2.00 2.00 W.O. L 4 P PJSA UD 1 jt tbg and retrieve ESP pump assy as per Baker.UD intake screen,upper and lower seal assy and motor assy. Retrieved 122 reg clamps.10 special clamp wl 3 damaged. 02:00 03:00 1.00 3.00 W.O. L 20 P PJSA R/D ESP and control lines to spooler and secure.245 bbls to 811 hole @ 7 bpm. 03:00 04:00 1.00 4.00 W.O. L 20 P PJSA Clear and clean rig floor.Strap and drift tubing and ready new Baker completion equipment.Fill hole w/20 bbls every 30 min. 04:00 07:00 3.00 7.00 W.O.O. 'K 20 P PJSA Bring new completion equipment to rig floor and stage.Volant tool to ng floor.Baker prep new pump and motor assy. in pipe shed. 07:00 08:00 1.00 8.00 W.O. K 9 P PJSA Fill hole oh 230 bbls @ 7 bpm. 08:00 10:00 2.00 10.00 W.O. K 20 P PJSA C/O ESP and cap line in dual spooler unit. 10:00 10:30 0.50 10.50 W.O. K 25 P PJSA service ng,Top-dnve,OW,Traveling blocks and crown. 10:30 11:30 ' 1.00 11.50 W.O. 'K 20 P PJSA Remove ESP line elephant trunk and drain line from sheave. 11:30 12:00 0.50 12.00 W.O. K 4 P PJSA M/U 2-30'sections of 7"shroud and RIH. 12:00 14:00 ' 2.00 14.00-W.O. 'K 20 P PJSA Change ESP&cap tube sheave in derrick.Remove camera to derrick for Volant CRT.Organize pipe shed,P/U clamps,XO's and motor oil to ng floor. 14:00 15:00 1.00 15.00 W.O. K 4 P PJSA P/U&M/U 7"shroud to shroud hanger,centralizer,TIC XO and Jt#1 and RIH.P/U pump and lower in tubing. 15:00 16:30 1.50 16.50 W.O. K 20 P PJSA Load floor wr vire inc equipment and R/U same. Set pump assy.w/wire line.POOH and disconnect @ shroud hanger.Verify proper pump seat and RIH.Wire line set packoff and test tool.POOH w/wire line. 16:30 17:30 ' 1.00 17.50-W.O. -K 12 P PJSA R/U and test pack off to 1000 psi f/15 charted min.R/D and blow down lines. 17:30 18:00 ' 0.50 18.00'W.O. -K 20 P PJSA RIH we wire line and retrieve test tool.Set tubing stop and R/D wire line equipment. 18:00 21:30 - 3.50 21.50 W.O. K 20 P PJSA P/U&M/U motor assy and service as per Baker.Attach well lift gauge and MIU tec line.Install cap tube and MLE to pothead terminal.Lower in hole installing Chnstolizers and clamps as per program. 21:30 22:30 ' 1.00 22.50-W.O. -K 20 P PJSA R/U Volant CRT and handling equipment. 22.30 00:00 ' 1.50 24.00 W.O. K 4 P PJSA P/U&M/U Pressure Discharge assy,install connector to TEC line and test.M/U Jt#2. Daily Contacts Position Contact Name Company Title E-mail i Office Mobile Eni representative Jack Keener ENI -Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 2.466.75 4.314.44 12/29/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gtL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2.513.08 1,139 65 OBM(FazePro) 1126.4 48.4 1550.8 176.7 r ft* Eni E&P Division (Well Name: SP27-N1 OR EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchuq • API/LIWI:50-629-23458-00-00 2^ Date:11/19/2013 - Report#: 5 II II page 1 of 1 wellbore name: SP27-N1 Well Header Permit/Concession N' Operator ENI Share(%( Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.42 12.43 3.99 11.20 9.67 Rig Information Contractor Rig Name Rig Type DOYON DRILLING _ _ DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) € SP27-N1 WORKOVER 2,223.21 1,115.76 718.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 0.00 107.0 -14.4 Light Snow WC-10' N @ 6 MPH Daily summary operation 24h Summary String new ESP and cap lines and perform splices.Run 4.5"ESP completion to 4825'as per tally.Note WO weather 9.5 hrs. .../- Operation Operation at 07.00 Running 4.5"ESP Completion as per tally at 6,724'MD 24h Forecast Complete running ESP completion and land on Vetco hanger.N/D BOPE and N/U tree and test.Check ESP readings.R/U and Lil Red freeze protect IA w/diesel.R/D and secure well.Release ng. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1006.5 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 W.O. K 20 P PJSA Strang new ESP and Cap line from spooler over sheaves to ng floor. 01:00 05:00 4.00 5.00 W.O. K 12 •P PJSA Baker and ENI electrician gator splice ESP and tested good.Splice cap line. 05:00 06:00 1.00 6.00 W.O. K 4 P PJSA RIH w/1 jt 4.5"12#L-80 HYD 563 tbg w/ESP and cap line.M/U GLM wl 3100 psi shear.RIH to 332'. It. 06:00 15:30 9.50 15.50 W.O. K 22 TWO1 WO weather.Fill hole w/252 bbls water @ 7 bpm. Total fluid losses for tour-451 bbls. 15:30 00:00 8.50 24.00 W.O. K 4 •P PJSA RIH w/4.5"ESP completion f/332'-4825',128k puw,115k sow,pump 10 bbls in hole every 10 jts.Total Fluid losses for tour-304 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 2,466.75 4.314.44 12/29/2011 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(giL) P LeakOff(kgflcm') 2.513.08 1,139.65 OBM(FazePro) 1126.4 48.4 1550.8 176.7 IffAillil Eni E&P Division I Well Name: SP27-N1 OR EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaltchuq • APIIUWI:50-629-23458-00-00 2 n ii Date:11/20/2013 - Report#: 6 I' II page 1 of 1 Wellbore name. SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level fin) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.42 12_43 3.99 11.20 9.67 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG _ _ Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP27-N1 WORKOVER 2,223,21 1,115.76 719.23 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 113.0 -23.9 Mostly Cloudy WC- W @ 9 MPH 29" _ Daily summary operation 24h Summary Complete running 4.5"ESP completion and land on Vetco hanger.Test hanger and ESP line.N/D BOPE and N/U Vetco tree and test.Operations freeze protect IA w/125 bbls of diesel.Release rig© 2400hrs. Operation at 07.00 R/U on well SP36. 24h Forecast Accept rig @ 0001hrs.Move off of well SP27 and move and setup on well SP36.Secure berming. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1006.5 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 W.O. K 4 P PJSA RIH wl 4.5"ESP compleion f/4825'-7209'.Testing ESP cable every 1000'and filling hole w/10 bbls water every 10 joints. 04:30 05:00 0.50 5.00 W.O. K 20 P PJSA M/U XO pup,install BPV in hanger and M/U hanger and landing jt.138k puw,110k sow. 05:00 08:00 3.00 8.00 W.O. K 12 P PJSA Baker splice ESP and Cap tube and test.L/D Cap line to spooler. 08:00 09:00 1.00 9.00 W.O. K 12 P PJSA Land tubing hanger @ 7252'as per Vetco.RILDS.Test upper and lower hanger seals to 5000 psi for 10 min.L/D landing jt.and ESP cable. 09:00 09:30 0.50 9.50 W.O. K 20 P PJSA Clear and clean rig floor. 09:30 12:00 2.50 12.00 W.O. K 20 P PJSA N/D BOPE&Riser and set back and secure. 12:00 14:00 2.00 14.00 W.O. K 12 P PJSA Prep well head and N/U tree.Test hanger void to 5000 psi f/10 min.Pull BPV and set TWC.Baker testing continuity on ESP. 14:00 15:00 1.00 15.00 W.O. K 12 P PJSA Fill tree w/diesel,R/U and test tree to 5000 psi.R/D line,pull TWC and secure well. 15:00 16.00 1.00 16.00 W.O. K 20 P PJSA Prep rig floor for skid,cont cleaning pits,R/D spooling unit and ng berming. 16:00 17:00 1.00 17.00 W.O. K 20 P PJSA Skid rig floor and raise stomper. 17:00 18:30 1.50 18.50 W.O. K 9 P PJSA R/U Operations to IA and pump 125 bbls of diesel into well.IA 0 psi,OA 200 psi. 18:30 19:00 0.50 19.00 W.O. K 2 P PJSA Disconnect rock washer and move down pad. 19:00 22:30 3.50 22.50 W.O. K 2 P PJSA Move pits and Sub down pad and spot Sub over well SP36.Mate up Pit module to Sub. 22:30 23:30 1.00 23.50 W.O. K 20 P PJSA Lower stompers and skid ng floor over well center. 23:30 00:00 0.50 24.00 W.O. K 2 P PJSA Spot rock washer.Release rig S well SP27 @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative -Davide Simeone -ENI Project Manager Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum,com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Lara Occhionero ENI Drilling Engineer Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondnlling.cow 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 2.466.75 4.314.44 12/29/2011 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgt/cm') 2,513.08 1,139.65 OBM(FazePro) 1126.4 48.4 1550.8 176.7 wA��F/ ��s THE STATE � ��I�i Alaska Oil and Gas j,� Of � ,od%T li e V do L Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFA P Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 David Simeone Well Operations Project Manager ENI US Operating Company, Inc. L ! 43 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 , Re: Nikaitchuq Field, Schrader Bluff Oil Pools, SP27-N1 Sundry Number: 313-573 Dear Mr. Simeone: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, ' I lr At . Foerster Chair, Commissioner • 51+— DATED thisday of November, 2013. Encl. • .). 31 (17 1 ECEV D' vl STATE OF ALASKA w1,00 0 12013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ADCC 20 MC 25.280 ,,�,'/•/ 1.Type of Request: Abandon IIIPlug for Redrill❑ Perforate New Pool❑ Repair Well i 7 Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing Q p Time Extension 2,/ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Rt RteG. 5P �• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Exploratory ❑ Development ❑✓ 211-139 3.Address: Stratigraphic [i] Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-629-23458-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ SP27-N1 9.Property Designation(Lease Number): .7i1 Hlt� 10.Field/Pool(s): ADL 0391283,9388883, 0388574, 0388574 Nikaitchuq Schrader Bluff Oil Pool 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): . 14,155 . 3,743 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2664 13.375 2664 2466 5,020 2,270 Intermediate 8245 9.625 8245 3739 6,870 4,760 Production Liner 6010 5.5 14103 3743 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8245-14103 • 3739-3743 41/2 L80 7,292 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q• 13.Well Class after proposed work: Detailed Operations Program ❑., • BOP Sketch ❑., • Exploratory ❑ Stratigraphic❑ Development Q• Service ❑ 14.Estimated Date for 22-Nov-13 15.Well Status after proposed work: Commencing Operations: Oil 2. Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Giuseppe Maugeri Email giuseppe.mauaeri(a�enipetroleum.com Printed Name Davide S e,ne Title Well Operations Project Manager Signature 4(� tk t , 1 1i Phone Contac 907-865-3328 Date 11/1/2013 C lY , COMMISSION USE ONLY • Conditions of approval: Notify Commi -on so that a representative may witness Sundry Number: /`•J( Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 Sono f'Sty P 7-Z r- FIBDM NOV - 6 14'1 Spacing Exception Required? Yes ❑ No LTJ Subsequent Form Required: /p-- Yd y APPROVED BY /� ApprovedCe:. .6.164Aki., HECOMMISSION Date: //A—j came,,,. I`' '� MIGIN ��'��� Submit Form and 1�1 Fdc, 10 403(Revised 10/2012) /Approved app Cation is valid for 12 months from the date of approval./.,//41 / %t t hments in Du licate /1/4 113 if .. NO V 0 . 2(0 i, ,llik • Enil •) 1IrHeum AOGGC _em 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907)865-3322 Email: Marc.kuck@enipetroleum.com November 1St,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for SP27-N1 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP27-N1. SP27-N1 was completed on December 31th, 2011 with a through-tubing conveyed electric submersible pump (TTC-ESP) set at a depth of 7292' MD. This ESP producer was completed without a packer. The well was put on production on January 6th, 2012. The well was operated until October 1211'2012,when a mechanical ESP failure occurred. On October 16th 2012,the upper GLM valve was sheared and diesel was pumped in tubing and annulus as freeze protection and the pump was changed with a rigless operation. Due to a problem with GLM, a straddle was set across it. On October 30th 2013,ESP is down again due to a mechanical problem. The estimated date for beginning this work is November 22St,2013. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information,please contact Giuseppe Maugeri at 907- 865-3328. Sincerely, Davide Sim-one 11 Opera ions Project Manager r0101 i Il 1 SP27-N1 Workover— Summary Page SP27-N1 Capital Rig Workover PTD#:211-139 Current Status Well SP27-N1 is currently stopped waiting for workover. Scope of Work Scope of this workover is change ESP pump. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1450 psi (8245'MD/3739'TVD ) during the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out on December 2011. Well type: Producer Estimated start date: November 2211d 2013 Drilling rig: Doyon 15 Completion Engineer: Giuseppe Maugeri: giuseppe.maugeri@enipetroleum.com Work: 907-865-3328 Procedure: 1. Try to POOH straddle across lower GLM with E-Line Tractor. 2. Try to change pump with E-Line Tractor, if negative 3. MIRU Doyon 15. 4. Run Dummy valve on upper GLM 5. Shear lower GLM valve and circulate 8.8 ppg hot water with 3 % KCl kill fluid through tree. Ensure well is killed. 6. Set BPV. ND tree and NU BOP and test to 3500 psi. 7. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 8. Circulate out remaining production fluid. 9. Continue POOH and lay down ESP assembly. 10. MU new ESP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Install BPV and nipple down BOP. 13. NU tubing adapter and tree. 14. Pull BPV, install test plug and test tree. 15. Circulate Freeze protect through tree down IA. 16. Shut in well. 17. RDMO. Below the current schematic of the well: ii, VAIC 4-%"12.6 ppf Production Tubing en! petroleum Al 2251'MD,2123'TVD 31°Inc-GLM,KBMG, 4-%:"x 1",with SP27-N1 1 2,000 psi STS-1 SOV installed Is Oil Producer with ill 4-14"x-cplg cable clamps,for ESP ESP Lift Power Cable,(1)3/8"Chem Inj Line 4 1� ` 7129'MD,3669'TVD,86°Inc-GLM,KBMG, 4-W x 1",with As Completed 12/31/11 3,100 psi STS-1 SOV installed Ilk 7190'MD,3673'ND-Discharge Gauge Sub 7292'MD,3681'ND,86°Inc—Bottom of Motor Centralizer Centrilift,TTC-ESP,134-stage 380P18SXD pump,513 GSB3 seals, Surf.Casing lib 150 HP MSP325 motor 13-3/8",68# t • 2,664'MD,2,466'ND8093'MD,3736'ND-Baker SLXP Liner Hanger/Packer 40°Inc. ice, // 5-W Silver Bullet Ecc. 12,329'MD-HAL 5-14" Nose Guide Shoe Oil Swell Packer i \ Interm.Casing \ Slotted Liner, 9-5/8 401t 10.264'MD-HAL 5-Y" 5-''"15.5 ppf 8245 MD,3,739'ND Oil Swell Packer 14,103'MD,3,743'ND 91°Inc 88°Inc Nikaitchuq Field-Spy Island VetcoGray MB-247 SURFACE COMPLETION SYSTEM N /01 3.50 —15' 37.19 r-----6444 I 8! d -` 1' �1i �im 0 CAM; � (_ • 901 . '' �skSZ 'a --- m?I � hia.1. i 51140‘4 S' a NlittindoT.O.S. EL 26' 5-3/4" at v■ �" 1.062 OFFSET C/L 1 B.O.S. EL 25' 7-1/4" luJ TOP OF WELLHEAD 5.00' EL 25' 2-1/4' t�� 1 a p Prr a 1011 ELECTRICALHRU b or• FEEDT' 21.81 13-5/8. 5000 PSI •4444.4.4 1�1 VG S137 CLAMP i51• ici p 010 al '1ST Q 1II 4-1/16' •' a _J : III ~�C J 1 1 X10 J.437 OFFSET 108.0 �r1 a 'ir 6.50"- 111 111 IP71!'I" 2-1 16' II 5000 PSI H iii, 2-1/16` M. ® .:S= "e. 5000 PSI `,C_ _ I ,, 66.71 Ai __ POSRION 11 - - �= 13.5000 PSI 52.96` 1��li,I ` .' VG 134 MOO. 26.5. i• It .r.`. -��;�R1 17 � 34.00' ri Com, �. ii, 21 16' 5006 PSI .�•` � I__ OUT OF 24.2 5\II L I. 15.25" POSMON •_r! I _ j TOP OF GRADING 1�I -�7 I EL 16?OG 1/4" I i I i -1.00 PROPRIETMt MoncE de � .: vetcogray- 20" OD 133 K-55 J �'"^x�� •Oledallaillow 13-3/8' OD 6B/ L-BO ujrPMPRADO« ENI ALASKA 9-5/8" OD 53.5I L-80 L11Ir- NAM R: HORIZONTAL MULTI-BOWL SYSTEM 4-i/2" OD KM 6-5/8 VII 20 X 1.3-3/8 X 9-5/B X "O.V, X 4-1/2 WITH 6-5/8 VII E.BORNE AND ESP FLAT CABLE SI PAWL 06 Q.E. '8. :,g H173370-1 1/A� PP g IOU PPP.; 06'®s XXXl.wlr pew I•m T v I PRP 10161, NC 10 OF 10 23 JANUARY 2009 0 0GE Imagination 01 work #' 6 13 5/8", 5000 PSI, HYDRIC ANNULAR BOP STUDDED TOP/FLANGED BOTTOM 4 6" f 3/8" > (.. FLANGE BOTTOM/FLANGE TOP BX 160 3' 1 1/2' C I D 13 5/8", 5000 PSI,10" MPL OPERATORS I -1- HYDRIL PIPE RAM 3/8' > rl I F..). FLANGE BOTTOM/STUDDED TOP BX 160 - 1' 10" C I I ^D 13 5/8 5000 PSI, 14"MPL OPERATORS, I I -_F- HYDRIC BUND/SHEAR RAM -` - 1.. STUDDED BOTTOM/FLANGE TOP BX 160 /�` / J 1: " �� 3 1/8 5000 PSI HCR VALVE ilik 2 0' 3 /8 CHOKE3" SOOOEPSI HCR VALVE --/ L�D \" `> 2" KILL LINE 3�6" 5000 PSI GATE VALVE r 3 1/8" 5000 PSI GATE VALVE 3/8" - - I I �� FLANGE BOTTOM/STUDDED TOP BX 160 1' 10 3/4" C i C 13 5/8", 5000 PSI, 10" MPL OPERATORS, - -L- - - - - - - - - -I __- HYDRIL PIPE RAM STUDDED BOTTOM/FLANGE TOP BX 160 BOP STACK I I ') ADAPTER SPOOL WELLHEAD I 1--I FLANGE/FLANGE U. ` A p;i W T= , I 1:::1,_J I I BOP STACK ELEVATION .y Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 01, 2013 11:09 AM To: 'Occhionero Lara' /37 Cc: Kuck Marc; Maugeri Giuseppe Subject: RE:SP27-N1 RWO r13) Lara, Thanks for your help. As I stated below you can do all the Eline work ( tractor) without sundry approval. Good luck!! We should have sundry ready for rig work next week. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Occhionero Lara [mailto:Lara.Occhionero(n)enipetroleum.com] Sent: Friday, November 01, 2013 11:05 AM To: Schwartz, Guy L(DOA) Cc: Kuck Marc; Maugeri Giuseppe Subject: RE: SP27-N1 RWO I've put in CC the right email address of Mr. Maugeri for any future communication. Regards Lara Occhionero Drilling Engineer Eni Petroleum Alaska Office : (907) 865-3323 Cell: (907) 947-4100 Email: lara,occhionero( enipetroleum.com. From: Occhionero Lara Sent: Friday, November 01, 2013 11:03 AM To: 'Schwartz, Guy L(DOA)' Cc: Kuck Marc; Guiseppe.maugeri �enipetroleum.com Subject: RE: SP27-N1 RWO Guy, We'll start to work with the Eline tractor next Monday on SP27, in case it fails need to move the rig on the location, and this will be on the 12th of November. If you have any other questions don't hesitate to ask. Regards 1 • Lara Occhionero Drilling Engineer Eni Petroleum Alaska Office : (907) 865-3323 Cell: (907) 947-4100 Email: lara,occhioaeroenip_etroleum.com From: Schwartz, Guy L(DOA) [mailto:quv.schwartz©aalaska.gov] Sent: Friday, November 01, 2013 10:20 AM To: Kuck Marc; Guiseppe.maugeri >enipetroleum.com Cc: Occhionero Lara Subject: SP27-N1 RWO Guiseppe, The date on the sundry says you are doing the workover on Nov 22nd??? I thought you said this Monday you would be working on the well?You may do the Eline Tractor work without a sundry...once you move in the Doyon 15 you will have to have an approved sundry. Can you clarify your work schedule? If the rig is going to move onto this well Monday(Nov 4th) you will have to send me an email requesting verbal approval to do so. Have you considered just pumping down a tubing puncher for circulation holes? Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 OF 7 • �wI�jjs THE STATE Alaska Oil and Gas OfALASKA Conservation Commission 1*R c GOVERNOR SEAN PARNELL 333 West Seventh Avenue Off:" TM • Anchorage, Alaska 99501-3572 ALAs�FMain: 907.279.1433 Fax: 907.276.7542 Marc D. Kuck Production Optimization Coordinator Eni US Operating Co. Inc. C-3 9 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 - Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP27-N 1 Sundry Number: 312-417 Dear Mr. Kuck: 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. Sincerel, . Norman am '- ioner DATED this /day of November, 2012. Encl. RECEIVED rosC Petirolleuirn Cin�ii n Q AOGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc D.Kuck Phone(907)865-3322 Email: Marc.Kuck@enipetroleum.com October 30,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for SP27-N1 ESP Replacement Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Workover Sundry for well SP27-N1. SP27-N1 was originally completed by Eni Petroleum on Spy Island on December 31,2011 with a Through- Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7292' MD. The well was started up for production on January 6, 2012. The well was operated until October 12,when a mechanical ESP failure occurred. A though-tubing attempt to repair the ESP will be attempted mid November. If the through-tubing efforts are not successful,a rigworkover will be required. ou g g q The estimated date for beginning the rig workover is December 6,2012. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information,please contact me at 907-865-3322. Sincerely, ✓ • A f • Marc D.Kuck Production Optimization Coordinator ' RECEIVED `\\`kr l- STATE OF ALASKA OCT 3 0 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑✓ . Time Extension 1111Operations Shutdown Re-enter Susp.Well Ell Stimulate ❑ Alter Casing[Il Other: QCC E.51) 2.Operator Name: 4.Current Well Class: 5.Permit to rill Number: Eni US Operating Co.Inc. Exploratorylorato ry ❑ Development ❑ 211-139 1il1 t rt- 3. ti3. Address: Stratigraphic ❑ Service El6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-629-23458-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? No Perforating SP27-N1 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): � ADL 391283• 388574 • NikaitchuqTe 1t r'ic�y lcc />« / 11. > /c• 1.) tz. PRESENT WELL CONDITION SUMMARY l , .3G•,- Total Depth MDgt: Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): /41/Sc 24, L. 3 7'{5 ' Casing (c-1.'Length �J "'Size MD ND Burst Collapse Structural Conductor 160.20" 160 160 Surface 2664 13-3/8" 2664 2466 5020 2270 Intermediate 8245 9-5/8" 8245 3739 6870 4760 Production 5910-5-1/2" 14155 3742 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8245-14155 3739-3742 4-1/2" L-80 7294 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 1 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑✓ . Service ❑ 14.Estimated Date for 6-Dec-12 15.Well Status after proposed work: Commencing Operations: Oil ❑✓ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc D. Kuck Email marc.kuck a(�enipetroleum.com Printed Name Marc D.Kuck Title Production Optimization Coordinator Signature •- /��// _ Phone 907 865-3322 Date 10/24/2012 f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 512.6(17 Plug Integrity ❑ BOP Test IT/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: le a S-64) s. ger 7;"5.t Spacing Exception Required? Yes ❑ No L -. :, Form Required: 10-401- / 0-40 AP: DlB:;N ROVEApproved by: �ai� MISSI � T.vi Date: // Y OR [G1-4NRAeL0/2012) V t k)){(W \;A' Su. it Form and i j/ Approved app kation is valid for 12 months from the date of appro -- �C��1 1.0 Machments in Duplicate /"/ SP27-N1 Workover - Additional Data Sheet 10/30/12 Workover Objectives: • Objective of this workover is to pull the failed TTC-ESP tubing completion and run in with a new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. General Well Information: Well Name: SP27-N1 Well Type: Producer Estimated Start Date: December 6, 2012 Rig: Doyon 15 BOP Config: Schematic attached Pressure Info: The ESP DH gauges are still functioning and reading 1100 psi at 7292' MD/3681' TVD. Reservoir depth is 8245'MD/3739' TVD. This well is expected to have a static max pressure of approximately 1300 psi during the time of workover, which places the fluid level well below surface. 8.8 ppg hot KCI seawater is planned as kill wt fluid for this workover. Well History: SP27-N1 was originally completed by Eni Petroleum on Spy Island on December 31, 2011 with a Through-Tubing Conveyed Electric Submersible Pump(TTC-ESP) set at a depth of 7292' MD. This ESP producer was completed without a packer. The well was started up for production on January 6, 2012. The well was operated until October 12, when a mechanical ESP failure occurred. On October 16, the upper GLM was sheared and diesel was pumped in tubing and annulus as freeze protection. The downhole electrical components of the ESP were tested and still maintain integrity. It is believed that a pump coupling may have sheared and could possibly be repaired through tubing. An attempt will be made in mid November to pull and inspect the through-tubing deployed ESP equipment. If it is ✓ determined the well cannot be repaired without pulling tubing, the rig workover will begin approximately the first week of December. The planned completion will be the same as the current completion attached. Operational Plan Summary: Pre-riq work: After the attempted through-tubing workover, the well will be left with brine in the tubing with diesel cap. The upper GLM will have a dummy valve installed and the lower GLM will have an open shear valve. 1. MIRU Doyon 15 rig. 2. Circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. rS < 3. Set BPV. ND tree and NU BOP and test to 3500 psi. /t/of7%9 4-aaeG 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop, check valve. ad ✓a/4�e 5. Circulate out remaining production fluid. 6. Continue POOH and LD ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, RILDS and test hanger. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree. 12. Circulate Freeze protect through tree down tubing. 13. Shut in well. 14. RDMO. 0 U U 4) W O - I5-M a) w O cJ- Cr • -5 O 00- U C . an s c-----Th • •11 O p o w r L in N � N 0 Z0 "= � � N \ z o c� J I I; N Ul N = a) -0 a M L p. to O N m V) ° W Q NN I I P d. co AItt _ Q a J Y '" I a) 01 m O UO O) < co = va a_ � 1 I o a = = p a) I x o c - 3 N • (// J O ' L co t1' OrN' a. MQ JY as X 0) a J N Q (a 2 0• mM 1 I , a m p a) 0 co Y m Ua) x I � 23 Q o CO r t (n 2 2 Y N U N ( ) oCO I O a_ J o -o E a — o J W 'c p u) tr) ca �) � � c0C COAG co I I;. a� o > MI- o I p I— o Q CO p g O co (a Co\ C M 2 E a_ c�) m oM b7 p N 2 O .1 cern 0 25 coto I— N a) Lc" (a r, U o ( (a c/) o N- U — 0 _ ( - c 0 a_ N ch a)_Ta ,,C) 00 _ fl- N F— Tp_o O S . w O2 cfl 0 '� N o Q M s�\‘ Co N N CV- \11140\\‘'\V/1.: - 111111111Z ill / m N t0 tt U (a _ N c 1 U ap o i D M Z c U CO CO m N Y . 7 15 RKB STACK UP Well: 5P30-W 1 t • • • FLOW LVE 16'BELL NIPPLE 11.27 ( 13 5/8- GL HYDRIL SM 1 1 =40 13 S78•'HYDR13-NPI.SN 15.02 L '..,1 17.49 —4 to#Fr NWntwioRy.2♦lN 1 Su*11'IG'MPS. (/�,-^�� 135!8" SM �" 20.18 - -----1 r` — B MUDEr SM — D Imo0- 11111111•1111111111111111 swer ice; 21.99 Drilling Riser 6.35 Top Flange _--_—_—_— — ♦ I 31.34 31.92 1 Upper lock Down Screws ---------------------- 33.07 Upper load Shoulder ------------------------- 141 34.74 Lower LDS -------------------•----•—•- lower LS ------------._._•••—• •---•---- 35.51 LandingRing LS ----_,-----_—_36.83—_---_ --_ VetcoGray MB-247 SURFACE COMPLETION SYSTEM /-WN /CL 3.50 -- / X15 37.19 u . ,,4i .) ili *441; I�11 �501 •• �4• elle it gPr)t =' C ',44 :MMI ' .• Si�� 0 ,,�I T.O.S. EL 26 5-3/4" .062 OFFSET OAI 8.0.5. EL 25' 7-1/4" Q TOP OF WELLHEAD 5.00' EL 25' 2-1/4 i / I I,' O Alt 1 ci CTRIpFr � � ►0104 13 FEEOIHRLI 2,.5, ?AMENI �— 13-5/8'5000 PSI � �w 1 VG S137 CLAMP I einpV“ ilillic . 4-1/16'6 -:,,, ,t, 5000 PSI 11111-1111.10... „„ ,,i,,,.:.. = -'__ ■11 3.437 OFFSET 108.0 6.50'7 2-1/16" ,- j7 5000 PSI •' .14::„...... .. ��12-1/15' = ®L..5000P51 .'i_ t', 66.71 PosmoN ._, , _ _ t3'5000 PSI > �' VG 134 1A00. 52.96' Milk It u1. 26.5• ' ii ...�i},•'ni 1- ' 34.00' _ •= i 2-1 t6' 5000 OUT OFI 24.2 . '• 15.25" POSrON •_i� �_• I� TOG TOP OF GRADING I � 1 ! - 1 EL 16' 1-1/4" I i L1.00 PROMO/WY NOTICE -„'_'-�:: vetcocr>ay- 20” OD 1330 K-55 S7J �l .�a•�y� 13-3/8" OD 68/ L-BO °1"'4` ENI ALASKA CO 9-5/8 OD 53.51 L-BO 9MOO RE HORIZONTAL MULTI-BOWL SYSTEM 4-1/2' OD WITH 6-5/8 VR L 20 X 13-3/8 X 9-5/8 X X 4-1/2 WITH 6-5/8 MT 1.•,MQ AND ESP FLAT CABLE 2..1 AFRL 06 6`11 H173370-1 A�' 401o.tau Flew81181.t•••soma wx Xltxrtl I•m v l PRP 10161, NC 10 OF 10 23 JANUARY 2009 0 GE Imogin0ticn a:work • Print Trend Page 1 of 1 (b)aryl dwnm slum 6 O O O O O O O O O O O 6 O O O O O O O O 0 6 O p♦ 0 /A h f M N O p♦ ap h Si h Sr M N A O Ot ♦"♦ 0 O O O O O O O O O T a al p• p. O• a 6 a 6 6 6 fJ A O N rJ O N "4 A O N N 0 A O N rJ o N A i A 6 N N A N A O •V N �• N s N O d • "' -- A Ore rJ ♦.� N N M • • N 1 14 Z o ' A O N r4 CL to a � • N Oi m A O N, "� As "♦ N N N f w N n N O N A O N "• A O ♦ M I O i "♦ N A 0 N f3 A Oh U V1 c7 h tl h O h O h V ♦! M M N N A A G LH-sn;rj5 https://vision.bakerhughesdirect.com/PrintTrend.aspx 10/26/2012 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SP27-N1 REVISION Date Dispatched: 21-Jun-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP27-N1 REVISION Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5 in TVD 1 i f Received By: ✓ �� y ,, Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan(a�enipetroleum.com LWD Log Delivery V2.1,03-06-06 Page 1 of 1 Schwartz, Guy L (DOA) FTC 2 (1--0.3`1 Sent: Tuesday, May 22, 2012 9:33 AM To: 'Bob Laule' Cc: Ed Ferguson; Regg, James B (DOA) Subject: RE: Furie Kick Cal Bob, I reviewed the Kick tolerance calculations and the LOT data. I assumed a LOT of 12.5 ppg EMW based on 700 psi value for Leak off. This slightly changes the max surface pressure to 263 psi vs 352 psi that you calculated using 11.5 ppg drilling mud at TD. In any case this reduces the maximum influx to about 44 bbls vs 62 bbls that you had calculated .. This is still acceptable. You have approval to proceed drilling ahead as we discussed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Bob Laule [mailto:marboblaule@gmail.com] Sent: Tuesday, May 22, 2012 8:52 AM To: Schwartz, Guy L (DOA) Cc: Ed Ferguson Subject: Furie Kick Cal Guy as requested Kick tolerance calculations for drill out of KLU#1 Re Entry. Thanks, Bob Laule Furie Operating Alaska, LLC FKA: Escopeta 1029 W.3rd Ave.Suite 500 Anchorage,Alaska 99501 907-277-3726 5/22/2012 . - - Fn.) 2 d-o SI SHOE D CASING TEST --- 1 P RIG: Spartan 151 DATE: 22-May-12 CHART TITLE INFO: FIELD: Cook Inlet FROM: Freeny/Johnson WELL: KLU # 1 TO Tony Consenza/Ed Ferguson CASING DATA: Li clo 7 SIZE INC. WGT/FT. GRADE CONN. TVD MD , .... 33,b ;Z p-1 i. 49fl • -- -- CSG. TEST TEST DATA: L.O.T. DATA:EMW Lb I BBLS PSI BBLS PSI EMW .7 ---) 0 LEAK OFF PSI = 0.5 325 0.5 11.15 MW-USED – 1 540 1 490 11.82 EMW = 12.90 1.5 760 1.5 660 12.49 5 MIN BLEED OFF 2 950 2 775 12.94 MINUTES PSI 2.5 1180 2.5 780 12.96 ) 1335 3.5 1525 3.5 4 1725 4 4.5 1930 4.5 5 1140 5 5.5 5.5 6 2530 6 6.5 2730 6.5 7 2940 7 7.5 3150 7.5 700 IMM MM 8 3250 a)" IMMIREPPINNE 8.5 a_ 650 m 7.!,..4r....!eere=M11411111FIMP 9 600 intEilliadaimnaissui. 9.5 550 MM _ MM 10 10.5 0 1 2 3 4 5 11 11.5 MINUTES 12 12.5 13 13.5 HELD FOR 30 MINS. Test for 13 3/8" Casing ' Casing Test -Shoe Test 3000 .. 2500 2000 (7) 1500 a. .1.607pc: ( ttvel 700 p si. +...----------........— / 4 2, f'S` 1000 -u -- -:" L01 e pc! 1,154, 00, 500 / [ 0 i I , , I , I I 1 0 1 2 3 4 5 6 7 8 9 KTF(KICK TOLERANCE FACTOR)=(LOT—MW current)(CSG SEAT DEPTH/PROPOSED TOTAL DEPTH OF CASING) = (12.84—11.5)(5065)/13400'=.506 MSP(MAXIMUM SURFACE PRESSURE) =(KTF)(0.052)(PROPOSED CASING DEPTH) =(.506)(0.052)(13400)=352.9 MFP(MAX. FORMATION PRESSURE)= (KTF+MW CURRENT)(0.052)(13400) = (0.506+11.5)(0.052)(13400)=8365 PSI MIH (MAX. INFLUX HEIGHT)= (MSP)/ [(11.5)(0.052)—0.1 PSI/FT GAS GRADIENT] =(352.9)/0.598)=588.6' MAXIMUM INFLUX IN BARRELS The BHA is 1109',of which the bottom 185' is an average of 8.625" OD in a 12'4" well bore. The rest of the BHA is 5" OD HWDP&DP, 1. 8.625"x 12''4" 4 0.0735 BARRELS PER FOOT FOR 185'= 13.6 BARRELS /3 4 2. 5.000"x 12 X" 4 0.1215 BARRELS PER FOOT FOR 403.6'=49.OBARRELS ?jo �C1 =62.64 BARRELS 5/22/12 FOA KLU1 13 3/8"CASING SEAT LEAK OFF TEST KICK TOLERANCE CALCULATIONS: On the LOT,the formation deviated from the straight line at 775 psi,this equates to a 12.84 ppg EMW. LOT=775 PSI/[5065'] [0.052] =2.942ADD THIS TO THE MW AT 9.9#MW 4 12.84# EMW The calculations are using 5065'as the casing seat depth as this is the depth where there is 70% formation/30%cement. In 2011,this casing seat test indicated a 13.8#EMW LOT. KTF(KICK TOLERANCE FACTOR)= (LOT—MW current)(CSG SEAT DEPTH/PROPOSED TOTAL DEPTH OF CASING) = (12.84—9.9)(5065)/13400' =1.112 MSP(MAXIMUM SURFACE PRESSURE) = (KTF)(0.052)(PROPOSED CASING DEPTH) = (1.112)(0.052)(13400)=775 MFP (MAX. FORMATION PRESSURE)= (KTF+ MW CURRENT)(0.052)(13400) = (1.112+9.9)(0.052)(13400)=6899 PSI MIH (MAX. INFLUX HEIGHT)= (MSP)/ [(9.9)(0.052)—0.1 PSI/FT GAS GRADIENT] = (775)/0.4148)=1868' MAXIMUM INFLUX IN BARRELS The BHA is 1109',of which the bottom 185' is an average of 8.625" OD in a 12'4"well bore. The rest of the BHA is 5" OD HWDP& DP. 1. 8.625"x 12%" 4 0.0735 BARRELS PER FOOT FOR 185'= 13.6 BARRELS 2. 5.000"x 12''A" 0.1215 BARRELS PER FOOT FOR 1683' =204.4BARRELS =218.0 BARRELS CALCULATING THE KICK TOLERANCE USING 11.5#MW: On the LOT,the formation deviated from the straight line at 775 psi,this equates to a 12.84 ppg EMW. LOT=775 PSI/ [5065'] [0.052] =2.942 ADD THIS TO THE MW AT 9.9#MW 4 12.84#EMW The calculations are using 5065'as the casing seat depth as this is the depth where there is 70% formation/30%cement. HALLIBURTON Sperry Drilling To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 Anchorage, AK 99501 Attn: Howard Oakland From: Sperry Drilling -Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield(c�Halliburton.com Re: Eni Well — SP27-N1 AFE # 5362 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports t 1 Final Data Listing on CD-ROM 1 Sets of Final Logs — each contains: • 2" Color Log — Formation Evaluation TVD • 2" Color Log — Formation Evaluation MD— • 2" Color Log — Drilling Engineering MD— • 2" Color Log — Gas Ratio MD - Received By: Print Name /2,44 Sign Name Date Please sign acknowledgement of receipt - email, fax, or mail back. ThankY ou. / RECEIVED STATE OF ALASKA FEB 1 6 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOR IANDilL&OGcons, Commission 1a.Well Status: Oil Q Gas ❑ SPLUG ❑ Other E Abandoned ❑ Suspended❑ lb.W II Class: ArIt.i'Iurdye 20AAC 25.105 20AAC 25.110 Devel pment ❑✓ Exploratory GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: • ENI US Operating Co.Inc. Aband.: 1/1/2012 211-139 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 12/2/2011 50-629-23458-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4440.8 FSL,1420.4 FEL,S19 T14N R9E UM 12/26/2011 SP27-N1 Top of Productive Horizon: 8.KB(ft above MSL): 53.87 15.Field/Pool(s): 3509 FSL,992 FEL,24 T14N R8E UM GL(ft above MSL): 13.1 Nikaitchuq/Schrader Bluff Oil Pool Total Depth: 9.Plug Back Depth(MD+TVD): 1788 FSL,292 FEL,14T14N R8E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511489.44 y- 6053622.43 Zone- 4 14155'MD/3742.58'TVD ADL 391283,388574 TPI: x- 506837.56 y-6052685.33 Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 502254.58 y-6056240.41 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) 1844'MD/1764'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 35 2664 35 2466 16 10.7 ppg ASL: 498 bbls N/A 12.5 ppg DeepCRETE:63 bbls 9.625 40 L-80 33 8245 33 3739 12.25 12.5 ppg DeepCRETE:221 bbls N/A 5.5 15.5 L-80 8093 14155 3736 3742 8.75 Slotted Liner N/A 24.Open to production or injection? Yesct No 1 If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation mice and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) t 4.5 7294'MD N/A pc( /`{rsC MO 3 737 37Y3' TV 4 tial, i ICA 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. j DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i 5LorrE0 L/&I5< !j `! 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): I 1/6/2012 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/6/2012 24 Test Period -*944 0 0.3 34/64ths N/R Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 236 0 24-Hour Rate - 944 0 0.3 17.7 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No❑, If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS FEB 16 12 Form 10-407 Revised 12/2009 t.. CONTINUED ON REVER Z./Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes ✓�lo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top Surface Surface needed,and submit detailed test information per 20 AAC 25.071. SV-4 770 767 SV-3 1140 1121 SV-2 1422 1380 Permafrost Base 1844 1764 SV-1 2034 1933 Ugnu Top(UG4) 2404 2253 UG-2 Coal Bed Marker 3084 2777 Lower Ugnu 5229 3364 N Sequence Top 6560 3577 N Sand Top 6773/ 3619 N Sand Bottom 6960 3655 N Sequence Base 7473 3693 OA Sand Top 8095 `/ 3736 Formation at total depth: OA Sbl 3 14155 3742 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: Luca Boni(907)865-3328 Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: >ti4 Phone: (907)865-3320 Date: 1/24/2012 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 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 - 0 G U > -1' U a) 1- In a1 Cn CD Q _ f` L 00 a) 1 \ Jim c '7 in ZW NZ C7 � n [ .� canaW � h � Cr) = I I 10 L6 NL 0 ICC = d C 1.6 l /cu o Q = - o z x o x c - w ;' Cr) J 67 - Eco a C _JY '7 a) O X a Q N U La �] (S) Cl) = LL 1 i - L� m v Y cu v Q1 s _c CD 0 CEJ CD c'5o N m - Amo R. 1 I I up bo ClJ O O - 0 ~ ' ( i CID u a) > [l E I 0 .> 0 coo 0HM 2 O o �- c � _ I- En CO 2 - d m _i 0 0u F- > O a) . CDU] 2 rn E. o m .( o � • U o HU] 03 _ co_co O nU � ".'.. U VA u CL m � p .- ° CO D 'N x ¢� N O - • - 0 N Q41011/. -4 N N k NLD =Y C] -O y Cl o m `r a.o UJ ,- z o_ COo L9 c IN x - L 0 • Eni E&P Division I Well Name:SP27-N1 fa*i ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^ Date:11/20/2011 - Report#: I If II page 1 of 1 Wellbore name: SP27-N1 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP27-N1 MOVING 12/2/2011 14,019.6 3.733.1 -11.77 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 14,155.0 0.0 102.0 -16.4 Partly Cloudy.WC- 338"NNW @ 3.9 27.6' mph Daily summary operation 24h Summary Complete fluid transfer to WIF and clean pits-D/N lines and skid floor section-Finish prep on SP18-N5 well for production.\Skid rig floor\Lay out Herculite and ng mats for SP27-N1./Move pit complex down pad./Spot sub complex over SP27-N1 conductor.\R/U Halliburton to change out GLM valve on SP18-N5./Spot pit complex in place.\Connect electrical lines between complex and set stompers.\ Skid rig floor over conductor. Operation at 07.00 R/U sub and pit complexes.\Halliburton change out GLM valve on SP18-N5. 24h Forecast R/U sub and pit complexes and spot suit cases transfer lines to rig and WIF.\Halliburton to change out valve in SP18-N5 GLM. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. _ Act. Plan Oper.Descr. 00'00 -08:00 8.00' 8.00 MOB A 2 P PJSM-Transfer remaining completion fluids to WIF.\Blow down and disconnect service to rig floor for skid.\Disassemble slurry line to WIF @ tee&cap-off./Clean active pits.\Disconnect interconnect mud and water lines between sub and pit complex.\Move rock wash from pit complex.(Note:Remove IA and OA secondary values f/multi-bowl,construction to finish -up production lines-clean area). 08:00 09:30 1.50 9.50 MOB A �2 P PJSM-Skid rig floor back over sub complex-prep pad area to lay out Herculite for SP27-N1.1 Blow down pit complex and prep to move. 09:30 -15:00 5.50 15.00 MOB A 2 P Lay out Herculite and rig mats for SP27-N1.\Blow down sub complex lines./Removed diverter lines section form top of well house for move.\P/U DS and ODS stompers./Disconnect electrical interconnect lines between complexes. 15.00 -18:00 3.00' 18.00 MOB A 2 P Move pit complex down pad(west)pass SP27-N1. 18.00 '22:00 4.00 22.00 MOB A '2 P Move sub complex form SP18-N5 to SP27-N1 center over conductor./Move pit complex to sub complex and align interconnects and set.1 Spot Halliburton unit on SP18-N5 to change out valve in GLM-missing new 3x5 Otis cross over for top of lubricator. 22:00 '23:00 1.00 23.00 MOB A °2 P Conned electrical interconnect lines between sub and pit complexes./Set DS and ODS stompers down. 23.00 '00:00 1.00 24.00 MOB A '2 P PJSM-Skid rig floor over conductor. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep -jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib(gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 11191* Eni E&P Division 'Well Name:SP27-N, ENI Petroleum Co.Inc. Daily Repo 1..}L Well Code:26116 Field Name: Nikaitchuq • 2 n^ Date:11/21/2011 - Report#: 2 API/UWI:50-629-23458-00-00 page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14,019.6 3.733.1 -10.77 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14.155.0 0.0 106.0 -12.8 Partly Cloudy.WC- 346'NNW @9.4 31.2` mph Daily summary operation 24h Summary Finished skidding rig floor over SP27-N1 conductor,hook-up glycol line to Eaton brake and secure rail hands.)Berm around ng and secure stairs and landing./Lay out Herculite and rig mats for#3 pump house and rock washer-spot both in place.\Halliburton changed out sheared valve in GLM of SP18-N5.\Crane work on diverter line.)Continue installation of eastern bulk pipe suitcases and make connection between them.\N/U diverter system-Vetco Gray rep.tested connection. Operation at 07.00 Installing eastern suit cases system-cleaning water tank. 24h Forecast Finish installing eastern suit cases system and prep to test./Clean water tank and steam heat back on rig./Work on diverter line./Install western suit cases systems to WIF./Assist Expro in R/U and testing of SP18-N5.\Load pipe shed with 5"drill pipe. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib(gal) 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 Finished skid rig floor over SP27-N1 conductor.\Install hand rail system on roof section./Hook-up glycol lines to Eaton brake. 01:00 06:00 ' 500 600 MOB A 2 P Install berm around sub and pit complex-R/U stairways and landing on same./Prep pad area for#3 pump house and rock washer trailer./Hook-up interconnect service lines between sub and pit complexes./Position bulk pipe suit case sections on eastern side for installation. 06:00 12:00 6.00 12.00 MOB A 2 P Lay out and seam sections of Herculite together for liners under#3 pump house and rock washer./Lay out mat boards and build loading rams./Prep to clean out hot well tank./Remove bear cage form injection well house and move injection line from WIF./Halliburton changed out sheared valve in GLM on SP18-N5. / 12.00 19:00 7.00 19.00 MOB A 2 P PJSM-spot#3 pump house./Crane section of diverter in place and weld out section in sub cellar./Spot rock washer in �/ te place./Continue clean hot well tank./Halliburton completed work on SP18-N5 and R/D©1400 hrs.\Secure upper and {� lower sections of beaver slide/Start setting eastem bulk pipe suit cases in place and connecting section together./Clean /J. rig water tank. �-� f�� 1900 00:00 5.00 24.00 MOB A 5 P N/U Velco Gray starting head on 20"conductor and test VG-Lock to 500 psi.for1B-mtn'S./Continue N/U riser and diverter---~_' system-test top and bottom QDC connection to 625 psi for 10 mins.eac art connecting diverter line to knife.)Continue work on eastem suit cases.)Clean rig water tank. Daily Contacts _--------- Position __Position Contact Name Company Title E-mail Of c'e Mobile 1,,. -,t, Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 I' Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) If* Eni E&P Division .. IWeIIName:SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUIM:50-629-23458-00-00 2^ Date:11122/2011 - Report#: 3 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14.019.6 3.733.1 -9.77 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14 155.0 0.0 105.0 -26.9 Clear.WC-26.9' 347'NNW @ 0 MPH Daily summary operation 24h Summary Install eastern suit cases and test./Complete N/U diverter system and function test.\Start installing western suit cases from rock washer to WIF./Complete cleaning ng water tank./Assist Expro in R/U and started flow back testing of SP18-N5 @ 2000 hrs. Operation at 07.00 Low pressure testing and fix leaks./Install 6"lines in shroud on top of rock washer. 24h Forecast Low pressure test eastern suit case lines./Install western suit cases to WIF and test./Re-install beaver slide./Load drill pipe into pipe shed. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06-00 6.00 6.00 MOB 'A 2 P Installing eastern suit cases and make up connection between each section./Remove beaver slide from rig for access to set interconnection to rig sub and suit cases./Complete berms around#3 pump house./Tighten bolts on diverter line @ knife valve•install bell nipple and flow line./Install valves on starting head./Cleaning ng water tank./Assist Expro. 06:00 12.00 6.00 12.00 MOB A 2 •P Work on eastern suit cases and connect valve box and jumper hose in the sub wheel well./Continue cleaning ng water./ Center and secure 20"diverter-install dnp pan and drain system./Assist Expro. 12:00 18:00 6.00 18.00 MOB A 2 'P Installing eastern suit cases./Finished riser containment and hook-up accumulator lines to diverter-check accumulator bottle per-charge(18 average 1100 psi.and 5 nitrogen bottles average 2350 psi.)./Remove temporary manifold and pipe l from rock washer to WIF to install western suit cases./Clean rig water tank./Spot crane for diverter line install. / 18:00 00:00 6.00 24.00 MOB A 2 P Continue installation of eastern suit cases and prep to test lines on same.\Function test_diverter system(Closure time. V Knife closed 17 sec.and element 34 sec.)./Install diverter line./Work on 33 mud pumps.\Dress shakers.\Install vertical bi✓[ CA shroud on rock washer for western suit cases./Expro start flow SP18-N5 @ 2000 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nihaitchuq • 2^fogi Date:11/23/2011 - Report#: 4 API/UWI 50-629-23458-00-00 I' II page 1 of 1 Wellbore name: SP27-N1 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14,019.6 3.733.1 -8.77 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14.155.0 0.0 101.0 -23.8 Cloudy,WC-35.3` 346'NNW @ 3.3 mph Daily summary operation 24h Summary Winterize lines,test and commission eastern suit cases(transfer water and diesel).\Suit cases incident and safety stand down.\Little Red injected 870bbls.of SP18-N5 fluids from Expro.\Remove saver sub and maintenance on top drive.\Install western suit cases from rock washer to WIF.\Start setting suit cases from production to WIF. Operation at 07.00 P/U 5"drill pipe and installing westem suit cases from rock washer and production valve box. 24h Forecast Continue installing two western suit cases system to WIF from rock washer and production valve box.\P/U 5"drill pipe,enough for intermediate hole section.:.Little Red injection of SP18-N5 completion fluids and WIF injection of residual fluids. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00' 1.00 MOB A 2 P Installing western suit cases from vertical shroud from rock washer to WIF.\R/U to test eastern suit cases lines with air. 01 00 02:30 1.50' 2.50 MOB A •2 P Incident accrued while installing western suit case in which a Doyon personnel right foot was impacted-went to on site medic-Informed town of incident @ 0130 hr.-ENI and Doyon HES personal responded and report/investigation to follow- safety stand down-discussed incident and focus on safety work practices. 02.30 06:00 3.50 6.00 MOB A 2 P Set 6"lines in vertical shroud of rock washer for the western suit cases.\Install winterize wrap on lines and interface section to rig-air up containment boots @ connection./Pressure test eastern suit cases.\Install heater on both ends to pre-heat before use.\Prep to install beaver slide to rig.\Work on starting Little Red equipment. 06.00 12.00 6.00' 12.00 MOB A 2 P Pressure test lines(120 psi.air)and retightening connection retest good.\Assist R/U of Little Red and start injection of produced fluids from Expro SP18-N5 flow back-Postpone work on western suit cases due to Little Red injection\Fill rig water tank thru eastern suit cases. 1200 18:00 ' 6.00' 18.00 MOB A 2 P Installing beaver slide.\Break out and remove 7 5/8"Reg x 4 1/2"IF saver sub from top drive./Postpone work on western suit cases due to Little Red injection./Install line guard on top drive and perform electrical maintenance.\Transfer diesel to ng from bulk system through eastern suit cases. 18.00 00.00 ' 6.00' 24.00 MOB A '2 P Load new 5"drill pipe shed-transfer through short side to long side of pipe shed./Continue to install vertical lines of shroud of rock shed to ground level suit cases and connect to suit case to WIF.\Dress scalpers shakers.\Little Red shut down @ 2400 hrs.for crew rest.\Start install of secondary suit case system to WIF from production. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI 'Co Rep -michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 019141 Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq en , Date:11/24/2011 - Report#: 5 APIIUWI:50 629-23458-00-00 ( If II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) _ - Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2!2011 14.019.6 3,733.1 -7.77 Daily Information End Depth(f1KB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0.0 101.0 -14.3 Partly Cloudy.WC- 346"NNW @ 3.1 23.1" mph Daily summary operation 24h Summary P/U 5"drill pipe and stand back in derrick(92 stands of TT 525).\MI Swaco installing suit cases form production valve box and Doyon working on system from rock washer to WIF.\Little Red injection of SP18-N5 flow back fluids and flush Expro lines.\WIF injection of residual fluids to flush well bore. Installed 7 5/8"x TT 525)saver sub.\First oil from SP18-N5 was introduced into production header @ 19.59 hrs.with 1350 BPD. Operation at 07.00 Installing two suit cases on western side of rig from rock washer and production valve box. 24h Forecast Installation of the two western suit cases to the WIF.\Little Red to inject SP18-N5 flow back fluids 1200+bbls,in tank farm.\Expro R/D off SP18-N5.\WIF injection of residual fluids before RID.\P/U 5" HWDP and set BHA in pipe shed. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00' 6.00 MOB A 2 P Finished loading 5"drill pipe(TT 525-total 276 jts.)into pipe shed through short side./Remove box thread protectors and strap./Service iron roughneck and inspect/change dies\Clear and clean inside mouse hole and set in rotary table./ Installing and work on western suit cases from rock wash and production valve box both going to WIF. 06:00 21:30 15.50 21.50 MOB A 2 P P/U 5"drill pipe and stand back in derrick(drift 2.875").\MI Swaco continue working on suit cases from production valve box and Doyon working from rock washer all going to WIF.\Little Red injecting flow back fluids from SP1 8-N5 until 1930 hrs.when a steady increase in injection pressure to 3000 psi.and rate reduction @ 2 bbls/min.-shut down.\Switched to WIF to inject residual fluids to flush well-pressure drop to 2300 psi.@ 3 bbls./min.\First oil from SP18-N5 introduced into production header @ 19.59 hrs.with 1350 BPD. 21 30 00.00 2.50' 24.00 MOB -A 2 P L/D mouse hole and clear floor of thread protectors.\Held PJSM-install saver sub(7 5/8"x TT 525)on lower IBOP of top drive./MI Swaco continue working on suit cases from production valve box and Doyon working on system from rock washer all going to WIF.\Little Red hook-up to Expro to flush lines.\WIF continued injecting residual fluids. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross 'ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.Lsmith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geofl.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) I_D(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 1154iiiilEni E&P Division ENI Petroleum Co.Inc. DaIIy Repo l..} (WelName:SP27-N1 Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^ Date:11/25/2011 - Report#: 6 (f lI page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14.019.6 3.733.1 -6.77 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(CF) Weather Wind 14,155.0 0.0 104.0 -19.8 Clear,WC-26.7' 240`SW @ 2.4 mph Daily summary operation 24h Summary P/U 5"HWDP and jars and stand back in derrick(6 stds with jars 4 1/2"IF)./Align pipe handler grabbing on saver sub.\Doyon and MI Swaco installing suit cases on western side between rig and WIF.\ Little Red injected SP18-N5 flow back fluids stored @ Expro tank.\WIF injection of residual fluids to flush well bore. Operation at 07.00 Installing suit cases to the tie-in point of MI Swaco shroud/dog house that connects to WIF. 24h Forecast Suit cases installation from rock washer and valve box to tie-in point of WIF./Little Red to inject SP18-N5 flow back fluids(+/-600 bbls.remaining)and MI Swaco will flush the well with residual when needed. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02-.00 - 2.00 2.00 MOB A 2 P Finished installing saver sub on top drive./Installing and work on connection of western suit cases from rock washer and production valve box going to WIF. 02.00 05.00 3.00 5.00 MOB A '2 P P/U 5"HWDP and drill jars(4 1/2"IF-total 18 jts.)stand back in derrick\Work continued on installation of suit cases system./WIF completed injection flush of well @ 0330 hrs. 05.00 10.00 • 5.00 10.00 MOB A 2 P Adjusted and align pipe handler grip for new saver sub./Doyon and MI Swaco installing suit cases on the western between rig and WIF./Work on PM's throughout rig equipment.\Lithe Red staged injection of fluids from SP18-N5 @ 0600 hrs. 10.00 18.00 I 8.00 18.00 MOB A 2 P MI Swaco and Doyon working on suit cases systems making connection of pipes./Load pipe shed with 13 3/8"csg.through short side-remove thread protectors and strap-work on drifting to 12.259"(ice build-up inside)./Work on remove plumbing cabinets,and disassembly plywood floor from under WIF complex for move./Little Red shut down @ 1330 hrs. d due to high pressure and reduce rate-MI Swaco flushed with residual fluids. 18.00 00.00 6.00 24.00 MOB A 2 -P Doyon and MI Swaco working on suit cases from rock washer and production valve box./Completed drifting of 13 3/8"csg\ Clear area in front on WIF complex to move./Little Red back to injecting 1930 hrs.-shut down @ 2300 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com '907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk m.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) Eni E&P Division I Well Name:SP27-N1 P441 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • Date:11/2612011 - Report#: 7 APIIUWI:50-629-23458-00-00 2" " page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14,019.6 3,733.1 -5.77 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0.0 93.0 -17.5 Clear,WC-23.1' 43°NNE @ 14.4 mph Daily summary operation 24h Summary Doyon and MI Swaco installing suit cases bunks and intersecting at valve building @ WIF end connecting two suit cases system together,had to replace transition bunk(from 32'to 24')-lay out matrix wrong./Load pipe shed with BHA 81 and replace hydraulic motor on pipe skate.\Prep to move WIF-remove temp lines.\Little Red finished injecting SP18-N5 flow back fluids from Expro tank and freeze protected. Operation at 07.00 Making-up connection between suit cases.\Lay out Herculite and spot rig mats for WIF move. 24h Forecast Make-up flange connections between suit cases and valve building tie-in point of WIF drop down shroud.\Little Red to inject residual fluids-to move WIF.\Lay out Herculite and MI Swaco move WIF to suit cases system.install shroud.\Continue making connections-ambient temperature-18F. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dar(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 MOB A 2 P Doyon and MI Swaco installing suit cases from rock washer and production valve box to intersect @ bunk dog house.\ Make-up flange connection between units/Found that suit cases from rock washer 8'too long,had the correct length and number of suit cases as per layout matrix. 06.00 12.00 6.00 12.00 MOB A 2 P Remove transition suit case bunk(32')from rock washer and replaced with shorter transition bunk(24').\Slide rock washer suit cases towards rig./Continue setting last section from the production valve box and making flange connection between suit cases./Work on slurry pump manifold in rock washer.\Change out hydraulic motor in pipe skate\Little Red started injection of fluids from SP18-N5 @ 0735 hrs. 1200 18.00 6.00 18.00 MOB A 2 P Install valve building @ WIF end connecting two suit cases system together.\Continue making connecting between units./ WIF complete injection of 200 bbls.flush @ 1515 hrs.and Little Red started pumping final fluids form SP18-N5 flow back./ Work on pipe skate hydraulic system. 18:00 00:00 6.00 24.00 MOB A 2 P Doyon and MI Swaco making-up flange connections in manifold building and suit cases bunks from production valve.\ Remove temp lines from WIF building and across pad.\Load pipe shed with BHA#1.1 Welder working on slurry pump manifold in rock washer./Little Red completed injection and freeze protect well @ 2311 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) I. _* Eni E&P Division I Well Name:SP27-Nr ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikadchuq • APIIUWI:50-629-23458-00-00 2�, Date:11/27/2011 - Report#: 8 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(fiKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14.019.6 3.733.1 -4.77 Daily Information End Depth(fiKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0.0 94.0 -15.3 Clear,WC-17' 36'NNE @ 9 mph Daily summary operation 24h Summary Crews installing flange connection/piping in manifold building and suitcases.\Install bridge over suitcases from rock washer.\Prep pad-lay felt and Herculite for WIF move(seam weld to Herculite).\PM on draw-works(check high&low drum clutches).\Perform derrick and stabbing board inspection.\PJSM-walk WIF towards manifold building.\Little Red heated Vac trucks fluids for cleaning and went to beach. Operation at 07.00 Moving WIF towards manifold building to set dog house drop shroud.Crews continued making connection between suitcases. 24h Forecast Move WIF in place and install dog house drop shroud(weld)-continue making flange connection-Alcan to hook-up electrical and data link. Low pressure test assembled lines with air./Set-up berm containment around WIF.\Check and confirm good communication and data links.\Doyon perform PM on rig equipment. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 6.00 6.00 MOB A -2 P Install bridge over suitcases from WIF.\Making flanged connection inside suit cases and at manifold building/dog house- (Doyon and MI Swaco)./Set two mats inside under WIF and clearing around WIF complex for move.\Remove clamps off WIF used for temp lines. 06.00 12-.00 6.00 12.00 MOB A 2 -P Continue flanging up pipes in suitcases and manifold building./Prep pad on eastern and southern side of WIF for liner and mats. Alcan unwired electrical and data lines to WIF\Seam weld Herculite section together.\Weld slurry pump manifold in rock washer.\Little Red heated fluids in VAC truck for cleaning. 12.00 18.00 6.00 18.00 MOB A 2 P Lay felt and Herculite liner(weld to existing liner under WIF)-Lay out mat boards for move.\Crews making-up connections in suitcases and manifold building./Welder fabricated lines on slurry pump manifold.hands installing same.1 Little Red left the island. 18.00 00.00 - 6.00 24.00 MOB A -2 P Installing piping in manifold building and flange connections in suit cases from production to WIF./Prep WIF shroud with crane rigging./PJSM-MI Swaco moving WIF towards manifold building./Perform PM on draw-works(check high&low drum clutches).\Perform derrick and stabbing board inspection. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Mike Ross 'ENI Co Rep michael.ross@enipetroleum.com -907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(fiKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(fiKB) TVD(fiKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10191* Eni E&P Division I Well Name:SP27-Ni ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2 Date:1112812011 - Report#: 9 II 'I page 1 of 1 Wellbore name: SP27-N1 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14.019.6 3.733.1 -3.77 Daily Information End Depth(fiKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14.155.0 0.0 102.0 -19.8 Partly Cloudy.WC- 41 NNE @ 13.2 26.5" mph Daily summary operation 24h Summary Move WIF complex to manifold building to spot connecting shroud.\GBR weld shroud to WIF.\Installing 3"well injection line suitcases.\Complete rock washer manifold 8 line-test to 120 psi.\ Maintenance on#2 MP and rebuild accumulator tri-plex pump,insulate steam lines on rig floor.\Reposition hot air heater for manifold building. Operation at 07.00 Installing lines from manifold building to WIF shroud and 3"injection line in suitcases. 24h Forecast Install 3"injection line in suitcases to SP37-DSP1.\Plumb in air heater to manifold building.\Install lines from manifold building into shroud of WIF.1 Alcan will hook-up electrical and data link.\Continue working on MI Swaco suitcases and performing 120 psi.air pressure test on assembled lines.)Set support tanks and equipment for WIF/Schlumberger units.Set-up berm containment around WIF. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 - 6.00 6.00 MOB A 2 P MI Swaco moved WIF complex to manifold building.\Spot crane to lift shroud in place for WIF.\Sort and inventory piping for transition from manifold building to WIF shroud.\Make-up flanged connection in WIF suitcases.\PJSM-Pick shroud and spot over manifold building along side of WIF complex. 06:00 12:00 ' 6.00 12.00 MOB A '2 P PJSM/MI Swaco,CH2MHill,GBR-level piping shroud and weld on WIF.\Continue aligning and flange-up connections in suitcases.\Remove covers and prep to installing 3"injection line in suitcases.\Maintenance#2 MP and rebuild accumulator tri-plex pump.)Work on slurry pump manifold in rock washer.\Insulated steam lines on rig floor. 12:00 20:00 ' 8.00 20.00 MOB A P GBR weld out shroud on WIF complex.\Finished rock washer manifold and line.\Pressure tested manifold and cuttings transfer line to WIF @ 120 psi.\Modifying cement line in rock washer shroud.\Installing 3"injection line in WIF suitcases. 20:00 0000 4.00 24.00 MOB A 2 P -Continue with 3"injection line in suitcases form WIF.\PJSM-MI Swaco walking WIF complex to final spot over manifold building.\Reposition hot air heater @ manifold building for suitcase heat line. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(fiKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq 2�,fifj* Date:11/29/2011 - Report#: 10 APIIUWI 50 629-23458-00-00 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14.019.6 3.733.1 -2.77 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0.0 104.0 -17.9 Partly Cloudy.WC- 216`WSW @ 4 mph 25.4` Daily summary operation 24h Summary Assist MI-Swaco finish moving WIF into place. Install low/high pressure piping in WIF dog house to shroud piping. Fabricate and install flange 90's on WIF dog house suitcase heater discharges. Fabricate top cover for rock washer shroud. Continue to assist MI-Swaco with injection line in suitcase. Finish modifications on 3"cement line in rock washer shroud. Continue to install piping and make up flanged connections in MI-Swaco manifold house. Install top hard line connections on cement line and make up 20'high pressure jumper hoses in rock washer shroud. Install hot air heater hose to manifold house. Adjust linkage TDS-8 and continue to insulate steam lines throughout rig. Operation at 07.00 Continue with ongoing projects. 24h Forecast Complete the modifications and test lines. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum • Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 '12:00 12.00 12.00 MOB A 2 P Assist MI-Swaco finish moving WIF into place. Install low/high pressure piping in WIF dog house to shroud piping. Fabricate and install flange 90's on WIF dog house suitcase heater discharges. Fabricate top cover for rock washer shroud. Continue to assist MI-Swaco with injection line in suitcase. Finish modifications on 3"cement line in rock washer shroud. 12:00 00:00 12.00 2400 MOB A 2 P Continue to install piping and make up flanged connections in MI-Swaco manifold house. Install top hard line connections on cement line and make up 20'high pressure jumper hoses in rock washer shroud. Install hot air heater hose to manifold house.Adjusr linkage TDS-8 and continue to insulate steam lines throughout rig. Daily Contacts . Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep "michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Torn Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division .} Well Name:SP27-N1 I IIIENI Petroleum Co.Inc. Daily Repo)l Well Code:26116 Field Name:Nikaitchuq • API/UWI:50-629-23458-00-00 2�, Date:11130/2011 - Report#: 11 II " page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14,019.6 3,733.1 -1.77 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 14.155.0 0.0 101.0 -10.5 Partly Cloudy,WC- 62'ENE©15.6 45- mph Daily summary operation 24h Summary Fabricate and install safety clamps and whip checks on cement line shock hose in transition bunk. Install hatch cover in rock washer. Fabricate bulkhead connections for bunk heaters. Mud pump#2 inspections and maintenance continue. Transfer 100 bbls of water from mud plant by suitcase transfer lines to pits for testing lines. Fabricate leak detection for pipe bunks. Continue to assist M-I Swaco with their manifold house and work on leak detection in suitcases. Work on rig PM's. Make up 4"master valve and 3x2"AVs-MB-247 for wellhead SP-27. Start picking up BHA,pick up 3x8"drill collars and rack back. Pickup motor and make up bit. Operation at 07.00 Testing lines. 24h Forecast Complete the modifications and test lines. Spud well. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00,00.. 12'.00 12.00 12.00 MOB A 2 P Fabricate and install safety clamps and whip checks on cement line shock hose in transition bunk. Install hatch cover in rock washer. Fabricate bulkhead connections for bunk heaters. Mudpump#2 inspections and maintenance continue. Transfer 100 bbls of water from mud plant by suitcase transfer lines to pits for testing lines. Fabricate leak detection for pipe bunks. 12-00 00.00 12.00 24.00 MOB A 2 P Continue to assist MI-Swaco with their manifold house and work on leak detection in suitcases. Work on rig PM's. Make up 4"master valve and 3x2"AVs-MB-247 for wellhead SP-27. Start picking up BHA,pick up 3x8"drillcollars and rack back. Pick up motor and make up bit. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross 'ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 'ilk/114'1 Eni E&P Division (Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchuq • Date:12/1/2011 - Report#: 12 APIIUWI:50-629-23458-00-00 2" " page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(15) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) •Water Depth(ft) RKB-Base Flange(it) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 MOVING 12/2/2011 14,019.6 3.733.1 -0.77 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14 155.0 0.0 106.0 -14.6 Partly Cloudy.WC- 204°SSW @ 11.5 43" mph Daily summary operation 24h Summary Make up stabilizer and x-over on motor. Pneumatic and hydro test slurry line from rock washer to WIF to 120 psi for 5 minutes. Insulate steam lines around rig. Mud pump#2 maintenance. Work on leak detection on suitcases. Fabricating pup for cement line in WIF dog house. Repair 5.0 air heater. Make penetrations in suitcases for air heaters. Install last section of cement line between MI manifold house and MI injection facility. Start up 4.0 heater at MI-Swaco manifold house. Rig up Howco slickline. Continue securing piping. Operation at 07.00 Testing and securing lines. 24h Forecast Continue testing and securing lines. Prepare and start drilling. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dar(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 1200 12.00 12.00 MOB A 2 P Make up stabilizer and x-over on motor. Pneumatic and hydro test slurry line from rock washer to WIF to 120 psi for 5 minutes. Insulate steam lines around ng. Mud pump#2 maintenance. Work on leak detection on suitcases. Fabricating pup for cement line in WIF dog house. Repair 5.0 air heater. Make penetrations in suitcases far air heaters. 12.00 0000 12.00 24.00 MOB A 2 P Install last section of cement line between MI manifold house and MI injection facility. Start up 4.0 heater at MI-Swaco manifold house. Rig up Howco slickline. Continue securing piping. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 i Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(itKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Suri Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) l Eni E&P Division (Well Name:Sp27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq "f* • API/UWI:50-629-23458-00-00 2^n Date:12/2/2011 - Report#: 1 �) II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 0.21 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 193.0 193.0 193.00 0.50 386.0 108.0 -13.4 Clear,WC-61.4' 220`SSW @ 23 mph Daily summary operation 24h Summary Continue testing and securing lines. Prepare and start drilling. Clean out Conductor 5193'MD. Operation at 07.00 Drilling 16"hole. 24h Forecast Drill ahead as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00-00 15-00 15.00 15.00 MOB A 20 P Finish testing cement line from rig floor to WIF to 120 psi with air. Seperate and inventory lifting subs and x-overs. Mud pump#2 maintenance. Change out Smith bit to Hughes MX1. Continue insulate steam lines. Fabricate landings for suit cases. Transfer 784 bbls of spud mud from mud plant to rig mud pits. Continue insulating steam lines around rig. 15:00 15:30 0.50 15.50 MOB A 20 P Pre-spud meeting. 15:30 18:30 3.00 18.50 MOB A 20 P Continue insulating steam lines around ng. 18:30 20:00 1.50 20.00 DRILL E 3 P Cleaning out conductor,tag up at 72',drill to 131'. 20:00 21:30 1.50 21.50 DRILL E 20 U Rockwasher auger packed off,unplug and thaw out. 21:30 00:00 2.50 24.00 DRILL E 3 P Continue cleaning out conductor from 131'to 193'with 10k weight on bit,600 gpm.and 40 rpm. Circulate,stand back 2 stands for prep.for picking up more BHA. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Suri Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division . I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report L Well Code:26116 Field Name:Nikaitchug rill* • APIIUWI:50-629-23458-00-00 2^n Date:12/3/2011 - Report#: 2 II II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155,00 156.69 90.3 1.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 1,107.0 1,089.7 914.00 6.22 146.9 104,0 0.5 High Winds,Blowing 55'ENE @ 44.3 Snow,WC-52.8 mph Daily summary operation 24h Summary - .... - - - Make up BHA#2,shallow test MWD,drill and slide from 193'to 929',rig down Gyro,backream out to 838',pull out of hole,changes to BHA,run in hole,drill and slide to 1,107'. Operation at 07.00 Drilling. 24h Forecast Drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03:30 3.50 3.50 DRILL E 4 P Continue make up BHA#2. 03.30 04:00 0.50 4.00 DRILL E 19 P Shallow test MWD. 04.00 16:00 12.00 16.00 DRILL E 3 P Drill and slide from 193'to 929'with 586 gpm,900 psi.40 rpm,25k weight on bit and 6k torque. 16.00 16:30 0.50 16.50 DRILL E 20 P Rig down gyro unit. 16.30 18:00 1.50 18.00 DRILL E 4 P Backream out of hole from 929'to 838'with three bottoms up for complete stand. 586 gpm,750 psi,40 rpm. 18:00 19.30 1,50 19.50 DRILL E 4 P Pull out of hole from 838'to 184'for changes to BHA#3. 19.30 21 30 2.00 21.50 DRILL E 4 P Run in hole with BHA#3 from 184'to 929'. 21 30 0000 2.50 24.00 DRILL E 3 P Drill and slide from 929'to 1,107 with 647 gpm.1.400 psi,40 rpm,35k weight on bit. ADT=2.97 hrs, ART=0.67 hrs.and AST=2.30 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross 'ENI Co Rep rnichael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division Well Name:SP27-N1 MI* ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchuq • API/UWI:50-629-23458-00-00 2'f II�, Date:12/4/2011 - Report#: 3 page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator EM Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 2.21 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 2,680.0 2,478.8 1.573.00 9.20 171.0 104.0 17.6 Mostly Cloudy,WC- 207'SSW @ 11.5 2.2 mph Daily summary operation 24h Summary Drill and slide from 1,107'to 2,680'. Backream out of hole from 2,680'to 1,297'. Operation at 07.00 Rigging up to run 13 3/8"casing. 24h Forecast Rigging up to run 13 3/8"casing. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 14:30 14.50' 14.50 DRILL E 3 'P Drill and slide from 1,107'to 2.680'with 800 gpm.1.900 psi,40 rpm,8-10k torque,and 16-20k weight on bit. Mao gas 400 units and 10.40 ppg ECD. 14.30 18:00 3.50° 18.00 DRILL E 4 P Backream out of hole from 2,680'to 2,324'with 80 rpm,800 gpm,1,700 psi. As per K&M backream first four stands at 30 minutes per stand. 18:00 00:00 - 6.00' 24.00 DRILL E 4 P Continue backream from 2,324'to 1,297'. Attempt to backream at 10 minutes per stand,packing off and excess torque. As per K&M continue backream at 30 minutes per stand and increase speed as hole permits. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross .ENI 'Co Rep michael.ross@enipetroleum.com .907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.corn 907-685-0715 Eni representative Geoff Ackerman ENI HOE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/15/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 1"1* Eni E&P Division I Well Name: SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikailchuq • APIIUWI:50-629-23458-00-00 2^ Date:12/5/2011 - Report#: 4 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(It) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ttKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 3.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,680.0 2,478.8 0.00 99.0 -6.5 Mostly Cloudy,WC- 234`SW @ 10 mph 28.9" Daily summary operation 24h Summary Backream to 830',lay down HWDP and BHA,clean drill floor,change out saver sub,dummy run with landing joint,rig up and run 13 3/8"casing to 1,700',circulate,run casing to 2,664'.circulate.rig down and rig up cement head. Operation at 07.00 Nipple down diverter. 24h Forecast Circulate,test lines,cement,displace,nipple down diverler,nipple up BOP's and test. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0200 2.00 2.00 DRILL E 4 P Continue backream out of hole from 1,297'to 924'at 20-30 FPH.shakers loaded with cuttings,continue backream out to 830'obtaining two bottoms up. Circulate til shakers clean. 02:00 04:00 2,00 4.00 DRILL 'E 4 P Monitor well.static,blow down top drive,lay down HWDP. 04:00 07.30 3.50 7.50 DRILL E 4 P Lay down BHA. 07:30 08.00 0.50 8.00 DRILL E -20 P Clear and clean drillfloor. 08:00 10.30 2.50 10.50 DRILL E 20 P Change out saver sub to 4 1/2"IF for Franks fill up tool, 10:30 11 30 1.00 11.50 DRILL E 20 -P Make dummy run with landing joint. 11:30 1430 3.00 14.50 DRILL E 20 P Rig up casing running equipment and safety meeting on running casing. 14:30 1930 5.00 19.50 DRILL •E 19 P Run 13 3/8"casing to 1.700'. P/U=175k,0/0=1506. 19:30 20.00 0.50 20.00 DRILL E 7 P Break circulation and circulate bottoms up below permafrost. 20:00 22.00 2.00 22.00 DRILL E 19 P Continue run casing from 1,700'to 2,664'with landing joint. 22:00 23.30 1.50 23.50 DRILL E 7 P Break circulation.circulate and reciprocate while rigging down. 240 psi,231 gpm,55 spm. 23:30 00'00 0.50 24.00 DRILL ;E 20 P Rig down Franks fill tool and ng up cement head. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36A 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) !CY* Eni E&P Division I Well Name: SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^nI Date:12/6/2011 - Report#: 5 II II Ipage 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth)TVD...Depth Dr.(MD)(ft). Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14,155.00 156.69 90.3 4.21 Daily Information End Depth(ftKB) End Depth)TVD)(f...Depth Progress(ft) Drilling Hours)hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 2.680.0 2,478.8 0.00 96.0 -20.0 Mostly Cloudy.WC- 122°ESE @ 10.2 46.1 mph Daily summary operation 24h Summary Blow down top driverig up cement head circulate.test lines,cement,displace,flush surface equipment.clean and prepare 10 set emergency sips set slips.lay down landing joint.clear drillfloor of casing tools.nipple down annular and prepare for cutting 13 3/8"casing. Operation at 07.00 Nipple up BOP's 24h Forecast Prepare and cut 13 3/8"casing. Nipple up BOP's.and test. Pick up BHA and run in hole. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur__ (hr) Phase - Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P Blow down top drive and rig up cement head. 00:30 02:30 2.00 2.50 DRILL E 7 P Circulate and condition mud for cementing. Stage pumps up to 6 bpm.and 220 psi. Reciprocate pipe.P/U=250k and / 5/0=190k. V 02.30 03:00 0.50 3.00 DRILL E 19 P Pump 100 bbls of 10.1 ppg mudpush at 5 bpm. 0300 0530 2.50 5.50 DRILL E 19 P Pump 10 bbls of water,test lines to 1000/3500 psi.drop bottom plug. Mix and pump 498 bbls of 102 ppg lead slurry at 3-5 bpm.followed by 63 Ibis 0112.5 ppg tail slurry at 3 bpm. Launch top plug and kick out with 10 bbls water. Reciprocate pipe while cementing. 05.30 07.30 2.00 7.50 DRILL -E 19 P Displace with 9.6 ppg mud at 5 bpm and 180 psi. Continue to reciprocate pipe,P/U=250k and S/0=190k. At 143 bbls into e41 displacement,cement returns to surface. At 276 bbls into displacement casing started to hang up.pull up to 300k. decision made to slack off and put hanger close to hangoff point and finish displacing. Pumped 379 bbls caculated to bump plug,did not bump. Attempt to set down on hanger,but no downward movement.work string and attempt to free up. Approxamently 6 1/2"from landing out decision made to displace half of shoe track,pump 6 more bbls.did not bump plug. 424 Cement in place at 0730 hrs. 07.30 08.30 1.00° 8.50 DRILL 'E 20 P Flush BOP's aand surface equipment of contaminated cement. 08'.30 10.00 1.50' 10.00 DRILL 'E 19 U Confer with wellhead representative to get stretch to casing for emergency slips.max pull 480k. 10.00 14.30 4.50- 14.50 DRILL 'E 20 U Clean rig floor.prepare stack to set emergency slips and set slips as per Vetco Gray. 14.30 18.30 4.00' 18.50 DRILL 'E 20 P Rig down landing joint and remove casing running equipment from dnllfloor. 18.30 00.00 5.50. 24.00 DRILL E 20 U Nipple down annular equipment and prepare for cutting 13 3/8"casing. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(f1KB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division (Well Name:SP27-N1 0111* EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchuq • APIIUWI:50-629-23458-00-00 2�, Date:12/7/2011 - Report#: 6 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftIhr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14.155.00 156.69 90.31 5.21 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,680.0 2,478.8 0.00 98.0 4.5 Partly Cloudy,WC- 69'ENE©20 mph 32.1 Daily summary operation 24h Summary Prepare and cut 13 3/8"casing. Nipple up BOP'S,and test. Replace choke manifold valve#13. BOPE test witnessed by AOGCC rep John Crisp. Operation at 07.00 Picking up 12 1/4"Rotary Steerable BHA#4. 24h Forecast Finish repair choke manifold valve,test manifold,remove test plug.install wear sleeve,pick up BHA#4,Run in hole.test MWD on way in. Run in hole tag plug,test casing,drill shoe track.make 20-50 ft new hole,change out mud to SOBM. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 20 U Rig up and cut 13 3/8"casing with Vetco air driven cutter. 03:00 06:00 3.00 6.00 DRILL C 5 P Pull hatches on wellhouse.set and align wellhead as per Vetco. Test multi-bowl lower seals to 1850 psi for 10 min. Good test. 06:00 06:30 0.50 6.50 DRILL C 5 P Cut diverter line pup joint in cellar deck. 06.30 15:00 8.50 15.00 DRILL C 5 P Nipple up riser and BOP's,prepare for testing. 15:00 16:30 1.50 16.50 DRILL C 12 P Test annular preventer to 250 psi low and 2,500 psi high. Test witnessed by John Crisp.(AOGCC). Y 16.30 18:30 2.00 18.50 DRILL C 25 U Work on choke manifold valve#13 disassemble and inspect. , / 18.30 22:00 3.50 22.00 DRILL C 12 P Continue testing BOP's with 5"pipe. Upper and lower rams.choke and kill valves.IBOP's,TIW',and dartvalve to 250/3.500 psi. (AOGCC witness John Crisp) 22.00 00:00 - 2.00' 24.00 DRILL C 25 U Remove and replace valve#13 on choke manifold. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Last Casing seat _ Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3.8 12.415 L-80 36.4 2.664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) f I'"" ' Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • API/UWI:50-629-23458-00-00 2^ Date:12/8/2011 - Report#: 7 '( II page 1 of 1 Wellbore name: SP27-N1 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40,77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 6.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,680.0 2,478.8 0.00 101.0 7.5 Partly Cloucy,WC- 68'ENE @ 17.3 22- mph Daily summary operation 24h Summary Finish repair choke manifold valve,test manifold.remove test plug,install wear sleeve, flush mud pumps,test casing,pick up BHA#4,Run in hole.test MWD on way in. Run in hole tag plug at 2,461'. circulate,test casing,drill shoe track to 2,522'. Operation at 07.00 Changing over to LSND 24h Forecast Drill shoe track,clean out to 2,680',drill new hole.change out mud to SOBM,perform LOT,if good drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.60 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan NI Oper.Descr. 00:00 03:00 3.00 3.00 DRILL C '25 U Continue replace choke manifold valve#13. 03:00 09.30 6.50 9.50 DRILL C 12 P Test choke manifold valves 250/3500 psi.charted for 5min. (State witness John Crisp) Flow test A and B manifold choke to 1500 psi. Flow test super choke to 1500 psi.volume CK.on poor boy de-gasser. 09:30 10:00 0.50 10.00 DRILL E 20 P Rig down blow down test equipment. 10:00 11:00 1.00 11.00 DRILL C 20 P Pull test plug,set wear ring. 11:00 11:30 0.50 11.50 DRILL E 12 P Flush mud pumps. 11:30 12:30 1.00 12.50 DRILL E '20 P Rig up and test casing against blind rams to 2,500 psi.charted for 30 min test. Pumped at 1.5 bpm with 4 bbls pumped. 12:30 16:00 3.50 16.00 DRILL E 4 P Pick up BHA#4. 16.00 16.30 0.50 16.50 DRILL E 19 P Shallow test downhole tools as per directional driller. 1630 19:30 3.00 19.50 DRILL E 4 P Trip in hole to 2,451',tag cement plug with 15k down. 19:30 21 30 2.00 21,50 DRILL E 7 P Circulate bottoms up and condition mud for casing test. 21:30 22:00 0.50 22.00 DRILL E 20 P Blow down top drive and rig up for casing test. 22:00 23:00 1.00 23.00 DRILL E 12 P Test 13 3/8"casing to 2,500 psi charted for 30 min.at 1 bpm.with 4 bbls pumped. ng down equipment. Good test. 23.00 00.00 1.00 24.00 DRILL E '19 P Drill out excess cement and shoe track from 2,461'to 2,522'with 600 gpm,950 psi.60 rpm.5-10k wob, P/U=150k S/0=130k ROT=140k. I Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI -Senior Co Rep 'jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter 'ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,710.0 2,501.71 LSND 9.20 610.0 13.89 1,8056 I I Eni E&P Division (Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • API/UWI:50-629-23458-00-00 2/iii^ Date:12/9/2011 - Report#: 8 page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14.155.00 156.69 90.3 7,21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftihr) POB Temperature(`F) Weather Wind 4.333.0 3.255.9 1.653.00 15.50 106.6 101.0 7.0 Partly Cloudy.WC- 60" ENE @ 16.2 20 MPH Daily summary operation 24h Summary Drill shoe track to 2,664'.clean out old hole to 2,680',doll new hole to 2,710',change out mud to LSND,clean surface equipment,pressure integrity test.drill ahead from 2,710'to 4.123'. Operation at 07.00 Drilling 12 1/4"hole. 24h Forecast Drill shoe track,clean hole,continue drill 12 1/4"hole per well plan Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr( Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 I 3.00 3.00 DRILL E '19 P Continue clean out shoe track from 2522'to 2,664'and clean out old hole to 2680'with 600 gpm,980 psi,60 rpm,10k wob. 03:00 03:30 0.50 3.50 DRILL E 3 P Drill new hole from 2.680'to 2,710'. 03:30 05:00 - 1.50 5.00 DRILL E 7 P Circulate out water base mud for new LSND. 05:00 07.00 I 2.00 7.00 DRILL E .20 P Clean surface equipment and prepare for leak off test. 07:00 08:30 I 1.50 8.50 DRILL E I11 P 'Perform pressure integrity test to 610 psi to a 13.89 EMW.pumped 1.6 bbls and bled back 1.5 bbls. Pressure bled from 610 psi to 420 psi with a 10 minute shut in. 08.30 00.00 I 15.50 24.00 DRILL E 3 P Drill and slide from 2,710'to 4,023'with 702 gpm,1,195 psi,80-120 rpm,25-35k web,9.87 ppg ECD,max gas at 35 units. P/U=157k S/0=110k ROT=143k. I Daily Contacts Position Contact Name Company Title E-mail Office _ Mobile Eni representative Jack Keener ENI Senior Co Rep -jack.keener@enipetroleum '907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 318 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal( Leak Off Pressure(psi) 2.710.0 2,501.71 LSND 9.20 610.0 13.89 1,805.6 Eni E&P Division .} (Well Name:SP27-N1 ral* EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchug • APIIUWI:50-629-23458-00-00 2 Date:12/10/2011 - Report#: 9 i� ��II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14,155.00 156.69 90.3 8.21 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4,333.0 3,255.9 0.00 101.0 9.7 Mostly Cloudy,WC- 60"ENE @ 30 MPH 25 Daily summary operation 24h Summary Drill to 4.333',MWD failure,circulate three bottoms up.backream to 2,396'circulate two bottoms up,pull out of hole.change out BHA,shallow test MWD on trip in,trip in to 2,623',fill pipe and prepare to cut drilling line. Operation at 07.00 Drilling 12 1/4"hole 24h Forecast Slip and cut drilling line.Drill ahead as per well plan. Lithology Shows MAASP Pressure(psi) -Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(he) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:30 6.50 6.50 DRILL E 3 P Drill from 4,023'to 4,333'with 898 gpm.1810 psi,80-130 rpm,15-35k wob,5-10k torque,and max gas at 6 units. P/U=160k 5/O=129k ROT=142k 06.30 07:30 1.00 7.50 DRILL E 7 P MWD Failure. Rotate,reciprocate.and circulate three bottoms up in prepration for backreaming out of hole. Circ.at 900 gpm,1780 psi.130 rpm. 07.30 13:30 6.00 13.50 DRILL E 4 P Backream out of hole from 4,333'to 2.396'with 130 rpm,900 gpm,and 1780 psi. 13.30 14:30 1.00 14.50 DRILL E 7 P Circulate two bottoms up as per K&M at 2,396'. 14.30 18:00 3.50 18.00 DRILL E 4 P Pull out of hole on elevators from 2,396',lay down bottom hole assembly as per directional driller. 18.00 19:00 1.00 19.00 DRILL E 20 P Clear and clean drillfloor.replace latch spring on 5"elevators. 19.00 21:00 2.00 21.00 DRILL E 4 P Pickup BHA#5 as per directional driller. 21.00 21:30 0.50 21.50 DRILL E 19 P At 360'shallow test MWD. , 21'.30 23:30 2.00 23.50 DRILL E 4 P Trip in hole from 360'to 2,623'. 2330 00:00 0.50 24.00 DRILL E 19 P Fill drillpipe and prepare for cut and slip drilling line. Daily Contacts Position I Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative 'Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HOE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondolling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,710.0 2,501,71 LSND 9.20 610.0 13.89 1,805.6 Eni E&P Division I Well Name: SP27-N1 0111# ENI Petroleum Co.Inc. Daily ReportWell Code:26116 Field Name: Nikaitchuq • Date:12/11/2011 - Report#: 10 APIIUWI:50-629-23458-00-00 2 rr 'r ii page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N" Operator EM Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14,155.00 156.69 90.3 9.21 Daily Information End Depth(ftKB) End Depth(TVD)(t.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 5.460.0 3,400.1 1.127.00 13.35 84.4 100.0 12.9 Cloudy,WC.9F 192°SW @ 9 MPH Daily summary operation 24h Summary Slip and cut drill line,service rig,calibrate blocks,run in hole to 2740'.take check shot,run in hole to 4294'.fill pipe tag bottom.drill ahead. Operation at 07.00 Drilling 12 1/4"hole. 24h Forecast Drilling 12 1/4"hole. Lithology Shows MAASP Pressure(psi) •Mud Weight(Ib/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 20 -P Slip and cut 120'drilling line,adjust brakes,and calibrate weight indicator. 01:30 02:30 1.00 2.50 DRILL E 20 P Grease and service rig. 02:30 03:00 0.50 3.00 DRILL E 20 P Calibrate and check tracking with Schlumberger after slip and cut. 03:00 03:30 0.50 3.50 DRILL E 19 P Trip in hole from 2624'to 2740'and check shot MWD. 03:30 05:00 1.50 5.00 DRILL E 4 P Trip in hole from 2740'to 4294',fill pipe and tag bottom. 05.00 00:00 19.00 24.00 DRILL E 3 P Drill from 4.333'to 5,460'with 900 gpm,1680 psi,80-130 rpm,25-30k weight on bit,torque 8-11k. Max gas.12 units. P/U=170k 5/0=120k Rot=148k.ADT=13.35 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Bobby Walls ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2.710.0 2,501.71 LSND 9.20 610.0 13.89 1.805.6 11Enl E&P Division I Well Name:SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • 2^„ Date:12/12/2011 - Report#: 11 API/DWI:50-629-23458-00-00 " II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(V.) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53,87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 10.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5.912.0 3.475.5 452.00 18.25 24.8 101.0 -14.0 Clear.WC-35 45'NE @ 20 MPH Daily summary operation 24h Summary Drill to 5.460',to 5,912'. Operation at 07.00 Drilling 12 1/4"hole. 24h Forecast 24 Hour Summary Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr)_Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00-.00 -00.00 - 24.00 24.00 DRILL E 3 P Drill from 5,460'to 5,912'with 900 gpm.1570 psi,80-130 rpm,10-30k weight on bit,torque off bottom 7k,and on bottom 8- 11k. Max gas 4units. P/U=170k S/0=128k ROT=150k Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Ow representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2.710.0 2,501.71 LSND 9.20 610.0 13.89 1,805.6 Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq 0'1 � APIIUWI:50-629-23458-00-00 2�, Date:12/13/2011 - Report#: 12 II II ii page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40,77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14.155.00 156.69 90.3 11.21 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) PO8 Temperature(CF) Weather Wind 6,410.0 3,554.2 498.00 19.30 25.8 102.0 -17.0 Clear.WC-42 17"NE @ 12 MPH Daily summary operation 24h Summary Drill Rotary Steerable 05912'-116410'as per well.\Back ream 30'before connection.\Change drilling parameters for best ROP due to erratic formation.\Total 210 joints of 9 5/8"csg.in pipe shed-(strap 8 drift). Operation at 07.00 Drilling ahead rotary steerable 12 1/4"hole as per well plan. 24h Forecast Drilling ahead 12 1/4"hole section as per well plan to proposed 9 5/8"csg.point @ 8,276'. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.30 Time Log Start End Cum Time Time Dur(hr) Dur)hr) Phase Opr. Act. Plan Oper.Descr. 00-00 06:00 6.00 6.00 DRILL E 3 P Drill Rotary Steerable 1/5912'-(/6171(3520'TVD)\Pump rate 603 gpm @ 940 psi.\60 RPM @ 8-9K torque.\WOB=20-30K \Up wt.=169K-Dn wt.=128K-Rot wt.=147K./Mud wt.=9,2 ppg.l ECD=9.69 ppg.\ART=5.0 hrs.\ADT=36.6 hrs.\Jars= 213.7 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Doll Rotary Steerable 1/6171'-116353'(3546'TVD)\Pump rate 625 gpm @ 990 psi.1 70 RPM @ 10K torque.\WOB=20-22K \Up wt.=169K-Dn wt.=129K-Rot wt.=147K\Mud wt.=9.2 ppg.\ECD=9.59 ppg.\ART=4.29 hrs.\ADT=40.89 hrs.\ Jars=217.99 hrs. 12:00 18.00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 1/6353'-116393'(3551'TVD)\Pump rate 624 gpm @ 980 psi.\60 RPM @ 10K torque.\WOB=18-20K \Up wt.=169K-Dn wt.=128K-Rot wt.=147K.1 Mud wt.=9.3 ppg.\ECD=9.75 ppg.\ART=4.51 hrs.\ADT=45.40 hrs.\ Jars=222.5 hrs. 18:00 00-.00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable f/6393'-116410'(3554'TVD)\Pump rate 900 gpm @ 1825 psi./90 RPM @ 8-10K torque./WOB=20- 30K\Up wt.=169K-Dn wt.=128K-Rot wt.=147K.\Mud wt.=9.4 ppg,\ECD=9,89 ppg.\ART=5,50 hrs.\ADT=50.90 hrs.\Jars=228 hrs. Total ADT=50.90 hrs. Total Jar=228.0 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth)ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.710.0 2,501.71 LSND 9.20 610.0 13.89 1,805,6 1 alroit Eni E&P Division (Well Name: SP27-N1 Daily Report ENI Petroleum Co.Inc. Well Code:26116 Field Name: Nikaitchuq • API/UWI:50-629-23458-00-00 2^ Date:12/14/2011 - Report#: 13 I' II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31/2 I Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 12.21 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,554.0 3,576.8 144.00 8.99 16.0 102.0 -22.0 Clear,WC-40 236'SSW @ 7.5 MPH Daily summary operation 24h Summary Drill Rotary Steerable(/6410'-1/6554'\Circulate bottoms-up until clean(3X)-rack back stand each CBU(/6554'-8/6280'\POOH back reaming f/6280'-1/2624'.1 Circulate bottoms-up until clean(3.5X), monitor well-static.)POOH f/6224'-1/6175'(wet)correct displacement-line to pump dry job.\Notified AOGCC @ 1000 hrs.for early BOP test-Matt Herrera returned call @ 1532 hrs.left message-We return call @ 1600 hrs.which Mr.Herrera waived witness of test. Operation at 07.00 Working BHA#5 as per Schlumberger DD/MWD. 24h Forecast Continue POOH to BHA#5\Schlumberger inspect and L/D smart tools-down load data.)Test BOP to AOGCC requirements.\M/U BHA#6-surface test.)RIH 1/6554'\Drill ahead to 9 5/8"csg.point. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 6.00 6.00 DRILL E 3 P Drill Rotary Steerable(/6410'-1/6480'(3562'ND))Pump rate 610 gpm @ 980 psi.\60 RPM @ 9-10K torque.)WOB=28- 30K\Up wt.=172K-Dn wt.=126K-Rot wt.=149K./Mud wt.=9.4 ppg.\ECD=9.84 ppg.\ART=5.60 hrs.\ADT=56.50 hrs.\Jars=233.6 hrs. 06.00 1000 4.00 10.00 DRILL E 3 P Drill Rotary Steerable(/6480'-V6554'(3576''ND))Pump rate 619 gpm @ 1030 psi.)80 RPM @ 8-9K torque.)WOB=22- 26K\Up wt.=172K-Dn wt.=126K-Rot wt.=148K./Mud wt.=9.4 ppg.\ECD=9.89 ppg./ART=3.39 hrs.)ADT=59.89 hrs. Jars=236.99 hrs. Total ADT=59.89 hrs. Total Jar=236.9 hrs. 10.00 13.00 3.00 13.00 DRILL E 7 P Circulate bottoms-up until clean(3X)1 Pumping 900 gpm @ 1900 psi.)Rotating and reciprocate pipe 130 RPM @ 7-8.5K torque-rack back one stand after each CBU f/6554'-1/6280'\Rot wt.=144K.\Monitor well-static.)Notified AOGCC of early BOP test @ 1000 hrs. _ 13.00 2200 9.00 22.00 DRILL E 4 P POOH back reaming(/6280'-52624'\Pump rate 900 gpm @ 1370 psi.\130 RPM @ 4-8K torque.)Rot wt.=142K.)Mud wt.= 9.4 ppg.\Checking tool joints for wear.)Matt Herrera with AOGCC retumed call @ 1532 hrs.left a message-retumed call @ 1600 hrs.which Matt waived witness of test. 2200 23.30 1.50 23.50 DRILL E 7 P Circulate bottoms-up until clean(3.5 X)\Pump rate 900 gpm©1350 psi.)120 RPM @ 2.5K torque.)Rot wt.=140K./ Monitor well-static @ 2610'. 23.30 00.00 0.50 24.00 DRILL E 4 P POOH on elevators(/2610'-V2175'(correct displacement))Line to pump dry job. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum '907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 I. Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.710.0 2.501.71 LSND 9.20 610.0 13.89 1.805.6 1111* Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^ Date:12/15/2011 - Report#: 14 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permi6Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14.155.00 156.69 90.3 13.21 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6.554.0 3,576.8 0.00 101.0 -22.0 Clear,WC-46 308`NW @ 11.5 MPH Daily summary operation 24h Summary Pump dry job and POOH 1/21751-V277\Work BHA#5-L/D HWDP and NM Flex DC due to hard band wear and to BOP test-down load data from tools./Test BOPE components to AOGCC requirements-AOGCC waived witness of test./P/U BHA#6 and surface test power drive-continue P/U and M/U NM Flex DC. Operation at 07.00 RIH with BHA#6-filling pipe as per Schlumberger. 24h Forecast Finish P/U BHA#6 and perform shallow test on tools./RIH 1/6554'/Drill ahead as per well plan to 9 5/8"csg.point. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P Pump dry job and POOH on elevators 1/21751-6277'-UD ghost reamer(1/8"under gauge)and XO's. 03:00 06:30 3.50 6.50 DRILL E 4 P Work BHA#5 as per Schlumberger DD/MWD-UD 3 joints HWDP and 2 NM Flex DC due to worn off hard band./L/D remaining BHA-2 stabilizers,ARC,Telescope,Xceed 900 for BOP test and down load data from tools. 06:30 08:00 1.50 8.00 DRILL E 20 P Clear floor of tools and clean/organized from POOH-Prep to pull wear bushing. 08:00 09:00 1.00 9.00 DRILL E 20 P Pull wear bushing and install test plug with Vetco Gray rep. ////1111 R� 09:00 19:00 10.00 19.00 DRILL E 20 P Test_B�to AOGCC requirements on 5"tubular./Test annular @ 250 psi./2500 psi./Pipe rams;mud cross choke and kill valves/HCR's:choke manifold and blind rams to 250 psi./3500 psi.-Chart record all test for 5 mins./Tested hydraulic and [J/ manual chokes to 1500 psi.-Chart record./Perform accumulator draw down test(Recovery times:f/1500-61700 psi.(200 . psi.)in 34 seconds with final @ 3000 psi.in 201 seconds-5 Nitrogen bottles @ 2450 psi.average)./Tested was waived by 1 AOGCC Rep.Matt Herrera @ 1600 hrs.11/14/2011. 1900 20:00 1.00 20.00 DRILL E 20 P R/D test equipment and pull test plug-Install wear bushing with Vetco Gray rep. ✓ • 20'00 00:00 4.00 24.00 DRILL E 4 P Held PJSM w/Schlumberger-P/U BHA#6 684'-surface test power dove-pump rate 660 gpm @ 660 psi.for 10 mins.r/ I Blow down TD and continue P/U BHA. • Daily Contacts I Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener -ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 '715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.7100 2,501.71 LSND 9.20 610.0 13.89 1,805.6 Eni E&P Division Well Name:SP27-N1 ENI PetroleumCo.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq IP* � API/UWI:50-629-23458-00-00 2^ Date:12/16/2011 - Report#: 15 II II page 1 of 1 Wellbore name: SP27-N1 Well Header PermiVConcession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 14.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,476.0 3,694.1 922.00 11.79 78.2 100.0 -16.3 Clear,WC-42 32°NE at 12 MPH Daily summary operation 24h Summary Finish P/U BHA#6 and perform shallow test on Schlumberger tools.\RIH f/283'-1/6445'./Wash 1/6445'-1/6554'.1 Drill ahead(/6554'-1/7476'. Operation at 07.00 Drilling 12 1/4"hole section to 9 5/8"csg.point. 24h Forecast Drill ahead as per well plan to 9 5/8"csg.point./Circulate bottoms-up 5-6X(rack back one stand each CBU).\POOH back reaming as per K8M parameters.\L/D BHA#6.1 Change upper rams to 9 5/8"csg.and test 250/3500 psi.\Install short wear bushing./R/U Tesco CDS to run 9 5/8"csg. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P P/U BHA#6 as per Schlumberger-shallow test tools @ 283'-good./Establish KW parameters with BHA. 02:30 08.00 - 5.50 8.00 DRILL E 4 P RIH 1/283'-V 6445'-fill pipe as required.\Break circulation @ 13 3/8"csg,shoe record parameters:600 gpm @ 850 psi.160 rpm @ 4-5k torque.\Rot wt.=139K.\Wash 1/6445'-5/6554'-pump rate 200 gpm @ 240 psi. 08.00 1200 4.00 12.00 DRILL E 3 P Drill Rotary Steerable(/6554'-/6750'(3611'TVD)/Pump rate 850 gpm @ 2100 psi./60 RPM @ 9K torque.\WOB=28K 1 Up wt=173K-Dn wt.=133K-Rot wt.=150K./Mud w1=9.4 ppg.\ECD=9.92 ppg.\ART=2.6 hrs.\ADT=2.6 hrs.\Jars= 239.59 hrs. 12.00 18.00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 1/6750'-117039'(3665'TVD)/Pump rate 900 gpm @ 2300 psi./60-120 RPM @ 8-10K torque.\WOB= 28K\Up wt.=173K-Dn wt.=133K-Rot wt.=150K.\Mud wt=9.4 ppg.\ECD=9.9 ppg.\Back ream 30'before connection./ ART=4.39 hrs.\ADT=6.99 hrs.\Jars=243,98 hrs. 18:00 00:00 - 6.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/7039'-117476'(3694'TVD)/Pump rate 900 gpm @ 2480 psi./120 RPM @ 10-12K torque.\WOB= 20K 1 Up wt.=168K-Dn wt.=123K-Rot wt.=140K./Mud wt.=9.4 ppg.1 ECD=10.1 ppg.\Back ream 30'or stand as needed before making connection./ART=4.8 hrs.\ADT=11,79 hrs.\Jars=248,78 hrs. Total ADT=11.79 hrs. Total Jar=248.78 hrs Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep �jack.keener@enipelroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipelroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2,664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,710.0 2,501.71 LSND 9.20 610.0 13.89 1,805.6 I lifj* Eni E&P Division (Well Name: SP27-N1 ENI Petroleum Co.Inc. Daily Report L} Well Code:26116 Field Name:Nikaitchuq • Date:12/17/2011 - Report#: 16 APIIUWI:50-629-23458-00-00 ' i rr ii page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 15.21 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8.261.0 3.738.7 785.00 6.01 130.6 105.0 -11.0 Clear,WC-59 35°ENE 28 MPH Daily summary operation 24h Summary Drill ahead 1/7476'-118261'-TD 12 1/4"intermediate hole section for 9 5/8"csg.\Circulate bottoms-up-rack back stand 68261'-118223'.\Service rig-Trouble shoot TDS-8(shot pin on pipe handler)\ Continue circulating bottoms-up-reciprocating and rotating pipe-rack back stand after each CBU(/8223'-t/7752'.\POOH back reaming(/7752'-1/6200'. Operation at 07.00 POOH back reaming as per well plan and K&M parameters. 24h Forecast Continue POOH back reaming to shoe as per K&M parameters./Circulate bottoms-up @ shoe(2264')while rotating/reciprocating string until clean(3X).\POOH on elevators to BHA#6-L/D same.: Change to 9 5/8"csg.rams&test to 250/3500 psi.\Install short wear bushing./R/U Tesco CDS tool and circulating lines./PJSM and P/U 9 5/S"csg.(40#;L-80;Hydnl 563)as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.55 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 600 6.00 DRILL E 3 P Drill Rotary Steerable(/7476'-t/7859'(3721'TVD)/Pump rate 885 gpm @ 2360 psi. 120 RPM @ 10-11K torque./WOB= 24-25K\Up wt.=170K-Dn wt.=130K-Rot wt.=150K./Mud wt.=9.4 ppg.\ECD=10.23 ppg.\Back ream as needed./ ART=4.41 hrs.\ADT=13.60 hrs./Jars=250.5 hrs. 06.00 12.00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable(/7859'-1/8261(3739'TVD)/Pump rate 892 gpm @ 2420 psi./120 RPM @ 11K torque./WOB=25K\ Up wt.=172K-Dn w1.=130K-Rot wt.=150K\Mud w1.=9.5 ppg./ECD=10.41 ppg.\Back ream before connection./ART= 4.20 hrs.\ADT=17.80 hrs.\Jars=254.7 hrs.\TD 12 1/4"intermediate hole section @ 8261'for 9 5/8"csg.point. Total ADT=17.80 hrs. Total Jar=254.7 hrs. 12.00 13:30 1.50 13.50 DRILL E 7 P Started circulating bottoms-up(1X)-reciprocating and rotating string-(record slow pump rates)./Pumping 900 gpm @ 2450 psi.\130 RPM @ t0K torque./Up wl.=178K-Dn wt.=122K-Rot wt.=150K.-rack back one stand at CBU f/8261'- V8223'. 13.30 14:30 1.00 14.50 DRILL E 25 P Service rig/trouble shoot TDS-8 shot pin on pipe handler./Monitor well-static. 14.30 20:00 5.50 20.00 DRILL E 7 P Circulate bottoms-up until clean(5X)/Pumping 900 gpm @ 2450 psi.\Rotating and reciprocate pipe 130 RPM @ 10K torque-rack back one stand after each CBU 1/8223'-17752'/Mud wt.=9.5 ppg.\ECD=10.33 ppg. 20.00 00:00 4.00 24.00 DRILL E 4 P POOH back reaming f/7752'-1/6200'/Pump rate 900 gpm @ 2350 psi./140 RPM @ 10-11K torque./Rot wt.=138K.\Mud V wt.=9.55 ppg./ECD=10.3 ppg.average. Daily Contacts Position Contact Name Company Title E-mail Office • Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 '715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 1 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 36.4 2.664.0 12/5/2011 1 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,710.0 2,501.71 LSND 9.20 510.0 13.89 1.805.6 Eni E&P Division 'Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq Viii* • APIIUWI:50-629-23458-00-00 2 II^,t Date:12/18/2011 - Report#: 17 �' I' page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14.155.00 156.69 90.3 16.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,261.0 3,738.7 0.00 104.0 -16.6 Clear.WC-51 20°NE 17.3 MPH Daily summary operation 24h Summary POOH back reaming(/6200'-112618'in shoe./Circulate until clean(3.5 CBU)\POOH on elevators(/2618-1283'\L/D BHA#6\Pull wear bushing\Change upper rams to 9 5/8"csg.\Set test plug and 9 5/8" test joint.\Test 1250 psi./3500 psi.\Pull 9 5/8"test joint and plug./Install short wear bushing and R/D 5"joint. Operation at 07.00 P/U 9 5/8"csg.and RIH with Tesco CDS. 24h Forecast R/U Tesco CDS tool and R/U circulating lines.\PJSM and P/U 9 5/8"csg.(40#;L-80;Hydril 563)RIH 1/8245'./R/U and fill 9 5/8"csg.\Circulate and condition mud for cement job./PJSM with Schlumberger and perform cement job. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.65 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 06:00 6.00 6.00 DRILL E 4 P POOH back reaming(/6200'-14400'\Pump rate 900 gpm @ 1900 psi.\120 RPM @ 5-8K torque./Rot wt.=146K./Mud wt.= 9.4 ppg./ECD=9.91 ppg. 06'00 12:00 6.00 12.00 DRILL E 4 P POOH back reaming 1/4400'-12618'inside shoe.\Pump rate 900 gpm @ 1700 psi./120 RPM @ 34K torque./Rot wt.= 135K./Mud wt.=9.4 ppg.\ECD.9.63 ppg. 1200 13:00 1.00 13.00 DRILL E 7 P Circulating bottoms-up until clean(3.5X)-reciprocating and rotating string./Pumping 900 gpm @ 1700 psi.\120 RPM @ 3K torque.\Mud wt.=9.4 ppg.\ECD=9.59 ppg.\Rot wt.=134K. 13.00 15:30 2.50 15.50 DRILL E 4 P POOH on elevators 1/2618'-1283'. 15:30 18:00 2.50 18.00 DRILL E 4 P Work BHA#6-f/283';stand back 5"HWDP in derrick./L/D Schlumberger tool string and down load data.-Prep for shipment of tools off island on Hoover craft./Clear and clean floor area. 18:00 1900 1.00 19.00 DRILL G 20 P P/U 5"test joint and pull wear bushing with Vetco Gray-pump out stack(blow down choke lines). 19:00 2030 1.50 20.50 DRILL G 20 'P PJSM-Change upper pipe rams from variable to 9 5/8"csg.(change door seal)./P/U Tesco control manifold and air and hydraulic lines to rig floor. 20:30 22.00 1.50' 22.00 DRILL G 20 P P/U and M/U 9 5/8"test joint and test plug-fill stack w/water-R/U equipment./Test rams 1250 psi/3500 psi.(chart record f/5 mins.). 22:00 0000 2.00 24.00 DRILL G 20 P R/D test equipment-Pull 9 5/8"csg.joint and test plug-L/D same./P/U 5"test joint and install short wear bushing with Vetco Gray(length 48 3/8"-12 11/4"ID-13 7/8"OD). Daily Contacts Position Contact Name Company Title • E-mail Office Mobile Eni representative Jack Keener ENI -Senior Co Rep 'jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3:8 12.415 L-80 36.4 2.664.0 12/5/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2.710.0 2.501.71 LSND 9.20 610.0 13.89 1.805.6 Eni E&P Division Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq Oil* e APIIUWI:50-629-23458-00-00 2�, Date:12/19/2011 - Report#: 18 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-NI DRILLING 12/2/2011 14,019.6 3,733.1 14,155.00 156.69 90.3 17.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8.261.0 3,738.7 0.00 103.0 -14.3 Clear,WC-21 302°NE 5 MPH Daily summary operation 24h Summary R/U Tesco CDS and equipment to run 9 5/8"csg.\PJSM-Run 9 5/8"csg as per wet plan.rotated 9/7005'-1/8245'.1 R/D Tesco CDS and equipment.\Install cement head(without plugs)and lines.\Fill 9 5/8"csg.with 250 bbls.of 9.4 ppg.LSND mud. Operation at 07.00 Break circulation and condition mud for cement job. 24h Forecast Fill 9 5/8"csg.with 9.4 ppg of LSND mud and confirm pipe is full.\Schlumberger install wiper plugs.)Break circulate @ 1/2 bpm and gradually increase U8 bpm.-condition mud as per well plan.\PJSM with Schlumberger and perform cement job.\Perform injective test down 13 3/8"x 9 5/8"annulus with mud.\Lift BOP stack to install emergency slips as per well plan.\Off line activity load pipe shed with 5"DP. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL G 20 P R/U Tesco CDS-remove bails and guide bowl from TDS-8.\P/U CDS tool and M/U on TD-calibrated torque turn.)Install i hose from stand pipe to choke manifold-blow down same.\Monitor well with trip tank-no loses. 1 04:00 12:00 8.00 12.00 DRILL G 20 P PJSM with Tesco-P/U shoe track-fill and check float equipment-OK.\Continue P/U 9 5/8"csg.(408;L-80;Hydril 563) empty with Tesco CDS tool 1/3600'\K&M recorded parameters @ 2639'with 30 RPM @ 3K torque.\Rot wt.=88K-Up wt= f 92K-Dn wt.=79K.\Monitor displacement with active pit#4-no loses. V 12:00 20:30 8.50 20.50 DRILL G '20 -P Continue P/U 9 5/8"csg.(40#;L-80;Hydril 563)with Tesco CDS 9/3600'.1/8245'(P/U landing joint).\K&M recorded parameters©5017'-6017'-started rotating f/7005'-1/8245'with 35 RPM @ 5-8K torque Rot wt.=70-80K.\Monitor displacement with active#4-no loses.\Gave AOGCC 24 hrs.ootificatio0_ J.815.hrs for RnP tost-Chuek Scheme n returned call©1820hrs.to waived witness.but will keep him updated on progress. L'J 20:30 21:30 1.00 21.50 DRILL G 20 P R/D Tesco CDS equipment and L/D from floor.\P/U long bails and install on TD. LLLL���, 21:30 22:30 1.00 22.50 DRILL G 20 'P Install cement head(without plugs)-R/U 2"high pressure hose from stand pipe manifold to fill on bottom outlet and another on manifold of cement head to bleed air to choke/gas buster.\Confirm open flow path line-up. 22:30 00:00 1.50 24.00'DRILL G 7 'P Fill 9 5/8"csg.with 250 bbls.of 9.4 ppg LSND mud @ 3 bpm with no pressure.\Start mixing Schlumberger Mud Push II in pill pit. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,710.0 2,501.71 LSND 9.20 610.0 13.89 1,805.6 Eni E&P Division I Well Name:SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^ Date:12/20/2011 - Report#: 19 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(It) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14.155.00 156.69 90.3 18.21 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,261.0 3,738.7 0.00 105.0 -20.0 Clear,WC-46 0°N @ 11.5 MPH Daily summary operation 24h Summary Fill 9 5/8"csg.with 9.4 ppg of LSND mud.\Break circulate and condition mud for cement job./PJSM with Schlumberger and cement 9 5/8"csg.-Plugs bump as calculated and in place @ 1333 hrs.\ Perform injective test on 13 3/8"x 9 5/8"annulus with mud-/N/D @ Multi bowl.\Lift BOP stack.\Vetco Gray set emergency slips and 9 5/8"pack-off./N/U BOP. Operation at 07.00 Testing BOP and cleaning active pits. 24h Forecast Tighten well head connection-test 9 5/8"csg.pack-off./Freeze protect 13 3/8"x 9 5/8"annulus with Little Red.\N/U BOP./Test BOP to AOGCC requirements\P/U BHA#7\P/U 5"DP RIH.\Finish cleaning active pits.\Transfer OBM to active pits. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 04:30 4.50 4.50 DRILL G 7 P Fill 9 5/8"csg.with 9.4 ppg LSND mud @ 3 bpm as per well plan-total 620 bbls.\Mix Schlumberger Mud Push II in pill pit.\ Load pipe shed with 5"DP. 04.30 05:30 1.00 5.50 DRILL H 1 P Confirm 9 5/8"csg.is full,\Blow down lines and choke manifold./Load wiper plugs in cement head. 05.30 09:30 4.00 9.50 DRILL H 7 P Break circulation with 1/2 bpm @ 240 psi.stage rate to 8 bpm @ 490 psi.-monitor for loses./Condition mud as per well plan for cement job. 09.30 14:30 5.00 14.50 DRILL H 7 P Hold PJSM w/all personnel involved with cement job.SLB pump 10 bbls H2O&test lines to 3500/psi.\Rig pumped 90 bbls. • Y, Mudpush II @ 10.5 ppg.-Pump rate of 6 bpm @ 255 psi.\Shut-down drop bottom plug./SLB mix&pump 221 bbls.slurry I @ 12.3 ppg.\DeepCrete 7$ sks_jYield 1.64 5.3/sk,mix water at 6.059 gallsk.]-Pump rate of 3.5 bpm @ 297 psi.\Shut down&drop top plug-SLB pump 10 bbIsT-1201 Displace with 608 bbls.@ 9.4 ppg LSND mud with ng mud pump at 7 bpm ' w/ICP 190 psi and FCP 450 psi;at 578 bbls away slow pump to 3.0 bpm with 450/psi.FCP\Bump plug to 500/psi,over to - 1 t'S 950/psi.-Hold for 10 minutes and bleed off-check floats holding-Good./Cement in place @ 1333 hrs.\R/D cement head and lines. • 14:30 1530 1.00 15.50 DRILL H 7 P R/U and perform infectivity test into 13 3/8"csg.x 9 5/8"csg.annulus with 9.4 ppg LSND mud pumping 42 gpm @ ICP 411 psi./FCP 656 psi. 15:30 18.00 2.50 18.00 DRILL G 20 P 'PJSM-N/D BOP-Flow line.bleeder,fill-up.choke lines-break Multi-bowl connection form well head./Clean surface equipment and pits for OBM. 18:00 21:30 3.50 21.50 DRILL G 20 P PJSM wNetco Gray-P/U BOP stack,user and Multi-bowl to approximate 24"/Prep to set emergency slip-P/U 105K over block weight-set slips with 100K weight transfer./Vetco Gray R/U cut 9 5/8"csg.and L/D./R/D spiders and long bails./ Clean active pits for OBM. 21:30 22:30 1.00 22.50 DRILL G 20 P 'PJSM-P/U 5"test joint and pull wear bushing form multi-bowl.\Dress top of 9 5/8"csg.and install pack-off.\Install bail guide.short bails and hook-up linkage./Clean active pits for OBM. 22:30 00.00 1.50 24.00 DRILL G 20 P 'Lower BOP stack,riser and multi-bowl onto well head and N/U BOP./Continue cleaning active pits for OBM. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Co Rep jack.keener@enipetroleum 907-685-0715 715-6434 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-6850721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.710.0 2.501.71 LSND 9.20 610.0 13.89 1.8056 1 • IP* Eni E&P Division Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^n Date:12/21/2011 - Report#: 20 I' (I II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(/) Well Configuration type 211139 ENI PETROLEUM 10000 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(88KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14019.6 3,733.1 14,155.00 156.69 90.3 19.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,261.0 3,738.7 0.00 105.0 -27.0 Clear,WC-37 255°N @ 6 MPH Daily summary operation 24h Summary M/U multi-bowl connection-Vetco Gray tested 9 5/8"pack-off 1/2400 psi.\Change rams and freeze protect OA with Little Red-total 165 bbls.-continue N/U choke and flow lines on BOP stack.\Shell test BOP-HCR flange connection leaked(replaced API)-retest good.\Test BOP to AOGCC requirements(Chuck Scheve waived witness after update @ 0603 hrs.).\P/U BHA#7 as per well plan./Security was notified of spill @ 2333 hrs.from production module D2U06-ACS and ENI operation responded-stopped @ 2340 hrs.-report to follow. Operation at 07.00 RIH P/U 5"DP singles. 24h Forecast Finish P/U BHA#7 and perform shallow test-record K8M parameters.\RIH P/U 5"DP singles.\Cut drilling @+/-8100'-circulate bottoms-up.\Test 9 5/8"csg.63000 psi.for 30 mins\Displace casing to OBM(FazePro).\Drill out float equipment and 20'-50'new hole.)Perform LOT/FIT.\Drill ahead 8 3/4"production hole section. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum ' Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL G 20 P M/U multi-bowl connection on well-Vetco Gray tested 9 5/8"pack-off to 2400 psi.f/10 mins.\Continue cleaning active and transferring fluid from rock wash to WIF. 01:00 02.00 1.00 2.00 DRILL -E 20 P PJSM-Change upper rams to variable from 9 518"csg.\R/U Little Red and freeze protect 9 5/8"x 13 3/8"annulus with diesel (90°-100°)-ICP 1 bpm @ 800 psi.started @ 0115 hrs. 02:00 05:30 3.50 5.50 DRILL -E 20 P PJSM-N/U choke line and flow line,hook-up fill-up and bleeder lines-install drip pan hoses and align stack./P/U 5"DP test joint and plug-install same.\Continue cleaning active pits.)Complete freeze protection of 9 5/8"x 13 3/8"annulus with ✓ Little Red,pumped 165 bbls.heated diesel with FCP 1.04 bpm @ 1200 psi.-monitor pressure 5 mins.800 psi @ 0446 hrs. -shut in and R/D. 05:30 08.30 3.00 8.50 DRILL -E 12 .P R/U test equipment and fill stack and choke with H2O-perform shell test on system-flange connection at choke HCR leaked-tighten connection and retest.still leaked-change out API ring and retested good./Finished cleaning active pits for OBM.\Called AOCGG with updated on testing @ 0603 hrs.-Chuck retumed @ 0717 hrs.still waived witness of test. 08:30 19.00 10.50 19.00 DRILL E 12 P Test BOP to AOGCC requirements on 5",4 1/2",51/r tubular./Test annular @ 250 psi./2500 psi.\Two variable pipe rams (top 4 1/2"x7"-bottom 2 7/8"x5");choke and kilt manual valves/HCR's;choke manifold;blind rams;top drive upper/lower n IBOP and floor valves to 250 psi./3500 psi.-Chart record all test for 5 mins.\Tested hydraulic and manual chokes-Chart / r ° /� record./Flow test volume from kill line through to degasser-17.5 bbls.\Perform accumulator draw down test(Recovery times:(/1525-1/1725 psi.(200 psi.)in 21 seconds with final @ 3000 psi.in 199 seconds.)5 Nitrogen bottles @ 2450 psi. average.\Transferred 600 bbls.of 9.4 ppg OBM(FazePro)and 190 bbls.of LVT into rig pits./Dress shakers with screen./ Assisted MI Swaco working on suitcase. 19.00 20.00 1.00 20.00 DRILL 'E 20 P R/D from testing-blow down-pull test plug and Vetco Gray installed wear bushing. 20:00 00.00 4.00 24.00 DRILL •E 4 -P PJSM w/Schlumberger-P/U BHA#7 as per well plan-load radioactive sources in tools.\Security was notified of spill @ 2333 hrs.from production module D2U06 and ACS and ENI operation responded-stopped @ 2340 hrs.-report to follow. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Mike Ross ENI -Co Rep michael.ross@enipetroleum.com 907-685-0715 ' Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 d Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 30.8 8.245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal( Leak Off Pressure(psi) 2.710.0 2,501.71 LSND 9.20 610.0 13.89 1.805.6 Eni E&P Division I Well Name:SP27-N1 fill* ENI Petroleum Co.Inc. Daily Report Well Code:26116 + Field Name: Nikaitchuq 2 n Date:12/22/2011 - Report#: 21 II API/DWI:50-629-23458-00-00 II I' page 1 of 1 Wellbore name: SP27-N1 Well Header PermiVConcession N° Operator ENI Share(/) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 20.21 Daily Information i End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8.261.0 3,738.7 0.00 103.0 -27.0 Clear,WC-41 183'SSW @ 9 MPH Daily summary operation 24h Summary P/U BHA#7 t/383'-shallow test MWD tool./RIH with P/U 5"DP singles f/383'-t/5610'.\RIH f/5610'-1/7952'with DP stands from derrick.\Wash 1/7952'-1/8149'tagged cement.\Perform 9 5/8"csg.test to 3000 psi.fl30mins.(chart record).\Service rig-Cut drilling line-Calibrate block height and hook load f/Schlumberger.\PJSM-Displace 9 5/8"csg.with OBM(9.4 ppg.FazePro).)Clean surface equipment of LSND mud. Operation at 07.00 Circulating bottoms-up for equal mud weight in/out to perform LOT/FIT. 24h Forecast Drill out float equipment plus 20'-50'new hole.\Circulate bottoms-up to equal mud weight in/out.\Perform LOT/FIT.\Drill ahead 8 3/4"production hole section as per well plan. Lithology •Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 00 1.00 1.00 DRILL E 4 P Continue P/U BHA#7 and RIH t/383'-Perform shallow test for Schlumberger tools and record K&M data. 01:00 12.00 11.00 12.00 DRILL E 4 P PJSM-RIH with 5"DP P/U singles(/383'-V5610.-filling pipe every 10 std.for Schlumberger Xceed tool.\Up wt.=148K-Dn wt.122K.\P/U 171 joints. 12:00 14.00 2.00 14.00 DRILL E 4 P Continue RIH f/5610'-V7952'.DP from derrick-filling every 10 std.for Xceed tool. 14:00 15:00 1.00 15.00 DRILL E 7 P Wash(/7952'-68149'pumping 212 gpm @ 430 psi.1 Up wt=190K-Dn wt.=110K-Rot wt.=140K.1 Tag cement @ 8149' not rotating\Rack back stand to 8134'. I 15:00 16:30 1.50 16.50 DRILL E 12 P Perform 9 5/8"csg.test for 30 minutes with 9.4 ppg LSND-chart record./Bleed off pressure-blow down cement and kill lines-R/D. 16.30 17:30 1.00 17.50 DRILL E 25 P Service rig-crown,top drive.draw-works. 17.30 19:00 1.50 19.00 DRILL E 25 P Cut drilling line-120'-inspect and adjust brake linkage. I 19:00 19:30 0.50 19.50 DRILL E 1 P Calibrate hook load and block height for Schlumberger MWD and CanRig/Sperry. 19:30 21:30 2.00 21.50'DRILL E 1 P PJSM to displace with OBM-spot trucks and blow down lines from rig to mud plant and WIF1 Verify communication with all.\Crew change out @ 2000 hrs. 21:30 23:00 1.50 23.00 DRILL E 7 P Displace well horn LSND to FazePro 9.4 ppg OBM.\Pump 30 bbls.LVT spacer pill(flush all three mud pumps)and increased rate to 340 gpm @ 830 psi.-transfer LSND to WIF for disposal.\Reciprocate&rotate 55 rpm @ 8K torque./Up wt.=175K-Dn wt.=126K-Rot wt.=142K./Good OBM to surface shut down. 23:00 00.00 1.00 24.00 DRILL E 20 P Clean possum belly.under shaker screen,and surface Tines.\Disconnect water and connect LVT to pit system. Daily Contacts I/Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geo9.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(HKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 30.8 8.245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 • Eni E&P Division [Well Name:SP27-N1 011* ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • Date:12/23/2011 - Report#: 22 APIIUWI:50 629-23456-00-00 2 rr 'r o page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3,733.1 14,155.00 156.69 90.3 21.21 Daily Information End Depth(11KB) End Depth(TVD)(L..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 8,820.0 3,736.7 559.00 8.56 65.3 102.0 -28.0 Clear.WC-38 226°SW @ 5.8MPH Daily summary operation 24h Summary Drill out cement and float equipment plus 24'new hole(/8146'-V8285'./Circulate bottoms-up to 9.4 ppg mud weight in/out.\Perform LOT 12.9 ppg.EMW\Drill rotary steerable 58285'-V8638'.\Back ream 1/8638'-0/8245'open hole and shoe track 0/8154'and ream down 0/8245'\RIH f/8245'-1/8601'.\Ream f/8601'-0/8638'.\Drill rotary steerable(/8638'-6/8820'. Operation at 07.00 Drilling ahead as per well plan. 24h Forecast Drill ahead rotary steerable 8 3/4"production hole section. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. PlanOper.Descr. 00:00 03:00 3.00 3.00'DRILL E 3 'P ,‘Drill cement,float equipment and clean out to original TD,1/8146'-0/8261'-Pump rate 400-500 gpm @ 1240-1720 psi.\60- 70 rpm @ 4-15 torque./WOB=2-12K\Up wt.=175K-Dn wt.=123K-Rot wt.=142K\M W=9.4 ppg.\ECD=10.39 ppg.\ ADT=1.50 hrs.\Jars=51.20 hrs. 03:00 03:30 0.50 3.50'DRILL E 3 P Drill rotary steerable 24'new hole f/8261'-0/8285"(3839'ND)-Pump rate 500 gpm @ 1700 psi.\72 rpm @ 5-15K torque.\ WOB=2-10K1 Up wt.=175K-Dn wt.=120K-Rot wt.=140K\MW=9.4 ppg.\ECD 10.41 ppg.\ART=0.13 hrs.\ADT=0.13 hrs.\Jars=51.33 hrs. 03:30 04:30 1.00 4.50 DRILL E 7 P Circulate bosoms-up and condition mud for equal 9.4 ppg in/out-Reciprocate&rotate-Pump rate 500 gpm @ 1700 psi.\ 72 RPM @ 4-12K torque.\Rot wt.=142K.\POOH into shoe @ 8241'. 04:30 06:00 1.50 6.00 DRILL E 12 P R/U and circulate test lines.\Perform LOT with 9.4 ppg.OBM(FazePro)-surface pressure of 688 psi.- MW=12.9 ppg.\ •\ f(Z. ` R/D and blow down. - 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable(/8285'-V8507'(3739'ND)-Pump rate 500 gpm @ 2000 psi.\70 rpm @ 5-17 torque.\WOB=2-15K\ Up wt.=177K-Dn wt.=110K-Rot wt.=142K\MW=9.4 ppg.\ECD 10.81 ppg.\ART=2.67 hrs.\ADT=2.8 hrs.\Jars=54.0 hrs. 12:00 15:30 3.50 15.50 DRILL E 3 P Drill rotary steerable f/8507-0/8638'(3739'TVD)-Pump rate 500 gpm @ 1950 psi.\70 rpm @ 5-17 torque.\WOB=2-15K\ Up wt.=177K-Dn wt=112K-Rot wt=142K\MW=9.4 ppg.\ECD 11.10 ppg.\ART=2.21 hrs.\ADT=5.01 hrs.\Jars= 56.21 hrs. I 15:30 17:00 1.50 17.00 DRILL E 6 P 'Monitor well-static./Back ream(/8638'-1/8154'open hole./Pump rate 550 gpm @ 1940 psi./125 RPM @ 3.5-14K torque/ Rot wt.=142K.\Continue back reaming shoe track 1/8154'and down 0/8245'.\To clean-up section due to slip-stick and manage torque on Schlumberger tools. 17:00 18:00 1.00 18.00 DRILL E 6 P Monitor well-static./RIH 1/8245'-1/8601'/Schlumberger down link tool./Ream f/8601'-5/8638'.1 Pump rate 530 gpm @ 1850 psi.\75 RPM @ 8.10K torque\Rot wt.=142K. 18:00 00:00 6.00 24.00'DRILL E 3 P 'Drill rotary steerable f/8638'-6/8820'(3737'TVD).\Reamed f/8700'-118770'to drop angle with no success.\Pump rate 480 i gpm @ 1620 psi./70 rpm @ 9-11 torque./WOB=2-15K\Up wt=170K-Dn wt=112K-Rot wt=140K\MW=9.4 ppg.\ ECD 10.72 ppg.\ART=3.55 hrs.\ADT=8.56 hrs./Jars=59.76 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date ' CASING 95/8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8.245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 Eni E&P Division (Well Name:SP27-N1 091* ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • Date:12/24/2011 - Report#: 23 APIIUWI:50-629-23458-00-00 2" " page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14.155.00 156.69 90.3 22.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,562.0 3,730.3 1.742.00 15.72 110.8 107.0 -21.0 Clear WC-37 220`SW @ 7 MPH Daily summary operation 24h Summary Drill rotary steerable 1/8820'-t/10,562'.Finish prepping 4 1/2"tbg.and load pipe shed w/5 1/2"slotted liner-start prep same to run. Operation at 07.00 Drilling ahead as per well plan-prep 5 1/2"liner. 24h Forecast Geo-steering 8 3/4"production hole section to TD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P Drill rotary steerable 1/8820'-119147'(3747'TVD).\Pump rate 450-510 gpm @ 1450-1700 psi.\70-120 RPM @ 10-15 torque.\WOB=2-8K\Adjusting drilling parameters to formation changes./Up wt.=170K-Dn wt.=120K-Rot wt.=1426\ MW=9.4 ppg.\ECD 10.76 ppg.\ART=4.96 hrs.\ADT=13.52 hrs.\Jars=64.72 hrs. 06.00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable(/9147'-09358'(3746'TVD)-Pump rate 550 gpm @ 1970 psi./70-125 RPM @ 8-11K torque.\WOB= 2-16K\Up wt.=170K-Dn wt.=120K-Rot wt.=144K\MW=9.4 ppg.\ECD 10.84 ppg.\ART=3.87 hrs.\ADT=17.39 hrs.\ Jars=68.59 hrs. 12.00 18.00 6.00 18.00 DRILL E 3 P Drill rotary steerable 1/9358'-610.002'(3732'TVD)-Pump rate 550 gpm @ 2000 psi./120 rpm @ 12K torque.\WOB=8- 12K\Up wt=165K-Dn wt.=110K-Rot wt.=1476\MW=9.4 ppg\ECD 11.10 ppg.\ART=3.59 hrs.\ADT=20.98 hrs.\Jars =72.18 hrs. 18:00 00.00 6.00 24.00 DRILL E 3 P Drill rotary steerable 1/10,002'-1110,562'(3732'TVD)-Pump rate 545 gpm @ 2200 psi.\120 rpm @ 12K torque./WOB=8- 10K\Up wt.=180K-Dn wt.=100K-Rot wt.=137K\MW=9.4 ppg.\ECD 11.20 ppg.\ART=3.30 hrs.\ADT=24.28 hrs. \Jars=75.48 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com -907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 z II* Eni E&P Division 'Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchuq • 2^n Date:12/25/2011 - Report#: 24 II APuuwl:50 6zs-23asa-oo-oo " II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3,733.1 14.155.00 156.69 90.3 23.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,805.0 3,727.7 2,243.00 13.60 164.9 107.0 -22.5 Clear,WC-42 036`NNE @ 11 MPH Daily summary operation 24h Summary Drill rotary steerable as to formation f/10,562'-1/12,805'.Finish loading and prepping 5 1/2"liner in pipe shed. Operation at 07.00 Drilling ahead 8 3/4"production section as per well plan. 24h Forecast Geo-steering 8 3/4"production hole section to projected TD @ 14,200'.1 Circulate bottoms-up(rack back stand each CBU).\POOH back reaming as per well plan and K&M parameters. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P Drill rotary steerable 610,562'-5/11,150'(3739'TVD)-Pump rate 556 gpm @ 2232 psi.\125 RPM @ 14-16K torque.\ WOB=3-10K\Up wt.=170K-Dn wt.=100K-Rot wt.=145K\MW=9.4 ppg.\ECD 11.06 ppg.\ART=3.89 hrs.\ADT=28.17 hrs.\Jars=79.37 hrs. 06:00 1200 6.00 12.00 DRILL E 3 'P Drill rotary steerable 611,150'-1111,740'(3748'TVD)-Pump rate 560 gpm @ 2290 psi.)125 RPM @ 13K torque./WOB= 10-16K\Up wt.=180K-Dn wt.=100K-Rot wt.=141K)MW=9.4 ppg.\ECD 11.33 ppg.\ART=3.2 hrs.\ADT=31.37 hrs.\ Jars=82.57 hrs. 1200 18 00 6.00 18.00 DRILL E 3 P Drill rotary steerable t/11,740'-1112,432'(3757'TVD)-Pump rate 545 gpm @ 2350 psi.\120-130 RPM @ 12-15K torque.\ WOB=8-10K\Up wt.=195K-Dn wt=80K-Rot wt.=139K\MW=9.4 ppg.\ECD 11.20 ppg\ART=3.43 hrs.\ADT=34.81 hrs.\Jars=86.01 hrs. 1 .00 00:00 6.00 24.00 DRILL E 3 ' 8 P Drill rotary steerable f/12,432'-1/12,805'(3734'ND)-Pump rate 555 gpm @ 2400 psi./120 RPM @ 12-15K torque.\ WOB=8-25K\Up wt.=195K-Dn wt.=80K-Rot v4.=139K\MW=9.4 ppg\ECD 11.40 ppg.\ART=3.07 hrs\ADT=37.87 hrs.\Jars=89.08 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Mike Ross ENI Co Rep 'michael.ross@enipetroleum.com '907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Em representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Tool Push Pete Martinusen Doyon Dnlling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 V Eni E&P Division I Well Name:SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2�,r, Date:12/26/2011 - Report#: 25 i "Ii page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 EM PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14,019.6 3.733.1 14,155.00 156.69 90.3 24.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 1.350.00 9.70 139.2 107.0 -11.5 Clear,WC-45 047'N @ 18 MPH Daily summary operation 24h Summary Drill rotary steerable as to formation f/12,805'-814,155'TD for production hole section.\Circulate bottoms-up rack back one stand after each CBU for the first 4X f/14,155'-(/13,832'and rack back two stand each CBU for 3 1/2-(/13,835'-813,366'(Total 71/2 X CBU). Operation at 07.00 POOH back reaming as per well plan and K&M parameters. 24h Forecast Circulate bottoms-up until clean(rack back two stand each CBU(113,36611 POOH back reaming as per K&M parameters(+1-7000)-drop rabbit in 9 5/8"shoe./POOH on elevators&maintain>9.0 EMW.\L/D BHA#7(radioactive sources).\Test BOP-AOGCC Bob Noble waived witness @ 2018 hrs.on 12/26/2011.1 Install wear bushing.\R/U GBR to run 5 1/2"liner. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00. 6.00 DRILL E 3 P Drill rotary steerable f/12,805'-1113,363'(3719'TVD)-Pump rate 550 gpm @ 2420 psi.\60-135 RPM @ 11-17K torque.: WOB=4-26K\Up wt.=190K-Dn wt.=N/A-Rot wt.=138K\MW=9.4 ppg.\ECD 11.60 ppg.\ART=4.54 hrs.\ADT=42.42 hrs.\Jars=93.62 hrs. 06.00 12.00 6.00' 12.00 DRILL E 3 P Drill rotary steerable f/13,363'-813,895'(3727 TVD)-Pump rate 550 gpm @ 2490 psi.\75-130 RPM @ 13-16K torque./ WOB=4-16K\Up wt.=190K-Dn wt.=N/A-Rot wt.=140K\MW=9.4 ppg\ECD 11.56 ppg.\ART=3.07 hrs.\ADT=45.59 hrs.\Jars=96.69 hrs. 12:00 16.00 4.00' 16.00 DRILL E 3 P Drill rotary steerable f/13,895'-814,155'(3745'TVD)TD for production hole section-Pump rate 554 gpm @ 2500 psi.\70- 135 RPM @ 10-18K torque\WOB=9-20K\Up wt.=190K-Dn wt.=N/A-Rot wt.=140K\MW=9.4 ppg.\ECD 11.61 ppg.\ ART=2.09 hrs.\ADT=47.58 hrs.\Jars=98.78 hrs.\Monitor well-static. 16:00 2000 4.00' 20.00 DRILL E 7 P Circulate bottoms-up(4X)-Pumping 550 gpm @ 2560 psi.\Rotate and reciprocate string with 135 RPM @ 12-14 torque.\ Rack back one stand after each CBU f/14.155'-813,832'.1 ECD=11.32 ppg.\SLM out of the hole. 20:00 0000 4.00' 24.00 DRILL E 7 -P Circulate bottoms-up(3 1/2X)-Pumping 550 gpm @ 2380 psi.1 Rotating and reciprocate pipe with 135 RPM @ 13K torque -rack back two stand after each CBU(/13,832'-813,366.1 Mud wt.=9.5 ppg.\ECD=11.27 ppg.\SLM out of the hole./Gave 24 hr notification to AOGCC for BOP test @ 2015 hrs.-Nob Noble returned call @ 2018 hrs.to waived witness of test. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleurn.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95:8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 f t 11* Eni E&P Division I Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 •Field Name:Nikaitchuq • API/UWI:50-629-23458-00-00 2 Date:12/27/2011 - Report#: 26 II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14,155.00 156.69 90.3 25.21 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0,00 111.0 -11.0 Clear,WC-47 057`ENE @ 18 MPH Daily summary operation 24h Summary BROOH to 6500'MD,circulate 3 bottoms up,pump 28 bbl.pill, POOH to 290'MD on elevators Operation at 07.00 Testing BOPE as per AOGCC requirements 24h Forecast Lay down BHA,test BOPE to AOGCC requirements/rig up to run 5 1/2"liner/run 5 1/2"liner Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 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 6 P PJSM,Continue to circulate and back ream out of the hole from 13366'MD to 12899'MD.Gpm=500 @ 2400 psi,Rotate at 130 RPM,Rotary Torque=12K. No loss of fluids or tight hole.Drag up=140K 02:00 15.30 13.50 15.50 DRILL E 6 P Continue to circulate and back ream out of the hole from 12899'MD to 6500'MD.At four minutes a stand.Gpm=500 @ 2400 psi,Rotate at 130 RPM,Rotary Torque=11K. No loss of fluids or tight hole.Drag up=134K 15:30 17.30 2.00 17.50 DRILL E 7 P Circulate 3 bottoms up @ 550 GPM with 1650 psi,No loss of fluids while circulating. 17:30 23.00 5.50 23.00 DRILL E 4 P Check for flow and then pump slug.POOH from 6500'MD to BHA.From 6500'MD to 6000'MD POOH at 4 minutes a stand.from 6000'MD to 5000'MD POOH at 3 minutes a stand and from 5000'MD to 250'POOH at 1.5 minutes a stand. 23.00 00.00 1.00 24.00 DRILL E 4 P PJSM on handling nuks.Lay down entire BHA a send to pipe shedlay down all HWDP and jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative -Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative David F Smith ENI Co Rep david.f.smith@enipetroleum.com 907-685-0715 632-3058 Eni representative Geoff Ackerman ENI HSE geofl.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher dg15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 30.8 8,245.2 12/20/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 l D Eni E&P Division (Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Well Code:26116 Field Name:Nikaitchuq • API/UWI:50-629-23458-00-00 2^n Date:12/28/2011 - Report#: 27 II II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14,155.00 156.69 90.3 26.21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0.00 109.0 -21.0 Clear,WC-30 192`S @ 6 MPH Daily summary operation 24h Summary Lay down BHA,Test BOPE,Pickup and 5 1/2"Liner Operation at 07.00 Pull out of hole laying down drill pipe. 24h Forecast Finish RIH with 5 1/2"liner,set liner,circulate OBM out and displace with Brine.POOH laying down Drill Pipe. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 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 G 4 P Perform PJSM.Lay down BHA 01.00 0230 1.50 2.50 COMP G 4 P Unload Nukes 02.30 03,00 0.50 3.00 COMP G 4 P Cont.to lay down BHA 03.00 0330 0.50 3.50 COMP G 4 P L/D tools from rig floor 03.30 04:30 1.00 4.50 COMP G 4 P Pull wear bushing and set test plug 04.30 05:00 0.50 5.00 COMP C 12 P R/U testing equipment 05:00 12:00 7.00 12.00 COMP C 12 P -Testing BOPE,250/2500 Annular,250/3500 on all rams,valves.All tests charted 5min.with 4.5"/5"/5.5"test joints. accumulator recovery 3 min.21 secs.nitrogen average=2450 psi 12.00 '12:30 0.50 12.50 COMP C 12 P R/D testing equipment. 12.30 13.00 0.50 13.00 COMP C 12 'P Install wear bushing 13.00 '15:00 2.00 15.00'COMP G 18 P PJSM.RU to run 5.5"slotted liner. 15.00 23.30 8.50 23.50'COMP G 18 P Run 5.5"slotted liner(140 jts),6 jts solid,and 2 swell packers as per program. 23.30 00:00 0.50 24.00 COMP G 18 P P/U and M/U SLZXP liner hanger,pump stack out.P/U single to Baker to prep hanger. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Rig Clerk john.spaulding@enipetroleum 907-685-0722 355-2607 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51:2 4.950 L80 8.093.0 14.155.0 12/29/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 ifok 1 Eni E&P Division Well Name:SP27-N7 ENI Petroleum Co.Inc. Daily Report L Well Code:26116 Field Name:Nikaitchuq • APIIUWI:50-629-23458-00-00 2^n Date:12/29/2011 - Report#: 28 II lI II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00.HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 DRILLING 12/2/2011 14.019.6 3.733.1 14,155.00 156.69 90.3 27.21 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,155.0 0.00 122.0 -19.5 Partly Cloudy.WC- 107°ESE @ 9 mph 46 Daily summary operation 24h Summary Finish RIH with 5 1/2"liner,set liner,circulate OBM out and displace with Brine.POOH laying down Drill Pipe. Operation at 07.00 LD drill pipe 24h Forecast Finish LD/DP.Cut&slip dig.line.RU to run tbg. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 COMP K 18 P PJSM,Fill liner hanger tie back sleeve with pal mix.LD working single. 00:30 01:00 0.50 1.00 COMP K 18 P P/U 1 std.dp RIH to 6165'liner depth.circ @ 2.5 bpm,130 psi and obtain rotary weight and torgues. 01:00 03:00 2.00 3.00 COMP K 4 P RIH with liner on 5"DP to 8218'MD,Circ pipe volume @ 3.5 BPM,230 PSI.Obtain Rotary WT=140K.P/U WT=15OK.SIO WT=129k.Torq=6-7K @ 30 RPM.All DP drifted to 2 875". 03:00 10:00 7.00 10.00 COMP K 4 P Cont.RIH with liner to 14,102'MD recording parameters every 500'.P/U=195K,5/0=115K. 10:00 10.30 0.50 10.50 COMP K 4 P P/U single 5"and RIH to 14,112"MD,pull string in tension @ 14,102"MD @ 195K. 10.30 11 00 0.50 11.00 COMP K 7 P Circ.145 BBLS.@ 4 BPM,360 PSI 11'.00 12'00 1.00 12.00 COMP K 7 P Drop setting ball&circ @ 2 BPM at 180 PSI. 12.00 13'30 1.50 13.50 COMP K 7 P Cont.to circ.@ 2 BPM,190 PSI,Seat ball and pressure up tp 3000 PSI and hold for 15 min.Coot to pressure up in 500 PSI increments to 4000 PSI and bleed pressure to 0 psi.Line up and pressure test annulus to 1500 PSI and hold for 10 min.OK.Bleed pressure to 0 PSI and P/U to verify that HDR running tool has release.OK 13.30 1600 2.50 16.00 COMP K 7 P PJSM.Circ bottoms up @ 10 BPM 750 PSI.Flush mud pumps and displace with 30 BBLS LVT.100 BBLS Citric Acid Spacer followed by 9.0 PPG KCL brine to surface. 16.00 19.30 3.50 19.50 COMP K 4 P PJSM.POOH from 8028'MD to 5600'MD LDDP. 19.30 20.30 1.00 20.50 COMP K 20 P Lubricate rig blocks,top-drive and drawworks. 20-.30 00'00 3.50 24.00 COMP K 4 P Cont.to POOH from 5600'to 1488"MD LD singles. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep 'michael.ross@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.950 L80 8,093.0 14,155.0 12/29/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 940 688.0 12.94 2,513.7 flit* Eni E&P Division (Well Name: SP27-N1 ENI Petroleum Co.Inc. Daily Report l Well Code:26116 Field Name:Nikaitchuq � API/UWI:50-629-23458-00-00 2 II^ Date:12/30/2011 - Report#: 1 II II n - page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40/7 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING _ DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 COMPLETION 12/2/2011 14.019.6 3.733.1 28.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 14,155.0 0.0 110.0 -19.7 Clear,WC-42.6° 157`SSE @ 10 mph Daily summary operation 24h Summary Finish LD/DP.Cut&slip drlg.line.RU to run tbg. Operation at 07.00 Running 4.5"H563 tubing. 24h Forecast Complete running tubing string and land on hanger. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 COMP K 4 P POOH LDDP 01 00 01:30 0.50 1.50 COMP K 4 P L/D Baker packer running tool. 01 30 02:00 0.50 2.00 COMP K 20 P Clean rig floor. 02.00 03.30 1.50 3.50 COMP K 4 P RIH w/37 stds 5"drill pipe from derrick. 03.30 05:00 1.50 5.00 COMP K 20 P PJSM Cut and slip drig line. 05.00 08:00 3.00 8.00 COMP K 4 P POOH LDDP Total of 111 jts. 08.00 08:30 0.50 8.50 COMP K 20 P Clean rig floor. 08.30 09:00 0.50 9.00 COMP K 19 -P Pull wear bushing. 09.00 12:00 3.00 12.00 COMP K 20 P PJSM,Mobilize Centrilift equipment to rig floor and hang sheaves. 12:00 15:30 3.50 15.50 COMP K 20 P Cont.to position sheaves and string up ESP and chemical injection lines. 1530 16:30 1.00 16.50 COMP K 20 P PJSM.P/U&M/U completion as per Centnliff,TIC XO/screen intake/1 jt of 4.5"tbg/pressure discharge sub.Well is static. 16.30 18:30 2.00 18.50 COMP K 4 P PJSM.P/U slick line equipment for M/U and set pump assy/Tbg packoff/Test plug.Prep.to test and test pack-off to 1000 psi for 15 min.Good.Bleed off pressure and pull test plug and install tubing stop. 18:30 19:00 0.50 19.00 COMP K 20 P R/D slick line. 19:00 21:30 2.50 21.50 COMP K 20 P P/U&M/U motor/seal assy./service. Check for rotation,fill and purge with oil,hookup ESP line. 21:30 00.00 2.50 24,00 COMP K 20 P PJSM.Connect 1/4"TEC line/MLE/connect 1/4"Tec to PDS and RIH to 110'MD Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross .ENI Co Rep michael.ross@enipetroleum.com .907-685-0715 Eni representative Russ Wimmer ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher hg15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(MB) Run Date LINER 51/2 4.950 L80 8.093.0 14.155.0 12/29/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8.245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2.513.7 1"1* Eni E&P Division (Well Name:SP27-N1 ENI Petroleum Co.Inc. Daily Report Wen Code:26116 Field Name:Nikaitchuq • 2 n Date:12/31/2011 - Report#: 2 APIIUWI 50-629-23458-g0-00 " II II page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(V.) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40/7 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 COMPLETION 12/2/2011 14,019.6 3.733.1 29.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 14,155.0 0.0 109.0 -31.0 Clear,WC-34' 118'ESE @ 4 mph Daily summary operation 24h Summary Complete running tubing string and land on hanger. Operation at 07.00 Test tree to 5000 psi. 24h Forecast ND stack 8 NU tree and test.Shear out valve in upper GLM and displace tbg and annulus to diesel.RU wire line and RIH and install new STS-1 shear valve in upper GLM.RD wire line and secure well. Prep for rig move. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 i 06:30 i 6.50 6.50 COMP K 4 P PJSM.M/U and secure motor splice as per Centdift. Perform tests on ESP and Cap tube lines. 06-30 '20:30 - 14.00 20.50 COMP K 4 P .PJSM.MU and run 4.5"tbg with ESP 8 Cap line to 7494'.PU-132K,SO-105K.Centrilift test lines every 1000'.Ran a total of 123 clamps. 20:30 '0000 3.50 24.00 COMP K 4 P 'PJSM.M/U hanger and landing jt.Make final splice of ESP cable to penetrator and test.Complete cap line installation. Land tbg.hanger and test hanger seals to 5000 psi for 10 min. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 f Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Pete Mauinusen Doyon Dnlling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 112 4.950 L80 8,093.0 14,155.0 12/29/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8.245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 f Eni E&P Division (Well Name:SP27-N1 EN!Petroleum Co.Inc. Daily Report Well Code:26116 Field Name: Nikaitchuq PI* • API/UNA:50-629-23458-00-00 2^n Date:1/1/2012 - Report#: 3 'I �I page 1 of 1 Wellbore name: SP27-N1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211139 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.87 40.77 13.10 36.76 31.72 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP27-N1 COMPLETION 12/2/2011 14.019.6 3.733.1 30.23 Daily Information End Depth(ftKB) End Depth(TVD)(f..t Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14.155.0 0.0 108.0 Daily summary operation 24h Summary ND stack&NU tree and test.Shear out valve in upper GLM and displace tbg and annulus to diesel.RU wire line and RIH and install new STS-1 shear valve in upper GLM.RD wire line and secure well. Prep for rig move. Operation at 07.00 Prep to move drill module to SP23-N3. 24h Forecast RD and move rig to Well SP23-N3 Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 30 1.50 1.50 COMP K 20 .P Finish hanger test to 5000 psi.R/D test equip..UD landing jt&set BPV. 01:30 02:30 1.00 2.50 COMP K 20 P Respool ESP and cap line,R/D sheaves&clear floor of Centrilift equip. 02:30 05.30 3.00 5.50 COMP K 20 P PJSM N/D BOP's and equip. 05:30 1230 7.00 12.50 COMP K 20 'P N/U tree,pull BPV and install TWC.Test tree to 5000 psi for 10 min.Pull TWC.Centrilift test lines on penetrator. phase/phase.3.4 OHMS balanced,MEG and commission test. 12:30 14.30 2.00 14.50 COMP K 19 P PSJM shear out valve in Upper GLM and displace tubing and annulus to diesel(160 bbls.) 14:30 18.00 3.50 18.00 COMP K 20 P PJSM R/U Haliburton slick line w/lubricator and pressure test. 18:00 22.00 4.00 22.00 COMP K 19 P RIH with slick line#1 and set slip/stop catcher below upper GLM.#2 Retrieve sheared valve from GLM.#3 install new shear valve STS-1 pinned to 2000 psi in GLM.Pressure test valve to 600 psi.#4 RIH and retrieve slip/stop catcher. 22:00 00.00 2.00 24.00 COMP K 20 P PJSM R/D Halibuton slick line equipment.Install EXPRO swab valve.Release rig @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Co Rep michael.ross@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Co Rep bobby.walls@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Rig Clerk tom.norvig@enipetroleum.com 907-685-0722 229-6100 Tool Push Pete Martinusen Doyon Dnlling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.950 L80 8,093.0 14,155.0 12/29/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,245.0 3,738.86 OBM(FazePro) 9.40 688.0 12.94 2,513.7 a g '5 SiNI�� rr nggR"t� { n1 n_W$n' Mil n Wn 6�gy 2m y 1 pn nN pN pn NCN CN ON OnO �tpfa of J nn �S♦p p♦ pa AAA ap vEE Np�pn np�pn fE�"O J $8888 aaaa W a a6W CCaa Om gal Go 03 W O� OD a, OIQ WOST Q� O�OWN O� rnrn.WW tdofrntoai of WtomW WWWWof ofofofdof 66o46oi ofofofofof ofofofofai 2 a 0 1 Mg! 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CnS 0 Oa. 1.1V1' LL LL U1 lo o 0 e o 0 . n Cu ch g g II 0 4 JJ o 211 -Xz9 21075 cob Scblumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No SP27-N1 Date Dispatched: 17-Jan-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP27-N1 -Logs: 1 2 in MD 1 2inTVD 1 5 in MD 5inTVD Received By: 6Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto@slb.com Hector Echeto Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 1.0* HALLIBURTON en 11• CMI PetiroHeuim Sperry Grilling PACKING LIST Spy Island Drillsite Nikaitchuq SP27-N1 Shipping Date: 1-Jan-2012 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 301 East 92nd Avenue;Suite 2 Anchorage,AK 99501 Anchorage,AK 99515 Attn: Howard Oakland 907-739-1235 SP18)S/V ( Washed and Dried Samples-50' 2,680'to 5,500' Paper envelopes 1 of 5 Washed and Dried Samples-50' 5,500'to 7,900' Paper envelopes 2 of 5 Washed and Dried Samples-50' 7,900'to 10,000' Paper envelopes 3 of 5 Washed and Dried Samples-50' 10,000'to 11,850' Paper envelopes 4 of 5 , Washed and Dried Samples-50' 11,850'to 14,155'TD Paper envelopes 5 of5 15} 7 One(1)Bundle Contains all Five(5)Boxes Notes: Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Andrew Buchanan 907-865-3388 Received by Expediter: f'ThC)A--I . 1L�J Date: i 1 ` .9C/ A„)„U • f3Uch4ho. 60 GNl PPS Jv vv- I W\ Y` 0 IOC ) i J ivt, a\fi 1 . , &l/ - / q n)T- iv("1\ i ' IF t, SEAN PARNELL,GOVERNOR IA 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 Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP27-N1 ENI US Operating Co. Inc. Permit No: 211-139 (revised) Surface Location: 4440.8' FSL, 1420.4' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 1778' FSL, 305' FEL, SEC. 14, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated November 2, 2011. 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, 46.-e— ----- -=---- Daniel T. Seamount, Jr. Chair g.d DATED this L day of December, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) 2_/ / 1•59 (2t? Y i S/6' /#*1E111 Petrolebm __ent . VeC 3800 Centerpoint Drive Suite 300 t;°.Anchorage, x'® Maurizio Grandka 99503 i ���� � � � % • 9t Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com December 15,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: REVISION to SP27-N1 APD 211-139 • Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Revision to Permit to Drill#211-139 regarding the SP27- N1 Production well. After a thorough review of the newly acquired seismic volume along the lateral of the SP27-N1 well,it was determined that there would be a significant area between the well path and a fault that runs adjacent to it that would not be swept by water flood. In order to maximize the sweep efficiency and ultimate recovery of oil in the area it was deemed necessary to move the lateral well path as close to the fault as seismic uncertainty would allow. Currently we are testing BOP's after pulling out the hole to change the bit in the 12-1/4"intermediate hole section. We plan to reach total depth of the intermediate section 12/17/2011. We are submitting a revision to the lateral as it will deviate more that 5 The 8-3/4"production hole ' section is estimated to begin at the earliest 12/19/2011./ Please find attached for the review of the Commission 10-401 and updated directional If you have any questions or require further information,please contact Joseph Longo at 907-865-3323 or Luca Boni at 907-865-3328. Sincerely, Maurizio Grandi Well Operation Project Manager RECEIVED STATE OF ALASKA ALASK, _AL AND GAS CONSERVATION COMMISSIL DEC 2 0 2011 PERMIT TO DRILL - REVISION 20 AAC 25.005 , Kaska Oii &Gas Cons.Commission 1a.Type of Work: lb.Proposed Well Class: Development-Oil E Service- Winj ❑ Single Zone ❑ 1c.Speci* lteoposed for: Drill ❑✓ . Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply 0 Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory 0 Service- WAG ❑ Service-Disp 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket D Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 SP27-N1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 14116 , TVD: 3719 ' Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): l( Surface: 4440.8 FSL 1420.4 FEL S19 T14N R9E UM ADL 391283:3188<-388574 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3505 FSL 990 FEL 24 T14N R8E UM ADL 417493 11/27/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1778 FSL 305 FEL 14 T14N R8E UM 1280 11140'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.87 15.Distance to Nearest Well Open Surface:x- 511489 y- 6053622 Zone- 4 GL Elevation above MSL: 13.1 to Same Pool: OP09-S1 -1241' 16.Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.32 degrees Downhole: 1660 psig Surface: 1257 psig 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight _ Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 _ X-65 Welded 160 36 36 160 160 Pre-Installed 1377 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2629 35 35 2664 2486 LEAD: 1141 sx 10.7 ppg ASL TAIL:236 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 8243 33 33 8276 3747 645 TOTAL sx 645 sx 12.5 ppg DeepCrete 8-3/4" 5.5" 17 L-80 Hydril 521 6040 8076 3705 14116 3718 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface • Intermediate - Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 12/15/2011 22. I hereby certify that the foregoing is true and correct. Contact Joseph Longo at 907-865-3323 Printed Name Maurizio Grandi Title Well Operations Project Manager Signature NA--‘1i1--(---'- ' Phone (907)865-3325 Date 12/15/2011 Commission Use Only Permit to Drill / J 2Ct API Number: iJ Permit Approv See cover letter for other Number: ! ( •.J / 50-tit, :,rC 'C 'Date: 1\ rtA" requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: Y Samples req'd: Yes❑ No[ ', Mud log req'd: Yes ❑ No 117 f� 0 V.! CIA-4J FTD . ,.�.t H2S measures: Yes❑ No[/ Directional svy req'd: Yes ['No ❑ Pj 42-/ 1 411 r/ APPROVED BY THE COMMISSION Z , DATE: ,COMMISSIONER II iG1 N .ap �1� �� Form 10-401(Revised 7/2009) This permit is valid for t e e prove!(20 AAC 25.005(9)) mit in Duplicate nt' / rte r k • • SP27-N1 (P6)Proposal Report Schlumberger -ni (Dot Plan) Report Date: December 14,2011-01:42 PM Survey IDLS Computation: MIMnum Curvet./Ludns4 Client: Eni Petroleum Vertical Section Arlmuth: 312.000°(True North) Field: Nikeitchun able Wall: Structure l Slot: Spy Sp27N1d$11 ��DO�(�°l0 "-Dv ��3]TVD RefTVD erence Datumtion: 53870?d uue MSL Borehole: SP27N1 �IUj'/ Seabed l Ground Elevation: 13.1008 above MSL UWI IAPM: Urtnuvn/5082923453-00 Magnetic Declination: 20.802° Survey Name: SP27N1(P8) Total Field Strength: 57851.732 nT Survey Data: December 12.2011 Magnetic Dip Angie: 81.062° Tort/AND/DOI/ERD Ratio: 258.128°/12004.4918/7.066/3.194 Declination Dab: December 01.2011 Coordinate Reference System: NAD27 Alaska State Plane,Zone 01,US Feet Magnetic Declination Model: BGGM 2011 • Location Lat l Long: N 70.33'27.7711r,,W 149°54'20.75299- North Reference: True Not Location Grid NIE 00: N 0053822.4306US,E 511489.440 8US Grid Convergence Used: 0000° CRS Grid Convergence Angle: 0.08886174° Total Corr Map NorlhaTrw 20.802• North: Grid Scale Factor: 0.09990015 local Coord Referenced To: Wall Heed MD led Aalm True TVDSS ND VBEC NS EW TF DLS Directional Exclusion Zone Eeclabn oe Northing ErWp ComT°Me (5) (1 () (a) (5) IM (N (A) (-) ('110011)DMlrity index Alert /°1 (8U8) (MUS) RTE 0.00 0.00 102.00 -53.87 0.00 0.00 0.00 0.00 162M WA 000 894 8053622.43 511480.44 KOP Cry 15/100 200.00 0.00 182.00 118.13 20000 000 0.00 0.00 16210 000 0.00 894 6053822.43 511499.44 Cly 2/100 30000 1.50 162.00 246.12 290.99 -1.13 -1.24 0.40 102M 1.50 0.29 10.15 8053621.19 511488.85 SV-4 705.71 10.81 162.00 708.63 762.50 44.31 48.70 15.82 NS 2.00 275 18.09 0053573.70 511505.34 SV-3 119050 1823 162.00 1007.33 1121.20 -124.81 -197.06 44.59 HS 1.00 3.43 2570 0053485.45 511594.16 Cry 0.5/100 1385.60 23.21 182.00 1300.23 1384.10 -201.11 -220.85 71.78 HS 2.00 3.74 30.86 8053/0171 511661.54 SV-2 1413.57 23.35 102.00 1325.03 1379.80 -210.00 -231.37 75.18 NS 0.50 3.70 30.80 0053301.20 511564.07 Cry 4/100 1935.50 25.90 162.00 1800.23 1854.10 -390.23 438.43 112.48 93.50 0.50 4.10 33.37 5005318426 5111132.56 SV-1 2020.11 2500 100.74 1870.33 1030.20 -420.93 474.20 151.48 80.55R 4.00 4.18 33.01 0053148.43 511011.04 Ugno Top(1.104) 2378.50 30.17 100.20 210403 2247.00 -527.37 437.30 135.77 500.416 4.00 4.40 30.10 0052985.35 511626.18 1338°Cog 2001.54 98.00 215.00 2490.23 2484.10 -504.40 -774.07 02.50 40.01R 4.00 4.68 4505 0052848.54 511553.13 13343.G509106000 2804.00 37.03 215.81 2432.20 2488.07 -584.58 -775.27 01.03 46.51R 4.00 4.09 45.71 0052847.33 511552.27 UG-2 3057.48 40.01 290.02 2720.13 2774.00 554.23 -06517 -124.14 35..37R 4.00 4.03 5887 8052858.17 511366.81 End Cry 3971.44 80.77 251.37 310835 316022 -299.77 -1340.40 -813.01 HS 4.00 5.41 56.51 6052280.80 51064787 L Upon 5228.83 80.77 251.37 330703 3301.80 338.96 -1730.91 -2020.04 HS 0.00 5.72 60.51 6051882.59 500472.31 Cry 3/100 5488.50 80.77 251.37 3349.58 3403.43 464.07 -1818.79 -2262.92 00.008 000 5.77 80.51 8051800.32 500220.57 Nik_Wipe_dle 5805.44 80.80 201.00 3400.43 3454.30 640.24 -1893.90 -2580.34 80.16 3.00 080 86.51 8051725.20 50802590 Fault B 6484.52 81.00 281.00 3504.93 3558.80 1140.32 -1878.08 -3233.55 85.038 3.00 0.04 83.21 0051799.59 508259.19 N Seg Top 0034.17 82.03 280.12 3526.13 9580.00 1278.02 -1842.60 -3377.34 85.29R 3.00 6.08 82.85 0051774.79 508115.90 N Top 0002.15 82.77 204.20 3591.69 301560 1523.27 -1751.11 -3828.47 84.226 3.00 0.14 82.39 8051865.87 50780009 N Bottom 7252.91 83.04 304.73 .3002.33 3050.20 1802.87 -1570.97 -3020.35 83R 3.00 521 81.87 6052038.53 507502.04 End Cm 7526.37 8500 312.00 3628.72 9682.59 2134.10 -1409.50 411124 HS 3.00 6.27 81.70 8052205.85 507350.81 • F-All 7650.50 8500 312.00 3040.33 3094.20 2207.07 -1389.18 4298.44 NS 0.00 529 81.70 6051100.82 50725948 04 Sand Top 8170.14 85.00 312.00 9084.89 3738.70 2775.05 -072.04 4011.04 HS 0.00 0.95 81.70 0052141.44 508880.38 SINI heel 8226.37 85.00 312.00 3080.73 3743.60 2831.65 -034.81 4852.07 65 0.00 6.38 81.70 8052680.50 506839.30 0-541.Gag 8270.37 8500 312.00 3694.09 3747.08 2881.45 40001 4089.58 HS 0.00 6.98 01.70 005271435 500802.70 18-191 8276.37 85.00 312.00 369109 3747.96 2881.48 -000.00 4888.58 HS 0.00 6.38 8170 6052714.35 50680276 Cry 2.75/100 8296.37 8500 312.90 3695.83 3749.70 280138 -88734 4703.18 17.631- 0.00 6.36 81.70 8052727.89 508758.15 • 8300.00 85.10 312.87 3898.14 3750.01 2005.00 884,88 4705.80 17.53L 2.75 8.38 81.80 6052730.34 506785.40 8400.00 87.72 912.04 370241 3756.28 3004.79 -81752 477913 17.481- 2.75 6,38 8451 8052797.59 506711.77 8600.00 9034 31122 3704.11 3757.98 3104.78 -751.10 -1854.16 17.47L 2.75 640 6723 005288388 506638.94 • 8000.00 9296 310.39 3701.22 3755.09 3204.89 885.79 -492982 17491- 2.75 8.42 89.94 8052929.06 5065561.10 End Cry 8813.83 93.32 310.28 3700.47 3754.34 321829 876.98 491020 HS 2.75 6.42 8989 0052937.85 506550.80 Qv 2.5/100 8670.57 93.32 310.28 3897.18 3751.05 3275.11 440.24 4983.56 17321L 000 6.43 89.89 6052974.53 508507.38 8700.00 92.59 310.19 3895.56 3749.53 3304.49 821.25 -5006.00 173321 250 6.43 8980 605299348 50648492 51441 Tot 8761.08 91.00 910.00 3893.85 3747.52 3388.50 -580.00 -5055.00 109.501. 2.50 6.45 8806 8053034.65 506435.86 8800.00 90.70 309.15 3893.12 3748.09 3404.38 557.12 -5082.118 10981L 250 6.45 8788 6053057.48 506408.15 • 8000.00 89.88 306.80 3892.63 3746.60 3504.12 405.59 -5181.50 109.62L 2.50 6.47 87.40 805311088 506329.24 0000.00 89.02 304.44 3893.81 3747.48 300349 437.38 -5242.78 109.591 2.50 0.49 8803 8053176.99 50624788 End Cry 901515 88.89 304.00 3693.90 3747.77 3819.49 428.27 -5258.12 HS 2.50 8.49 8685 8053186.05 506234.52 9100.00 88.89 304.06 3895.53 3719.40 3702.52 381.31 -5325.57 HS 0.00 8.00 8885 0053232.90 506105.01 Cry 2/100 0194.02 88.89 304.06 3697.36 3761.23 3795.63 32888 -5103.45 60.088 0.00 8.51 8685 805328542 506087.06 0200.00 88.91 304.17 3697.48 3751.35 3801.55 325.31 -5405.40 60.086 2.00 0.51 8890 6053288.77 508082.11 0300.00 89.94 305.90 3698.45 3752.32 3900.50 -207.91 -549027 60.076 2.00 8.52 8782 80533460/ 508000.15 SI-N1 1612 9905.71 90.00 30600 3698.15 • 3752.32 3908.51 -261.54 -5494.92 7127R 2.00 6.53 8786 8053349.40 505985.50 9400.00 90.81 307.79 3697.95 3751.82 4000.39 -207.95 -5570.30 71.28R 2.00 6.54 8799 6053405.86 505920.04 End Cry 9453.28 90.95 30870 369723 3751.10 4053.55 -174.04 -561211 HS 2.00 6.55 88.18 6053435.80 505878.18 9500.00 90.95 308.79 3696.48 3750.33 4100.19 -145.68 -564852 HS 000 6.55 88.18 605346801 505841.73 9800.00 90.95 308.79 3694.81 3748.88 4200.02 -03.03 -5726.45 HS 0.00 6.58 88.18 8053530.53 505783.71 0700.00 90.95 308.79 3693.15 3747.02 4299.85 -20.39 -580438 HS 0.00 6.57 88.18 505353.04 505885.89 Cry 2/100 9767.3 90.95 308.79 3692.03 3745.90 4367.42 22.01 -5857.12 128.18R 0.00 6.68 88.18 805363538 505832.89 9800.00 90.55 300.30 369101 3745.48 4399.69 42.37 -5882.22 128.113R 2.00 8.58 87.71 805365587 505807.76 • SI-N1 1913 984432 90.00 310.00 363140 3745.27 444357 70.05 -591634 77.811. 2.00 0.50 87.07 605368390 505573.80 0000.00 90.24 308.91 3691.29 3745.16 4499.60 106.03 595933 77.811. 2.00 6.80 87.48 W5371921 505530.50 End Cm 8927.93 90.35 30837 3891.14 3745.01 4527.48 123/8 -5981.15 HS 2.00 8.99 87.88 605373682 505508.72 .• 10000.00 90.35 30837 3890.70 3744.57 4599.40 188.21 5037.65 HS 0.00 881 87.86 6053781.28 505452.15 •• 10100.00 90.35 30837 389008 371395 469920 230.27 8118.08 HS 0.00 0.62 87.66 8053813.19 505373.66 10200.00 90.35 30837 3689.47 371331 4799.0 29234 4194.46 HS 0.00 6.99 8706 8053905.13 505295.10 10300.00 90.35 30037 3688.85 3742.72 489879 364.40 8272.87 HS 0.00 6.64 8708 805398707 505216.87 • Cry 2/100 10383.25 0035 308.37 3888.16 374213 1961.92 39386 8322.46 164.891 0.00 0.65 8788 6054005.25 505187.02 • SI-N1 T914 10382.75 90.00 306.20 3865/0 374227 488137 405.71 5337.76 54.746 2.00 6.66 8733 8054018.30 505151.70 10400.00 90.20 308.48 388837 374224 4998.59 418.44 8351.30 54.740 2.00 0.85 8749 6054028.98 505138.15 End Cry 10432.29 90.57 309.01 3688.15 3742.02 503082 436.65 8378.48 HS 2.00 6.68 87.78 80540/9.15 505112.94 10500.00 90.57 30001 3687.48 374115 5098.44 479.27 8429.09 HS 0.00 860 8778 605409188 50508027 10600.00 90.57 309.01 3886.48 3740.35 519830 54221 -6508.79 HS 0.00 0.07 87.78 805415/49 504982.48 10700.00 90.57 309.01 3655.48 373935 5298.16 805.15 5584.49 HS 0.00 8.68 8778 006421731 501901.89 Cm 2/100 10751.56 90.57 309.01 368497 3738.81 5349.64 637.99 -8824.55 117.581 0.00 808 87.78 9954249.69 504861.58 OA Send Top 1076712 00.43 908.73 3884.83 3798.70 536518 047.97 -0030.07 117.58. 2.00 0.89 8708 0054250.44 504852.45 10800.00 00.12 30815 388467 3738.54 539600 66781 8682.42 117.501. 2.00 6.69 8748 6054279.84 504826.87 10900.00 80.20 30838 388518 3739.13 549765 728.38 8742.00 117.599 2.00 6.70 86.81 605/310.25 504747.00 S1N1 Tgt 5 10921.30 89.00 308.00 3685.60 373017 5518.83 740.93 8759.19 156.701- 2.00 8.71 88.57 605435280 504729.80 End Cr. 10988.40 87.77 30547 3887.49 3741.38 558551 780.10 8813.84 HS 200 0.72 85.53 9954391.89 504575.30 11000.00 87.77 305.47 388795 374132 559702 786.83 8823.07 HS 000 6.72 85.53 6054398.80 504685.85 11100.00 87.77 305.47 3891.84 374571 569630 84481 X04.45 HS 0.00 8.73 85.53 8054458.15 504584.39 Cry 2/100 11182.79 8777 305.47 389429 3718.18 5758.83 881.22 -6955.55 87.181. 0.00 8.73 85.53 6054492.77 504533.24 11200.00 86.05 304.78 3695.65 3749.52 5705.55 002.82 8985.96 67.83- 2.00 0.74 85.91 6054514.12 504502.80 11300.00 88.80 30293 3698.40 3752.27 5994.50 068.30 -7068.97 67.784. 2.00 6.75 ' 9994 6054589.67 504419.71 11400.00 8950 30108 3690.83 3753.70 599297 1011.29 -7153.76 67.78. 2.00 6.711 8707 6054022.52 501334.85 SIN/Tgl6 11458.18 90.00 30000 3700.05 375392 6049.98 1040.85 -7203.87 81.081 2.00 8.77 88.57 995485200 504284.70 11500.00 90.16 208.97 3099.99 3753.86 999081 1081.43 -7240.28 81.081- 2.50 0.78 88.89 605467253 504248.28 11000.00 90.55 206.80 3699.37 375324 6187.72 1107.08 -7328.78 81.1L 2.50 8.79 8986 8054718.91 504159.70 11700.00 90.94 294.03 3898.07 3751.94 6283.46 1150.3 -7419.20 81.131 250 6.80 89.58 805476144 504089.22 11800.00 91.32 291.56 3696.11 3749.98 6377.87 1180.36 -751117 81.181- 2.50 6.82 88.82 605480002 503977.00 11000.00 91.70 280.08 3893.47 374734 6470.78 1224.07 -7005.11 81.241 250 8.83 8806 6054834.58 503883.22 End Cry 11910.41 9176 288.3 369297 3746.84 6485.84 122038 -7620.82 HS 2.50 8.83 8793 605439.86 503887.70 1 12000.00 91.70 23.3 3890.40 374427 6562.57 1254.14 -7899.77 HS 0.00 6.84 87.03 605488650 503788.51 Cry 2.5/100 12005.96 91.76 23.3 388837 374224 6623.11 1277.25 -7762.23 92566 0.00 0.84 8793 6054887.51 503726.03 1 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 2:59 PM Page 1 of 2 • • Exclusion Zone MD Mel Adam True TVDSS TVD VSEL NS EW TF DLS Directional Exclusion Zone Northing Emitting CemmenbIM () ()' (0) IM (0) (0) (6) 1°I (°nooft)0/OEnlh Index cart A"ole 1,1 11n1s) (flus) 1210000 91.73 289.53 3887.33 3741.20 6854.45 128839 -7794.38 92.588 250 6.85 8810 6354898.80 50369386 • 12200.00 9181 292.03 3884.42 3738.29 874783 132385 -7887.83 92.688 2.50 8.86 88.80 6054933.81 503800.37 12300.00 91.49 294.53 3881.71 3735.58 884229 138325 -7979.65 92.720 2.50 887 89.11 6054973.28 503508.50 12400.00 91.37 297.02 387920 3733.07 6938.27 1406.81 -808968 92.798 2.50 8.89 89.61 8055016.59 503418.43 12500,00 91.25 299.52 3878.91 3730.78 703538 145417 5157.70 92.84R 2.50 690 8988 6055063.80 50333032 12800.00 91.13 302.02 3674.83 3728.70 7133.44 150531 5243.60 92.9R 2.50 691 89.38 8055114.80 503244.35 12700.00 91.00 304.52 367298 3726.85 7232.20 1580.15 5327.19 92.94R 2.50 692 88.87 6055169.51 50310069 12800.00 90.87 30701 367135 372522 7331.64 1618.59 5408.32 92.98R 2.50 6.93 88.37 6055227.81 50307948 12900.00 90.74 309.51 3889.95 3723.82 7431.41 1680.50 5488.82 93028 250 695 87.87 6055289.60 503000.89 13000.00 90.61 312.01 3868,77 3722.84 7531.37 174578 5562.56 93.05R 2.50 696 8737 8055354.75 50292508 • 51N1 T919 13079.84 90.50 314.00 366800 372187 7611.19 1800.22 -8820.94 89.540 2.50 6.97 88.98 805540910 502888.60 • 13100.0D 90.50 314.50 388782 3721.69 763134 181429 -863538 89.540 2.50 697 86.91 6355423.15 502852.14 13200.00 90.52 317.00 386893 3720.80 7731.11 1885.92 -870514 89.578 2.50 698 88.58 6355494.86 502782.27 End Cry 13252.17 90.63 318.31 366645 3720.32 7783.03 1924.48 5740.28 05 2.50 8.99 88.41 6355533.18 502747.07 13300.00 90.63 318.31 386600 3719.87 7830.56 1950.19 -877209 445 0.00 6.99 86.41 8055568.82 502715.21 13100.00 %.53 318.31 3885.0] 3718.63 7029.% 2034.88 5838.80 HS 0.00 7.00 88.41 6355643.38 502648.59 Cry 2.5/100 13135.17 %.63 318.31 3664,74 9718.81 798941 2061.13 5882.00 %.268 0.00 ].00 8841 6355689.80 502625.16 1356300 90.38 319.92 3684.22 371809 802923 2110.14 46304.43 95.270 2.50 7.01 86.04 605571854 502582.68 13600.00 90.15 322.41 366375 3717.62 6127.95 2188.03 5967.12 95.29R 2.50 7.02 85.48 805579832 502519.85 SINi 1510(04 13623.63 90.10 323.00 3138370 3717.57 8151.17 2206.83 5981.44 93.07R 2.50 7.02 85.35 6355815.10 502505.50 2.5/100) 13700.00 90.00 324.91 386383 3717.63 8225.88 2268.57 -902838 93.088 2.50 7.03 85.00 8055876.77 502480.47 13800.90 89.88 327.40 3663.76 3717.63 8322.83 2351.82 -9082.07 93.079 2.50 784 84.54 6055959.72 502404.86 End Cry 13875.28 8978 329.28 368400 3717.63 8395.05 2415.63 -9121.57 HS 2.50 7.05 84.21 6058023.71 50236506 • - 13900.00 89.78 32928 3664.10 371797 8418.67 2438.94 -9134.21 HS 0.00 705 84.21 6358044.96 502352.40 14000.00 89.76 329.28 3884.52 3718.39 8514.18 252291 5185.29 HS 0.00 7.06 84.21 6358130.84 502301.19 14100.00 89.78 329.28 38E4.93 3718.80 8809.64 260860 5236.37 HS 0.00 7.07 84.21 6356216.72 502249.98 SI-N1 toe 1 14118.18 69.76 329.28 1 388500 , 3718.87 8625.08 262278 5244.63 0.00 707 84.21 6058230.60 502241.70 Survey Type: Del Plan Survey Error Modal: ISCWSA Revs"'3-D 95.000%Cmrida nce 2.7955 sign. Survey Program: Description MD From MD Two EOU Fn..i Survey Tool Type Borehole/Survey 0.000 40.770 1/100.000 SLBGYRO-MWD-Depth ONY SP27N1/SP27N1(P46) ' 40770 500.000 1/100.000 SLB GYRO-MWD 5727N1/SP27N1(P40) 500.000 2000.000 1/100.000 510_MWDSTD 0727N1/5P27441(P4b) 2000.000 2861.537 1000.000 SLB_MWD0GMAG SP27N1/SP27N1(P4b) 2861.537 4160.000 1000.000 SL6_MWDSTD 5P274411 5P27N1(P46) 4180.000 8276.368 1/100.000 SLB_MWD•GMAGee2 SP27N1/SP27N1(P4b) 8276.386 8278.370 1/100000 5LB_MWDSTD SP27N1/5P27N1(P46) 8276370 14118.164 1/100000 SLBMWD•GMAG"3 5027N1/0P27N1(P8) Legal Description: Na1Mm m Eas0nn 00 Surface: 4440.8 ESL 1420.4 FEL 5191145 R9E UM 6053622.430 511463.440 si-n1 Net 3505 FSL 990 FEL 24 114N R8EUM 8052680.500 506839.300 si-n1 W110(072.5/100): 1383 FSL 41 FEL 14T14N R8EUM 6055815100 502505.500 • ei-n1 be/BHL: 1778 FSL 305 FEL 14 T145 R8EUM 6356230000 502241.700 • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 2:59 PM Page 2 of 2 o . ' n o • 3 i E K k i k 3 ■ § CO § ■ I �• ! UM o - •, o co tc . co CID ! N | . N ! = }) § , .. Cal -0 /' N # w § T (a k . ;;, \ § 4. 3 S \ — — CD CD / II k;c . S'§ ct ;Iv ) E//® )co , i' / »e, | / ! 2 & & Sr II 7 2 0 0 , / k a co [| © k Z .§|k & E ! ,� # \ :! ■ ' U, | 8 .:j ( ) 0 p t > Al ! !: ; § t 0 (t 14 (0• g _ !I z » I & a 2 , = C I k \ C U)0. �§ ) f ) W i- Ai 0 3 F . 0 3 0 0ce) i co§ a n § U«$I.=e'en al Jr' Schlumberger cin u WELL FIELD STRUCTURE SP27-N1(P6) Nikaitchuq Spy Island M.al414 Peremelem Su0b;e L08 5a. NFD27 Meeh Siete Mane.Zane 04.US Feel AU.IMrea® M.el BGGM2011 D4: 81002° Qs December 01.2011 LS: N 703327.771 N l41 g. 6053822.438US G.Com 008886174' SW: 5727 7VDRei Rotary TebIN53.an1 above MSL) Meg Dec'. 20.802• FS: 57851 7n3 L. W 148 54 20.753 Ee5.g: 511488 44 SUS S.Fad 0 08000015 P. SP27NI(PS) Snr!D. December 12,2011 -600 0 600 1200 1800 2400 3000 0 • RTE i i i < <•' 0 KOP Cry 1.5/100 Cry 21100 600 ; ' 600 _.._.._..y..----.._..-.._.._..-.. .G ..-..-..-..-..-..-.._.. .._.._.._.._.._.._.._.._..-.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..-.._.._.._.._.._.._.._.._ y. • -V-3 1200 t t a t t < 1200 _.._.._..y.._.._.._.._.._. V ._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._..—..—.._.._ y. Crvi.5/100 C O c9. 1800 1800 ll _.._.._..y.._.._ V_�..BrvM10g-..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y. c0) t) /n O _.._.._..y.. .._.._. .— y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._ y. gnu Topp(UG-UG.4�� 2400 4) L 2400 13.318"Cog _.._.._.._. G-2 ._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..-.._..- - -.._..- -.._..- -._.- - -.._..- _.._ -.._.._.-..-.._..-.._.._.._.._..- - - -._.._.._. 3000Cry 2.751100 3000 Cry 2.81100 8.5/8"Csg Tie-In End Cie _.._.._..y.._••_••_••_••_••_••_.•_••4••_..-L_••_ .._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..y.._.._.._.._.._..-..-..-..y.._.._.._.._.._.. ... ..y. SI-N7 heel - .._.. _.._.._.._.._.._.._..i.._.._.._.._.._.._.._.._..i..-..---..---..-..-.._..:.._.._.._. .._.._..• .._•. Ntk_ltblue:dte Cry 31100 • 3600 .--.:=::_::=::=ti •moi:• .:a.._..-.-11. .._.._.._..-::=::a::=::_::_::_::_::_::_::_::�::_:::::_::_:: _.._.._.._.._.._.._.._.._.._.._.._..:.._.._.._.._.._.._.._.._..:.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._. E-511. ._.._.._.._.. .._.._.._.•DA Sand Top End Cry SP27-44N1(P4/ SP27-N1(P6 -600 0 600 1200 1800 2400 3000 Vertical Section(ft)Azim=312°Scale=1:600(ft) Origin=0 N/-S,0 E/-V • \ 0§ § n« 0 CD CD LO — M E= 8 • a, oo . 2 3 .. % 3 ®! •! 2 §! t E >1 E - a ; ■ a Li ;§ . I!!— \ A '''\ „- A i iir. w i « 7 > o |,; 8 2§ $ § || 9 ! . , E €f § 2 § o ' ) ^ I v a� 2 co .OS }\ e :• e V |�, $ . . \ a & . $ | !�! e - ` W ! tf, - | ; . K © ;w It . a a s| t l8 in -A: | 4' f !B ! > e § CO u O `go 8 k 1. .... ....!.Ao z ' 2°® £ rs. ! §_| a ,; r ! § ) & ,= V| , K £ k X' W i 2 ' � \ / o 0st 0 0 § «« N WOOS l.:l.=m©S S »» 'Pik Schiumberger enn WELL SP27-N1 (P6) P'EL° Nikaitchuq S1R0°—Spy Island U4g]4l:Parema 8,, Sudxe Loralion NAD20 Mee.StM.PM.Zone 04,US Feet Mlac4laneom Model: DGGM 2011 Dip. 81002° Dale. December 01,2011 Let. N 703327.771 Na1M,'. 0053822.43BUS God Com:0.08889174° Slot'. SPI] ND Ref. Rotary Teda153.0711 above MSL) Meg Dec'.20.802° FS'. 578511n1 Lan: W 1495420.753 Fasting. 51148944 MUS Scala Feet 080890015 Plan: SP2J.NI(PS) SoN Date:December 12.2011 S114-N6(P2) S108-FN6 (P2) 11 S113-FN4 (P2) SP05-FN7(P2) S119-FN2(P2) SP16-FN3(P3) SP10-FN5(P2) SP11-N7(P2) -100F0 -8000 -60004002 2000 0 2000 1 1 1 1 1 1 111 iiii ' • " I ii ' ii i I ' , , , I ' oil I I " - - ,< -18- 5 fie • - ksvey 6000 - P23-N3(P5 4" �' 6000 • • n • SP22-FN1 (P2) o• o ' 0- '• H gyp• tv SI25-N2(P• °M ,�` , y,� ft.- 4000 a� I$��E ( ) ��, `^�, q :ice, - 6 P2 SP27-N1 (P6) "' "' - n g4N. °•1-6 ,j `'PO4-SE5(P2) A q ` A 2000 f • ''' TDp`•�� SP30-V31 (P2) -c'° •e4, -1:';').^16..:' , . ( ) o - 0 • . .;�1 �:4 g .� .I07-SE4 (P2) o :5 -W2(P2) .c`°• .� , �,o Nt, �p.�, ••,; •i�1 c •••� II 0 - �:• . ., ; ti' e'4,-.,..;•';'‘,*;;-' J f � 0 Tu : '�� °py ^�c`°•�o• cj9• • .co ,; I,�'j%..b,0 4PB1 (P1)`P12-SE3(P2) co 33-W3(P2) �,� ,� •., ..•I f $�vs ^tib •i VD (J) - Nil.- •}454'N• • '�Iw•,• ii 000 ND Ilh v -2000 \ :__� I .:Pt• ° 2000 ^~ •�� .. 5-W4(P2) •a� ( ) ` ° 17-SE2 P2 191 x8019 T`1�y .11 �- G Oa ' /'am^ � •: . 1111 .0 • • '36-W5(P' � qLS '24-SE 1 (P2) -4000 - - , -a000 - �.± q,, if .' 1. 13-03 P• 4i.," o ,c'°• • 4e ��^�,,q' �°• s• " • h h �� q -6000 • A' h i, 6000 • • I ' ' ' . �, �y f• I3'-O (P'4) ' ' ' ' h,' �� I ��ory 10000 00 -6000 �� r 4 00 -200 0 2000 <<< W Scale 1:2000(ft) E ►> OP14-S3 0113-03(P2) 0115-S4 (P5) S129-S2 (P3) 0113-03(P5) 0113-03(P6) OP10-09 0113-03(P3) 0113-03(P2) Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell, Suite 400 Anchorage,AK 99503 Tel (907)273-1766 Fax(907)561-8367 Friday December 14, 2011 Joe Longo, Luca Borri, Spy Island SP27-N1 (P6) ENI Petroleum Doyon 15 Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the Schlumberger close approach anti-collision standards(S002 v5.2). Method of analysis: 1. A list of wells to be analyzed is created in SLB DOX drilling software. The list is created using in house procedures by evaluating the surface location of the subject well and scanning the AOGCC database list of all wells in the area. Wells are then loaded into the database using in house and AOGCC records. 2. Wells are analyzed using the SLB DOX Anti-collision module with major risk safety factors applied. Wells failing the surface anti-collision allowable deviation rule and/or wells having an oriented separation factor (OSF) less than 1.5 are noted as failing either minor or major risk criteria. Further analysis of those wells is subject to Schlumberger's exemption process. 3. All depths are relative to the planned well profile. Survey Program: Description MD From MD To EOU Freq Survey Tool Type Borehole I Survey Inl th) (h) 0 000 40 770 1/100 000 SLB_GYRO-MWD-Depth Only SP27-N1/SP27-N1(P4b) 40 770 500 000 1/100 000 SLB GYRO-MWD SP27-N1/SP27-N1(P4b) 500 000 2000 000 1/100.000 SLB MWD-STD SP27-N1 1 SP27-N1(P4b) 2000 000 2664 000 1/100 000 SLB MWD+GMAG SP27-N1/SP27-N1(P4b) 2664 000 4160 000 1/100.000 SLB MWD-STD SP27-N1/SP27-N1(P4b) 4160 000 8276 366 1/100 000 SLB MWD+GMAG^"2 SP27-N1/SP27-N1(P4b) 8276 366 8276 370 1/100 000 SLB_MWDSTD SP27-N1 I SP27-N1(P4b) 8276 370 14116 164 1/100.000 SLB_MWD+GMAG'3 SP27-N1/SP27-N1(P6) Survey Interval Surface hole—1 per stand —93 ft Intermediate hole—93 ft Final hole— 1 per stand — 93 ft Close Approach Analysis results: Under method (2), note: All wells pass major. Note that there is only one (disposal well) well drilled on this project. There may be magnetic interference below the rig and around the conductor, so a single shot is planned to be run for 500', or as necessary. A Traveling Cylinder with tolerance lines, referencing the planned wells, will be drawn up. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A traveling cylinder will be provided. Checked by: Crispin Chatar 14/Dec/2011 r< Wimikerger 111r#41 SP27-N1 (P6) Anti-Collision Summary Report eni Analysis Date-24hr Time: December 14,2011-16:04 Analysis Method: 3D Least Distance Client: Eni Petroleum Reference Trajectory: SP27-N1(P6)(Def Plan) Field: Nikaitchuq Depth interval: Every 10.00 Measured Depth(ft) Structure: Spy Island Rule Set: DAM AntiCollision Standard S002 v5.1/5.2 Slot: SP27 Min Pts: All local minima indicated. Well: SP27-N1 Borehole: SP27-N1 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 5125-N2(P2)(Def Plan) Warning Alert 10.02 1479 2.96 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 16.02 1405 2.96 N/A 19000 19000 MinPts 16.6 13.52 3.54 N/A 390.00 389.91 MINPT-O-EOU 1808 12.83 5.02 N/A 480.00 479.66 MINPT-O-EOU 48.14 42.61 35.08 N/A 860.00 854.81 CtCt<=15m>15.00 Exit Alen 21843 209.29 205.3 MEM 1610.00 155947 MinPt-O-SF 317.65 291.47 278.8 MBES 449000 3243.35 MinPt-OSF 1 28303125782 24525 11.26 475000 3285.04 MinPt-CtCt 28456 257.331 244.20 10.80 4780.00 3289.85 MINPT-O-EOU 286.17 257.5 243.79 10.33 4810.00 3294.65 MinPt-O-ADP 376.64 326.85 302 44 7.701 5190.00 3355.58 MinP1-0-SF 975.3 877.36 82885 10.04 8030.00 3726.49 MinPt-ClCt 975.56 877.06 828.30 9.99 8080.00 373084 MINPT-O-EOU 975.93 8771 82822 9.97 8110.00 3733.46 MinP1-0-ADP 981.28 88087 831.16 9.86 8276.37 3747.96 MinPt-OSF 1043.63 933.27 878.58 953 8910.00 3746.53 MinPt-O-SF 1392.60 1235.67 1157.69 8.92 11210.00 3749.85 MinP1-0SF 1 1831.07 1608.341 149747 8.25 14116.16 371887 MinPts S129-52(P3)(Def Plan) Warning Alert 16.02 14.80 2.96 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 16.02 14.07 2.96 N/A 190.00 190.00 MinPle 16.03 13.99 297 N/A 210.00 21000 MINPT-O-EOU 46.86 42.36 33.80 N/A 520.00 519.48 CtCt<=15m>15.00 Exit Alert 757.29 748.17 74422 95.7 1670.00 1614.07 MinPt-O-SF 916.05 806.17 751.73 8.40 6840.00 3607.58 MinPI-O-SF 87541 770.92 719.16 8 7190.00 3649.44 MinPt-O-SF 874.72 770.361 718.68 845 723000 3653.77 MinPts I 874.68 77037 718.71 8.46 7240.00 3654.83 MinPt-CtCt 562.81 503.88 474.91 9.70 8610.00 3754.55 MinPt-CtCt 563.04 503.691 4745141 9.63 8630.00 3753.40 MinPts 573.34 511.88 481.69.461 8730.00 3748.37 MinPl-OSF 5376.40 5296.95 5257.72 68.51 14116.16 371887 TD SP30-W 1(P2)(Det Plan) Warning Alert 2399 2277 4.55 N/A 0.00 0.00 CICt<=15m<15.00 Enter Alert 23.99 21.96 4.55 N/A 200.00 200.00 MinPts 25.28 18.60 5.84 N/A 600.00 598.93 MINPT-O-EOU 48.06 29.57 20.r.Emma 1935.50 1854.10 MinPt-O-SF 70.99 55.89 4884 4.96 3000.00 273559 OSF>5.00 Exit Alert 127.04 100.77 88.13 4.98 3810.00 3126.35 05F<5.00 Enter Alert 15556 121.14 104.4.EMI 4090.00 3179.23 MinPt-O-SF 158.82 123.69 106.6,limn 4120.00 3184.04 MinPt-O-SF 373.03 297.38 26004 4.98 5800.00 3453.43 OSF>5.00 Exit Alert 1019.47 933.6 12.00 8276.37 3747.96 MinPt-O-ADP 754.16 601.73 526.01 4.97 11750.00 3751.04 OSF<5.00 Enter Alert 1 464.351 28406 19441 258 12970.00 3722.97 Min%-CtCt 464.9 283.491 193.24 2.57 13020.00 3722.43 MINPT-O-EOU 465.89 283.6',71 193 2.57 13050.00 3722.14 MinPt-O-ADP 468.88 285.22 193.88 2.561 13110.00 3721.61 MinPt-O-SF 676.47 469.24 366.13 3.28 14116.16 3718.87 TD SP24-SE1(P2)(Def Plan) Warning Alert 39.13 37.90 7.58 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 32.46 27.10 0.92 N/A 460.00 459.73 MinPts 3292 26.88 137 N/A 480.00 479.66 MINPT-O-EOU 47.17 39.69 15.63 N/A 580.00 579.09 CtCt<=15m>15.00 Exit Alert 1259.21 1221.04 1202.:1MEIM 3110.00 2807.65 MinPt-O-SE 1 935.61 899.59 882.04 26.64 3840.00 3133.84 MinPt-CtCt 936.211 898.89 880.73 25.74 387000 3140.79 MINPT-O-EOU 937.24 899.0 880A 25.18 3890.00 3145.12 MinPt-O-ADP 1119.02 1058.30 1028.43 18.721 448000 3241.75 MinPt-O-SF 7473.16 7416.12 7388.09 133.29 14116.16 3718.87 TD SP22-FN7(P2)(Def Plan) Warning Alert 55.16 53.94 22.36 N/A 000 0.00 Surface 48.77 44.54 15.96 N/A 43000 429.82 ClCt<=15m<15.00 Enter Alert Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 1 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 46.98 40.93 14.17 N/A 500.00 499.57 MlnPts 47.07 40.83 14.26 N/A 510.00 509.53 MINPT-0-EOU 48.77 41.84 15.96 N/A 550.00 549.30 CtCt<=15m>15.00 Exit Alert I 2144 7 1963.53 1873.40 11.89 11810.00 3749.74 MinPt-CtCt 2145.3 1962.90 1872.16 11.82 11880.00 3748.47 MINPT-O-EOU 2146.26 1963.05 1871 911.77 11890.00 3747.63 MinPI.O-ADP I 1489.99 1258 37 1143.05 6.461 14116.16 3718.87 MinPts SP23-N3(P5)(Def Plan) Warning Alert 47.07 45.85 14.26 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 47.07 45.10 14.26 N/A 190.00 190.00 MinPts 47.67 41.15 14.86 N/A 600.00 598.93 MINPT-O-EOU 49.20 41.99 16.39 N/A 890.00 884.04 CtCt<=15m>15.00 Exit Alert 77.48 60.87 44.67 N/A 2120.00 2019.84 OSF<5.00 Enter Alert =11E. 56.5'MEM N/A 2260.00 2144.35 MinPts 75.7' Z.130 42.93 N/A 2290.00 2170.75 MINPT-0-EOU 103.21 80.90 70.36 2520.00 2368.31 MinP1-0SF 105.65 83.30 72.73 4.94 2530.00 2376.65 OSF>5.00 Exit Alert 355.69 332.47 321.3 mmicg 3620.00 3066.47 MinPt-O-SF 703.41 674.30 860.24 24 98 4790.00 3291.45 MinP1-0SF 1826.26 1770.38 1742.94® 6510.00 3562.47 MInPt-OSF 1840.35 1784.04 1756.38® 6540.00 3566.76 MinPt-O-SF 2647.18 2511.89 2444.7,MIKE 11700.00 3751.94 MinPt-0SF 2685.72 2548.61 2480. •11.1111M1 11800.00 3749.98 MinP1-0-SF may.MEE MEM MECO 14116.16 3718.87 MinPts S132-W2(P2)(Def Plan) Warning Alert ,. 47.94 46.71 15.13 N/A 0.00 0.00 CICt<=15m<15.00 Enter Alert 47.94 45.91 15.13 N/A 200.00 200.00 MinPts 48.01 45.88 15.20 N/A 280.00 279.99 MINPT-O-EOU 49.21 43.17 16.40 N/A 490.00 489.62 CtCt<=15m>15.00 Exit Alert 49.71 16.90 N/A 520.00 519.48 MINPT-O-EOU 1436.18 1354.83 1314 35]1314 351MBETI 6160.00 3510.18 MInPt-OSF I2194.71 2113.49 2073.38 27.34 7460.00 3676.65 MinPt-CtCt 2195. 2112.811Y1 2072.21 26.96 7510.00 3881.16 MINPT-0-EOU 2221.03 2119.76! 2069.621 22.14 8276.37 3747.96 MinPt-O-ADP 1665. 1467.96 1369.70 8.47 12970.00 3722.97 MinPtCtCt 1666. 1467.401 1368.54 8.42 13020.00 3722.43 MINPT-O-EOU 1666.99 1467.5 1368.38 8.40 13050.00 3722.14 MinPt-O-ADP 1730.53 1518.30 1412.68 8.191 13590.00 3717.65 MinPt-O-SF 1877.40 1653.24 1541.65 8.41 14116.16 3718.87 TD OP09-S1(Def Survey) Warning Alert 4892.21 4734.40 4656.85 31.52 0.00 0.00 Surface 4610.77 4445.62 4364.41','. _ 36000 359.95 MinPt-O-SF 3404.7'MgelfflI 3140.36.I�'•.:r: 1890.00 1813.16 MinPts 916.58 728.11 636.62 4.98 4850.00 3301.07 OSF<5.00 Enter Alert 501.31 357.01 286.3 EE 5540.00 3411.69 MinPt-O-SF 398.39 283.52 226.58 3.49 6030.00 3489.93 MinPt-CtCt 408. 191.65 83.50 1.89 702000 3629.96 MinPt-CtCt 412.20 186.06 73.48 1.83 7080.00 3637.03 MINPT-O-EOU 413.42 186.25 73.15 1.82 7090.00 3838.19 MinPt-O-ADP 414.84 186.75 73.20 1.821 7100.00 3639.34 MinPt-O-SF 800.92 636.55 556.56 4.98 7780.00 3704.70 OSF>5.00 Exit Alert 6964.23 6865.67 6818.71 74.10 14118.16 3718.87 . TD SP33-W3(P2)(Def Plan) Paas 56 03 54.80 23.22 N/A 0.00 0.00 Surface 56.03 54.06 23.22 N/A 190.00 190.00 MinPts 56.04. 53.99 23.23 WA 220.00 220.00 MINPT-0-EOU 56.69` 54.05 23.89 N/A 350.00 349.96 MINPT-O-EOU 59.52 53.52 26.71 N/A 500.00 49957 MINPT-0-EOU 1334.68 1260.82 1224. •MEM 5880.00 3466.20 MinPt-O-SF I 2875.9 2690.60 2598.45 1560 1297000 3722.97 MinPt-CtCt 2876.661 2689.931 2597.06 15.48 13030.00 3722.33 MINPT-O-EOU 2877.26 2690.081 2596.9 15.45 13050.00 3722.14 MinPt-O-ADP 3085.23 2873.32 2767.86 14.621 14116.16 3718.87 MinPt-O-SF Sx34-N Sand(P2)(Def Plan) ' Pass 64.02 62.80 31.21 N/A 0.00 0.00 Surface 64.02 61.99 31.21 N/A 200.00 200.00 MinPts 64.20 61.75 31.39 N/A 300.00 299.99 MINPT-O-EOU 240.53 223.55 207.72 N/A 3190.00 2857.03 MINPT-O-EOU r 240.50 223.56 207.6 N/A 3200.00 2862.97 MinPts 560.29 538.04 527.41 26.31 3970.00 3159.99 MinPt-O-SF 2950.53 2877.40 2841.33 40.89 7620.00 3690.75 MINPT-O-EOU 2952.54 2877.53 2840.51 39.87 7710.00 3698.60 MINPT-O-EOU 2955.42 2877.55 2839.11 38.43 7830.00 3709.05 MINPT-O-EOU 2957.60 2877.57 2838.04 37.40 7920.00 3716.90 MINPT-O-EOU 2966.19 2878.18 2834.64 34.07 8276.37 3747.96 MINPT-0-EOU 2966.67 2878.26 2834.5 33.92 8296.37 3749.70 MinPt-O-ADP 3024.90 2925.55 2876.38 30 741I 9010.00 3747.66 MinP1-0SF 6178.45 6101.08 6062.86 80.87 14116.16 3718.87 TD 5119-FN2(P2)(Det Plan) Pass 79.13 77.91 46.32 N/A 0.00 0.00 Surface 68.53 61.72 35.72 N/A 540.00 53936 MinPts 68.60 61.61 35.79 N/A 550.00 549.30 MINPT-O-EOU Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 2 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 3101.69 3052.18 3027.91 63.89 5500.00 3405.27 MinPt-O-SF 2918.3 2747.74 266292 1720 11510.00 3753.83 MinPt-CtCt 2918.96 2747.16 2661.76 17.08 11560.00 3753.57 MINPT-O-EOU 2919.84 2747.34 2661.5 17.02 11590.00 3753.33 MinPI-0-ADP I2573.02 234824 2236.3 11.491 14116.16 3718.87 MinPts 5120-N4(P4)(Det Plan) Pass 71.10 69.87 38.29 N/A 0.00 0.00 Surface 71.10 69.13 38.29 N/A 190.00 190.00 MinPts 7117 69.02 38.37 N/A 270.00 270.00 MINPT-O-EOU 7346 6736 40.66 N/A 560.00 559.23 MINPT-O-EOU 3460.19 340980 3385.0. ilig 6210.00 3517.87 MinPt-O-SF 3791.07 3710.53 3670.76 47.64 8510.00 3757.89 MinPt-CtCt 3791.3 3710.26 3670.24 47.35 8560.00 3756.79 MINPT-O-EOU 3791.65 3710.33 3670.16) 47.18 8590.00 3755.59 MinPt-O-ADP 3867.561 3768.46 3719.41 39.41 9850.00 3745.27 MINPT-O-EOU 3868.18 3768.59 37192 39.22 9860.00 3745.22 MinPt-O-ADP I4127.96 3940.32 38469 22.111 14116.16 3718.87 MinPts 5120-N4PB1(P1)(Def Plan) Pass 71.10 69.87 38.29 N/A 0.00 0.00 Surface 71.10 69.13 38.29 N/A 190.00 190.00 MinPts 7117 69.02 38.37 N/A 270.00 270.00 MINPT-O-EOU 7346 67.36 40.66 N/A 560.00 559.23 MINPT-O-EOU 4994.79 4965.82 4951.8 =12M 8276.37 374796 MinPt-O-SF 5541.98 5511.21 5496.3. 186.0 9016.15 3747.77 M1nPt-O-SF 5778.94 5746.88 5731. '•I 9300.00 3752.32 MinPt-O-SF 7152.70 7110.76 7090.2. 174.66 10930.00 3739.63 MinPt-O-SF 7378.26 7335.00 7313.87=ME 11180.00 374681 MinPt-OSF 9151.82 9102.73 9078.6:=EH 13040.00 3722.24 MinPt-O-SF 10013.46 9958.65 9931.7• 186.0 14116.16 3718.87 MinPt-O-SF S135-W4(P2)(Def Plan) Pass i. 72.02 70.79 39.21 N/A 0.00 0.00 Surface 7202 70.05 39.21 N/A 190.00 190.00 MinPts 7202 6998 3922 N/A 210.00 210.00 MINPT-O-EOU 1532.04 1457.19 142026 mum 6240.00 352245 MinPt-OSF I 4021.25 3843.07 3754.47 22.69 12940.00 3723.32 MinPt-CtCt 40220 38424 3753.151 22.51 13000.00 3722.64 MINPT-O-EOU 4022.66 3842.5 3753.041 22.46 13020.00 3722.43 MinPt-O-ADP 4246.23 4040.88 3938701/ 20.771 14116.16 3718.87 MinPt-OSF SP36-W5(P2)(Del Plan) Pass 80.07 78.85 47.27 N/A 0.00 0.00 Surface 80.07 78.11 4727 N/A 190.00 190.00 MinPts 8008 78.04 4727 N/A 210.00 210.00 MINPT-O-EOU 1640.30 1567.03 1530.89 6230.00 3520.93 MinPt-O-SF I4990,88' 4813.25 472492 28.25 12970.00 3722.97 MinPt-CICt 49916'°71 4812.571 4723.533��/ 28.03 13030.00 3722.33 MINPT-O-EOU 4992.23 4812 7 4723A� 27.95 13050.00 3722.14 MinPI-O-ADP 5200.19 499590 48942 25.571 14116.16 3718.87 MinPt-O-SF 5117-SE2(P2)(Def Plan) Pass 103.16 101.94 70.36 N/A 0.00 0.00 Surface 88.83 8084 56.02 N/A 570.00 569.16 MinPts 88.93 80.73 56.12 N/A 580.00 579.09 MINPT-O-EOU I156926 1519.30 1494.81 32.02 3180.00 2851.05 MinPt-CtCt 1569.59 1519.03 1494.25 31.64 3200.00 2862.97 MINPT-O-EOU 1570.35 151921 1494.1 3129 3220.00 287471 MinPt-O-ADP 1651.04 1592.19 156326 28.521 3580.00 3051.20 MinPt-O-SF 8021.38 7961.10 7931.46 135.28 14116.16 3718.87 TD SP18-N5PB1 field survey(Del Survey) Pass I 95.12 93.90 62.32 N/A 0.00 0.00 MinPts 90.73 84.98 57.93 N/A 590.00 589.01 MinPts 90.74 84.87 5793 N/A 600.00 598.93 MINPT-O-EOU t 896.18 873.98 863.371 42.191 3130.00 2820.42 MinPt-O-SF •�.al 4823.08 4774.29 50.42 8410.00 3756.66 MinPt-CtCt 4921.6, r 4774.21 50.39 8430.00 3757.27 MINPT-O-EOU 4921.74 4823.06 50.37 8440.00 3757.51 MinPt-O-ADP 4923.58 4824.58 4775.5:MOE 8540.00 3757.37 MinPt-O-SF 5049.8•NEM 4881 6 45.31 9350.00 3752.21 MinPts 5069.9 M •:�'- '.imecE 9710.00 3746.86 MinPts 6850.72 6738.85 6683.41 61.77 14116.16 3718.87 TD SP18-N5 field survey(Non-Def Survey) Pass I :211:6 93 90 E N/A 0.00 0.00 MinPts MEM 84.98 NMI N/A 590.00 589.01 MinPts 90.74 57.93 N/A 600.00 598.93 MINPT-O-EOU 896.18 873.98 863.37�1 3130.00 2820.42 MinPt-O-SF 4897.44 4794.37 4743.3 �'S 8520.00 3757.77 MinPt-O-SF 4897.1 d'• '+ 48.00 8550.00 3757.11 MinPts �: •,J 4794.19 4743.20 48.02 8560.00 3756.79 MinPi-CtCt 5024.56"°.•-, 4859.9 46.05 9540.00 3749.67 MinPts 5027.1 1.01E113111103131E 44.34 9570.00 3749.17 MinPts 5101.8•Mr==ME 40.13 10320.00 3742.60 MinPts 5114.37:. yl 4907.56 37.26 10650.00 3739.85 MINPT-O-EOU Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 3 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)1 EOU(ft) Dev.(ft)... Fact. MD(ft) I TVD(ft) Alert I Minor I Major 511456 497622 4907.54 3723 10670.00 3739.65 MinP1-0-ADP 5135. 4980.94 4904.18 33.44 11160.00 3748.05 MinPt-CtCt 51355 4980.83 4903.98 33.41 11180.00 3748.81 MINPT-0-EOU 5135.63 4980 86 4903.96 33.39 11190.00 3749.17 MinPt-0-ADP 519726 5038.63 4959.81 32.961 11670.00 3752.40 MinPt-O-SF 547229 5302.17 5217.60 32.35 12460.00 3731.67 MinPts 5491.30 5317.16 5230.58 31.71 12550.00 3729.71 MinPts 1 535857 5153.58 5051.58 26.261 14116.16 3718.87 MinPts SD37-DSP1(Def Survey) Peas 96.70 95.47 63.89 N/A 0.00 0.00 Surface 95.24 92.40 62.44 N/A 33000 329.97 MinPts 95.3 92.25 62.57 N/A 380.00 379.92 MINPT-0-EOU 95.94 92.19 63.14 N/A 440.00 439.80 MINPT-O-EOU • 3859.41 3837.18 3826.61 6800.00 3602.37 MinP1-O-SF 3936.92 3914.34 3903.5.NEM 6920.00 3617.74 MinPt-O-SF 4040.54 4017.39 4006.3 mEEEE 7090.00 3638.19 MinPt-O-SF • 4672.06 4642.38 4628.03 MBE 8276.37 3747.96 MinPt-O-SF 6993.07 6950.17 6929.2. 166.8. 11250.00 3751.06 MinPt-O-SF 9520.10 9464.88 9437.76 wpm 14116.16 3718.87 MinPt-O-SF SP16-FN3(P3)(Def Plan) Pass 111.09 109.86 7828 N/A 0.00 0.00 Surface 99.18 93.98 66.38 N/A 570.00 569.16 MinPts 99.21 93.93 66.40 N/A 580.00 579.09 MINPT-0-EOU 3242.34 3197.54 3175.67 5488.50 3403.43 MinPt-O-SF I 3819.08 3710.97 3657.41 35.64 8960.00 3746.91 MinPt-CtCt • 3819.37 3710.561 3656.64 35.41 9000.00 3747.48 MINPT-O-EOU I 3749.15 3601.54 3528.23 25.56 10890.00 3739.00 MinPt-CtCt 3753.54 3600.46 3524.41 24.67 11130.00 3746.88 MINPT-O-EOU 3755.40 3600.69 35238 24.42 11200.00 3749.52 MinPt-0-ADP 11 3762.271 3540.50 3430.11 17.041 14116.16 3718.87 MinPts 8113-FN4(P2)(Def Plan) Peas 135.07 133.84 10226 N/A 0.00 0.00 Surface 122.89 115.04 90.08 N/A 590.00 589.01 MinPts 12294 114.97 9013 N/A 600.00 598.93 MINPT-O-EOU 3260.08 3219.25 3199.361 5380.00 3386.04 MinPt-O-SF 4223.361 4134.69 4090.84 48.15 8430.00 3757.27 MINPT-O,E0U 4228.04 4135.39 4089.566 46,11 8690.00 3750.00 MinPt-O-ADP 1 4844.851 4634.17 4529.3 23.101 14116.16 3718.87 MinPts 5114-N6(P2)(Def Plan) Pass 127.07 125.84 9426 N/A 0.00 0.00 Surface 127.07 125.10 9426 N/A 190.00 190.00 MinPts 1271 124.9 94.33 N/A 270.00 270.00 MINPT-O-EOU 129.55 123.32 9674 N/A 570.00 569.16 MINPT-O-EOU • 5345.85 5316.64 5302.5 189.3 8276.37 3747.96 MinPt-O-SF 5873.61 5842.93 5828.0 197.7 9016.15 3747.77 MinPt-O-SF 6102.89 6071.01 60555 197. 9300.00 3752.32 MinPt-O-SF 6264.9511 6166.77 6118.17 64.45 9510.00 3750.16 MinPts 6277.54 6173.50 6121.98 60.90 9870.00 3745.25 MinPt-O-ADP • 1 6532.53 6338.92 6242.60 33.911 14116.16 3718.87 MinPts SP12SE3(P2)(Def Plan) Paas 158.21 156.99 125.40 N/A 0.00 0.00 Surface MEMO 13763® N/A 590.00 589.01 MinPts 146.00=I1DEI 113.19 N/A 600.00 598.93 MINPT-O-EOU 2945.21 2907.11 2888.5+ 79.48 4680.00 3273.81 MinPt-O-ADP 3322.56 3276.90 325456 mum5300.00 3373.21 MinPt-O-SF 4239.87 4186.86 4160.8 5n 7260.00 3656.95 MinPt-O-SF 4339.43 4284.88 4258.114° •16 7880.00 3713.41 MinPt-O-SF 4356.09 4301.32 4274.4.1111111:3M 7960.00 3720.38 MinPt-O-SF 4376.47 4321.45 4294.4 80.96 8050.00 3728.23 MinPt-O-SF 4396.04 4340.78 4313.6 80.9: 8130.00 3735.20 MinPt-O-SF 8405.46 8341.45 8309.9 =RH 14116.16 3718.87 MinPt-O-SF SP70.FN5(P2)(Def Plan) Pass 17432 173.09 141.51 N/A 0.00 0.00 Surface 164.83 156.87 13202 N/A 590.00 589.01 MinPts 164.87 156.80 13206 N/A 600.00 598.93 MINPT-O-EOU 3249.40 3214.63 3197.77 96.37 5130.00 3345.96 MinPt-O-SF 3301.40 3266.08 3248.96 96.37 5200.00 3357.18 MinPt-O-SF r 5902.54 5705.421 5607.37 30.10 14116.16 3718.87 MinPts SP11-N7(P2)(Def Plan) Paas • 166.24 165.02 133.43 N/A 0.00 0.00 Surface 166.24 164.27 133.43 N/A 190.00 190.00 MinPts 166.26 164.20 133.45 N/A 220.00 220.00 MINPT-O-EOU 4218.64 4196.40 4185.81 199.21 6310.00 3533.05 MinPt-O-SF 4715.76 469219 4680.94 20956 6920.00 3617.74 MinPt-O-SF 5581.04 5550.84 5536.23 190.9 8276.37 3747.96 MinPt-O-SF 7512.61 7361.9 7287.09 50.18 10880.00 3738.89 MinPts 1 7732 91 7510.0 7399.03 34.841 14116.16 3718.87 MinPts S108-FN6(P2)(Def Plan) , Pap 190.25 189.02 157,44 N/A 0.00 0.00 Surface ( 184.841 178.661 152.031 N/A 620.00 618.75 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 4 of 11 • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 3045.58 3015.95 3001.67 106.60 4840.00 329946 MinPt-O-SF 6821.971 6643.54 6554.81 3844 14116.16 3718.87 MinPts S107-SE4(P2)(Def Plan) Pass 198.21 196 99 16540 N/A 0.00 0.00 Surface 19279 18533 159.98 N/A 540.00 539.36 MinPts 19313 18491 16032 N/A 580.00 579.09 MINPT-O-EOU 3758.17 3726.49 3711.1:MEM 5488.50 3403.43 MinPt-O-SF 4970.33 4914.97 4887.78 :1110 8276.37 3747.96 MinPt-OSF 8317.52 6250.86 8218.01 13435.17 3718.61 MinPt-OSF 8729.84 8659.75 8625.2.=j1ZE 14116.16 3718.87 MinPt-O-SF SP05fN7(P2)(Def Plan) Pass 222.32 221.10 189.51 N/A 0.00 0.00 Surface 218.62 21169 185.81 N/A 530.00 529.42 MinPts 218.89 211.25 18609 N/A 570.00 569.16 MINPT-0-EOU 3465.94 3437.08 3423.1'=Ka 5130.00 3345.96 MinP1-0-SF 3521.44 3492.13 3470.0 =ELE 5200.00 3357.18 MinPt-0SF 5116.06 5061.33 503446 / 8276.37 3747.96 MinPt-0-SF 7636.18 7473.90 7393.25 MMIE 14116.16 3718.87 MinPt-O-SF SP04SE5(P2)(Def Plan) Pass 230.21 228.99 197.40 N/A 0.00 0.00 Surface 228.95 223.88 196.14 N/A 510.00 509.53 MinPts 22933 223.48 19652 N/A 570.00 569.16 MINPT-0-EOU 3121.45 3098.05 3086.8'=ME 4670.00 327221 MinPt-O-SF 3160.07 3136.39 3125.0•fir'- ' 4720.00 3280.23 MinPt-O-SF 5290.59 5244.67 5222.21 m1a5/ 8276.37 3747.96 MinPt-O-SF 5596.06 5544.92 5519.84® 8980.00 3747.16 MinP1-0-SF 6616.29 6559.43 6531.''=-., 10751.56 3738.84 MinPt-O-SF 9105.36 9031.52 8995.08 MEM 14116.16 3718.87 MinPt-0-SF SI02SE8(P2)(Del Plan) Pass 246.19 244.97 213.38 N/A 0.00 0.00 Surface 246.19 24422 213.38 N/A 190.00 190.00 MinPts 246.77 243.63 213.96 N/A 360.00 359.95 MINPT-O-EOU 248 243.72 215.24 N/A 430.00 429.82 MINPT-O-EOU 4480.79 4458.55 4447.9 Man 6110.00 350244 MinPt-O-SF 4664.99 4642.02 4631.06 M-1 6360.00 3540.53 MinPt-O-SF 5629.65 5591.63 5573.11=Hu 8276.37 3747.96 MinPt-0-SF 9656.58 9569.92 9527.09 1P.aai 14116.16 3718.87 MinPt-O-SF SP01SE7(P2)(Def Plan) Pass 254.30 253.08 221.49 N/A 0.00 0.00 Surface 254.07 251.26 22127 N/A 350.00 349.96 MinPts 254.72 250.66 22191 N/A 450.00 449.77 MINPT-0-EOU 5680.14 5645.91 5629.2:E.y 8276.37 3747.96 MinPt-0-SF 7961.00 7911.75 7887.6. 14"' 11600.00 375324 MinPI-0-SF 9959.46 9893.82 9861.49=En 14116.16 3718.87 MinPt-O-SF Kigun 1(Def Survey) Puss 4971.51 4969.59 4938.70 N/A 0.00 0.00 Surface 4971.38 4968.77 4938.5 N/A 170.00 170.00 MinPts 4971.41 4968.63 4938.60 N/A 200.00 200.00 MINPT-O-EOU 1 4971.05 496474 493821 N/A 860.00 854.81 MinPts 4971.30 496449 4938.49 N/A 990.00 980.94 MINPT-O-EOU 4972.02' 4964.25 4939.21 N/A 1160.00 1143.49 MINPT-O-EOU 2014.93 1991.91 1982.0'MO,1/ 5990.00 3483.64 MinPt-0SF 1134.15 1080.36 1055.35 22.60 7350.00 3666.14 MinPt-CtCt 113541 1079.38 1053.22 21.63 7390.00 3670.06 MINPT-0-EOU 1136.88 1079.74 1053.02 21.21 7410.00 3671.98 MinPt-O-ADP 1298.79 1221.49 1184.31 17.431 7900.00 3715.16 MinPt-O-SF 6793.00 6720.93 6685.71 96.39 14116.16 3718.87 TD Kigun 1 PBI(Def Survey) Pass 4971.51 496959 4938.70 N/A 0.00 0.00 Surface MM 4968.7 N/A 170.00 170.00 MinPts 4971.41 4968.6 4938.60 N/A 200.00 200.00 MI81PT-O-EOU MECE112 4964.7.MEER N/A 860.00 854.81 MinPts 4971.3. 4964.4' 493849 N/A 990.00 980.94 MINPT-O-EOU 4972.05 ' 4939.21 N/A 1160.00 1143.49 MINPT-O-EOU MIME 1425.02 1405.16 36.88 7310.00 3662.12 MinPl-CtCt 1468.31 1404.05 35.87 7340.00 3665.15 MINPT-O-EOU 1469.22 1424.64 MIMI 35.23 7360.00 3667.13 MinPt-O-ADP 1741.32 1673.06 1639.96 MOW 8150.00 3736.94 MinPt-O-SF 1825.85 1754.95 1720.36',, 8296.37 3749.70 MinPt-O-SF 683297 6762.22 6727.65 98.81 14116.16 3718.87 TD Tuvaaq ST 1(Def Survey) Pass 4971.51 4969.59 4938.70 N/A 0.00 000 Surface 1.11EFEEE 4968.77 WEME N/A 170.00 170.00 MinPts 4971.41 4968.6 i 4938.60 N/A 200.00 200.00 MINPT-0-EOU -EINE 4964.7• N/A 860.00 854.81 MinPts 4971.3. 4964.4''x. 4938.49 N/A 990.00 980.94 MINPT-0-EOU 4972.0 4964.2 1 4939.21 N/A 1160.00 1143.49 MINPT-0-E0U MICEEI 1436.36 1409.07 27.32 8030.00 3726.49 MinPt-CtCt 1496.49 1434.34 1405.00 25.44 8150.00 3736.94 MINPT-0-EOU 1501.34 1435.52 mama24.02 827000 3747.40 MinPt-O-ADP Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 5 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major 1719.54 1627.72 1583.311 19.33 9810.00 3745.40 MinPt-O-SF 1772.59 1677.74 1631.791 19.261 10030.00 3744.38 MinPt-O-SF 1932.28 1827.48 1776.481 18.911 10690.00 3739.45 MinPt-O-SF 2058.90 1947.67 1893 361 18.93 11140.00 3747.27 MinPt-O-SF 2241.94 2113.89 2051.011 17.81 12370.00 3733.80 MinPt-O-SF 2265.96 2136.32 2072.62 17.77 12480.00 3731.22 MinPt-O-SF 304957 2898.80 2824.24 2044 14116.16 3718.87 TD OP14-S3(Def Survey) Pass 6591.07 6397.30 6301.82 34.50 0.00 0.00 Surface 5823.5 5618.86 NM=MEM 1380.00 1330.54 MinPts 11112130 1916.08 1796.85 9.04 6930.00 3618.99 MinPt-CtCt 2161.77 1915.90 1796.54 9.03 6950.00 3621.46 MINPT-0-EOU 2162.10 1915.96=En 9.02 6970.00 3623.92 MinPt-O-ADP 2171.10 1922.97 1802.51 8.98 7110.00 3640.49 MinPt-OSF 2204.64 1953.33 1831.2;IMO 7310.00 3662.12 MinPt-O-SF 7530.79 7422.21 7370.73 73.08 14116.16 3718.87 TD 0115-54(P5)(Det Plan) Pass 7591.01 7370.83 7262.21 34.93 0.00 0.00 Surface 1 3341.77 305827 2919.51 1202 707000 3635.87 MinPt-CtCt 3342.06 3057.97 2918.92 12.00 7100.00 3639.34 MINPT-0-EOU 3342.51 3058.03 2918.79 11.98 7120.00 3641.63 MinPt-O-ADP 3382.72 3073.77 2932.28 11.861 7350.00 3686.14 MinPt-0SF 7941.26 7816.03 7756.26 66.39 14116.16 3718.87 TD OP10-09(Oaf Survey) Pate 8555.76 8352.47 8252.16 42.64 0.00 0.00 Surface 1 4657.99:14409.48 4288.18 19.18 6840.00 3607.58 MinPt-CtCt 4657. 4409.481 4288.15 19.17 6850.00 3608.86 MinPta 4661.19 4412.34 4290.87 19.161 6940.00 3620.23 MinPt-O-SF 4867.15 4407.01 4279.70 18.31 7010.00 3628.77 MinPts 4689.51 4423.21 4292.79 17.961 7230.00 3653.77 MinPts 4799.68 4528.99 4396.40 18.08 7640.00 3692.49 MinPts 4802.82 4531.82 4399.07 18.0 7650.00 3693.37 MinPt-O-SF 4980.72 4705.74 4571.05 18.4 8170.00 3738.69 MinPt-O-SF 5161.2A 4875.911 4735.99 18.42 8890.00 3750.00 MinPts 5170.11 4884.26 4744.07 18.421 8720.00 3748.71 MinPt-OSF 8291.51 8100.24 8007.45 44.65 14116.16 3718.87 TD 0113-03(P6)(Non-Def Plan) - - Pass 9981.54 974846 9633.02 43.22 0.00 0.00 Surface 6189.79 5912.23 5775.93 22.69 6860.00 3610.15 MinPt-CtCt 6190.04 NE= 5775.36 22.64 6890.00 3613.97 MINPT-O-EOU 6190.48 5912.00® 22.61 6910.00 3616.49 MinP9-O-ADP 6374.1. :!® 21.43 7730.00 3700.34 MinPts 6516.2 6190.5. 602955 20.24 8210.00 3742.17 MinPts 6548.88 6218. 5 6055.00 20.04 8370.00 3754.88 MinPt-O-ADP 8559.3. 6216.76 6047 06, 19.32 8430.00 3757.27 MlnPta MOSE 6084.70 5897.58 17.26 10140.00 3743.71 • MinPt-CtCt 6462.1 6084.6 =IRE 17.26 10160.00 3743.58 MinPta 6463.97 6086.09 5898.83® 10290.00 3742.78 MinPt-O-SF 6543.14 6173.9 wine 17.95 12120.00 3740.60 MinPt-0-ADP 6543..'mmiii 6991.87 17.96 12130.00 3740.30 MINPT-O-EOU 6174.04 5992.13 17.97 12150.00 3739.72 MinPt-CtCt 749277 7152.17 6984.67 22.35 14116.16 371887 TO 0113-03(P3)(Non-Def Plan) Pass 10002.62 979477 9692.37 4883 0.00 0.00 Surface I 6221.12 5995.23 5885.10 28.22 6870.00 3611.43 MinPt-CtCt 6221.1 5995.11 5885.03 28.21 6880.00 3812.70 MINPT-O-EOU • 6221.26 5995.211 5885.01 28.20 6890.00 3613.97 MinPt-O-ADP 6234.15 6006.50 5895.50 28.0 7090.00 3638.19 MinPt-O-SF 8275.42 6046.19 5934.40 28. 7320.00 3663.14 MinPt-O-SF 1 6287.561 5984.63 5835.43 21.06 12820.00 3728.32 MinPts 6287.59 5984.64 5835.43 21.06 12630.00 3728.12 MinPt-O-ADP 6288.33 5985.26 5836.02 21.051 12670.00 3727.38 MinPt-O-SF 6842.57 6541.95 6394.39 23.17 14116.16 3718.87 TD 0113-03(P4)(Non-Def Plan) Pats 1000262 9793.54 9690.52 48.53 0.00 000 Surface ( 6221.12J 5993.90 5883.10 28.05 6870.00 3611.43 MinPt-CtCt 6221.1 5993.83 5883 03 28.04 6880.00 3612.70 MINPT-O-EOU 6221.26 5993.8 5883 001 28.03 8890.00 3613.97 MinPt-O-ADP 6234.15 6005.19 5893 52 27.8 7090.00 3638.19 MinPt-O-SF 6275.42 6044.90 5932 45 27. 7320.00 3663.14 MinPt-O-SF 1_6287.561 5984.27 5834.87 21.03 12620.00 3728.32 MinPta 6287.59 5984.27 5834.87 21.03 12830.00 3728.12 MinPt-O-ADP 6288.66 5985.19 583574 21.02, 12680.00 3727.20 MinPt-O-SF 6842.57 6541.21 6393.26 23.11 14116.16 3718.87 TD 0113-03(P5)(Non-Def Plan) Pass 10004.80 9794.89 9691.41 48.33 0.00 0.00 Surface I 6221.39 5993.79/ 5882.79 28.00 6870.00 3611.43 MinPt-CtCt 6221. 5993.7691 5882.731 27.99 6880.00 3612.70 MINPT-O-EOU 6221.55 5993.7 588227.98"��/� 6890.00 3613.97 MinPt-O-ADP 6235.84 6006.42 5894.51 27.Bq 7100.00 3639.34 MinPt-O-SF 6271.32 6040.56 5927. 27.8 730000 3661.10 MinPt-OSF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 6 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)EOU(ft)., Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6287.7 5985.15 5836.09 21.08 12620.00 3728.32 MinPts 6287.82 5985.15 5836.08 21.08 12630.00 3728.12 MinPt-0-ADP 6288.88 5986.07 5836.95 21.071 12680.00 3727.20 MinPt-O-SF 6842.76 6542.01 6394,37 23.16 14116.16 3718.87 TD 0113-03(P2)(Non-Def Plan) Peas 9982.85 9796.31 970451 54.36 0.00 0.00 Surface 1 6222.80 6013.96 591235 30.59 6860.00 3610.15 MinPt-CtCt 6222.89 6013.82 5912.10 30.56 6880.00 3612.70 MINPT-0-EOU 6223.01 6013.84 5912.06 30.54 6890.00 3613.97 MinPt-0-ADP 6351.93 6134.91 6029.18 30.01 7570.00 3686.39 MinPt-OSF 6609.00 638469 6275.20 30.16 8296.37 3749.70 MinPt-0SF 6898.00 6663.18 6548.35 30.02 9350.00 375221 MinPt-0-SF 9311.73 9111.59 9014.27 47.81 14116.16 3718.87 TD OP12.01(Def Survey) Pass 9716.72 9577,21 950927 7148 0.00 0.00 Surface 7709.23 7567.19 7498.82 56.341 3690.00 3091.00 MinPt-O-SF 6986.25 6865.76 6808.74 61.20 5860.00 3463,01 MinPt-0-ADP 6986.14 6865.76 6808.79 61.26 5870.00 346461 MINPT-0-EOU I 6986.11 6865.82 6808.91 61.31 5880.00 3466.20 MinPt-CtCt 8464.40 8356.06 8304.71 MIIIM 8296.37 374970 MinPt-0-SF 13665.94 13576.14 13532.56 156.76 14116.16 3718.87 TD OP17-02(Def Survey) Paw 1136218 11151.94 11047.58 5443 0.00 0.00 Surface 7678.37 7411.21 7279.53 29.14 6980.00 3625.14 MinPl-CtCI 7678.39 7411.191 7279.49 29.14 6990.00 3626.35 MinPts 7685.19 7417.46 7285.54 29.11 7130.00 3642.76 MinPt-0-SF 865497 838247 8248.46 3228 9900.00 3745.16 MinPI-0-SF 11055.26 10816.67 10699.45 47.14 14116.16 3718.87 TD Nlka9chuq 4(Def Survey) Paw 8243.12 8241.20 8210.31 N/A 0.00 0.00 Surface 8243.0:•= 8210.28 N/A 20.00 20.00 MINPT-O-EOU :6'r, :�, N/A 50.00 50.00 MinPts 8243.1. 8210.31 N/A 80.00 80.00 MINPT-0-EOU 8151.90 810624 8084.3 =ON 560.00 559.23 MinPt-0-SF 7904.00 7857.68 7835.:=MB 1260.00 123763 MinPt-0-SF MEMI 7682.01 7659.88 174.50 2170.00 2064.51 MinPts 7740.78 7694.36 7672.1....M. 2350.00 2223.19 MinPt-0-SF 8292.56 8245.8* jjjjjjjjj3440.00 2990.70 MinPts 8918.73 8870.35 8847.*-Ijjjjjjjj 6 4140.00 3187.24 MinPI-O-SF 10693.21 10640.86 10615.56 1j.* 6040.00 3491.50 MinPt-0-SF 10946.03 10892.41 10866.4:11.131111a 6350.00 3539.04 MinPt-0-SF 11647., 11.=�"' 167.05 7650.00 3693.37 MinPts 11850.69 11776.01 11739.48 NEM 8276.37 3747.96 MinPt-O-SF 12580.12 12505.76 12469.3•=Mg 9810.00 3745.40 MinPt-O-SF 13725.73 13643.49 13603.18.=i 11700.00 3751.94 MinPt-0-SF 15268.84 15173,24 15126.2IP.4•,' 14116,16 3718.87 MinPt-O-SF OP17-02PB1(Def Survey) Paw 11415.02 11202.95 1109767 54.20 0.00 0.00 Surface 1 7731.85 7472.07 7344.18 30.21 6910.00 361649 MinPt-CtCt 7731.89 7472.051 7344.13 30.21 6920.00 3617.74 MinPts 7742.97 748228 7353.97 30.16 7100.00 3639.34 MinPt-OSF i 7905.34 7634.85 7501.64 29.66 7680.00 3695.98 MinPts 7996.91 772244 758721 29.55 7940.00 3718.64 MinPts 8148.3 7861.35 7720.76 28.96 8350.00 3753.72 MinPts 8226.0 7928.53 7781.54 27.97 8600.00 3755.09 MinPts 10718.99 10458.18 10329.86 41.75 14116.16 3718.87 TD 011ktok Point 1-2(Det Survey) Pew 10759.12 10588.70 10504.86 64.15 0.00 0.00 Surface 7922.03 7756.52 7676.48 49.451 5500.00 3405.27 MinPt-0-SF 7802.36 7641.80 756437 50.35 6090.00 3499.32 MinP1-0-ADP 7802.25 7641.77 7564.39 50.38 6100.00 3500.88 MINPT-O-EOU 7802.21 7641.81 7564.47 50.40 6110.00 350244 MinPt-CtCt 13880.12 13762.28 1370473 120.56 14116.16 3718.87 TD Nikaitchuq 3PB1(Def Survey) Paw 7995.16 7993.25 7962.36 N/A 0.00 0.00 Surface 7995.13 7993.22 7962.32 N/A 20.00 20.00 MINPT-0-EOU I7995.13 7993.20 7962.32 N/A 50.00 50.00 MinPts 7941.34 7926.63 7908.53 N/A 2000.00 1912.11 MinPts 12768.03 12738.61 12724.71 459.111 8276.37 3747.96 MinPt-0-SF 1720223 17136.78 17104.87 269.48* 14116.16 3718.87 MinPt-O-SF Nikafchuq 3PB2(Def Survey) Paw 7995.16 7993.25 7962.36 N/A 0.00 0.00 Surface 7995.1 7993.22 7962.32 N/A 20.00 20.00 MINPT-0-EOU I7995.1 7993.201 7962.3N/A 50.00 50.00 MinPts 7941.34 7926.63 7908.53 N/A 2000.00 1912.11 MinPts 12768.03 12738.61 1272471 459.11 8276.37 3747.96 MinP8.O-SF 17202.23 17136.78 17104.87 269.48 14116.16 3718.87 MinPt-O-SF Nikaachuq 3P83(Def Survey) Paw 7995.16 7993.25 7962.36 N/A 0.00 0.00 Surface 7995.1 MagEg 796232 WA 20.00 20.00 MINPT-0-EOU Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 7 of 11 • • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ftj EOU(ft) Dev.(ft), Fact. MD(ft) I TVD(ft) Alert I Minor I Major 7995.13 7993.20\ 7962.3 N/A 50.00 50.00 MinPts 7941.34 7926.63 7908.53 N/A 2000.00 1912.11 MinPts 12788.03 12738.61 12724.71 459.11 8276.37 3747.96 MinPt-O-SF 17202.23 17136.78 17104.87 269.48 14116.16 3718.87 MinPt-O-SF Nikaitchuq 3(Del Survey) Pass 799516 7993.25 7962.36 N/A 0.00 0.00 Surface 7995.13 7993.22 7962.32 N/A 20.00 20.00 MINPT-O-EOU 7995.13 7993.20 7962.32 NSA 50.00 50.00 MinPts 7941.34 7926.63 7908.53 NA 2000.00 1912.11 MinPts 12768.03 12738.61 1272471 459.11 8276.37 3747.96 MinPt-O-SF 17202.23 17136.78 17104.87 269.48 14116.16 3718.87 MinPt-O-SF OPO4-07(Def Survey) Pass 9376.06 9313.39 9284.28 161.00 0.00 0.00 Surface ( 7948.711 7879.60 7847.71 124.52 3110.00 2807.85 MinPt-CtCt 7948.79 7879.541 7847.56 124.23 3130.00 2820.42 MinPts 9085.27 8993.59 8949.45 102.86 5620.00 3424.55 MinPt-O-SF 11557.48 11463.62 11417.521 125.3 8296.37 3749.70 MInPt-OSF 17261.53 17167.57 17121.09 185 66 14116.16 3718.87 TD Nikaitchuq 1(Def Survey) Pass 8127.75 8125.83 8094.94 N/A 0.00 0.00 Surface 8109.87 8097.97 8077.06 N/A 1640.00 1586 78 MinPts 8110.46 8097.40 8077.65 N/A 1760.00 1695.73 MINPT-0-EOU 13073.42 13037.95 13021.*-mum8276.37 3747.96 MinP1-0SF 17188.67 1709478 17058.63® 14118.18 3718.87 MinP*-0SF Nikaitchuq 4PB1(Def Survey) Pass 8243.12 8241.20 8210.31 N/A 0.00 0.00 Surface 8243.09 8241.17 8210.28 N/A 20.00 20.00 MINPT-O-EOU 1 8243.09 8241.15 8210.281 N/A 50.00 50.00 MinPts 8243.12 8241.11 8210.31 N/A 80.00 80.00 MINPT-O-EOU ( 8221.15 8206.68 8188.351 N/A 1978.11 1892.43 MInPts 8221.16 8206.68 8188.35 N/A 1980.00 1894.13 MINPT-0-EOU 13101.72 13072.55 13058.7.MEE 8276.37 3747.96 MinPt-O-SF 17545.92 17480.47 17448.56 warn14118.16 3718.87 MinPt-O-SF OP08-04(Def Survey) Pass 10388.30 10339.42 10317.20 233.65 0.00 0.00 Surface 10374.10 10325.25 10303.0 ®1 40.00 40.00 MinPt-0-SF 9271.55 9224.83 9204.11® 2200.00 2091.22 MinPt-0SF I 8683.35 8638.17 8618.45 220.07 3920.00 3151.16 MinPt-CtCt 8683.39 8638.14 8618.38 219.64 3930.00 3153.05 MINPT-O-EOU 8683.48 8838.15 8618.35 219.20 3940.00 3154.87 MinPt-O-ADP 9598.18 9521.74 9486.83 137.37 6820.00 3604.98 MinPt-O-SF 11010.64 10932.66 10895.5 148.1 8298.37 3749.70 MinPt-O-SF 16648.62 18572.02 16534.22 220.17 14118.16 3718.87 TD 0111-01(Def Survey) Pass 10757.67 10699.96 10673.22 201.11 0.00 0.00 Surface 9385.29 9325.83 9298.7.MIIMME 2700.00 2514.62 MinPt-O-SF I 8828.14 8763.40 8733.93 149.67 5190.00 3355.58 MinPt-CtCt 8828.80 8782.92 8732.97 147.31 5280.00 3370.00 MINPT-O-EOU 8829.42 8783.08 8732.80 145.72 5340.00 3379.82 MinPt-O-ADP 945966 9381.10 9344.42 128.89 6900.00 3615.23 MinPt-0SF 10747.26 10664.24 10624.8 136. 8296.37 3749.70 MinPt-OSF 16237.43 16156.93 16117.28 204.77 14116.18 3718.87 TD 0124-08(P9b)(Def Plan) Pass 12475.72 12253.08 12142.28 56.30 0.00 0.00 Surface ( 8883.18 8615.55 8483.48 33.62 6880.00 3612.70 MinPt-CtCt 8883.51 8615.04 8482.56 33.51 6920.00 3617.74 MINPT-O-EOU 8883.99 8615.10 8482.41 33.46 6940.00 3620.23 MinPt-O-ADP 8963.17 8684.17 8546.40 32.521 7440.00 3874.80 MInPt-OSF 12393.83 12147.19 12025.59 50.95 14116.16 3718.87 TD OPO4-07PB1(Def Survey) 4 10537.66 10486.37 10462.88 224.23 0.00 000 Surface I 913399 9077.42 9051.69 177.39 3260.00 2897.61 MinPt-CtCt 9134.04 9077.39 9051.61 177.09 3270.00 2903.21 MINPT-O-EOU 9134.15 9077.41 9051.59 178.79 3280.00 2908.78 MinPt-O-ADP 10364.95 10279.93 10239.06 126.7 6140.00 3507.09 MinPt-O-SF 12422.20 12335.31 12292.8 146.1 8298.37 374970 MinPt-O-SF 18160.93 18074.25 18031.40 211.91 14116.16 3718.87 TD I 0107-04(Def Survey) Pass 10577.73 10521.19 10494.81 200.43 0.00 0.00 Surface 1 9273.481 9211.59 9182.89 161.47 3060.00 2775.65 MinPts 9273.53 9211.60 9182.88 161.34 3070.00 2782.18 MinPt-O-ADP I 10544.27 1046207 10422.24 132.36 5770.00 3448.63 MinPt-0SF 12910.77 12827.03 12785. 158. 8298.37 3749.70 MinPt-0-SF 18618.70 18533.39 18491.23 220.79 14116.16 3718.87 TD OP18-08(Def Survey) 1 Pass 13693.71 13484.59 1338057 65.81 0.00 0.00 Surface 1 9627.82 9316.18 9161.14 31.04 7360.00 3887.13 MinPt-CtCt 9627.90 9316.05 916090 31.02 7380.00 3689.09 MINPT-0{OU 9626.04 931607 9160.881 31.01 7390.00 3670.06 MinPt-O-ADP Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 8 of 11 • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 9739.11 9418.15 9258 681 30.53 8296.37 3749.70 MInPt-0SF 9803.24 9478.33 9316 961 30.371 8710.00 3749.10 MinPt-OSF 9847.12 9520.68 9358 651 30 381 9130.00 3749.99 MinPt-O-SF 11603.13 11284.95 11127.52 36 84 14118.18 3718.87 TD OP16-08PB2(Def Survey) Pass 13693.71 13484.64 13380.64 65.83 0.00 0.00 Surface 9776.18 9482.68 9337.06 33.56 7130.00 3642.76 MinPt-CtCt 9776.19 9482.83 9336.98 33.55 7140.00 3643.89 MINPT-O-EOU 977627 9482.64 9336.96 33.55 7150.00 3645.01 MinPt-O-ADP 9799.94 9504.77 9358.39 33.471 7410.00 3671.98 MinPt-O-SF 12628.34 12345.91 1220623 45.19 14116.16 3718.87 TD Oliktok Point I-2PB2(Def Survey) Pass 12538.46 12417.49 12358.44 106.13 0.00 0.00 Surface 10640.24 10518.97 10460.4 90.91 3971.44 3160.22 MinPt-O-SF 10233.58 10115.35 10058.63 90.17 5500.00 3405.27 MinPt-O-SF 10204.01 10086.52 10030.20 90.55 5800.00 3453.43 MinPt-O-ADP 10203.991 10086.51 10030.20 90.56 5810.00 3455.03 MinPts 11695.95 11578.46 11521.7.MEE 8296.37 3749.70 MinPt-O-SF 16776.23 16671.43 16619.67 162.02 14116.16 3718.87 TD OP16-03(Def Survey) 14306.28 14105.29 14005.28 71.52 0.00 0.00 Surface 10511.12 10213.49 10065.36 35.48 7290.00 3660.07 MinPt-CtCt 10511.24 10213.421 10065.21 35.46 7310.00 3862.12 MinPts 10666 16 10360.03 10207.89 35.051 8296.37 3749.70 MinPt-OSF 12713.74 12407.02 12254.99 41.81 14116.16 3718.87 TD OP03-P05(Def Survey) • Pass 11756.68 11695.65 11666.70 203.00 0.00 0.00 Surface 10554.111 10487.45 10455.96 167,51 2990.00 2728,77 MinPt-CtCt 10554.14 10487.451 10455.94 167.41 3000.00 2735.59 MinPts 11851.40 11767.47 11726.42 144.34 5720.00 3440.61 MinPt-O-SF 14257.23 14171.19 14128.67 167.6 8296.37 3749.70 MinPt-O-SF 19960.55 19872,76 19829.35 229.93 14116.16 3718.87 TD OP08-04PB1(Def Survey) Pass 12111.82 12083.07 12070. • 0.00 0.00 MinPt-O-SF 12099.68 12070.94 12058.'' 40.00 40.00 MinPt-O-SF 10661.12 10625.55 10610.07 344.17 3620.00 3066.47 MinPt-CtCI 10661.36 10625.33 10609.62 339.11 3650.00 3077.33 MINPT-0-EOU 10661.76 10625.41 10609. 335.79 3670.00 3084.28 MinPt-O-ADP 11866.09 11790.16 11753. 163.12 6820.00 360498 MinPt-O-SF 13300.80 13222.32 13184.21 174. 8296.37 3749.70 MinPt-O-SF 18979.68 18901.25 18882.53 245.07 14116.16 3718.87 TD 0106-05(Def Survey) yt„sg 12000.05 11935.47 11904.33 192.66 0.00 0.00 Surface 10911 10 10843.46 10810.97 167.88 2800.00 2591.80 MinPt-CtCt 10911 11 10843.451 10810.95 167.81 2810.00 2599.34 MlnPts 12375.40 12294.05 12253.87 153.98 5500.00 340527 MinP1-0SF 14963.69 14880.17 14838.91 181.3 8296.37 3749.70 MinPt-O-SF 20571 15 20484.44 20441.58 239.94 14116.16 3718.87 TD 0106-05PB1(Def Survey) Pass 12277.04 12216.86 12187.97 212.43 0.00 0.00 Surface I 11184.901 11122.291 11092.35 186.75 2840.00 2621.74 MinPts 12697.97 12620.33 12582.00 165.62 5670.00 3432.58 MinPt-0-SF 15157.71 15078.07 15038.7 192.6 8296.37 3749.70 MinP1-0SF 20797.68 20714.95 20674.08 254.41 14116.16 3718.87 TD OP05-06(Def Survey) * ^ ' E Pets 12616.54 12558.35 12529.88 221.54 0.00 0.00 Surface 11640.501 11581.01 11551.99 200.56 2680.00 2498.80 MinPts 11640.53 11581.02 11551.99 200.49 2890.00 2506.72 MinPt-O-ADP 13311.57 13238.48 13202.43 184.61 5500.00 3405.27 MinPt-0SF 15901.22 15827.05 15790. 217.2 8296.37 3749.70 MinPt-O-SF 21412.54 21332.97 21293.68 272.47 14116.16 3718.87 TD 0120-07(P14)(Def Plan) Pass 15583.32 15411.92 15326.75 91.48 0.00 0.00 Surface I 11646.57 11237,55 11033.53 28.54 7390.00 3670.06 MinPt-CtCt 11648.67 11237.471 11033.36 28.53 7410.00 3671.98 MinPts 11739.57 11323.33 11115.71 28.27818296.37 3749.70 MinPt-O-SF 11836.88 11416.97 11207.68 28.29220.00 3751.68 MinPt-O-5F 13339.43 12927.26 12/22.26 32.53 14116.16 3718.87 TD Ol11-01PB1(Def Survey) a/, 'I. t3 sr `431,-•A .., Bn:; sr,a• , t -k. .-t../2 ;'Piet 13397.78 1337647 13364.97 N/A 0.00 0.00 Surface 11902.611 11870.36 11856.34 424.49 3850.00 3136.22 MinPt-CtCt 1190291 11889.97 11855.61 414.22 3890.00 3145.12 MINPT-O-EOU 11903.32 11870.03 11855.49 409.26 3910.00 314921 MinP1-0-ADP 13022.14 12948 15 12912.71 183.681 7100.00 3639.34 MinPt-O-SF 14175.36 14098.19 14060.80 189.4 8296.37 3749.70 MinPt-O-SF 19747.89 19669.94 1963146 256.56 14116.16 3718.87 TD OP03-P05PB2(Def Survey) Pass Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 9 of 11 • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 13439.98 13391.41 13368.52 293.43 0.00 0.00 Surface I 12239.31 12186.59 12161.89 247.67 3150.00 2832.81 MinPt-CtCt 12239.32 12186.56 12161.83 247.44 3160.00 2838.93 MINPT-O-EOU 12239.38 12186.57 12161.82 247.20 3170.00 2845.01 MinPt-O-ADP 13727.69 13650.95 13613.32 182.4 8400.00 3546.45 MinPt-O-SF 15567.47 15489.18 15450.53 201.3 8296.37 3749.70 MinPt-O-SF 21307.38 2122830 21189.26 272.84 14116.16 3718.87 TD OP22-WW03(P1)(Def Plan) Pass 14836.89 14790.17 14767.44 326.28 0.00 000 Surface I 12281.87 12224.64 12198.12 231.51 3890.00 3145.12 MinPt-CtCt 12281.95 12224.51 12197.90 230.64 3910.00 3149.21 MINPT-O-EOU 12282.09 12224.55 12197.88 230.20 3920.00 3151.18 MinPt-O-ADP 13239.32 13151.77 13109.76 157.52 7020.00 3629.96 MinPt-O-SF 14324.04 14232.50 14188.41 162.37 8296.37 3749.70 MinPt-O-SF 19662.63 19568.52 19522.25 212 45 14118.16 3718.87 TD OP23-W W 02(Def Survey) Pat 14342.31 14306.08 14289.40 429.89 0.00 0.00 Surface I 12304.57 12261.22 12241.85 317.59 3680.00 3087.67 MinPt-CtCt 12304.63 12261.18 12241.76 318.76 3690.00 3091.00 MINPT-O-EOU 12304.75 12261.20 12241.73 315.92 3700.00 3094.27 MinPt-O-ADP 13553.09 13479.84 13444.77 193.18 6900.00 3615.23 MinP1-0SF 14844.87 14769.43 14732.9 203.3 8296.37 3749.70 MinPt-O-SF 20430.01 20355.32 20318.46 277.16 14116.16 3718.87 TD OP05-06PB2(Del Survey) Pass 13452.38 13398.10 13371.73 25504 0.00 0.00 Surface 12439.87 12386.16 12360.21[ 239.701 2700.00 2514.62 MinPt-O-SF I 12437.80 12384.131 12358.20 239.81 2780.00 2578.63 MinPts 12439.32 12385.67 12359 74 239.8 2850.00 2629.14 MinPt-O-SF 14128.17 14060.99 14027.89 213.42 5800.00 3453.43 MinPt-O-SF 16485.38 16416.93 16383.2 244.3 8296.37 3749.70 MinPt-O-SF 22105.24 22031.58 21995.23 304.11 14116.16 3718.87 TD Oliktok Point I-1A-106(P5)(Def Plan) Pass 13569.63 1339881 1331436 80.33 0.00 0.00 Surface 12655.25 12477.33 12389.33 71.89 2820.00 2450.67 MinPt-CtCt 12655.26 12477.311 12389. 71.88 2830.00 2458.76 MinPte 12679.69 12501.21 12412. 71.7 2890.00 2658.37 MinPt-O-SF 12883.48 12504.95 12416.58 71.7 2910.00 2872.76 MinPt-O-SF 22453.02 22265.95 22173.22 121.06 14116.16 3718.87 TD Oliktok Point I-2PB1(Def Survey) Pass 14770.71 14688.26 14648.23 184.48 0.00 0.00 Surface I 1287030 12780.29 12737.13 149.08 560000 3421.33 MinPt-CtCt 1287030 12780.251 12737.08 149.02 5610.00 3422.94 MinPts 13346.73 13250.65 13204.32 143.98 6900.00 3615.23 MinPt-OSF 14549.97 14449.85 14401.1 149.2 8296.37 3749.70 MinPt-OSF 19762.35 19665.38 19617.38 205.87 14116.16 3718.87 TD OP26-DSPO2(Def Survey) • Pass 14889.14 14867.10 14856.33 N/A 0.00 0.00 Surface '®"' 13057.51 13042.12 425.33 3880.00 3142.99 MinPt-CtCt 13092.68 '® 13041.64 418.76 3910.00 3149.21 MINPT-O-EOU 13093.10 13057.36 MEM 414.50 3930.00 3153.05 MinPt-O-ADP 14243.85 14169.59 14133." 199.98 7200.00 3650.53 MinPt-O-SF 15279.86 15202.62 15165.0. 8296.37 3749.70 MinPt-O-SF 20812.82 20735.24 20696.95 271.72 14116.16 3718.87 TD OP21-W WS1(P3)(Def Plan) Pass 17130.46 17067.19 17036.05 275.04 0.00 0.00 Surface I 15339.41 15270.95 15237.77 231.13 3620.00 3066.47 MinPt-CtCt 1533943 15270.90 15237.69 230.88 3630.00 3070.15 MINPT-O-EOU 15339.52 15270.91 15237.66 230.63 3640.00 3073.77 MinPt-O-ADP 16500.74 16407.53 16361.41 178.89 6790.00 3601.06 MinPt-O-SF 17904.74 17808.69 17761.1 188.31 8296.37 374970 MinPt-O-SF 2350851 23411.91 23364.11 245.87 14116.16 3718.87 TD OP03-P05PB1(Def Survey) Pass 16753.10 16714.44 16695.94 452.81 0.00 0.00 Surface I 15544.41 15501.56 15481.18 381.38 3410.00 2976.35 MinPt-CtCt 15544.50 15501.50 15481.05 379.99 3430.00 2985.97 MINPT-O-EOU 15544.61 15501.54 15481.05 379.29 3440.00 2990.70 MinPt-O-ADP 16979.23 1690455 16867.73 230.51 6900.00 3615.23 MinPt-0SF 18344.03 18266.76 18228.61 240. 8296.37 3749.70 MinPt-O-SF 24022.27 23944.55 23906.19 313.06 14116.16 3718.87 TD Nike itchuq 2(Del Survey) i Pass 16032.27 16030.36 1599947 N/A 0.00 0.00 Surface I 16032.271 16030.351 15999.46 N/A 20.00 20.00 MinPts 15834.05 15818.50 1580124 N/A 2150.00 2046.67 MinPte 18520.93 18493.04 18479.97 708 63 5700.00 3437.40 MinPt-O-SF 25325.93 25254.94 25220.26 365.04 14116.16 3718.87 MinP1-0-SF OP18-08P81(Def Survey) Pass 17621.11 17608.99 1758830 N/A 0.00 0.00 Surface Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 10 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1666431 16637.50 16624.90 661.59 3830.00 3131.40 MinPt-CICt 16664.85 16636.95 16623.82 634.30 3890.00 3145.12 MINPT-O-EOU 16665.52 16637.09 16623.68 621.51 3920.00 3151.16 MinPt-O-ADP 17941.83 17870.40 17835.28 255.38 7400.00 3671.02 MinPt-0-SF 18798.58 18723.72 18686.81 2546111 8296.37 3749.70 MinPt-0-SF 24190.79 2411214 24073.33 311.65 14116.16 3718.87 TD Oliktok Point I-1(Def Survey) Pass 17839.78 17838.67 17806.97 N/A 0.00 0.00 Surface 1 16953.96 16922.88 16908.00 569.72 3620.00 306647 MinPt-CtCt 16954.12 16922.72 16907.68 563.48 3650.00 3077.33 MINPT-0-EOU 1695440 16922.77 16907.62 559.30 3670.00 3084.28 MinPt-O-ADP 17047.56 17005.98 16985.79 422.20 4520.00 3248.16 MinPt-OSF 18366.91 18296.67 18262.05 265.21 7400.00 3671.02 MinPt-OSF 19228.85 19155.29 19119.00 264.94 8296.37 3749.70 MinPt-0-SF 24639.06 24561.94 24523.86 323.57 14116.16 3718.87 TD OP09-06P81(Def Survey) Pass I17846.10 17844,88 17813.291 N/A 0.00 0.00 17846.30 17846.30 17843 92 1781349 N/A 200.00 200.00 MINPT-O-EOU 17043.77 17018.59 17006,69 715.69 3740.00 3106.76 MinPt-CtCt 17044.26 17018.01 17005.57 68467 3800.00 3123.73 MINPT-O-EOU 17044.90 17018.11 17005.40 670.17 3830.00 3131.40 MinPt-O-ADP 18386.36 18315.63 18280.8 263.91 7400.00 3671.02 MinPt-O-SF 19245.94 19171.93 19135.42 263.53 8296.37 3749.70 MinPt-0-SF 24643.64 24566.19 24527,95 32226 14116.16 3718.87 TD • • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P6) 12/14/2011 4:06 PM Page 11 of 11 Schlumberger Traveling Cylinder Plot TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP27-N1 Oriented EOU Dimension ,N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule . = Date: December 12,2011 used:Minor Risk-Separation ..„ ' Factor 8276 ft - TD North 350 0 10 340 20 330 30 140 320 40 .#iI120 *it 310 A41141111111 81#1 ikk 50 300 illy0P10110111111/%47 60 SIMI 2904.14 tillt4' friii4S 70 280 , , Ilk 80 itifilar 20I 27 1111111111111116 gild llirl,wimiMll . g 1 11111 I 11 11 I I lik_ _. 260 01IteII104.1".11*° oAdiam 100 V 250 or' 4110. cz, 110 o! ;yarn,tO otic �,. 240 120 MISS Or 230i*Aihr tall, 130 2204e110111 140 210 150 200 MO 160 190 180 170 Well Ticks Type: MD on SP27-Nl(P6) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger Traveling Cylinder Plot TRAVELING CYLINDER PLOT' Client: Eni Petroleum NoGo Region EOU's based on: Well: SP27-Nl Oriented EOU Dimension h, Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule A 1, Date: December 12,2011 used:Minor Risk-Separation -.NMI pp lir Factor 2664ft - 8276ft RECEIVED , T North DEC 15 2011 350 0 10 340 20 Alaska Oil&Gas Cons. Commission 330 30 Ancnorhge 140 32010 Oil i40 120 310 50 300 4110,100 _ 60 44100111:. 290 //tit 1 \ \ 70 illW 280 80 4,k*,• Alit* 20I ■I11_` g-. 90 270 iiiiiiirp.--milwi "11Thirillialillill41.144,0 260 r 04 ` 100 04111 14 11 *4 k 250 110 Pad iil otiN I I*1110k 'ainli.1108 120 VIII (1.11.r. 220 imø140 210150 200 1.1.1111111 160 190 180 170 Well Ticks Type: MD on SP27-N1(P6) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft ma Ga o co a 11cn o ( c 0 3 M o O 'a0 a-, - r- 0 30 _, 'c -, '0 N.) N 0 .o 7 )V 0) _, m cn (n.co N 0 K3 p to n) p O cwo 73 p o 0 O\ 0 7 0 3 7 0 N 0 N 0 N fD () O O O q 0 w G.) w w w0) 0) 0) 0) 0)NN.) N.) N.) N.) N.) N.) N.) N.) N.) N -L -, -+ -L - -, CO CO J 0) 01 A 0) N - - 0 2 co 00 J 0) 01 A w N.) O (0 CO V 0) 01 A 0) N -, 0 CO CO 0) (n A C.) N.) -L O J O N (n 0 - o * 0 co co 0 D -,. 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(D 0 0 co 7 - G 'O CD * (D 0 w Cl CD -o CD 0 CD CD V). °- N. 0 = 7 CD Cn 0 Z 7 - Cl Cl CD O (n = CS O CD -1 O - - 0o co - c co 0 = 0. ° o * co 0 -o co D 0 O N (O - CD O0 N CD (D CD S CD N O 0 -i 7 c co 7" (%) j N cn cn (D 0 7 CO Cl 2 CO (D (n N CO CA N CD cD Cl .7. 3 01 0 c C N 0 o a • Cl 0 o a 0 o m 0 v 0- -0 6 (A CO 0 a• Q A - 0 N83 D Z c0 7 co O C CD .n-. N CA 0 .N. 0 xi a 7 0 0) co Cl o 7 -, —8 r o CD m 0 Cl .0 'O (A 0 7 CDD 0 ° 00 W N' * (U 0 v_,. (-°O 'O 4) - O N 0 co CO CD _. (1) 0 0 0 o N Cl 0) 3 m 0)) v 3 cn m m w 0 a) c. 7 0 O d 0 Cr < A ° C a '< (n 0 0 o O a 7• - -O p r 3 C 7 0 O N `2- (D (� 0) w 0 7 * 7 oo 13 SLow co ecu co N co (n O co * A CD ox A N o CD 0 O O D CO s o Cl 7 — N m 0 N 0 0 a 3 v 0 a a a ? .< 0 Cn 0 7 o- 7 0 1 co O 7' a aco C 7 0 C - o' CU 0 7 0 m c N N m0 co N N CU G) 1 0) 11_i I_ 1 SC , �� lif 111\ SIE 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 Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP27-N 1 ENI US Operating Co. Inc. Permit No: 211-139 Surface Location: 4440.8' FSL, 1420.4' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 2166' FSL, 5232' FEL, SEC. 13, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development 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, 4% Daniel T. Seamount, Jr. h Chair DATED this Z day of November, 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 A. AKA OIL AND GAS CONSERVATION COM. 3ION PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil U. Service- Winj U Single Zone ❑ 1 c.Specify if well is proposed for: Drill ❑✓ . Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co. Inc. Bond No. RLB0008627 • SP27-N1 • 3.Address: 6.Proposed Depth: . 12 field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 13952 • TVD: 332 EI uff Oil Pool 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): � r , Surface: 4440.8FSL 1420.4 FEL S19 T14N R9E UM ADL 391283,3 ,388574 ®CT 1 a 20H Top of Productive Horizon: 8.Land Use Permit: APIv1ti3 1' A, 13.Approximate Spud Date: 3505 FSL 990 FEL 24 T14N R8EUM ADL 417493 Alaska Oil a/ Q Total Depth: 9.Acres in Property: 14. is a aS 2166FSL 5232 FEL 13 T14N R8EUM 1280 1114(iffnenftgary Mitt*/ 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.4 feet 15.Distance to Nearest Well Open Surface:x- 511489- y- 6053622 ` Zone- 4 GL Elevation above MSL: 12.4 feet to Same Pool: OP09-S1 16.Deviated wells: Kickoff depth: 200 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1680 psig - Surface: 1269 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 124 36 36 160 160 pre-installed • 16" 13-3/8" 68 L-80 BTC 2257 35 35 2292 _ 2173 1038 sx 10.7#ASL,252 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 Hydril 563 8176 33 33 8209 3723 643 sx 12.5#Deeperete 8.75" 5.5" 15.5 L-80 Hydril 521 5943 8009 3723 13952 3732 uncemented liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production - Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni @ 907-865-3328 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature MAPhone 907-865-3320 Date 10/12/2011 Commission Use Only Permit to Drill // API Number: //�� Permit Approve See cover letter for other Number: I ( /56750�;Z - 54_2-CC ,?" ate: \\V- \\ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed met ane, as hydrates,or gas contained in shales: Other: X 3500 Ps k 130 P %si Samples req'd: Yes❑ No[ Mud log req'd: Yes ❑ No a -1-Z SOV es 1 •i„w .4.r T: 1- C h.-ih) H2S measures: Yes❑ No[tom Directional svy req'd: Yes [VNo❑ // I . APPROVED BY THE COMMISSION ` [ �� /'i DATE: ,COMMISSIONER 704 /0'26'1 f OR ! I ,,,, )f Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Dupiicat 1 '`7 f0#1141.- JL Enii ��1� .� Ileum pill 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi eni etroleum.com ___ " +++ � @ P ®err �'� October 12,2011 'Oyp, Algia Od$ C Alaska Oil and Gas Conservation Commission ons. �,, Co 333 West 7 Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill producer SP27-N1 PP Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Permit to Drill for the offshore island producer well SP27- N1.The well will be drilled and completed using Doyon rig 15. The planned spud date is 11/27/2011. i Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323 or • Jason Brink at 907-865-3321 or Luca Borri at 907-865-3328. Sincerely, MA'Cll`^1 } Maurizio Grandi Well Operation Project Manager 1 :Voikt Oliktok Point Nikaitchuq Field II a '2r1ll oerr©lkurnn� SP27-N1 P3 Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" X-65 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res Surface Csa Dir ea 13-3/8" Base Permafrost 1,835' 1.763' N 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor (— L-80.BTC 9.2-9.5 Lost Circulation Hole Cleaning N' V 1 1.... i. Oro rR(7f N13-3/8"Casing Point 2,292' 2,173' ' 6 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation 40 lbs/ft MW(ppg) Hole Cleaning L-80,Hydril 563 9.4 Torque&Drag TOC 6.142' . n „...., Ao V1 "N"Sand Top 7.142' O m )D v 0 TOL 8,009' a 9-5/8"Casing Point 8,209' 3,723' 12-1/4" 85°F LSND GR/RES Periscope/PWD Wellbore Stability Neutron/Density Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 15.5 lbs/ft MW(ppg) Xceed 675 L-80,Hydril 521 9.4 (Geo-Steering) 5-1/2"Slotted Liner TD/5-1/2"Lnr 13,952' 3,732' 8-3/4" 85"F FazePro • Enil Petirolleum e nn n Application for Permit to Drill Saved: 12-Oct-11 Application for Permit to Drill Document Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Lateral Mud Program(MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25.005(c)(9) 6 10. Seismic Analysis 7 Requirements of 20 MC 25.005(c)(10) 7 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed: 12-Oct-11 cin n• Enil Petirolleum Application for Permit to Drill Saved: 12-Oct-11 12. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 MC 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 AOGCC PERMIT Document.doc Page 2 of 9 Printed: 12-Oct-11 fois4" r � u troHeum _era Application for Permit to Drill Saved: 12-Oct-11 1. Well Name Requirements of 20 MC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 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: SP27-N1 2. Location Summary Requirements of 20 MC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4440.8 FSL 1420.4 FEL S19 T14N R9E UM - ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.4'AMSL Northing 6053622' Easting: 511489' Pad Elevation 12.4'AMSL Location at Top of 3505 FSL 990 FEL 24 T14N R8E UM Productive Interval ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8209' Northing: 6052680.5' Easting:506839.3' Total Vertical Depth, RKB: 3723' Total Vertical Depth, SS: 3670' Location at Total Depth 2166 FSL 5232 FEL 13 T14N R8EUM • ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13952' Northing: 6056618.8' Easting: 502593.8 Total Vertical Depth, RKB: 3732' Total Vertical Depth, SS: 3679' Please see Attachment 7:Surface Platt and (D)other information required by 20 MC 25.050(b); Requirements of 20 MC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore AOGCC PERMIT Document.doc Page 3 of 9 Printed:12-Oct-11 • En troleum _enit Application for Permit to Drill Saved: 12-Oct-11 (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 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 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3732'TVD)(0.45 - 0.11 psi/ft) = 1269 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed:12-Oct-11 • Enii tr le Application for Permit to Drill Saved: 12-Oct-11 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2257 35 35 2292 2173 1038 sx 10.7#ASL,252 sx 12.5# Deeperete 12.25" 9-5/8" 40 L-80 563 HydriI 8176 33 33 8209 3723 643 sx 12.5#Deeperete ' 8.75" 5.5" 15.5 L-80 H521 I 5943 8009 3723 13952 3732 uncemented liner in open hole 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. Ellxequests4ha ' e. .'. - - - - - -: .' - - - . _ : - II.I . . 2). ' Letol.eJ[ S 72z AOGCC PERMIT Document.doc Page 5 of 9 • Printed: 12-Oct-11 *fit • En L-=\trs Ileum Application for Permit to Drill Saved: 12-Oct-11 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033,' Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 • 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (/b/100 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy• 15 - 25 Funnel Viscosity (CP) (seconds) 45 - 60 Yield Point Plastic Viscostiy (/b/100 s17 15 - 20 (CP) 12 - 18 • HTHP Fluid loss Yield Point (m//30 min c <5.0 (lb/100 st) 18-24 _200psi& 100°F API FiltrateOil/Water (cc/30 min)) 4 - 6 Ratio 60/40 Chlorides(mg/I) <500 Electrical >600 pH 9.0- 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(1); AOGCC PERMIT Document.doc Page 6 of 9 Printed:12-Oct-11 *ill E Application for Permit to Drill Saved: 12-Oct-11 Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 MC 25 005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 MC 25005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 MC 25 005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 MC 25005(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 Doyon 15. . 2. Rig up Diverter and test 3. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5. Install and test wellhead to 5000 PSI. 6. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 7. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 8. PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. `r bo r ec- 9. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording n results. (_� r i " -'- 10. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. AOGCC PERMIT Document doc Page 7 of 9 Printed:12-Oct-11 41111. • Eni troHeum Application for Permit to Drill Saved: 12-Oct-11 12. RU casing drive system. 13. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14. Install 9-5/8"Emergency Slips. 15. Install 9-5/8"packoff and test to 5000 psi. 16. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17. Pressure test casing to 3000 psi per AOGCC regulations. Record results. Fir 18. PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, /2_/f 7; clean out cement to top of float equipment. 19. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording .--"J► results. 20. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 21. PU and run 5-1/2"slotted liner to TD. 22. Land liner, set liner hanger with 200' Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 23. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 24. Nipple down BOP, nipple up tree and test. Pull BPV. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). , (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 25. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 26. Move rig off. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 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. AOGCC PERMIT Document.doc Page 8 of 9 Printed: 12-Oct-11 $0....(pis eni us operating WELL SP27-N1 Drilling Procedure SP27-N1 Spy Island Conductor slot#27 Reser ' ' : ocatio ;:- N1 Produce , <-Bluff) IlitiP ' ch q Project Drilling Wellplan Page 1 of 38 10/25/11 r $.140,,,_. _ • us op rrai i WELL SP27-N1 100101 Spy Island Nikaitchuq Field (nit �e�rokur i SP27-N1 North Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 2G" Hole Angle o X-65 0° 20"Conductor Shoe 160' 165' Deven Welded N/A 0 GR/Res IsiStirg Dir/PWD o 1_-2'8" a y 68 lbs ft MW(ppg) Wellbore Stability Mud Motor Surface T/Tall Cement 1792 1/:' i L-80,BTC 8.8-9.5 Lost Grculation — Hole Cleaning Casing Sections KOP:200' Casing Wear DLS: B/Permafrost 1551 ISIS 0-4°/100' Hole Angle111 28.27 Deg 13-3/8"Csg 2,292' 2,173' 16" 50"F WBM GR/RES Neutron/Density/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Grculation Xceed 900 40 lb/ft MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 81.39 Deg BHA Expense Intermediate TOC 6,140' 3,498' if Pick-up Top of Sand IG.aJ N Top 7,140' 3,627' TOL 8,009' 3,705' Hole Angle 85.00 Deg 9-5/8"Csg 8,209' 3,723' Al 12.25" 85"F LSND GR/RES Neutron/Density/PWD Wellbore Stability Lost Circulation 6slotted Liner Hole Cleaning 5-1/2" Torque&Drag 17 lb/ft MW(ppg) Casing Sections ai Xceed 675 L-80,Hydril 521 8.7-9.4 Casing Wear • BHA Expense E "a_ •Hole Angle , r 89.88 Deg 5-1/2"Liner 13,952' 3,732' i 8-3/4" 85°F MOBM Drilling Wellplan Page 2 of 38 10/25/11 en11 us operating WELL SP27-N1 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 10 Surface Cementing 13 Pick Up Intermediate Drilling Assembly 15 INTERMEDIATE SECTION 16 Intermediate Drilling 18 Intermediate Casing 19 Intermediate Cementing 22 Pick Up Production Drilling Assembly Wit. 23 PRODUCTION SECTION 25 Production Drilling 27 Production Liner 28 ATTACHMENTS 31 Recommended Drilling Practices.... 32 Health, Safety& Environment 33 Safety Meeting Topics 34 Well Shut In Procedure While Running Production Tubing 36 Conductor Broach Contingency Cementing Plan 37 TAM PORT COLLAR Utilization Decision Tree 38 Drilling Wellplan Page 3 of 38 10/25/11 2rnno us operating- WELL p rratingWELL SP27-N1 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Producer Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 5-1/2"Slotted Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. e directional program and a summary of close approaches can be found in the attachments. These close approache• I be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis a i ose Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to .r- the directional plan is executed as planned,that the position of the well as it is drilled is monitored on .n anti-col • diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planne. -II pat. `. any major deviations from the profile may adversely affect the ability to drill future wells and still adhere • •rrent close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as need,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and fixture ti,ell paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-goiines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. ud Logging Program Mudlogging will be utilize. spud •roduction hole TD. Refer to the Geological Mud Logging Procedure document. Drilling Wellplan Page 4 of 38 10/25/11 ani us operratorog WELL SP27-N1 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2. Land Intermediate casing point within 100'radius of the planned directional target. 3. Land the Intermediate hole section with the targeted inclination of 85° -87°within the OA sand. Maximum dogleg severity in the landing shall be no greater than 3.5°/100' DLS. 4. Target Greater than 90%within the OA sand Reservoir. 5. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD—Require GR/Res/Dir to achieve TD. Drilling Wellplan Page 5 of 38 10/25/11 42n us op rrahng WELL SP27-N 1 MIRU SECTION Cpn Jµ OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PO Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation su mark by the surveyors > Surveyors to also mark each conductor with a degree of angle et each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distan p d sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N . e. • Ensure all concerned parties(Directional Driller ' I ••erators,a eologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco startel head,the diverter spool,and the annular preventer. Function test the system. D Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test > Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating tl erig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: > Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac truckswhile cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). Drilling Wellplan Page 6 of 38 10/25/11 2rnn� us op`rrafing WELL SP27-N1 SURFACE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan(P3) Measured True Vertical Formation Tops Comments Depth,ft Depth,ft SV-4 755 752 SV-3 1136 1121 SV-2 1412 1378 B/Permafrost 1951 1868 Ugnu Top (UG-4) 2292 2173 Set Surface Casing UG-2 3011 2748 L Ugnu 4864 3308 Schrader Bluff 6619 3565 N Seq Top 6893 3599 N Top 7140 3627 N Bottom 7363 3649 OA Sand Top 8095 3713 Drilling Wellplan Page 7 of 38 K i l l 10-5* no us operating WELL SP27-N1 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point A luid Interval Depth Density Reading oss Chlorides(mgn) PH (ml/S.t)min) 110'—1800' 8.8-9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800'—C.P. 9.2-9.5 20-24 <6 <2000 9.0-9.5 Surface Logging/Formati ation Program: Surface: MWD Directional LWD GR/Resisti urfa rill Pipe Pipe WT Grade Con Tool Tool';;' Body Make Up Joint Body DP Tensile (ppJ) type 'sloini Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (ft.lbs) (gal/ft) w/5"D P cptg 19.5 35 NC50 `' 6-5/8 3-1/4 4.276 26,800 51,700 74,100 .726 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections Drilling Wellplan Page 8 of 38 10/25/11 11-001 en o usop rratang WELL SP27-N1 Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully re -w the antis ed close crossings with existing wellbores. Make sure that directional drillers are awar- .11 drilling do •ssing issues,hardlines and no-go lines. If a no-go or hardline has been or will be c •d,sto 'rillin im i •diatel and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base o permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 h any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encs tered. ➢ Consider adding 0.5%Drilzdne for n blinding in shallow intervals right below the conductor. 5. Surface casing point: ➢ Landed in good shale found in this area between 2000' SSTVD and 2150' SSTVD ➢ Below the sand at the base cif"the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). ➢ Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: ➢ Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher ➢ Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. Drilling Wellplan Page 9 of 38 10/25/11 2n� Trim us operrfins ` WELL SP27-N1 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from:While backreaming out of the hole in the transition from horizontal to vertical, have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers cl 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg 11111111141k(in) Drift(in) Collapse Burst Tensile Yield (in) (PPO Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface.Casing Connection Make Up Torque(ft.lbs) • T Opt. Grade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. Drilling Wellplan Page 10 of 38 10/25/11 los no us operating WELL SP27-N1 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: ➢ obtain SO Weights every 10 joints ➢ obtain PU Weights every 10 joints 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** I ly run if losses are TAM BTC port collar+1-500 ft expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel ha r 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a co ion that can be broken below the rotary table,will need to be run to allow for running the dril4ipe imide the- -3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +1- 18 13-3/8"Tandem Rise Weatherford Drilling Wellplan Page 11 of 38 10/25/11 en! us operating WELL SP27-N1 Surface Centralizer Placement )MC 4e1S1111 10' oa 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 1st joint. • 1 at 10'above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry),1 centralizer per joint run on collars. l)o not allo'n centralizer to float hetNNcen collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. 8' A Drilling Wellplan Page 12 of 38 10/25/11 11134#1 2no • us operr tang LWELL SP27-N1 Surface Cementing Program Section Casing Size Type of Fluid / Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 452 bbls Yield 2.45 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 89 bbls Yield 1.56 ft3/sk Top of Tail @ 1,790' MD Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing .n the job ble 'or to pumping the cement. DO NOT pump cement if there are any doubts as to cern- ality,;uantities, ping times,or thickening times. b. Use split landing joint if TAM port collar is utilize. nee, . be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate wt on bo • at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if neces > To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 2 exceshe Pafrost. D If necessary, ' that the 1 Tech has located the proper crossovers to his combo running tool ➢ If necessary,rac run tool in derrick and ready to run > Hook up or install a i elow the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered eturns when necessary. > Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: D Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. D Do not over displace the cement(no more than'A the shoe joint volume). Drilling Wellplan Page 13 of 38 10/25/11 Trin eno us operrahng WELL SP27-N1 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. D In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. / ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indica . on the conductor markings. D If there is any doubt about the proper orientation,call the Drillin: ' •erintendent. D Ensure that the seal between the casing hanger and well head• -st= ' 5,000 psi for 10 minutes. D Measure the distance from the rig floor to the top flange e well he.. •d record on the IADC report and in WellView. Complete the Rig Elevation Record and p it in the electron -11 folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the A C Pe to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi 250 psi low D. Test annular preventer to 2500 psi high/2 •w D Do not test BOPE against casing. D Notify AOGCC 24 hours prior to performin P test. • PERMIT TO DRILL requires B`:' testi equency every 14 days unless notified otherwise by AOGCC Ate Drilling Wellplan Page 14 of 38 10/25/11 iTio rnn Ms operating WELL SP27-N1 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: D. 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120—140 RPM ➢ See BHA attachment for running order and specifications 2. RIB to top of float equipment and pressure test surface ca ' o 2500 psi for 3 ' and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there i air entrained in the mud. Repeat Casing pressure test if needed. IN iN ➢ Note:All BHA trips thru the TAM port c Ilar(I icabl should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50'of new hole using spud mud 5. Displace hole to new LSND mud system.. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. Drilling Wellplan Page 15 of 38 10/25/11 If* 2no us oerrfing WELL SP27-N I INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan(1) Measured True Vertical Formation Tops Comments Depth,ft Depth,ft SV-4 755 752 SV-3 1136 1121 SV-2 1412 1378 B/Permafrost 1951 1868 Ugnu Top(UG-4) 2292 2173 Set Surface Casing UG-2 3011 2748 L Ugnu 4864 3308 Schrader Bluff 6619 3565 N Seq Top 6893 3599 N Top 7140 3627 N Bottom 7363 3649 OA Sand Top 8095 3713 Drilling Wellplan Page 16 of 38 10/25/11 drofiki en fl us cooperralinng WELL SP27-N1 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density PV 6 RPM API FL pH DrillSolidsMBT (ppg) Reading (m1/30min) (/o Intermediate: 9.2—9.4 _-l 8 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Press ile Drilling) LWD—GR/Res Intermedia • -rill P' • Tool Joint Body DP WT Conn. Joint Tool Bo' ake Up Tensile Torsion Torsional capacity Pipe (ppf Grade Type OD ID(in) orque al Yield Yield w/conn. Capacity (in) lbs) (ft lbs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 NC50 6-5/8 3- . • 6,800 51,700 74,100 .726 712 w/G-I 05 cplg 5"HWDP 49.5 Intermediate Section Notes: a. If the well is to be an ESP pro'ucer,a pump tangent must be placed in the intermediate hole section as per the planned ionarofile. The pump tangent must be within 300'TVD from the top of the uppermost OA sand t least 200'MD in length. b. Efforts sho e made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment wi damaged running through high dog legs(>6 degrees per hundred). c. Shallow test ols. d. Monitor hole conditiis carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off'slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Drilling Wellplan Page 17 of 38 10/25/11 IR* • 2nd Ms operating WELL SP27-N1 Intermediate Drilling Directionally Drill 12-1/4"hole Use the following Parameters: • Flow rate of 900 GPM • 120—140 RPM 2. Casing Point:Land Intermediate casing 50'into the 0A2 sand reservoir 3. LOW ROP:Consult with Town as ROP drops to< 1-2 ft/hr for one(1) our. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: ➢ Circulate until shakers are clean(+/-5 to 7 bottom er odel)whi e backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM V ➢ Backream into the surface casing shoe. : :: • Slow backreaming # •• _ to the surface casing shoe/rathole. Hold parameters steady at 900 GPM .•• • RP arge chunks of coal can be deposited in the 16"rathole near the shoe. • Lesso -arned fro' •P0' •While backreaming out of the hole in the transition from horizontal to verti• have the sh. box b-guns running or ready to run at the first sign of clay balling. Have the flo line jets hook up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mu• system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. ➢ Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. Drilling Wellplan Page 18 of 38 10/25/11 riffs en 0 us operrafing WELL SP27-N1 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile field (in) (ppf) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque(ft.lbs) Min. Target Max OD WT Grade Conn. Tjpe aUp Make Make Up Yield Torque (in) (PP.° Torque,e ft- To Torque lbs 9-5/8 40 L-80 Hydril 10,800 ,000 N/A 75,000 563 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are inst. •nd tested prior orunning intermediate casing. b. Rig up and utilize a casing fil ool the casing job. Shoe Track: 1. Have a spare float shoe and collar up with centralizers and on location ready to go ➢ Shoe joint misalignment h.• .us-. Iss threading with Hydril 563 connection and requires make up by hand for first 10-15 'oints • Make-up - track(and 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cros -ading • The shoe track . sh' be Bakerlocked. • Inspect the float v. . the shoe track is picked up. • Run the shoe track in s the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. ➢ Draw a longitudinal line across the pin and box and reapply the published target torque. ➢ If the drawn line does not move more than 1/4"after the second torque application,continue running the rest of the string normally using the published target torque. ➢ If the drawn line moves more than 1/4"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than 1/4",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than'h",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than 1/4". Drilling Wellplan Page 19 of 38 10/25/11 V'Oki eni use; operating WELL SP27-N1 • It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order 1 Float shoe—Davis-Lynch Model 501-DV-PVTS Baker-Lock down jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger I'k 7 9-5/8"landing joint lick landing joint for reciprocation purposes C alizers +/-38 9-5/8"x 11-3/4"Rigi. .rofo P Floatin• Volant 1. Inspect and drift inte P . 8.75"). 2. Centralizers(See P ram Below) 3. Pull wear bushing. I 9-5/8"r. and test. Pick up and run casing. 4. Monitor running speeds t. ,i• - surge and swab pressures while running in or picking up off slips. D K&M Engineer will provi•e a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. D Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000'MD and check flow through floats. Circulate bottoms up each time. D Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: D obtain SO Weights every 10 joints 6. Once on bottom with the casing: D obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. Drilling Wellplan Page 20 of 38 10/25/11 l W - eno us operating WELL SP27-N1 Intermediate Centralizer Placement <, , 10' RP IMI9-5/8"x 11-3/4"Hydroform Centralizers Collar ,/ Run 1 Hydroform: • On Stop collar 5'above Float shoe. 400011110111° • No centralizer on next joint • On Stop collar 10'above Float Collar. • From 4th joint to+1-1000'above the shoe- 111111 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+1-500'above N sand oil bearing zone CI � 1.111 i.i,j___ , J L Drilling Wellplan Page 21 of 38 10/25/11 no • us opera-lung WELL SP27-N1 Intermediate Cementing Program Section Casing Size Type of Fluid /Cmt Volume Properties Intermediate 9-5/8" Mudpush II 70 bbls Density 10.5 ppg DeepCrete 179 bbls Density 12.5 ppg Top of Cement @ 6,140'MD (645 sacks) Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on job blend ' r to pumping the cement. DO NOT pump cement if there are any doubts as to cement quali uantities,pum times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than'h th e' volume). c. For injectors,a cement bond log is required. Prefer to nic LWD in production hole BHA and log intermediate casing on trip in hole to drill c - ediate )101°. 1. Perform Rig pump efficiency check and confirm+�' 'e`efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cem volumsed on"N"sand actual depth! D Cement volume is based ori e ss and at I�t 1000'of annular fill above top of the N sand(highest known hydrocarbon bearing z efer to attached cement detail sheet for volumes. 3. Batch mix cement. T eme s mp cement job as per the attached Schlumberger program. 4. Displace cement rig pumps and LS D water-based drilling mud. D Ensure that the ce'`ent unit g pumps are manifolded so there will be redundancy in case of any pump failure during displacem• t D Pump cement at 5 bpm a displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger D Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. D Do not exceed 80%of intermediate casing collapse D Record test on IADC report and in WellView Drilling Wellplan Page 22 of 38 10/25/11 2rnnn ills operating WELL SP27-N 1 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. D. Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. D. Pressure limitations are as follows:80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) D Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) > Test rams and choke manifold components to 3500 psi high/2 'low D Test annular preventer to 2500 psi high/250 psi low D Do not test BOPE against casing. D Notify AOGCC 24 hours prior to performing B e .est. • PERMIT TO DRILL requires BOP testing fre r every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to rec • ■ Pits must be clean and of all ite Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit an BHA asse bly as per the attached BHA diagram. D 8-3/4"PDC > Rotary Steerable D Flow rate: 550 GPM ➢ 120-140 RPM 2. RIH to the float equipment. D. Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form in N drive Drilling Wellplan Page 23 of 38 10/25/11 y Pno us operrattns WELL SP27-N1 Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits ➢ Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50'of new hole usin the Oil Based Reservoir Drill-In fluid 6. Perform Leak Off Test as per AOGCC requirements following the LOT Procedure. ➢ PU into casing and perform LOT. D. If the pressure continues to rise past 13.0 ppg EMW,shut ' n and ca FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 12.1 EM ontact Dril ing Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determi here is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive 11110 Drilling Wellplan Page 24 of 38 10/25/11 wilos end us operrfins WELL SP27-N 1 PRODUCTION SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (l'31 Measured True Vertical Formation Tops Comments Depth,ft Depth,ft SV-4 755 752 SV-3 1136 1121 SV-2 1412 1378 B/Permafrost 1951 1868 Ugnu Top (UG-4) 2292 2173 Set Surface Casing UG-2 3011 2748 L Ugnu 4864 3308 Schrader Bluff 6619 3565 N Seq Top 6893 3599 N Top 7140 3627 N Bottom 7363 3649 OA Sand Top 8095 3713 Drilling Wellplan Page 25 of 38 10/25/11 iPA , • us operrahng WELL SP27-N1 Production Mud Program: FazePro Density HTHP FL Electrical Interval (Ppg) VP (m1/30min) Oil:water Stability m1Volts Production 9.4 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Resistivity Production Drill Pipe Tool Tool Make Up Body DP Tensile Pipe WT Grade Conn. Joint Joint y sue Tors Torsional capacity Capacity (PPI) type OD n) al Yield Yield w/conn. (in) ID(in) t.lbs) (ft lbs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 NC50 6-5/8 4.27. 6,800 51,700 74,100 .726 712 w/G-105 cplg 4.5"DP 16.6 S-135 NC46 6-1/4 )100, - '00 39,200 43,500 .582 468 Production Section Notes: a. Monitor hole conditions carefully. Be alert of early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow tesMWD too" c. Good drilling and tripping` , ctiare vital for avoidance of differential sticking. Make every effort to keep the drills 'ng moving whenever possible and avoid stopping with the BHA across the sand for any extended perio time., d. Keep shut down ti a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while e survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. Drilling Wellplan Page 26 of 38 10/25/11 2nd us op rrfing WELL SP27-N1 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. D. Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle .ullin• 1 t ter bottoms u.. Once the first 50% cleanup cycle is completed circulate the remaining 50%of th- -d cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pu • •ressu tate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming Spee• • pullin into the Intermediate casing shoe/rathole. Hold parameters steady at ai nd 12 PM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on C. •letion • COMPLETIONS.` ' :BIT SIZE: 2-3/8"OD • All drifting tools wil le accounted for and held in one place at all times. 4. Continue backreaming until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. ➢ Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town Drilling Wellplan Page 27 of 38 10/25/11 no us operreing WELL SP27-N1 Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (pp) Type (in) (psi) (psi) (kips) 5-1/2 15.50 L-80 Hydril 5.713 4.950 4.825 4990 7000 242 521 Production Liner Connection Make que(ft-lbs) OD WT Grade Conn. Type Min. Target Max. (in) (PPP Make U Make Up e Up Yield Torqu - Torque* que Torque lb 5-1/2 15.50 L-80 Hydril521 4600 5500 N/A 24000 * See attached TenarisHydril Guidelines ue recommendations P r tion Centralization From To Quanti. '' ointfixed/Floating Type Shoe Liner 1/joint Find 5-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) 1111111141 "- Production Liner Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • The liner will be run in FazePro RDF. Consult with completions engineer for liner detail. Liner string will be adjusted according to actual depths after drilling. Consult with completion engineer and ops geologist to determine exact placement and number of swell packers prior to installation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. Drilling Wellplan Page 28 of 38 10/25/11 2rnno us operating WELL SP27-N1 • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: String Components Yield Torque(ft-lb) 5" 19.5#NC50 Drill Pipe 51,700 4-1/2"16.6#NC46 Drill pipe(prem) 43,500 HRD Running Tool 1,000 7"29#Hydril 563 ',000 5-1/2" 17#Hydril 521 4,000 • Shear pressures for liner hanger assembly: Item Description Shear Valuer S1 Range HRD Running Tool,7" Nominal- ' 3192 15%+ 3671 psi 4650 mch rel,2 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat 'SOLID *****Make-up torque for liner ha' sub .embl eluding running tool connections,should be torqued to 14,01 -lbs pr to deliver to rig. Procedure: 1. Hold Pre job safety meeting to e'sure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix"and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO, and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt.immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. Drilling Wellplan Page 29 of 38 10/25/11 ros 2no us operating WELL SP27-N1 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has re .sed. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically ased,4,650 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Dis lace mud frost.. er to, surface with 9.0 .. KCl brine ser MI recommended program. 19. POOH and LD and inspect the liner running tools. till%P* ti Drilling Wellplan Page 30 of 38 10/25/11 los en n us operrafing WELL SP27-N1 ATTACHMENTS 1. Recommended Drilling Practices 2. Health,Safety,and Environment 3. Safety Meeting Topics 4. Well Shut In Procedure While Running Tubing 5. Conductor Broaching Contingency Plan 6. Port Collar Decision Tree 7. ENI LOT procedure 8. ENI FIT Guidelines /\ 110 Drilling Wellplan Page 31 of 38 10/25/11 0 qi. — _ 2nd us operating WELL SP27-N1 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as possible. b) Emphasize proper hole cleaning after slides by rotatin axim llowable RPM c) As the hole angle increases,hole cleaning practices t be altered. imum pipe rotating speeds along with maximum achievable flow rates will incre le cle ing efficie s. Circulating times prior to trips should be increased accordingly to accou Ion mes required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip /Connection Speeds High POOH and RIH speeds can aggrto fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive trip and r ing speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and t try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. Drilling Wellplan Page 32 of 38 10/25/11 .01/4 en o oo �ramino o�c z C � --- WELL SP27-N1 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in ess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equip 'ng the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also aintain location. 3. Self-contained Breathing Apparatus for all rig personnel w' e maintained on ion. 4. All personnel engaged in the drilling operation will bet d in emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All ersonnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and persorEl will have the,equi nt and training to identify and contain a H2S emergency situation. If it becomes necessary tolotify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures.full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,d ily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. Drilling Wellplan Page 33 of 38 10/25/11 Trfn en Ms 0OrerraCor WELL SP27-N1 Safety Meeting Topics Move In,Rig Up D. Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with vari sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. > A Diverting Shallow Gas'drill should be held with ' rews prior d,unless each crew on tour has completed this drill within the past 3 months. Do ent drill and reco morning report. ➢ An'Accumulator'drill should be held with rig s pri spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly schedule 's. A suggested minimum is once per day on alternating tours. Document and record on morning rep ➢ Check trip tank for leaks and confirm gauges are calibrate . Complete trip sheets and submit to the . Drilling Supervisor after each • ➢ Perform and document all s. ➢ Designate crew memb contro cess at pad entrance in case of diverter operation. Surface D A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months.;Document drill and record on morning report. D A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. D A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production > Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. D Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. Drilling Wellplan Page 34 of 38 10/25/11 i filo s . eno us op rrains WELL SP27-N1 ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion ➢ Operation of the control line spooler. ➢ Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. ➢ Well control practices while running production tubing with control line. ➢ Pressure testing and minimizing personnel exposure to pressurized lines. IS° NIIIIIIP I 110 Drilling Wellplan Page 35 of 38 10/25/11 i iA ens us oerraiong WELL SP27-N 1 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced •ut across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete abo .e . e s: 1. Install TIW and close annular around pipe and control li 2. Shut off air to control line spool and bleed off line pr e whi e picking u• -'joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and co line and the a joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cuffs required to cut control line. • Need to have access to a joi £of drill pipe and the appropriately sized elevators at all times. k Drilling Wellplan Page 36 of 38 10/25/11 ar- 2nn Ms operating WELL _ SP27-N1 Conductor Broach — Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID:(36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has'occurred,POOH an nd back BHA. 2. RIH with open-ended drill pipe to 20'below the base oche conductor pipe. 3. Establish circulation with mud at normal drillin te. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water re `rns are selfrom the broach. 5. RIH to 200'below the base of the co ductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50'below the conduc ' POO,-`'o 20' inside the conductor. 6. Mix and displace+/-80 bbls o` 'c Set., 16.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace D'. .,..'or an. :...a all returns. 7. POOH and WOC for : . . 8. PU 16"bit and BH "' nd RIH to c ' out •-ment to 40'below conductor. Establish normal circulating rate and evaluate broaching. „jj• broachin_ seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. Drilling Wellplan Page 37 of 38 10/25/11 • nn us op!rrafinc WELL SP27-N 1 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job No Cement to Surface Drilling Foreman and Engineer determine the Top of Cement Top of Continue Cement Ceme with above Port below Port Completion ", Collar Collar (1000'TVD) (1000'TVD) f ---- Indicators of Cement Top Perform Top Job as per ► Open Port Coll If To 's ineffective or 1. Observation of Tracers in Spacer ahead of lead cement requirements of unacce to AOG using drillpipe 2. Calculated Displacement AOGCC 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and irdulate Cement Test BOP's to Surface and close Port Collar •_ Continue with Nipple Up and Completion Test BOP's • Continue with Completion Drilling Weliplan Page 38 of 38 10/25/11 • Enft P en Application for Permit to Drill Saved: 12-Oct-11 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 AOGCC PERMIT Document.doc Page 9 of 9 Printed: 12-Oct-11 0) 0 gg44201 b d p O N g3,7-:=4,4' I M^O n NMrt(at OrN b(0D MOImo tMO� [;17,4 ty Cm ddmNb •-rmQ� 41 qC M W mmN Oni,§pO.d- NC0,1d C.- . � min Ol<ai Min rOOnip� N ` 0 0 0 0 0 0 0 h b b m�!)(A)U) M M h N N ((00 b N 1 p b (0 m m b b (0(0 0 O O M m W M a m m m b m b m N m m b m b N m b b h b b b b m b W b m b y1 h m b b b m m b m b a coON,_CZNdmON Hill NI o mNryrrN mmdmiQb mrym0 'O^M 0M r,T N N ! !!! m Nn' mm0 ! !!CaG ' '!-CCOiN IN <%27,44 b O 7, W ll NY C O ;a C Y t asz o Y Y Y • w 358828 YOONMNNryW 0 NrMNGm r br M0 '.,02:2z_ bNmNd O42,%1,17- 1:222 OCOOC-- NCNNth MthpMM Mh1MM h0«p dVVpp <V<00 VQ<p tT 53 a N Q ONO O pp O 2 00 O p 0 0 O O p 0 0 N NNN 0 O O O pp p MI!! 0 0 0 0 0 0 0 0 J Z O O O p 0 0 O p O N O b tO b 0 p O O O p 0 0 0 0 0 0 p D �(V lV N lV N N lV N lV IV N N GOO O C GCC e' O P Q et ej Q d O O d O v v.1 O 3 123 C. 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A |§ ... 0 w XEj E | � 0 t| ' 0 / /§ & d i 14 82 g 1i ® . \ ! 7 ) ■ & § B gig t It 3 V z ); � ° &-§ _. z / |:! ■ I.° - — — ' !§& a • i &,11| !; 'i■ |$© !§ 0 j/ §, g a . ■ 00 }. � � Ps C" ea ■ 3§ ° §! & i! ji'� �A , � © 2 !{ . 3» / z ,| a N , • » " '9 0. §e Cl) :] , 5i ; 2,2 0K ° k 0) 0 "< N UmG;%#=oleos s >>> Sclieuhner SP27-N1 (P3) Anti-Collision Summary Report Analysis Date-24hr Time: October 05,2011-14:30 Analysis Method: Normal Plane Client: Eni Petroleum Reference Trajectory: SP27-N1(P3)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Spy Island Rule Set: O&M AntiCollision Standard S002 v5.1 Slot: SP27 Min Pts: All local minima indicated. Well: SP27-N1 Borehole: SP27-N1 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major SI25-N2(P2)(Det Plan) Warning Alert 16.02 14.79 2.96 12.09 0.00 0.00 CtCt<=15m<15.00 Enter Alert 16.02 1198 2.96 7.28 200.00 200.00 MinPts 16.6 13.51 3.54 499 390.11 390.02 MinPt-O-EOU 1795 12.82 4.90 3.26 475.19 474.86 MinPt-O-EOU 19.25 1329 6.19...33520.23 519.71 MinPt-OSF 4867 43.14 3561 8.58 861.05 855.83 CtCt<=15m>15.00 Exit Alert 323.72 291.66 276.1.MIME 4548.56 3261.09 MinPt-OSF 274. 247.36 234.31 10.48 4824.68 3302.42 MinPt-CtCt 275.2 246.8 233.14 10.01 485865 3307.51 MinPt-O-EOU 277.25 247.2 232.7 9.53 4888.38 3311.96 MinPt-O-ADP 37324 318.47 291.5 6.921 5232.45 3363.46 MinPt-O-SF 1 965.48 869.89 822.59 10.20 775846 3684.05 MinPt-CtCt 9666 868.710 820.25 9.96 7858.42 3692.76 MinPt-O-EOU 968.06 869.01 819.971 9.86 7908.36 3697.12 MinPt-O-ADP 991.27 884.53 831.641 9.361 8231.85 3725.31 MinPt-O-SF 1006.4' 897.91 844.12 9.35 8612.81 3733.58 MinPt-O-EOU 1008.54 898.31)))))))))mretr:.-.''�' 9.22 8653.33 3733.08 MinPt-O-ADP 1308.83 1080.73 967.18 5.76 13930.89 373255 TD S129S2(P2)(Def Plan) Warning Alert 16.02 14.80 296 12 09 0.00 0.00 ClCt<=15m<15.00 Enter Alert 16.02 13.99 2.96 7.30 200.00 200.00 MinPts 16.03 13.97 2.97 7.19 209.99 209.99 MinPt-O-EOU 16.68 1446 162 6.95 269.94 269.94 MinPt-O-SF 20.00 17.15 6941 6.581 34967 349.62 MinPt-O-SF 48.47 43.19 35.41 8.96 52065 520.12 CtCt<=15m>15.00 Exit Alert 65492 645.30 641.1.)jj)1)))) 0 1202.40 1183.55 MinPt-O-SF I2461. 2380.18 2340.04 30.65 5925.28 3467.06 MinPt-CtCt 246156 2380.091 2339.85 30.57 597842 3474.92 MinPts 2463.40 2381.64 2341.26 30.4 6137.58 349821 MinPt-OSF 1892.35 1810.46 1770.01 23.3 8229.12 3725.07 MinPt-O-SF 832.14 766.01 733.44 12.76 8915.52 3739.46 TD 907.97 791.43 733.6 7.8 7137.85 3626.80 MinPt-O-SF 866.76 759.661 706.6 8.16 7385.20 3651.35 MinPt-O-ADP 865.56 759.431 706.87 8.22 7408.90 3653.50 MinPt-O-EOU I 864.56 76043 708.85 8.37 7456.37 3657.72 MinPt-CtCt 539.12 460.31 421.40 6.91 8574.25 373440 MinPt-O-SF 530.04 452.53 414.26 6.91 8595.77 3733.90 MinPt-O-SF 489.09 423.18 390.71 7.52 8708.31 3733.05 MinPt-O-ADP 486.101 422.6'41 391_38 7.76 8721.72 3733.22 MinPt-O-EOU 1 48406 424.50 39522 8.25 8742.82 373364 MinPt-CtCt SP24-SE1(P2)(Oct Plan) Warning Alert 39.13 37.90 7.58 30.97 0.00 0.00 CtCt<=15m<15.00 Enter Alert 32,46 27.32 0.91 6.08 453.33 453.08 MinPts 3285 26.88 1.30 5.29 477.54 477.21 MinP1-0-EOU 34.35 2764 2.801 501.56 501.13 MinPt-OSF 49.14 4161 17.60 6.36 581.48 580.55 ClCt<=15m>15.50 Exit Alert 2571.96 2550.62 2540.41=ME 2800.84 2595.37 MinPt-OSF 1987.98 1935.71 1910.07 38.74 4605.96 3269.68 TD 9179 881.488 863.76 25.86 3861.78 3151.78 MinPt-CtCt 9179 8818 86363 25.78 386668 3152.95 MinPt-O-EOU 918.04 8814 863.63 25.75 3868.31 3153.33 MinPt-O-ADP 96221 92237 902.95 24.7 3974.65 3174.85 MinPt-O-SF 1016.57 97452 953.99 24.7 4046.87 3185.99 MinPt-O-SF SP3O-W1(P2)(Def Plan) Warning Alart 23.99 22.77 4.55 18.60 0.00 0.00 CtCt<=15m<15.00 Enter Alert 21.96 11.23 200.00 200.00 MinPts 25.28 NEM 5.:•m 599.60 598.53 MinPts 26.23 19.38 6.7r NM= 719.46 717.01 MinPt-O-SF 39.53 26.18 20.0, EIM 1548.58 150344 MinPt-O-SF 48.15 29.64 20.99 I® 1938.48 1856.78 MinPt-O-SF 73.21 57.74 50.49 4.98 2924.75 2687.06 085>5.00 Exit Alert 197.13 159.92 141.81 ;IM 4137.49 3199.55 MinPt-0-SF 1015.49 928.39 885.3 ) 8231.93 3725.32 MinPt.OSF 1015.33 928.2''- , 11.79 8256.11 3727.30 MinPt-O-ADP 1015.3. 885.26 11.79 8260.14 372761 MinPt-O-EOU MIME. 92829 885.27 11.79 8264.17 3727.92 MinPt-CtCt 1033.3'mzER.magE, 11.45 8688.92 3732.95 MinPts 1063.38 9562.misE 10.00 9609.19 3745.99 MinPt-O-ADP 1066.53 957.3:ENEEEE'''' 9.85 9709.13 374547 MinPt-O-ADP Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 1 of 11 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 1069.26 958.62 903 79 9.74 9793.09 3745.78 MinPt-O-ADP 1076.90 961.45 904 22 9.40 10027.96 3748.62 MinPt-O-ADP 1082.43 963.52 904 561 9.17 10197.86 3750.68 MinPt-O-ADP 1085.64 964.55 904 50 9.03 10298.81 3751.25 MinPt-O-ADP 1101.14 969.33 903.91 8.41 10788.56 3750.50 MinPt-O-ADP 1184.39 989.75 892.9 6.11 13427.78 3731.50 MinPt-O-ADP 120129 993.46 890.04 5.80 13952.90 373260 TD SI32-W2(P2)(Def Plan) Warning Alert 47.94 46.71 15.13 38.17 0.00 0.00 CtCt<=15m<15.00 Enter Alert 47.94 45.91 15.13 23.02 200.00 200.00 MinPts 48.01 45.87 15.20 21.80 279.87 279.87 MinPt-O-EOU 49.20 43.17 16.40 7.96 489.44 489.06 CtCt<=15m>15.00 Exit Alert 49.70 111111111Z0 16.89 7.22 519.37 518.85 MinPt.O-EOU 51.97 43.85 19.17 599.19 598.13 MinPt-O-SF 259.84 250.74 227.0 jjjjjjjjjjj 1491.56 1451.30 MinPt-O-SF 1089.71 1067.58 1056.'.EMCEE 3316.06 2935.49 MinPt-O-SF 1424.82 1349.18 1311.• =MI 5775.42 3444.75 MinPt-O-SF 2115.13 2064.53 21.90 8254.35 3727.16 MInPt-CtCt 2217. MIME 2064.48 21.89 8267.40 3728.16 MinPt-O-EOU 2217.36 2115.111jjjjjj 21.89 8273.93 3728.63 MinPt-O-ADP 2236. 'jjjjjjj MOM 20.97 8688.38 3732.95 MinPts • 2247.09 2133.91 W2M11 20.02 9009.41 3742.68 MinPt-O-ADP 2253.06 2136.6r®- 19.51 919286 3747.93 MInPt-O-ADP 2279.74 2146.5 MECZOM 17.24 10036.81 3748.73 MinPt-O-ADP 2285.05 2148.'; 2080.6' 16.84 10201.73 3750.73 MinPt-O-ADP 2303.43 2153." 2079.6' 15.50 10788.44 3750.50 MinPt-O-ADP 2386.01 2173.91 2068.35. 11.30 13427.33 3731.50 MinPt-O-ADP 2402.82 2177.60 2065.48 10.71 13952.90 3732.80 TD SP23-N3(P3)(Del Plan) Warning Alert 47.07 45.85 14.26 37.46 0.00 0.00 CtCt<=15m<15.00 Enter Alert 47.07 45.04 1426 22.57 200.00 200.00 MinPts 47.67 41.15 1486 7.12 600.66 599.59 MinPt.O-EOU 49.20 41.99 16.39 6.65 890.71 884.74 CtCt<=15m>15.00 Exit Alert 78.42 61.47 43.61 jjjjjjjjjjjgrz 1912.29 1833.23 MinPt-O-SF 77.20 62.06 44.3'jjjjjjjjjjjji;111 1936.20 1854.74 MinPt-O-SF 77.06 60.63 44.25 4.62 2118.71 2018.83 OSF<5.00 Enter Alert 73.19 54.67 40.3;jjjjjjjjjjjjj� 2261.22 2145.85 MinPt-OSF 72.81 53.95 40.0,jjjjjjjjjjjjjj 2289.40 2170.73 MinPt-O-SF 72.7 53.7, 39.'' 3.78 2303.45 2183.09 MinPts 72.91 53. 40.10 3.71 2326.77 2203.57 MinPt-O-EOU 73.97 54.09 41.16 1111111ES 2363.88 2235.98 MinPt-OSF 97.47 77.17 64.66 4.75 2531.50 2379.31 OSF>5.00 Exit Alert 355.95 333.52 322.801 1655 3371.10 2964.68 MinPt-O-SF 27 366.00 342.95 331.916.54 3435.56 2996.88 MinPt-O-SF 373.45 349.98 338.73 16.56 3487.04 3021.02 MinPt-O-SF 436.24 414.06 403.43 19.62 3872.13 3154.22 MinPt-O-SF 605.39 583.29 572.58 27.35 4379.73 3235.82 MinPt-O-SF 886.65 845.10 824.82. 21.83 4731.42 3288.46 MinPt-O-SF 2109.77 2034.91 1997.97 28.5 6723.60 3578.37 MinPt-O-SF 2098.70 2026.231 1990. 29.34 7211.37 3634.47 MinPt-O-ADP 2097.821 2026.0 1990.61 29.61 7287.93 3642.12 MinPt-O-EOU 2156.37 2072.42 2030.9 mosEE 8229.38 3725.10 MinPt-O-SF 2165.1.jjjjjjin1176 2040.52 26.26 8604.57 3733.73 MinPt-O-EOU 2166.01 2081.'. .1 26.04 8627.39 3733.36 MinPt-O-ADP 2396.83 2206.54 2111.88 12.66 13952.90 3732.60 TD 1 OP09-S1(Def Survey) Warning Alert 557.25 440.45 385.13 4.98 5639.81 342445 OSF<5.00 Enter Alert 391291 274.65 216.82 3.37 6140.00 3498.56 MinPt-CtCt 374.29 168.281 65.761 1.821 6953.08 360624 MinPts SP22-FN1(P2)(Del Plan) Warning Alert 55.16 53.94 22.36 44.07 0.00 0.00 Surface 49.09 45.05 16.28 11.85 424.34 424.18 CtCt<=15m<15.00 Enter Alert 46.99 40.99 14.18 7.62 497.56 497.15 MinPts 47.12 40.83 14.31 7.30 512.04 511.55 MinPt-O-EOU 48.93 41.97 16.12 6.86 550.32 549.62 CtCt<=15m>15.00 Exit Alert 49.77 42.66 16.96® 559.81 559.05 MinPt-O-SF 7331.73 7310.49 7298.9.1jjjjjjjjj 6 2292.32 2173.31 MinPt-O-SF 3826.98 3804.78 3794.1 ® 2565.31 2407.51 MinPt-O-SF 3410.52 3324.02 3281.26381.47 3532.85 MinPt-O-SF i 3367.92 3285.1...Ban 41.17 6811.36 3589.31 MinPt-O-ADP 3367.7.ljjjjjj3244.33 4126 6825.37 3591.03 MinPt-O-EOU MEM 3285.36 3244.79 41.50 6860.44 3595.28 MinPt-CtCt 1061.69 848.12 741.83 499 13934.53 3732.58 OSF<5.00 Enter Alert 1054.93 840.85 734.30 4.95 13952.90 3732.60 OSF>5.00 Exit Alert 18838.24 18813.32 18801. 786 74 809.93 805.87 MinPt-0SF 18760.40 18735.57 18723.6 786 74 812.27 808.17 MinPt-O-SF 18677.70 18652.98 18641.11 786 73 814.78 810.62 MinPt-0SF 18599.89 18575.27 18563 45 786 73 817.17 812.96 MinPt-0SF 18517.23 18492.71 18480.95 786 75 819.72 815.45 MinPt-OSF 18757.23 16735.04 16724.42 754.94 879.77 874.08 MinPt-0SF 15152.71 15132.75 15119.9 759.06 946.16 938.56 MinPt-O-SF 15008.73 14988.93 14975 92 758.20 952.78 944.98 MinPt-OSF 14931.98 14912.33 14899.17 759.73 956.36 948.44 MinPt-O-SF 14845.67 14828.15 14812 86 760.1 960.43 952.38 MinPt-0SF 14759.40 14740.00 14726 60 760.61 964.55 956.36 MinPt-OSF 13427.64 13410.12 13394.8 766.1 1034.48 1023.75 MinPt-O-SF 13327.86 13310.47 13295.0 766 38 1040.26 1029.30 MinPt-0SF 13228.14 13210.88 13195.3 766 61 1046.12 1034.92 MinPt-OSF 13123.74 13106.63 13090.9 766 801 1052.35 1040.89 MinPl-OSF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 2 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status r Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major • 13019.43 13002.45 12986.6 766.93 1058.67 1046.95 MinPt-OSF 12915.19 12898.36 12882.391 767.00 106508 1053.09 MinPt-OSF 12811.04 12794.34 12778.24 767.00 1071.59 1059.32 MinPt-O-SF 12706.98 12690.41 12674.17766 931 1078.19 1065.63 MinPt-O-SF 12598.27 12581.84 1256546 766 761 1085.20 1072.33 MinPt-0SF 12489.86 12473.37 12456.85 766.501 1092.33 1079.13 MinPt-O-SF 15144 54 15117.14 15103.94 573 371 2411.51 2277.25 MinPt-O-SF SP33-W3(P2)(Def Plan) Pass 56.03 54.80 23.22 44.78 000 0.00 Surface rt' 54.00® 27.00 200.00 200.00 MinPts 56...MIIIM 23.23 26.73 219.96 219.96 MinPt-O-EOU 56.8•imig 23.84 21.33 344.70 344.67 MinPt-O-EOU 59.38® 26.57 9.91 494.33 493.93 MinPt-O-EOU 83.31 55.57 30.50=LIM 599.08 598.02 MinPt-0SF 822.71 800.51 789.9. firE 3446.47 3002.12 MinP1-0SF 134504 1275.11 1240.6 MILLE 5567.89 3413.67 MinPt-OSF 3468 89 3367.27 3316,96 34.46 8999.99 3742.36 MinPt-CtCt 3469.60 3366.58 3315.56 33.99 9079.98 3745.11 MinPt-O-EOU ) 347075 3366.8 MEE 33.71 9130.57 3746.80 MinPt-O-ADP 3482.56 3371...® 31.49 9539.16 3746.35 MinP1-0-ADP 3487.93 3372.7•i® 30.53 9724.08 3745.39 MinPt-O-ADP 3497.83 3375.86® 28.90 10057.04 3748.98 MinPt-0-ADP 3520,01 338165 MERE 25.62 10817.45 375060 MinP1-0-ADP 3534.71 3385.64 MatiMt 23.86 11302.38 3766.15 MinP1-0-ADP 3537.0 3386.02 3311,00 23.57 1138406 3765.80 MinPt-O-EOU 3611.03 3397.46 3291.17 16.98 13952.90 3732.60 TD SI19-FN2(P2)(Def Plan) Pass 79.13 77.91 46.32 63.65 0.00 0.00 Surface 68.54 61.81 35.73 1000 53625 535.63 MinPts 68.70 61.60 35.89 9.51 555.29 554.56 MinPt-0-EOU 70.49 62.72 37.69 8.92 592.99 591.97 MinPt-OSF 4954.52 4932.32 4921.71 223.13 2556.35 2400.06 MinPt-OSF 3703.83 3616.80 3573.78 43.03 6478.67 3546.20 MinPt-O-SF 3623.11 3542.44 3502.61 45.46 7015,76 3613.41 MinPt-O-ADP 3622.731 3542.3 3502.68 45.63 7033.25 3615,38 MinPt-O-EOU 1 3622.3"11 3542.73 3503.40 46.04 7074.12 3619.91 MinPt-CtC1 2093.86 1877.57 1769.91 9.72 13952.90 3732.60 TD 1298421 12967.71 12951. ..11.5:31 1013.29 1003.38 MinPt-O-SF 12887.48 12871.04 12854.6'mum 1018.48 1008.37 MinPt-O-SF 12810.08 12793,73 12777.2 mgmE 102268 1012.41 MinPt-OSF 12698.90 12682.67 12666.0•.: 6 1028.79 1018.28 MinP1-0SF SI17-SE2(P2)(Def Plan) pass 10316 101.94 70.36 83.29 0.00 0.00 Surface 88.84 80.88 56.03 11.01 568.59 567.76 MinPts 89.00 8073 56.19 10.61 582.53 581.60 MinPt-O-EOU 89.46 80.96 56.65 mom 596.37 595.33 MinPt-OSF 2391.33 2369.25 2358.52 J 3031,38 2761.34 MInP1-0SF 2218.54 2184.91 2168.58 67.93 3588.40 3064,33 TD 1565.22 1514.69 1489.92 MEM 3169.40 2850,42 MinPt-O-SF 1560.04 1509.911 1485.33 3172 3187.93 2861.73 MinPt-O-ADP 1560.01 1509.9 1485.33 31.73 3188.73 2862.22 MinPt-O-EOU L 1560.00$ 1509.91 1485.35 31.75 3189.53 2862.70 MinPt-CtCt S135-W4(P2)(Del Plan) Pass- 72.02 70.79 39.21 57.84 0.00 0.00 Surface 72.02 69.99 39.21 34.88 200.00 200.00 MinPts 72.02 8998 39.22 34.71 209.98 20998 MinPt-O-EOU 90.44 82.67 57.63 MilK0 598.21 597.15 MinPt-O-SF 361.30 349.54 328.5. ilill 1466.93 1428.74 MinPt-O-SF 1035.09 1012.94 1002.28 46.69 3766.36 3126.26 MinPt-O-SF 1418.78 1354.49 1322.:•� U6 5660.81 3427.59 MinPt-O-SF 4526.31 4440.05 4397.42 53.07 8314.40 3731.24 MinPt-CtCt 4526.3 4440.04 4397.40 53.06 8319.14 3731.51 MinPt-O-EOU 4526.34 4440.05 4397. 53.05 8321.51 3731.64 MinPt-O-ADP 4728.86 4547.7 4457.6 26.24 12891.39 3734.33 MinPt-O-ADP 4736.54 4551.39 4459.3 25.71 13067.91 3732.77 MinPt-O-ADP 4774.74 4567.41 4464.24 23.14 13952.90 3732.60 TD 12364.82 12249.11 12191.751 107 77f 1906.34 1827.87 MinP1-0SF 12331.16 12215.77 12158.561 107 771 1918.50 1838.81 MinPt-O-SF 12406.15 12290.04 12232 48 107.751 1943.59 1861.38 MinPt-O-SF 12432.48 12316.12 12258.",`,.Ip107.751 1945.32 1862.93 MinPt-O-SF 5037-DSP1 current(Non-Def Survey) Pass 95.22 85.73 62.41 9.90 324.93 324.91 MinPts 96 16 83.15 65.35 6.46 542.58 541.93 MinPt-0-EOU 106.66 88.23 73.85 liEg 693.75 691.66 MinPt-0SF 1559.27 1544.19 1526.46=ME 3331.15 2943.64 MinPt-0SF 3111.19 3096.95 3078.38 218.45 3731.46 3115.57 TD S120-N4(P4)(Def Plan) Pass 71.10 69.87 38.29 57.09 0.00 0.00 Surface 71,10 69.07 38.29 34.41 200.00 200.00 MinPts 711 69.02 3636 3250 270.16 270.16 MinPt-O-EOU 73.55 67.36 4074 11.68 566.02 565.21 MinPt-O-EOU 74.07 67.39 41.26 10.91 601.12 600.03 MinPt-OSF 99.75 8825 66.95 8.56 1402.74 1369.86 MinP1-0SF 116.45 103.24 83E41 8.721 1766,68 1701.78 MinPt-OSF 118.61 105.16 85.8 8.731 1806,36 1737.68 MinPl-OSF 606.71 594.92 573. 51.391 2718.63 2531.65 MinPt-O-SF • Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 3 of 11 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 2020.04 1997.86 1987.2 91.01 3406.52 2982.64 MinPt-O-SF 2285.11 2258.28 2245.36 88.3 3565.92 3055.21 MinPt-O-SF •• 2918.30 2882.58 286521 83.98 4007.66 3180.12 MinPt-0-SF • 2990.08 2953.51 2935.7. 84.011 4052.04 3186.76 MinPt-O-SF 3911.43 3840.46 3805.46 55 88 6794.65 3587.26 MinPt-O-SF 3796.41 3731.66 3699.7: 59 52 7424.61 3654.92 MinPt-O-ADP 3796.2 3731.63 3699.81 59 64 7435.20 3655.86 MinP1-0-EOU 3799.3 3720.36 3681.341 4868i1 8225.44 3724.75 MinPta 3605.65 3418.13 3324.87 19 32 13952.90 3732.60 TD 8273.90 8253.13 8241. 358.39 1281.88 1258.07 MinPt-0SF 7336.12 7316.61 7303.31 376.11 1380.93 1349.82 MinPt-0SF 6870.35 6851.53 6837. 365.09 1489.25 1449.18 MinPt-0SF 6410.55 6392.38 6377.7 352.63. 1614.04 1563.14 MinPt-O-SF 5512.23 5495.06 5479.42 320.86 1988.16 1901.48 MinPt-O-SF 6435.67 6417.04 6402.86 345 461 2281.94 2164.16 MinPt-O-SF 6913.68 6894.49 6880.87 360.201 2359.55 2232.21 MinPt-O-SF 7398.08 7378.36 7365.27 375.14 2412.99 2278.52 MinPt-O-SF 8372.78 8352.05 8339.97 403.95 2489.23 2343.69 MinPt-O-SF S120-N4PS1(PI)(Del Plan) Pap 71.10 69.87 38.29 57.09 0.00 0.00 Surface 71.10 69.07 38.29 34.41 200.00 200.00 MinPts 71.17 69.02 38.36 3250 270.16 270.16 MinPt-O-EOU 73.55 67.36 40 74 11.68 566.02 565.21 MinPt-O-EOU 74.07 67.39 41 26 IMMI1 601.12 600.03 MinPt-O-SF 99.75 88.26 66.95® 1402.74 1369.86 MinPt-O-SF 116.71 103.47 83.94 MIME 1771.64 1706.28 MinPt-O-SF 118.61 105.16 85.801132 1808.36 1737.68 MinPt-O-SF 1586.36 1553.45 1533.55 121.20 3331.89 2944.04 TD SP16-FN3(P2)(Oaf Plan) Pap • 111.09 109.86 78.28 89.76 0.00 0.00 Surface I 99.19 91.68 66.38 13.04 574.45 573.58 MinPts 99.33 91.54 66.52 12.60 588.53 587.56 MinPt-O-EOU 99.69 91.78 66.88® 602.53 601.44 MinPt-OSF 4083.17 3996.36 3953.,'- 6595.37 3561.81 MinPt-O-SF 3935.52 3858.881 52.01 7257.17 3639.09 MInPt-O-ADP 3934 99® 3821.16 52.29 7276.57 3641.01 MinPt-O-EOU i mom 3859.17 3821.87 52.87 7315.42 3644.79 MinPt-CtCt 3250.41 3033.50 2925.54 15.05 13952.90 3732.60 TD 10432.68 10418.49 10399.87L 734.861 1129.26 1114.32 MinPt-O-SF SP36-745(P2)(Def Plan) Pap 80.07 78.04 47.27 38 85 200.00 200.00 MinPts 80.08 7804 47.27 38.75 204.99 204.99 M1nPI-0-EOU 101.46 93.79 68.65 Min 597.85 596.80 MinPt-O-SF 391.70 379.66 358.•0 mg's' 145745 1420.05 MinPt-0SF 1004.27 986.56 971. mil 3466.22 3011.43 MinPt-O-SF 1056.70 1034.54 1023.8.MUT. 3907.59 3162.08 . MinPt-0SF 1500.81 1438.22 1407.41 ME10 5606.16 3419.41 MinPt-O-SF 5469.04 5427.13 66.25 8265.13 3727.99 MinPt-CtCt 5553.8 ='4' 5427.05 66.19 8275.74 3728.76 MinPt-O-EOU 5553.92 5469.01 66.16 8282.11 3729.20 MinP1-0-ADP mmiliz.�: .,t: ' 62.51 8689.54 3732.95 MinPts 5597.55 5493.4.:,, 54.26 9506.51 3746.52 MinPt-0-ADP 5602.33 5495.01 IIIMER 52.68 9671.42 3745.67 MinP1-0-ADP 5603.93 5495.5 Nigall 52.16 9726.32 3745.38 MinPt-0-ADP 561368 5498.6 MMIER 49.22 10052.74 3748.92 MinPt-0-ADP 5615.16 5499. 4 1111=511 48.83 1010272 3749.53 MinPt-O-ADP 5635.25 5504.2. 43.34 10795.42 3750.50 MinP1-0-ADP 5722.21 5418.51 28.35 13793.25 3732.26 MinPt-0-EOU 5723.09 5519.56 1: 28.25 13823.23 3732.33 MinPt-O-ADP 5725.01=En 5417.72 2003 13888.20 3732.46 MinPt-0{OU 5726.91 5520.12 5417.21 27.82 13952.90 3732.60 TD 13699.72 13562.21 13493.• NM= 1961.67 1877.64 MinPt-0SF 13716.84 13579.02 13510.74 100.3: 1772.05 1706.64 MinPt-O-SF I 13276.88 13143.74 13077 751 100 53 1933.24 1852.07 MinPte SD37-DSP1(P4b)(Def Plan) Pass 96.70 94.80 63.89 50.44 195.45 195.45 MinPts 97.16 94.44 64.35 35.31 354.80 354.76 MinPl-O-EOU 97. 94.49 65.13 28.04 429.22 429.05 MinPt-O-EOU 102.98 97.48 70.17 mals 601.63 600.55 MinPt-O-SF 4024.40 4008.48 3991.59 252.69 3828.65 3143.54 TD S113-FN4(P2)(Def Plan) Pass 135.07 133.84 102.26 109.35 0.00 0.00 Surface 122.90 115.07 90.09 15.54 588.75 587.77 MinPts 122.93 114.98 90.12 15.31 598.09 597.03 MinPt-O-EOU 123.05 115.08 90.24 607.39 606.25 MinPt-O-SF 4413.74 4327.76 4285.26 MHZ 6718.38 3577.71 MinPt-OSF 4222.7.main 4086.54 46.83 8265.29 3728.00 MinPt-O-EOU MEM 4132.69 4088.7311.31M 48.00 8386.01 3734.44 MInPt-CtCt IIESHE 4117.67 4070.91 45.03 8746.16 3733.72 MinPt-CtCt 4104.18 4050.24 39.04 9528.49 3748.42 MinPl-CtCt 4247.5. 4083.98 4002.70 26.12 11846.26 3762.40 MinPt-O-EOU 4277.85 408860 3994.46 22.72 12853.36 3735.69 MinPt-O-ADP 4326.86 4109.34 400106 19.98 13952.90 3732.60 TD SP12-SE3(P2)(Def Plan) Pass 158.21 156.99 125.40 128.26 0.00 0.00 Surface 145.98 137.58 113.17 17.24 592.58 591.57 MinPts 145. 137.57 113.19 17.18 597.19 596.14 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 4 of 11 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 146.26 137.80 113.46 1713 615.53 614.32 MinPt-OSF 2451.70 2436.74 2418.90 163.804 2288.66 2170.08 MinPt-O-SF 2551.85 2529.69 2519. 115.1,`,1` 2746.24 2553.29 MinPt-O-SF 2524.57 2490.05 2473.29 75.26 2872.66 2649.19 TD 2480.28 2423.16 2395.0 44.16 2755.81 2560.73 MinPt-O-SF 2384.97 2335.22 2310 48.88 2796.51 2592.06 MinPt-O-ADP • 2384.72335 16 2310.88 49.08 2797.54 2592.85 MinP1-0-EOU I 2384.47 2335 39 2311.34 49.55 2799.99 2594.72 MinPl-CtCt SP1O-FN5(P2)(Def Plan) Paas 17432 173.09 141.51 14142 0.00 0.00 Surface 164.83 156.89 132.02 20.60 589.06 588.07 MinPts 16487 156.80 13206 20.30 598.38 597.32 MinPt-O-EOU 165.14 157.05 132.33 20 26 618.92 615.69 MinPt-0SF 485619 4771.44 4729.56L 57.96 6842.20 3593.08 MinPt-O-SF 5464 01 5246.55 5138.31 25.24 13952.90 3732.60 TD .11784 29 1772.29 1751.48 148.6 1529.34 1485.85 MinPts S114-N6(P2)(Def Plan) Pass 127.07 125.84 94.26 102.82 0.00 0.00 Surface 127.07 125.0494.26 61.98 200.00 200.00 MinPts 127.1 124.99 94.33 58.51 270.29 270.28 MinPt-O-EOU 12951 123.32 96.70 20.70 566.84 566.03 MinPt-O-EOU 182.56 163.99 149.75 9.77 1939.50 1857.70 MinPt-O-SF 6918.81 6830.17 6786.34 78.9 6423.93 3538.72 MinPt-O-SF 6207.59 6138.11 6103.86 90.61 7446.86 3656.89 MinPt-O-ADP 6207:21 6138.101 6103.88 90.69 745141 3657.29 MinPt-O-EOU 6209. 6125.50 608406 74.91 8241.36 3726.11 MinPt-CtCt 6012.09 581967 5723.96 31.40/ 13952.90 3732.60 TD 4952.68 4916.73 4899.25 141.63 2002.96 1914.79 MinPt-OF 448458 4452.08 4436.32 142.28 2185.22 2078.32 MinPt-O-SF 4369.85 4338.16 432280 142.28 2220.22 2109.49 MinPt-O-SF 3780.45 3750.25 3735.64 129 37 2358.34 2231.15 MinPt-O-SF 3531.86 3504.16 3490.811 132.181 2392.61 2260.92 MinPt-O-SF 3176.91 3154.75 3144.111 143.281 2441.92 2303.38 MinPt-O-SF 1344.62 1328.511 1311.81 83.45 2673.72 2495,96 MinPte S108-FN6(P2)(Def Plan) Pass 184.85 178.66 152.04 29.69 621.42 620.16 MinPts 184.85 178.66 152.04 29.65 626.15 624.84 MinPt-O-EOU 185.97 179.70 153.1j44444444444�T, 682.14 680.20 MinPt-O-SF 188.11 181.76 155.31111M13 718.62 716.18 MinPt-O-SF 5168.23 5086.08 5045. r 63.66 6977.94 3609.11 MinPt-O-SF 6609.10 6393.33 628594 30.77 13952.90 3732.60 TD 10007.64 9939.52 9905.96 149.05 4889.08 3312.06 MinPt-O-SF 19526.53 19501.50 19489.47 81180 729.80 727.19 MinPt-O-SF 19449.00 19424.06 19412.08 81177 731.60 728.96 MinP1-0-6F 19366.65 19341.81 19329.88 811.76 733.52 730.85 MinP1-0-SF 19284.32 19259.58 19247.701 81176 735.46 732.76 MinPt-O-SF 19202.01 19177.37 19165.55_ 811.77 737.41 734.68 MinPt-O-SF 19114.88 19090.36 19078.58 811.8 739.49 736.73 MinPt-O-SF 17296.37 17274.17 17263.56 77922786.83 783.24 MinPt-O-SF 13006.77 12990.46 12973.96 797.49 939.78 932.38 MinPt-O-SF 12894.86 12878.70 12862.05 797.58 944.86 937.31 MinPt-O-SF 1277844 12762.42 12745.8 797.56 950.23 942.50 MinPt-O-SF 12666.82 12850.93 12634.01 797. 955.45 947.55 MinPt-O-SF 1 1750.281 1738.131 1717.47 143.98 1616.91 1565.76 MinPts 8107-SE4(P2)(Oaf Plan) Pass 198.21 196.99 165.40 160.94 0.00 0.00 Surface 192.79 185.21 159.98 25.29 546.15 545.47 MinPts 193.15 184.90 160.34 23.25 578.94 578.03 MinPI-0-EOU 193.88 185.31 161.071 22.461 602.02 600.93 MinP1-0SF 666.73 657.17 633.93 69.57 1159.02 1142.56 MinPt-O-SF 3130.06 3107.83 3097.25 140.80 2192.79 2085.07 MinPl-OSF 3313.06 3264.58 3240.83 69.73 2457.50 2316.71 MinPt-CtCt 3313.3 3264.23240.21 68.82 2459.02 2318.01 MinPt-O-EOU 3313.83 3264.36 324012 68.33 2459.85 2318.72 MinPt-O-ADP 3613.31 3546.05 3512.9 54.501 2510.75 2361.88 MinPt-O-SF 10341.29 10274.06 10240.94 156.10 2595.20 2432.20 TD SP18-N5(P4)(Def Plan) Pap 95.12 93.09 62.32 46.22 200.40 200.40 MinPts 96.60 90.16 63.79 14.81 561.83 561.05 MinPt-O-EOU 97.33 90.29 64.52 13.651 602.02 600.93 MinPt-O-SF 106.00 68.48 73.19 13.94 843.36 838.57 MinPt-O-SF 227.58 209.17 194.77 12.301 1936.23 1854.76 MinPt-O-SF 5196.14 5106.90 5062.78 58.87 6779.52 3585.38 MinPt-O-SF 5153.29 5064.81 5021.06_ 58.88 6852.22 3594.29 MinPt-O-SF 5138.06 5049.8001 5006.17 58.86 6880.72 3597.72 MinPt-O-SF 4995.35 4915 4875.32 6293 7420.30 3654.53 MinPt-O-ADP 4995. 4914. 4875.37 63.11 7432.95 3655.66 MinPI-0-EOU • 1_4994 4906.90 4863.63 57.69 7802.32 3687.87 MinPt-CtCt 4809.69 4596.80 4490.84 22.69 13952.90 3732.60 TD 5098.63 5071.42 5058.31 194.41 193546 1854.07 MinPt-O-SF 4906.50 4878.57 4865.1 182.0 2644.37 2472.33 MinPt-O-SF 1-6753.08 6720.67 6704.9 214.8 2838.97 262416 MinPts SP18-N5(P3)(Non-Def Plan) Pass 95.12 93.09 62.32 46 22 20040 200.40 MinPts 96.60 90.16 63.79 14.81 561.83 561.05 MinP1-0-EOU 97.33 90.29 64.52'4444444444441 ' 602.02 600.93 MinPt-O-SF 106.00 9848 73.1.mom 843.36 83857 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 5 of 11 , 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 227.58 209.17 194.77 12.30 1936.23 1854.76 MinPt-O-SF 5196.14 5106.90 5062.78 58.871 6779.52 3585.38 MinPt-O-SF 5153.29 5064.81 5021.06 58.881 6852.22 3594.29 MinPt-O-SF 5138.06 5049.80 5006.17 58.861 6880.72 3597.72 MinPt-O-SF 4995.35 4915.000 4875.32 62.93 7420.30 3654.53 MinPt-O-ADP 4995.06 4914.^94 4875.37 63.11 7432.95 3655.66 MinPt-O-EOU I 4994.44 4906.90 4863.63 57 69 7802.32 3687.87 MinPt-CtCt 4809.69 4596.80 4490.84 22.69 13952.90 3732.60 TD I! 5098.63 507142 5058.31.1111=11 1935.46 1854.07 MinPt-0-SF 4906.50 4878.57 4865.10 0 PFS 2644.37 2472.33 MinPt-O-SF F-6753 08 6720.6 Pd=gin 2838.97 2624.16 MinPts SP05-FN7(P2)(Def Plan) - Pass 222.32 221.10 189.51 180.64 0.00 0.00 Surface 218.62 211.64 185.81 31.15 53279 532.19 MinPts 219.02 211.24 186.22 27.97 575.50 574.62 MinPt-O-EOU 219.83 211.66 187.02 26.75 603.54 602.43 MinPt-O-SF 5607.47 5527.02 5487.29 70.55 7087.24 3621.35 MinPt-O-SF 7777.22 7561.62 7454.31 36.23 13952.90 3732.60 TD 15254.32 15232.13 15221.51 687.25 847.20 842.31 MinPt-O-SF 11885.71 11850.36 11832.90C_ 772.81 995.47 986.21 MinPt-O-SF I 11817.28 11802.00 11784.48 772.90 998.12 988.77 MinPt-O-SF ' 11876.07 11660.96 11643.26 772 55 1005.72 998.09 MinPt-O-SF , 11 1784.451 1782 921 1761.65 155 55 1504.43 1463.07 MinPts - Sx34-N Sand(P2)(Def Plan) Pass • 64.02 62.80 31.21 51.31 0.00 0.00 Surface • 64.02 61.99 31.21 3088 200.00 200.00 MinPts 64 20 61.75 31.39 25.71 299.77 299.76 MinPt-O-EOU 72.47 67.42 39.6 MEM 603.08 601.98 MinPt-O-SF 110.24 103.28 77.' .111113 1018.78 1008.66 MinPt-0SF 122.89 115.17 90.0,'a 1107.50 1093.61 MinPt-O-SF M."0 215.3 ,MCIE 12.40 3225.57 2884.22 MinPts 234. .=gem 201.41 12.35 3230.33 2887.01 MinPt-O-EOU i 242.21 222.06 209.40 minzi 3313.37 2934.02 MinPt-O-SF 2978.81 2899.04 2859.6 0000000051 6956.21 3606.60 MinPt-O-SF 2976.73 2883.56 2837.46 NEM 8229.39 3725.10 MinPt-0SF I 2978.21 2884.18 2837.67 32.00 8614.61 3733.55 MinPt-CtCt 2979. 2882.96 2835.200J 31.18 8672.32 3732.97 MinP1-0-EOU • 2980.16 2883. 2834.91 30.99 8686.75 3732.95 MinPt-0-ADP 2984.56 2884.6 2835.1 30.1511 8864.86 3737.72 MinPts SP04-SE5(P2)(Def Plan) Pass 22895 223.87 19614 4483 510.84 510.36 MinPts 229.27 22348 196.46 39.36 584.52 563.72 MinPt-O-EOU 232.07 225 74 199271 36.441 650.24 648.68 MinPt-0-SF 236.47 230.03 203 661 36 56 705.62 705.62 703.36 MinPt-0-SF 3743.39 3721.18 3710 581 168 501 2041.78 1949.72 MinPt-0-SF 5085.29 5011.02 4974.381 69 381 2375.02 2245.66 MinPt-O-SF 10842.58 10756.17 10713.46 126 91 2509.94 2361.19 TD 5102-SE6(P2)(Def Plan) Pass 246.19 244.97 213.38 200.14 0.00 0.00 Surface 246.19 244.16M13.38 120.65 200.00 200.00 MinPts • 246.80 243.62 213.99 7725 361.07 361.02 MinP1-0-EOU 248.01 243.69 215.21 57.08 425.86 425.69 MinPt-O-EOU 259.26 251.33 22645 MI= 599.55 598.48 MinPt-O-SF 5022.02 4999.81 4989.21 MEM 1806.34 1737.66 MinPt-O-SF 5492.84 5446.2 5423.57 12111 2064.31 1969.98 MinPI-0-EOU 5493.52 5446. 5423.3 119.29 2068.78 1974.00 MinPt-O-ADP 6578.84 6477.48 6427.291 65.5 .2299.11 2179.28 MinP1-0SF 11445.14 11324.10 11264.07 95.32 2435.54 2297.92 TD SP01-SE7(P2)(Def Plan) Pass 25430 253.08 221.49 206.77 0.00 0.00 Surface 254.07 251.29 221.26 90.88 346.23 346.19 MinPts 254.78 250.67 221.97 61.67 451.69 451.45 MinPt-O-EOU 262.35 256.06 229.54 mugs 603.70 602.59 MinPt-O-SF 6200.77 6178.55 6167.961 1763.19 1698.62 MinPt-0SF 8305.62 8184.89 8125 021 69.36 2285.73 2149.84 MinPt-0SF 11509.74 11367.32 11296.60 81.37 2362.54 2234.81 TD SP11-N7(P2)(Def Plan) Pass 166.24 165.02 133.43 134.82 0.00 0.00 Surface 166.24 164.21 133.43 81.28 200.00 200.00 MinPts 186.26 164.20 133.45 79.87 220.11 220.11 MinPt-O-EOU 177.13 170.24 144.33® MinPt-O-SF 601.42 198.34 190.85 165.53 863.86 858.57 ' MinPt-OSF 385.38 366.19 352.57 Min 1936.57 1855.07 MinP1-0SF 8175.03 8056.34 7997.49 69.44 6496.78 3548.65 MinPt-O-SF , 8170.19 8051.57 7992.75 M1 1M 6499.44 3549.01 MinPt-O-SF 7391.38 7303.:' 7260 56 -85.38 7431.49 3855.53 MinPt-0-ADP 7390.7.�: 7260.69 85.89 7445.68 3856.78 MinPt-O-EOU 7290 89 7239.36 71.75 8253.89 3727.13 MinPt-C1Ct 721256 699176 6881.85 32.81 13952.90 3732.60 TD 5519.66 546219 5433.9411 97.70 1873.93 1798.67 MinPt-0SF 5496.29 5439.06 5410.^s4 97.70 1884.13 1807.87 MinPt-O-SF 000000 1 15332811111115s. E;1111111111 5 2551.46 2395.99 MinPts Kigun 1(Def Survey) Pass 4971.38 4968.77 49'08571 1908.90 169.07 169.07 MinPis 4971.43 4968.65 4938.62 1790.13 199.07 199.07 MinPt-O-EOU ' 4971.04 4964.71=MN 785.86 863.88 858.60 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 6 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ftL Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 4971 92f 4964 351 4939 12 655.98 1121.87 1107.29 MinPt-O-EOU 5041 69 5026.50 5008 88115 1968.80 1884.06 MinPt-0SF 5011.12 4996.6' 4978 31 345.49 2085.11 1988.67 MinPt-O-EOU 1 4996.6 • 4978.31' 345.70 2086.82 1990.21 MinPts 1169.861 1088.61 22.56 7312.65 3644.52 MinPts 1169.88 111446 1088.60 22.55 7312.93 3644.55 MinPt-O-ADP 117126 1115.71 1089.781 7315.79 3644.82 MinPt-O-SF 5480.65 5441.68 5423.08 147.24 7746.88 3683.04 TD Klgun 1 P81(Def Survey) Pass 4971.38 4968.77 4938.5 1908.90 169.07 169.07 MinPts 4971.43 4968.65 4938.62 1790.13 199.07 199.07 MinPt-O-EOU 1 4971.04 4964.71 4938.21 785.86 863.88 858.60 MinPts 4971.92 496435 4939.12 655.98 1121.87 . 1107.29 MinPt-O-EOU 5041.69 5026.50 5008.••1 1968.80 188406 MinPt-O-SF 5011.1 4996.62 4978.31 345.49 2085.11 1988.67 MinPt-O-EOU 5011.1 4996.63 4978.31 345.70 2086.82 1990.21 MinPts 1481.10 1436.07 1415.06 35.181 7275.20 3640.88 MinPts Tuvaaq ST 1(Def Survey) Pass 4968 77 1908.90 169.07 169.07 MinPts 4® 4968.65 4938 62 1790.13 199.07 199.07 MinPt-O-EOU wan 4964.71 4938.23 785.86 863.88 858.60 MinPts 4971,92 4964.35 4939.12 655.98 1121.87 1107.29 MinPt-O-EOU 5041.69 5026.50 5008 88 Man 1968.80 1884.06 MinPt-O-SF 5011.121 4996.62 4978.31 345.49 2085.11 1988.67MinPt-O-EOU '®1 4996.63 4978 345.70 2086.82 1990.21 MinPts 61MEI:=1 1427.64 1397.96 25.05 8078.78 3711.97 MinPt-C1Ct 1491.611 1394.48 23.84 8195.39 3722.13 MinPt-O-EOU 1492.01 1425.751 23.71 8208.55 3723.28 MinPt-0-ADP 1498.64 1431.73 1399.961 8288.65 3729.65 MinPt-O-SF 1596.32 1525.20 1491. •Immes 8687.47 3732.95 MinPt-O-SF 1649.35 1576.40 1541.61 mgza 8857.04 3737.45 MinPt-O-SF 1738.73 1662.21 1625.6.mgaw 9142.92 3747.13 MinPt-O-SF 1814.81 1735.01 1696.7'11 9378.65 3747.18 MinPt-O-SF 1998.45 1909.90 1867,161] 9949.12 3747.67 MinPt-OSF 2033.67 1943.61 1900.10® 10037.97 3748.74 MinPt-0SF 2101.01 2008.38 1963. '.1111111=1 10201.13 3750.72 MinPt-O-SF 2402.87 2298.24 2247.221 10902.64 3752.60 MinPt-0SF 2418.82 2313.54 2262.18 10940.46 3754.01 MinPt-O-SF 2455.27 2348.50 2296.3 1 11025.40 3757.19 MinP1-0SF 2535.87 2425.72 2371. •1 11209.41 3764.08 MinPt-O-SF 2621.34 2508.72 2453.5 1 11361.97 3765.97 MinPt-O-SF 2853.49 2732.09 2672.3r MEM 11851.24 3762.36 MinPt-O-SF 3067.59 2938.05 2874.1 1 12306.00 3759.05 MinPt-O-SF 3196.90 3063.30 2997.311 12556.49 3749.64 MinPt-O-SF 3334.19 3196.83 3128.9 1 12967.09 3733.13 MinPt-O-SF 3529,54 3388.29 3318.4 11 13429.02 373150 MinPt-0SF 3782.92 3636.66 3564.34 26.14 13952.90 3732.60 TO OP14-S3(Def Survey) , Pees 14386.03 14354.48 14340.06=an 3750.68 312154 MinPt-OSF 1 2213.24 196648 1846.66 9.21 6939.04 3604.61 MinPt-CtCt 221469 1964.97 1843.61 9.10 6982.60 3609.64 MinPt-O-EOU 2216.01 1965,23 1843.32 9.06 6998.69 3811.48 MinPt-0-ADP 2231.64 1975.01 1850.02 8.901 7092.86 3621.96 MinPt-O-SF 0115-S4(P5)(Def Plan) Pass 1 3387.39 3102.28 2962.71 12.11 7081.94 3620.77 MinPt-CtCt 3390.15 3099.37 _ 2956.86 11.87 7143.00 3627,35 MinPt-O-EOU 3391.45 3099.50 2956.381 11.831 7156.06 3628.73 MlnPts OP10-09(Def Survey) Pass 1 17855.26 17854.0 17822.41 14587.13 0.97 0.97 MinPts 1785569 178532 17822.88 738274 213.35 213.35 MinPt-O-EOU 17855.68 17853.2 17822.871 7419.24 216.07 216.07 MinPts 4712.32 4463.38 4341.82 19.36 6841.52 3592.99 MinPt-CtCt 4716.34 4455.94 4328.49 18.48 6952.73 3606.20 MinPI-CICt 4718.33 4454.39 4325.10 18.23 6988.54 3610.32 MinPt-O-EOU 4723.54 4455.22 4323.67 17.93 7034.26 361549 MinPt-O-ADP 4927.87 4633.39 4488.18 16.951 7353.37 3648.39 MinPt-O-SF 0113-03(P6)(Def Plan) Peas 1 624292 6021.33 5912.99 28.79 6873.57 3596.86 MinPt-CtCt 6243.39 6020.87 5912.04 28.86 6893.33 3599.22 ' MinPt-O{00 6244.00 6020.99 5911.901 28.60 6903.79 3600.46 MinPt-O-ADP 1 6555.5 6303.72 6179.15 26.30 8326.58 3731.91 MinPt-CtCt 6555.6611 6303.581 6178.84 2627 8347.53 3732.95 MinPt-O-EOU 6555.86 6303.6`"11 6178.80 26.25 8358.95 3733.44 MinPt-0-ADP 6569.55 6314.40 6188.07 25.99 8667.73 3732.99 M1nPt-OSF 6588.69 6325.10 6194.57 25.23 9545.67 3746.32 MinPt-0-SF OP12-01(Def Survey) Pass 1 17857.34 17854.601 17824.49 6621.821 200.13 200.13 MinPts 7064.87 6943.58 6886.14 61.44 5887.16 3461.41 TD 1 17857.301 17854.611 17824.49 6629.731 19951 199.51 MinPts OP17-02(Def Survey) Pass 7869.101 17867.49f.0111 11121.56 114.82 114.82 MinPts 17869.2 MITNEI 17836.41 9755.40 140.85 140.85 MinPt-O-EOU 17869.3 17866.9'MEMO 7613.69 218.81 218.81 MinPts 17869.41 17867.06 17836 60 MIME 225.10 225.10 MinPt-0SF 17870 23 17868 12 17837 42 Moan 246.00 246.00 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 7 of 11 Offset Trajectory Separation Allow Sep. Reference TrajectorySeparation Factor Alert Statue Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 7727.29 7459.77 7327.90 29.28 6984.84 3609.90 MinPt-CtOt 7727.60 7459.46 7327.27 29.21 6990.80 3610.58 MinPt-0-EOU 7727.99 7459.54 7327.18 29.18 6993.78 3610.92 MinPt-O-ADP 7846 73 7565.41 7426.40 28.211 7123.54 362527 MinPt-O-SF OP17-02PB1(Det Survey) Pass 17869.1 17867.4 17836.2 10794.49 114.82 114.82 MinPts 17869. 17867.3 17836.41 9562.87 140.85 140.85 MinPt-O-EOU 17869.42 17867.05 17836.61 7547.9 213.37 213.37 MinPt-O-SF I 17869.34 17866.951 17836.51 7553.61 218.81 218.81 MinPts • 17869.41 17867.04 17836.6 7549.691 225.10 225.09 MinPt-O-SF ' 1 7783.32 7523.04 7394.89 30 35 6913.67 3601.63 MinPtCtCt • 7783.78 7522.54 7393.90 30.24 6922.48 3602.67 MinPt-O-EOU • 7784.45 752268 7393.77 30.18 6927.38 360324 MinPt-O-ADP 8003.48 7708.99 7563.13 27.431 7267.37 3640.10 MinPt-O-SF Oliktok Point 1-2(Def Survey) Pess 17842.26 17840.05 17809.4) 8099.8511 243.07 243.07 MinPt-O-SF 17150.64 17128.37 17117 831 777.901 3600.93 3069.28 MinPt-O-SF 1 7876 86' 7715.941 7638.31 50 70 6116.79 3495.19 MinPts Nikaitchuq 4(Def Survey) Pass 8243.09 8241.15 8210.26 4242.89 52.90 52.90 MinPts 8243.12 8241.13 8210.31 4129.36 67.84 67.04 MinPt-O-EOU I 8221.15 8206.69 8188 341 568.88 1975.79 1890.35 MinPts 8221.15 8206.89 8188.34 568.71 1976.47 1890.95 MinPt-O-EOU 8224.08 8209.43 8191.251 562 471 2004.64 1916.31 MinPt-0SF 8248.80 8232.05 8213.791 566.681 2066.36 1971.83 MinPt-O-SF 8255.16 8240.58 8222.36 566.011 2080.85 1984.85 MinPt-O-SF 8015.86 7993.39 7983.051 356.67 2258.56 2143.49 MinPt-OSF 795726 7933.27 7922.23 360.43 2259.41 2144.24 TD 7728.39 7681.77 7659.421 172.85 2169.84 206459 MinPt-O-ADP 7728.22 7681.74 7659.46 173.39 2170.45 2065.14 MinPt-O-EOU 1 7728.07 7681 87 7659.73 174.48 2171.62 2066.18 MinPt-CtCt OPO4-07(Def Survey) Paas I 17844.61 17843 38 17811.801 14578.42 0.74 0.74 MinPts 17844.92 17842.5 17812.11 7474.38 214.78 214.78 MinPt-O-EOU I17844.91 17842.5 17812.11 7488.99 216.14 216.14 MinPts 17845.51 17843.16 17812.70 7597.54 243.07 24306 MinPt-O-SF 16281.57 16255.99 16244.04 680.65 3684.36 3100.00 TD Nikaitchuq 3PB1(Def Survey) Pass MIME 7993.1 7962.3 4115.11 52.90 52.90 MinPts 7941.37 7926.66 7908.57 539.911 1996.80 190925 MinPt-O-SF 7941.34 7926.63 7908.53 540.14 2000.85 1912.89 MinPt-O-EOU 7941.34 7926.64 7908.53 540.64 2003.58 1915.35 MinPts 8699.90 8685.75 8667." 614 69' 2502.48 2354.90 MinPt-O-SF 10190.97 1017484 10158.16 2781.68 2580.71 MinPt-0-SF 11025 54 11006.72 10992.7•- 2812.30 2604.07 MinPt-O-SF Nikaitchuq 3PB2(Def Survey) Pass 7993.1•mom 4115.11 52.90 52.90 MinPts 7941.37 7926.66 7908.57 1996.80 1909.25 MinPt-O-SF 7941.34 7926.63 7908.53 540.14 2000.85 1912.89 MinPt-O-EOU 7941.341 7926.64 7908.53 540.64 2003.58 1915.35 MinPts 8699.90 8685.75 8667.0 614.6 2502.48 235490 MinPt-O-SF 10573.17 10555.64 10540.36 603.19 2797.68 2592.96 TD Imo• 10560 =gm 603.04 2797.68 2592.96 MinPts Nike6chuq 3PB3(Def Survey) Pass 3 1, 7993.1,MEM 4115.11 5290 52.90 MinPts 7941.37 7926.66 7908.57 MEMO 1996.80 1909.25 MinPt-OSF 7941.34 7926.63 790853 540.14 2000.85 1912.89 MinPI.0-EOU 1 MEM 7926.64 7908.53 540.64 2003.58 1915.35 MinPts 8699.90 8685.75 8667.09 614.69 2502.48 2354.90 MinPt-O-SF 10796.03 10778.31 10763.23 609.08 2780.40 2579.73 MinPt-O-SF 10935.42 1091747 10902.61® 2781.40 2580.50 MinPt-OSF 11157.41 11139.02 11124.61:® 2782.29 2581.18 MinPt-O-SF 11206.22 11187.73 11173.41 606.07 2782.43 2581.29 MinPt-O-SF Nikaitchuq 4PB1(Def Survey) Pate 8243,09) 8241.1 4242.89 52.90 52.90 MinPts 8243.1 I r. 8210.31 4129.36 67.84 67.84 MinPt-O-EOU 1 .• M3111111 8206.69 NE= 568.88 1975.79 1890.35 MinPts i 8221.15 8206.69 8188.34 568.71 1976.47 1890.95 MinPt-O-EOU 8224.06 8209.43 8191.251 2004.64 1916.31 MinPt-O-SF 8246.60 8232.05 8213.7' 566.6. 2066.36 1971.83 MinPt-OSF 8255.16 8240.58 8222.36 566.01 2080.85 1984.85 MinPt-O-SF 8582.30 8568.03 8549.49 6D1.52 2320.60 2198.15 TD OP08-04(Def Survey) Pass 10800.60 10763.33 10746.991 330.3211 3561.47 3053.38 MinPt-O-SF 1 8709.43 8662.971 8642.62 213.78 3867.90 315323 MinPts 0124-08(P9)(Def Plan) Pass 1 8935.41 8665.87 8532.84 33.57 6898.41 3599.82 MinPt-CtCt 8937.43 866379 8528.66 3306 693524 3604.16 MinPt-O-EOU 8939.97 8664.32 8528.15 32.81 6953.65 3606.31 MinPt-O-ADP 8945.68 8667.06 8529.36 32.471 6981.24 3609.49 MinPt-O-SF Dill-S1(Def Survey) Pass VA M�.r'', 14588.40 0.85 0.85 MinPts 17854.58', '�'' 7391.77 20385 203.85 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 8 of 11 Offset Trajectory r Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft)... Fact. MD(ft) I TVD(ft) Alert I Minor I Major 8893.42 8829.69 8800.72 153.36 4879.92 3310.69 MinPts OPO4-07P81(Def Survey) Pass 17844.6117843 38 17811.801 14578.42 0.74 0.74 MinPts 17844.92 17842.53 17812.11 7474.38 214.78 21478 MinPt-O-EOU 17844.91' 17842.53 17812.11 7488.99 216.14 216.14 MinPts 17845.51 17843.16 17812.70 7597.54) 243.07 243.06 MinPt-O-SF 16281.57 16256.00 1624404 680.69 3684.36 3100.00 TD 0107-04(Oef Survey) Pass 16946.76 16920.98 16908.79 695.03 3675.59 3096.96 TD 13214.84 13172.50 13152.96 Ma111 3396.36 297755 MinPt-0-SF 13621.36 13579.83 13560.6.�1 3425.41 2991.96 MinPt-0SF 13872.07 13830.01 13810.46 MEE 3441.82 2999.89 MinPt-O-SF 14942.16 14901.49 14882.•.m., 3525.65 3038.19 MinPt-0-SF 15101.41 15060.46 15041.1:MIMi 3538.71 3043.81 MinPt-O-SF OP18-08(Daf Survey) Peas I 9661.71 9349.28 9193.86 31.08 7365.31 3649.51 MinPt-CtCt 9661.78 9349.17 9193.65 31.06 7367.80 3649.74 MinPt-O-EOU 9661.92 9349.19 9193.61 31.05 7369.46 3649.89 MinPt-O-ADP 9683.97 9368.54 9211.54 30141 7407.02 3653.33 MinPt-O-SF OP18-08PB2(Def Survey) Pass I 9819.251 9525.25 9379.381 33.65 7135.16 3626.52 MinPts Oliktok Point I-2PB2(Def Survey) Pass 17841.91 17839.70 17809.10 8103.75 233.93 233.93 MinPt-0SF 17842.26 17840.06 17809.45 8104.14 243.07 24307 MinPt-0SF 17842.33 17840.22 17809.5 24483 244.83 MinPt-0SF 17149.50 17127.23 17116.69 777.81 3601.49 3069.50 MinPt-0-SF 1 10283.701 10165.001 10108.04 90.23 5817.44 3451.02 MinPts OP16-03(Def Survey) Pass 11018.69 10775.82 10655.82 45.90 6732.59 3579.51 MinPt-CtCt 11017.90 10771.52 10649.72 45.22 6761.81 3583.17 MinPt-CICt 11018.65 10770 78 10648.23 44.94 6774.27 3584.73 MinPt-0-EOU 11019.61 10770.96 10648.01. 44.80 6780.87 3585.55 MinPt-O-ADP 10547.78 10249 47 10101 02® 7292.79 3642.60 MinPts OP03-P05(Def Survey) Pass I17843,1 17841.6 17810.321 12258.95 90.90 90.90 MinPts 17843.31 17840. 1781050 755101 209.29 209.29 MinPt-0-EOU 17843 31 17840. 17810.501 7557.64 21065 210.65 MinPts 16897.15 16872.88 16861.45 739.17 3669.50 3094.82 TD 16074.14 16031.77 16011.451 395.451 3397.71 2978.23 MinPt-0-SF 1 16780.95 16733411 16720.36 642.20 3623.69 3078.06 MinPts 0106-05(P9c)(Def Plan) Pass I 17077.59 17053.97 17042.83 76621 3657.26 309046 MinPt-CtCt 17077.60 17053.961 17042.821 765.88 3657.61 3090.59 MinPts 17166.61 17141.70 17129.92 728.63 3682.47 3099.35 TD 17497.68 17469.73 17456.36 654.581 3657.97 3090.72 MinPt-0-SF I 17167.94 17143.021 17131 231 728.50 3682.47 3099.35 MinPts 0P08-04P81(Def Survey) Pass 15579.18 15549.96 15536.39 573.84 3730.43 3115.24 TD 10949.67 10912.17 10895.67 331.581 3549.06 3048.20 MinPt-0SF I 10880.411 10643621 10627.83 333.83 3573.23 3058.21 MinPts NikaIchuq 1(Def Survey) Pass 8109.85 8098.02 8077.05 685.10 1634.35 1581.64 MinPts 8110.15 8097.72 8077.35 652.30 1685.71 1628.34 MinPt-O-000 8178.50 8158.78 8145.69 nom 1975.97 1890.51 MinPt-0-SF 8246.70 8224.56 8213.89 EllEfar 2002.52 1914.39 MinPt-O-SF 8385.37 8362.87 8352.56 MIME 2036.38 1944.87 MinPt-0-SF 8408.55 8385.83 8375.43 404.0 2040.36 1948.44 MinPt-O-SF 8539.93 8517.10 8506.64 408.2. 2061.68 1967.61 MinPt-0-SF 9999.72 9968.35 9953.63 mon 2237.81 2125.11 MinPt-0-SF 10327.47 10294.44 10278.89�rS 2276.48 2159.34 MinPt-0SF 10782.31 10747.90 10731.58 'T. ,7 2325.51 2202.47 MinP1-0SF 10901.58 10866.80 10850.3.1 2337.97 221337 Min191-0SF 11148.17 11112.56 11095.63=EDE 2362.70 223495 MinPt-0SF 11399.21 11363.12 11345.1.mEEEE 2387.71 2256.68 MinPt-0SF 11651.84 11614.98 11597. mum 2414.24 2279.60 MinPt-0SF 12741.07 12703.49 12685.59 355.72 2562.51 2405.18 TD 0120-07(P14)(Def Plan) Pass I 11679.241 11269.561 11065.221 28.571 7394.67 365221 MinPts OP05-06(Def Survey) Pees IlliEzEm:NEEEKJ 14579.64 084 0.84 MinPts 17846 37145•• 6 17813.57 8217.85 170.84 170.84 M1nPt-O-EOU 17846.324E 'l 17813.51 7486.22 213.39 213.39 MinPt-0-EOU 17846.321 17843.•S' 7502.18 21475 214.75 MinPts 17067.61 17041.52 17029.15 689.94 3660.73 3091.71 MinPt-CtCt 17068.39 17040.93 17027.87 653.63 3662.94 3092.50 MinPt-0-EOU 17068.44 17040.935 852.33 3663.00 3092.52 - MinP1-0-ADP 17074.66 17046.22 17032.68 630.48 3667.03 3093.95 TD 12718.35 12663.77 126374.5 2796.02 2591.69 MinPI-0-SF 13170.95 13113.57 13085.80® 2837.85 2623.33 MinPt-O-SF 13589.83 13529.69 13500.5•man2876.36 2651.91 MinPt-O-SF 13851.27 13790.48 13760.99® 2898.39 2668.02 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 9 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)1 EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major 14117.60 14055.54 14025.38 234.04 2918.29 2682.42 MinPt-O-SF 14467.82 14403.52 14372.19 230.89 2941.21 2698.83 MinPt-O-SF 15139.19 15070.29 15036.56 224.35 2979.24 2725.59 MinPt-O-SF 15329.61 15260.07 15225.99 224 84 2988.80 2732.23 MInPt-O-SF 15453.23 15383.50 15349.30 225.88 2995.64 2736.95 MinPt-O-SF 15754.07 15683.48 15648.81 227.13 3014.61 2749.96 MinPt-0-SF 16111.37 16038.74 16003.00 225.37 3042.11 2768.56 MinPt-O-SF 17147.82 17069.56 17030.52 221.88 3115.61 2816.70 MInPt-O-SF 17731.51 17650,54 17610.55 221.68 3147.13 2836.61 MinPt-O-SF I p 17098.67 17069.90 17056.21 624.111 3661.45 3091.97 MinPt-O-SF t 1 17074.871 17046.421 17032.88f 630.44 3667.03 3093.95 MinPts . OI11-01PB1(Def Survey) Paas • ._.56.820117855.608 17824 01 14588.40 0.85 0.85 MinPts • 17857.0 17854.5 17824.19 7391.77 203.85 203.85 MinPts 12944.52 12911.51 12896.85 441.48 3810.20 3138.66 TD I 11927.431 11893.771 11879.051 404.961 3800.07 3135.90 MinPts • 0P03•P05PB2(Oaf Survey) Pass 17843.1 17841.6 17810.301 12258.95 90.90 90.90 MinPts 17843.31 17840. 17810.50 7551.01 209.29 209.29 MinPt-O-EOU 17843.31 17840. 17810.5 7557.64 210.65 210.65 MinPts 16897.15 16872.88 16861.45 739.17 3669.50 3094.82 TD 16074.14 16031.77 16011.44 395.431 3397.71 2978.23 MinPt-O-SF I 16760.951 16733.411 16720.36 642.20 3623.69 3078.06 • MinPts OP22-W W 03(P1)(Def Pian) ������ Pass 1 171001 17075.99 1706459 749.94 3687.55 3101.10 MinPt-CtCt 17100.1 17075.98 17064.58 749.62 3687.93 3101.23 MinPts I 12297.63 12239.46 12212 49 227.891 387445 3154.76 MinPts Oliktok Point 1-1A-I06(P5)(Def • Plan) Pass 17146.70 1712443 17113.•.®1 3600.66 3069.18 MinPt-O-SF 17028.16 17004 29 16992.99 753.57 3648.57 3087.31 TD 13613.00 13466.66 13394.36 94.141 2720.47 2533.10 MinPt-O-SF 16992.071 16955.95 16938.92 498.93 3522.88 3036.98 MinPts 1697470 16941.88 16926.12 538.61 3550.68 3048.88 MinPt-0-ADP 16974.54 16941.85 16926.16 540.87 3552.18 3049.51 MinPt-O-EOU • I 16974.43 16942.04 16926.50 546.16 3555.20 3050.77 MinPt-CtCt OP23-W W 02(Def Survey) Pass 16488.62 16461.45 16448.72 64744 3779.18 3130.00 TD I 12320,49 12276.00 12256.07 308.99 3648.70 3087.36 MinPt-CtCt 1 12320.50 12275.991 12256.06 308.91 3648.78 3087.39 MinPts 12562.52 12517.88 1249717 303.29 3681.19 3098.91 MieP1-0SF 12742.26 12697.99 1267700 303.54 3699.01 3104.98 MinPt-0SF 12761 75 12717.51 12696.50 303.54 3700.82 3105.59 MinP5-0-SF 0106-05 current(Non-Def Survey) Pass IMO 17846.37:'• 14580.86 1.01 1.01 MinPts 17847.7.mom. 17814.93 9188.66 146.01 146.01 MinPt-O-EOU 17847.8.MEM 17814.99 7520.55 217.43 217.43 MinPt-O-EOU In= 17845.4 7536.41 218.79 218.79 MinPts 17848.50 17846.15 17815.69 7597.99 243.30 243.30 MinP1-0SF I 17098.67 1707484 17063.59 759.91 3651.48 3088.37 MinPt-CtCt 17098.69 17074.841 17063.581 759.35 3651.83 3088.50 MinPts 17211.49 17184.23 17171.22 661.79 3681.14 3098.89 TD mEmE mem!mime 661,77 3681.14 3098.89 MinPts Oliktok Point I-2PB1(Def Survey) P.S. 17842.26 17840.05 17809. 8099. 243.07 243.07 MinPt-0SF 17150.64 17128.37 17117.8 777.9 3600.93 306928 MinPt-0-SF I 12952.201 12860.331 12816.23 146.80 5614.39 3420.64 MinPts OP26-DSPO2(Def Survey) Pass 18071.0 18069.921 18038.231 16212.27 0.89 0.89 MinPts 18071.1 18068.911 18038.38 7920.58 203.78 203.78 MinPt-0-EOU 1 18071.1 18068.91 18038.3 7938.52 • 206.47 206.47 MinPts 18071.93 18069.69 18039.1 8052.511 242.68 242.68 MinPt-OSF I 13115.58 13079.18 13063.05 406.61 3839.19 3146.23 MinPt-CtCt 13115.59_ 13079.181 13063.05 406.49 3839.36 314828 MinPts 13206.31 13169.06 1315230 393.791 3866.62 3152.93 MinPt-O-SF 13247.38 13210.28 13193.52 395.09 3871.92 315417 TD ' 1 Nikaitchuq 3(Oaf Survey) Paas , E' .' 7993.1•MEM 4115.11 5290 52.90 MinPts , 7941.37 7926.66 7908.57=i)=11 1996.80 1909.25 MinPt-O-SF 7941.34 7926.63 7908.53 540.14 2000.85 1912.89 MinPt-O-EOU MEM 7926.64 7908.53 540.64 2003.58 1915.35 MinPts 8699.90 8685.75 8667..• 6 469 2502.48 2354.90 MinPt-O-SF 10796.03 10778.31 10763.2• 609.07 2780.40 2579.73 MinPt-OSF 10935.42 10917.47 10902.61 609.14 2781.40 2580.50 MinPt-OSF 11066.72 11048.52 11033.91 607.87 2782.09 2581.02 MinPt-OSF 11100.75 11082.48 11067.94 607.49 2782.16 2581.08 TD 12303.73 1228129 12270.92 548.12 2739.43 2547.97 MinPt-O-SF 11335.41 11316.86 11302.6 610.9 2774.09 2574.87 MinPt-0SF 11140.96 11122.60 1110815 606.81 2781.96 2580.93 MinPt-0SF [EMU' 11087 131 1107260, 60741 278215 258107 MinPts OP03-P05PB1(Def Survey) Pass II 178,13 13i1 17841 6811 17810 3211 12258 95 90 90 90.90 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 10 of 11 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft), Dev.(ft)_ Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17843.31 17840.94 17810.50 7551.01 209.29 209.29 MinPt-0-EOU 17843.31 17840.94 17810.5 7557.64 21065 21065 MinPts 16897.15 16872.88 1686145 73917 3669.50 309482 TD 16025.37 15982.90 15962.55 393.861 3394.87 2976.80 MinPt-OSF 1 16760.951 16733.411 16720.36 642.24 3623.69 3078.06 MinPts OP21-W W01(P3)(Def Plan) Pass 1 1711104 1708710 1707579 756.63 3678.72 309805 MinPt-C1Ct 17111.04 17087.0 17075.78 756.30 3679.09 3098.18 MinPts 17104.74 17077.52 17064.64 863.87 3764.93 3125.83 TD 1 15355.65 15286.59 15253.11 229.32 3589.79 3064.88 MinPt-CtCt 15355.74 15286.511 15252.95 228.78 358985 3064.91 MinPt-O-EOU 15355.82 1528652 15252.93 228.55 3589.88 3064.92 MinPt-0-ADP 15382.29 15310.04 15275. 219.7 3594.33 3066.68 MinPt-O-SF 15709.36 15631.17 1559257 203.47 361166 3073.46 MinPt-O-SF OP18-08PB1(Def Survey) Pass _. I 16690.151 16662.401 16649.331 638.601 3751.46 3121.78 MinPts Oliktok Point I-1(Def Survey) Pass 17146.70 17124.43 17113.9.MILIMO 3600.66 3069.18 MinPt-O-SF 17028.16 17004.29 16993.00 753.73 364857 3087.31 TD 17365.35 17277.93 17234.71 200.891 3046.72 2771.65 MinPt-O-SF 16974.70 16942.20 16926.60 544.18 355068 3048.88 MinPt-0-ADP 16974.54 16942.17 1692663 546.36 3552.18 3049.51 MinPt-O-EOU 1 16974.43 16942.34 16926.95 551.54 3555.20 3050.77 MinPt-CtCt OP05-06PB2(Def Survey) • Pass 1 17846.10 17844.88 17813.291 14579.64 0.84 0.84 MinPts 17846.37 17844.20 17813.57 8217.85 170.84 170.84 MinPt-O-EOU 17846.32 17843.94 17813.51 7486.22 213.39 213.39 MinPt-0-EOU I17846.32 17843.94 17813.511 7502.18 214.75 214.75 MinPts 17067.61 17041.52 17029.15 689.94 3660.73 3091.71 MinPt-CtCt 17068.39 17040.93 17027.87 653.63 3662.94 3092.50 MinP1-0-EOU 17068.44 17040.93 17027.851 652.33 366300 3092.52 MinPt-O-ADP 1707466 17046.22 17032.68 630.48 366703 3093.95 TO 12886.73 12831.65 12805.0 =UM 2811.40 2603.39 MinPt-OSF 13170.95 13113.54 13085 76.11M 2837.85 2623.33 MinPt-O-SF 13589.83 13529.66 13500.4•. 2876.36 2651.91 MinPt-OSF 13851.27 13790.45 13760..•MOM 2898.39 2668.02 MinPt-O-SF 14117.60 14055.50 14025.3 =EMI 2918.29 2682.42 MinPt-O-SF 14467.82 1440348 14372.1'MEE 2941.21 2698.83 MinPt-O-SF 15139.19 15070.26 15036. •mum 2979.24 272559 MinPt-O-SF 15329.61 15260.04 15225.,'11111E312 2988.80 273223 MinPt-O-SF 15453.23 15383.47 15349.2'® 2995.64 2736.95 MinPt-O-SF 15754.07 15683.45 15646.7 ®' 3014.61 2749.96 MinPt-OSF 16111.37 16038.70 16002.' 3042.11 2768.56 MinPt-O-SF 17147.82 17069.53 17030.8 mEggp 3115.61 2816.70 MinPt-O-SF 17731.51 17650.51 17610.50 mggin 3147.13 2836.61 MinPt-O-SF 17098.67 17069.00 17056 21 WZMI1 3661.45 3091.97 MinPt-O-SF .05"'MEM 630.44 3667.03 3093.95 MinPts Nikaitchuq 2(Def Survey) up Pass 1 16032.271 16030.35p 15999.461 8363.66 14.15 14.15 MinPts 15900.27 15886.08 15867.46 1122.661 2058.89 1965.11 MinPt-O-SF 15834.1 15818.63 15801.33 1024.51 2145,33 2042.67 MinPts 15834.14 15818.63 15801.34 1024.39 2145.62 2042.93 MinPt-0-EOU 15900.13 15877.85 15867.32, 707.25 2201.54 2092.87 MinPt-O-SF 15928.51 15904.39 15893.30 717.55 2212.62 2102.73 MinPt-O-SF 16004.52 15976.12 15962.8 604.34 2241.21 2128.12 MinPt-OSF 16059,14 16030.60 16017.29 2257.44 2142.51 MinPt-OSF 16120.88 16092.05 16078.60. 599.31 2270.48 215404 MinPt-OSF 16327.52 16298.11 16284.294 590.42 2303.94 2183.53 MInP1-0SF 16444.47 16414.24 16400.01 577.87 2316.66 2194.71 MinPt-OSF 17180.21 17144.56 17127.61 506.85 2401.03 2268.20 MinPt-OSF 17289.87 17253.99 17236.9 506.55 2413.53 2278.99 MinP1-0SF 17647.89 17610,51 17592.69 495.33 2449.23 2309.65 MinPt-O-SF 17768.05 17730.35 17712.38`9435 2461.96 2320.52 MinP9-OSF 17927.20 17889.15 17871.00 493.96 2480.15 233599 MinPt-O-SF 18088.98 18050.78 1803257 498.48 249965 2352.52 TD OP05-06PB1(Def Survey) 1 j Pass MIEMIE,MIUMEMIZIEM. 14579.64 0.84 0.84 MinPts 17846.3 now 17813 57 8217.85 170.84 170.84 MinPt-O-EOU 17848.3.. 17813 51 7486,22 213.39 213.39 MinP1-0-EOU m 17843.t'I- 7502.18 214.75 214.75 MinPts 17067.61 17041.52 17029.15 689.94 3660.73 3091.71 MinPt-CtCt 17068.39 17040.93 17027.87 653.63 3662.94 3092.50 MinPt-O-EOU 17068.44 1704093 nun 652.33 3663.00 3092.52 MinPt-O-ADP 17074.66 17046.22 17032.68 630.48 3667.03 3093.95 TD 17098.67 17069.90 17056.21 624.111 3661.45 3091.97 MinP1-0SF I17074.871 17046 42j 17032.88 630.44 3667.03 3093.95 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Spy Island\SP27-N1\SP27-N1\SP27-N1(P3) 10/5/2011 2:31 PM Page 11 of 11 Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP27-N1 Oriented EOU Dimension g- Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rul. All Date: October 05,2011 used:Minor Risk-Separation110YI Factor 4 I Nort h 0-900'md 350 0 10 I 340 6,-P OuIL_ 20 SP 4-Sri (P 330 .0 b 30 320160..44 . 50 VgAnk ` 310 „,- ",...4-4'5.11.1.1.1.4.1,11% imiei k,li hA1,00 :;`50 "...,: 300 � /1,� �. 60 Ai iitlj.miik, W.t..,i'tsr"i-ik.01,-"' -•••'---„,4„ t'.0.0.Ii.IaIA:I ,1�� SI29-S2 P2) 0 / ' / 2901 -4 .' / 70 I ``1`�`�` 20, + 1 280 `, \ -',—`\\ 15 ,��. c' II1 P23-t3(P '. '``` `.-w,,, / .s I5,./ ,s000. ,,. 80 , 4tIZI Ok° \ •AK 270 _` // l \ tit III 0 IWV!P I!, , k Vt VIV\ AW1F ' •`-� % 90 �;!►.� s� iii 3. `1�,';, `,it.� �11111 , 'I �4\ tt I ° . ' 1 �”;�`:'�,•,'` ` `� 100 �,�'. )11 fid' lir-- , `-. _�`� ,�;��250 Itite .��i���_ juk .\�_��_ �110 P 41 lir 7v.11)111i /I■. :25 N2(i„ 0.1*4".. :?' , ' 240 I f, 4 A 1 ■■ 120 230 V:1all, V 'vWO 130 IIIVA, 111111 1 Ail, 220 OA / $ 40 i 210 6 150 200 ' 160 14n .__ 170 Well Ticks Type: MD on SP27-N1 (P3) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=20.00 ft Schlumberger TRAVEL NG CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP27-N1 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rule Date: October 05,2011 used:Minor Risk-Separation Factor North 900- 13-3/8" 350 0 10 340 iiii*. 330 30 140 320 40 /` \ 120 �� 310 `, I zpBa • 05614RB4)(P1) \ 100 ��~� 8D37-I" 'ht 300 ��g : (& 0f ,V1,--........,. �� ���i► 70 41*** i�11 1498 ,;,,, ,.„,w,...„ ,. .,� � 40 ri '', 1!"1 s,W �4 i .4 !, .•":0W�� ;�. ,L� 'w''.- .114-N6(P2) 280 `� ,i iite#0V .`� ` X 1 or t u•,- 80 270 :� 'I//- ��= ;•90 �Af ( (10 � o ...........414 ,--291111110110: .P18-N5(Ps) 260g4. • of.i3$•p'°,P9, re .rWt��0' 100 �ai � ' , •tel _ \ .a1,V°.,,,,, 250 mac' ,/r , pw 110 ill 11 oct s.vio0 240`,�ill * 4 i • friiik �, 120 03 i 998 1111 i 230 04o 3� 130 220 '�:/ 140 _ /\ SI25-N2(P2) .„. • 'Cl.• 4 21� `l,) 150 200 „_ 160 191 180 170 Well Ticks Type: _ MD on SP27-N1 (P3) _ Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP27-N1 Oriented EOU Dimension N Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rul Date: October 05,2011 used:Minor Risk-Separation �I Factor 13-3/8"-9-5/8" North 350 0 10 340 0 20 330 -- Sand(P2) X00- irtit 34 — 28(' t#3,t0 _ 320 e• 26,E At. 01194R64)(P1) 5-N2(P2) 310 2.I � �yrm74 50 s ,_ '3a 211 , i ,4i,�i4 ;v�� �r I 300 ' 10,011 , 18 '/t$,/;lif,,4 , 60 IP fril 164 % ' 404110 slii ,A, i 290Alt 11#. . 1.�40 i't4 ��'li, ,liffitf*.T'P4-N6(P2) me ••O./Mail VI 100 ,\` It4T,4-,4. . 280 , ''r 60 ` ( •/ 1/ 1 80 3o8r �� 40k fig�vo 2�0 ' Ills 20 III ^ ` �(Yll itrf ti ,�� 90 1;4i o ` ` P18 N5(P4) A # 9, '-260 '��gar , o o°/ oa :�r♦I , '45 .X14 ;\;mo:=SI26 N2(P2) cn 250'27111:1 o O�c� N . 1 •,,,-$ '` ti / / ,`►110 r04/01122:1?''4 1111 a* O Oyu! 2401 /��.�rl:r►141 . O: �w 120 1 100,, t►,�h O rt iii j►�14` . \ ! +t ►. 230 #A•� J♦��1 / 130 411�j;#4n� �-40 �ITO� AiliSP23-N3(P3) V*44220 II# i� X47 0 #41101111.1.ft,,, 'riknk 140 ,I 4111#4-00k 210 �I 440 1, 150 200 —�.�a 160 190 - 1Rn 170 Well Ticks Type: _MD on SP27-N1 (P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger TRAVELING CYLINnm PLOT Client: Eni Petroleum NoGo Region EOU's based on: Well: SP27-Nl Oriented EOU Dimension Field: Nikaitchuq Structure: Spy Island NoGo Region Anti-Collision rut= A = Date: October 05,2011 used:Minor Risk-Separation Factor *4 North 9-5/8"-TD 350 0 10 340 450 20 330 . 420 390 30 1 320 . 360 Mkt40 330 • 310 , . 300 •� 50 4/ �TO 270 300 �� 240 �111 ' 60 44' II - **A 210 290 , 180 150 Jt%$' 70 jo, . tilsitair 120�90 ma 11, 80 270 i4L 1. ...._1 01♦■� 260 II7 o I, ..�. ♦ °.. e ,,, i14 ,00 250 orno0`� �� `•. Wir•�1 oFo� °mow 110 ci 240 a � 110444m411.11111)*TO 1II% ° o�� �d 120 o 230 , 130 0* 220 . 40 . 21�♦ err rmi .�50 200 160 190 180 170 Well Ticks Type: MD on SP27-N1 (P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=150.00 ft Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate • Trip speeds,proper hole filling(use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates,mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates,mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out,backreaming 13 g • 6l- .! 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'' Cr t6 Q 0 as Q a °' 1�°r° Schlumberger CemCADE*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : SP27-N1 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Doyon 15 Proposal No. : Draft v1 (P3) Service Point : Prudhoe Bay,Alaska Date Prepared : 08/09/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-748-7555 Cell : 907-223-0093 E-Mail Address : Jlong1Ca3slb.com OL &TE ) Disclaimer Notice: Schlumberger submits this document with the benefit of as 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 : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2293.0 ft BHST : 38 degF Bit Size : 16 in ft (x 1000) psi 0 n1 .0 1.5 — — Frac I ------ Pore I 0 —Slltstone— o 0 ::▪ :Sandstone':: o– —-Siltstone- — _ •▪•••••Sandstone 1 • O O • • •Sandstone• • • 0 0 N– Well Lithology Formation Press. Page 2 sp27-n1 Ip31 v1 10-9-11.cfw,10-11-2011; loadCase Surface Casing.Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Sillier!" String : 13.375 District : Prudhoe Bay,Alaska �j' Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 178.9 18.250 Landing Collar MD : 2212.0 ft Casing/liner Shoe MD : 2292.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2292.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 203.9 % Mean OH Equivalent Diameter: 20.326 in Total OH Volume : 856.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1835.0 16.000 250.0 21.184 2292.0 16.000 35.0 16.822 2293.0 16.000 0.0 16.001 Page 3 sp27-n1)p3)v1 10-9-11 cfw.10-11-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 ScImiWrier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 28 deg Max. DLS : 4.001 deg/100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 162.0 0.000 100.0 100.0 0.0 162.0 0.000 200.0 200.0 0.0 162.0 0.000 300.0 300.0 1.5 162.0 1.500 400.0 399.9 3.5 162.0 2.000 500.0 499.6 5.5 162.0 2.000 600.0 598.9 7.5 162.0 2.000 700.0 697.8 9.5 162.0 2.000 800.0 796.1 11.5 162.0 2.000 900.0 893.8 13.5 162.0 2.000 1000.0 990.6 15.5 162.0 2.000 1100.0 1086.5 17.5 162.0 2.000 1200.0 1181.3 19.5 162.0 2.000 1300.0 1274.9 21.5 162.0 2.000 1384.8 1353.4 23.2 162.0 2.004 1400.0 1367.3 23.3 162.0 0.461 1500.0 1459.0 23.8 162.0 0.500 1600.0 1550.4 24.3 162.0 0.500 1700.0 1641.4 24.8 162.0 0.500 1800.0 1732.0 25.3 162.0 0.500 1900.0 1822.2 25.8 162.0 0.500 1934.7 1853.4 26.0 162.0 0.519 2000.0 1912.2 25.8 168.0 -4.000 2100.0 2002.1 26.1 177.1 4.001 2200.0 2091.5 27.0 185.8 3.999 2293.0 2173.9 28.3 193.3 3.973 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 754.0 11.60 8.43 SV-4 Siltstone 1135.0 11.70 8.43 SV-3 Sandstone 1411.0 11.80 8.43 SV-2 Siltstone 1 1835.0 11.90 8.43 SV-1 Sandstone 1950.0 12.00 8.43 Permafrost Base Shale 2291.0 12.50 8.43 Ugnu Top(UG4) Sandstone 2293.0 12.50 8.43 TD Shale Page 4 sp27-n1(p3)v1 10-9-11.cfw;10-11-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1950.0 1867.2 32 -1.5 2293.0 2173.9 38 -1.0 ft degF 30 35 40 45 50 55 60 65 70 75 80 85 0- - -Geoth.Profile -Tubular Fluids -Annulus O a- u) 8 O— O O_ U) O O O N O 0 U) Temp. Profile At 186 min Page 5 sp27•n1(p3)v1 10-9-11.cfw;10-11-2011; LoadCase Surface Casing;Version wcscem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 To: 0.48 lbf/100ft2 Displacement Volume 331.2 bbl Total Volume 953.2 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 ASL 452.0 1790.0 10.70 k:9.99E-2 lbf.s^n/ft2 n:0.276 Ty:16.35 lbf/100ft2 LiteCRETE 70.0 502.0 1790.0 12.50 k:3.97E-3 lbf.s^n/ft2 n:0.949 Ty:21.23 lbf/100ft2 Mud 331.2 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2029 psi at 2212.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton Check Valve Diff Press 166 psi Page 6 sp27-n1(p31 v110-9-11_cfw:10-11-2011: LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well :SP27-N1 String : 13.375"Surface Casing District : Prudhoe Bay,Alaska Country : USA ft lb/gal 8 9 10 11 12 13 o- < —Hydrostatic _ — —Mn.Hydrostatic —Max.Dynarric —Mn.Dynamc - Frac O — Pore O- rn O_ Y � 3 0 O O U r t to• - • U • $ Z 1 U O Lc) — Fluid Sequence Dynamic Well Security N ■NUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 ASL Load 2 452.0 bbl 10.70 lb/gal Herschel:k=9.99E-2 lbf.s^n/ft2 n=0.276 Ty=16.35 Ibf/100ft2 LiteCRETE Load 4 70.0 bbl 12.50 lb/gal Herschel:k=3.97E-3 Ibf.s^n/ft2 n=0.949 Ty=21.23 Ibf/100ft2 ■Mid 331.2 bbl 9.50 lb/gal Herschel:k=8.28E-2 tbf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 2293.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Schlumberger Page 7 sp27-n1Ip31v110-9-11.cfw;10-11-2011; LoadCaseSurface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Start Pumping Spacer 3.0 0.0 80 Drop Bottom Plug 5.0 0.0 80 Line Up Cement Unit ASL 5.0 452.0 90.4 452.0 80 Start Mixing Lead Slurry LiteCRETE 4.0 70.0 17.5 70.0 80 Start Mixing Tail Slurry 5.0 0.0 80 Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Rig Pumps To Displace 5.0 0.0 80 Line Up Rig Pumps Mud 8.5 311.2 36.6 321.2 80 Rig Pumps To Displace Mud 5.0 10.0 2.0 331.2 80 Slow Rate Shut-In 0.0 0.0 5.0 0.0 80 Bump Plug Total 03:05 hr:mn 953.2 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 3 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2029 psi at 2212.0 ft Burst 4794 psi at 0.0 ft Temperature Results BHCT 59 degF Simulated Max HCT 77 degF Simulated BHCT 77 degF Max HCT Depth 2292.0 ft CT at TOC 71 degF Max HCT Time 03:05:41 hr:mn:sc Static temperatures : At Time 00:02 hr:mn (hr:mn) Geo.Temp. Top of Cement 71 degF 71 degF 60 degF Bottom Hole 76 degF 76 degF 38 degF Page 8 sp27-n1(p3)v1 10-9-11.cfw,10-11-2011, LoadCase Surface Casing.Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 ScImttrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD at Casing Shoe: Depth= 2292 ft cd N - I Hydrostatic N Dynanic Frac Pore O T • � I Oi 09 0 20 40 60 80 100 120 140 160 180 200 Time(min) ECD at Conductor Shoe: o Depth= 160 ft Fluids at 2292 ft N � I Hydrostatic c--� Dynanmic Frac Pore CO 131 v o� ( I N_ • co cd- od • 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 sp27-n1(p3)v1 10-9-11.cfw;10-11-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing BHCT Simulation: First Sack Depth r N -- First Sack Temp. O Last Sack Depth 63- ------ Last Sack Temp. _[r C5 (0 Pc' �ppp 0 rP O N Tr 'fillillt 4 lii co r' P- RNN `N (2N 0 30 60 90 120 150 180 210 Time(min) Surface Pressure Model: Calc.Pump Press. Calc.CemHP W .771 yn§ Q vs.—, N 71- - 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 10 sp27-n1(p3)v1 10-9-11.cfw;10-11-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 ScbIiderger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 2292 ft -O Out — - - ------ -Q ki CO— N— (0_ —N co- - O 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity: Depth= 2292 ft Annular Velocity 8- le- 8- :F• - R-8- a� 8- O� 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 11 sp27-n1(p3)vt 10-9-11.ctw;10-11-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 lb/gal Rheo. Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. : 65 degF n :0.262 Ty :0.48 lbf/100ft2 Gel Strength : 6.40 Ibf/100ft2 MUD Mud Type :WBM Job volume : 331.2 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 ASL Load 2 DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k :9.99E-2 lbf.s^n/ft2 At temp. : 70 degF n :0.276 Ty : 16.35 lbf/100ft2 Gel Strength :9.98 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 11.513 gal/sk Job volume :452.0 bbl Dry Density : 110.25 lb/ft3 Yield :2.45 ft3/sk Quantity : 1037.50 sk Sack Weight : 100 lb Solid Fraction : 37.1 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 11.513 gal/sk Page 12 sp27-n1 1031 v1 10-9-11.ctw;10-11-2011: LoadCase Surface Casing:Version wcs-cem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing LiteCRETE Load 4 DESIGN Fluid No: 6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 3.97E-3Ibf.s^n/ft2 At temp. : 70 degF n : 0.949 Ty : 21.23 lbf/100ft2 Gel Strength :40.56 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.472 gal/sk Job volume : 70.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity : 251.17 sk Sack Weight : 100 lb Solid Fraction : 53.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.472 gal/sk Additives Code Conc. Function D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D167 0.2500%BWOB Fluid loss D153 0.1000%BWOB Antisettling Annulus ID : 13.375 in Flow Rate : 8.5 bbl/min O rn LiteCRETE Load 4 ASL Load 2 rVUDPUSH II - Mid 00 _ O a - N N co d in C �... O _ M 15.9 16.0 16.1 16.2 16.3 16.4 16.5 16.6 16.7 16.8 16.9 17.0 17.1 Annulus OD (in) Page 13 sp27-n1(p3)v1 10.9-11.cfw;10-11-2011; LoadCase Surface Casing:Version wcscem462_12 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2285.3 ft Casing Shoe :2292.0 ft NB of Cent. Used :35 NB of Floating Cent. :35 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1852.0 23 1/2 NW-TR-13 3/8-8-TR 3 W304 18.6 352.0 2212.0 9 1/1 NW-TR-13 3/8-8-TR 3 W304 19.6 1852.0 2292.0 3 3/2 NW-TR-13 3/8-8-TR 3 W304 84.7 2212.0 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 ft 0 20 40 60 80 100 - Between Cent. + +Bt Cent. O L �} O— Lr) ++ O •O U, o— CSI u7 — Well Pipe Standoff Page 14 sp27-n1(p3)v1 10-9-11.cfw;10-11-2011; LoadCase Surface Casing;Version wcscem402_12 Client : Eni Petroleum Well : SP27-N1 Schliilkirger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II ft % % 0 50 100 0 25 50 75 100 O— E - - - > I I -Std Betw.Cent. -Mad Contamination -'--4.- _ _. -Cement Coverage { - Uncontaminated Slurry O —\ . O- u O O O- O O 10— ....r" ......*Et".. ..... O O_ O N O O in N- Fluid Sequence Cement Coverage Uncontaminated Slu y Fluid*Concerbalwn Fink Mud m do Wel L3 z 3`- `3 z 3� 0—i' Iiii 0 0 11 0 200- 200 200 200 400- r 400 400 400 600- 600 600 600 800- 800 800 800 1000- 1000 E. . 1000 1000 a 1200- 1200 a a 1200 1200 S- 0 1400- 1400 c o 1400 1400 c A 1600- I 1600 1600 1600 1800 1800 1800 1800 2000 2000 2000 2000 2200 2200 2200 2200 m ; w m 3 al o 3 o 3 ? 0 o 0 z z IIMLileCRETE Load 4 la 12=11 •Meal,, •Nae Page 15 sp27-n1(p3)v1 10-9-11.cfw,10-11-2011; LoadCase Surface Casing:Version wcscem462_12 Client : Eni Petroleum Well : SP27-N1 SchluNbrgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name B809 103751 lb 1038 sack 100 lb D972 25115 lb 252 sack 100 lb D182 5521b 23 sack 251b D047 20.0 gal 5 can 5.0 gal D031 9537 lb 87 sack 110 lb D046 51 lb 2 sack 50 lb D065 63 lb 2 sack 50 lb D167 63lb 3 sack 251b D153 251b 2 sack 251b Mix Water Requirements : Fresh water 17185 gal MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.0000 lb/bbl of base fluid D047 20.000 gal 0.2000 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer ASL Load 2 Volume :452.0 bbl Density : 10.70 lb/gal Yield : 2.45 ft3/sk Dry Phase Liquid Phase Blend: 103750 lb Design Mix Water 284.4 bbl 10.0 bbl LAS Design B809(100 lb 103750.219 Fresh water 284.393 bbl 10.001 bbl lb LiteCRETE Load 4 Volume : 70.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix 32.7 bbl 10.0 bbl LAS Design Water D972 25114.070 lb Fresh 32.721 bbl 10.001 bbl water D046 50.228 lb 0.2000%BWOB D065 62.785 lb 0.2500%BWOB D167 62.785 lb 0.2500%BWOB D153 25.114 lb 0.1000%BWOB Page 16 sp27-n1(p3)v1 10-9-11_cfw,10-11-2011, LoadCase Surface Casing;Version wcs-cem462_12 Schlumberger C emCAD E* well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : SP27-N1 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Doyon 15 Proposal No. : Draft v1 (P3) Service Point : Prudhoe Bay,Alaska Date Prepared : 10-09-2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-748-7555 Cell : 907-223-0093 E-Mail Address : JLong1@slb.com ���GN Q C L 9AT E Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment.experience.and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations.computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided 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 : SP27-N1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8210.0 ft BHST : 67 degF Bit Size : 12 1/4 in ft (x 1000) psi > . 0 2.5 ,—Frac —Slltstone— —Pore MMMMM _ 1 F— _? Shale Coal CD Shale `a '::Sandstone': a=Min • • ••• •Sandstone• • • • • a,_ Well Lithology Formation Press. Confidential for authorized person only 2 / 17 Client : Eni Petroleum Well : SP27-N1 SAM M IE! String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2284.0 13 3/8 68.0 12.415 Landing Collar MD : 8129.0 ft Casing/liner Shoe MD : 8209.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 8209.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 HYD 563 Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.370 in Total OH Volume : 1029.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 8209.0 12.250 50.0 13.371 8210.0 12.250 0.0 12.249 Confidential for authorized person only 3/ 17 Client : Eni Petroleum Well : SP27-N1 ScbI hrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Max. Deviation Angle : 85 deg Max. DLS : 4.063 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 162.0 0.000 100.0 100.0 0.0 162.0 0.000 200.0 200.0 0.0 162.0 0.000 300.0 300.0 1.5 162.0 1.500 400.0 399.9 3.5 162.0 2.000 500.0 499.6 5.5 162.0 2.000 600.0 598.9 7.5 162.0 2.000 700.0 697.8 9.5 162.0 2.000 800.0 796.1 11.5 162.0 2.000 900.0 893.8 13.5 162.0 2.000 1000.0 990.6 15.5 162.0 2.000 1100.0 1086.5 17.5 162.0 2.000 1200.0 1181.3 19.5 162.0 2.000 1300.0 1274.9 21.5 162.0 2.000 1384.8 1353.4 23.2 162.0 2.004 1400.0 1367.3 23.3 162.0 0.461 1500.0 1459.0 23.8 162.0 0.500 1600.0 1550.4 24.3 162.0 0.500 1700.0 1641.4 24.8 162.0 0.500 1800.0 1732.0 25.3 162.0 0.500 1900.0 1822.2 25.8 162.0 0.500 1934.7 1853.4 26.0 162.0 0.519 2000.0 1912.2 25.8 168.0 -4.000 2100.0 2002.1 26.1 177.1 4.001 2200.0 2091.5 27.0 185.8 3.999 2292.4 2173.3 28.3 193.3 4.001 2300.0 2180.0 28.4 193.9 3.987 2400.0 2267.2 30.2 201.2 4.001 2500.0 2352.7 32.3 207.7 3.999 2600.0 2436.0 34.8 213.4 4.001 2700.0 2516.8 37.5 218.4 3.995 2800.0 2594.5 40.4 222.9 4.004 2900.0 2669.0 43.4 226.8 3.999 3000.0 2739.7 46.6 230.3 4.000 3100.0 2806.3 49.8 233.4 4.000 3200.0 2868.6 53.1 236.3 3.998 3300.0 2926.3 56.5 238.9 4.005 3400.0 2978.9 59.9 241.3 3.995 3500.0 3026.3 63.4 243.5 4.008 3600.0 3068.3 66.9 245.6 3.989 3700.0 3104.7 70.5 247.7 4.005 3800.0 3135.2 74.0 249.6 4.006 3900.0 3159.7 77.6 251.4 3.995 4000.0 3178.1 81.2 253.3 3.998 4006.0 3179.0 81.4 253.4 4.063 4100.0 3193.1 81.4 253.4 0.000 4200.0 3208.1 81.4 253.4 0.000 4300.0 3223.0 81.4 253.4 0.000 4400.0 3238.0 81.4 253.4 0.000 4500.0 3253.0 81.4 253.4 0.000 4600.0 3267.9 81.4 253.4 0.000 4700.0 3282.9 81.4 253.4 0.000 4800.0 3297.9 81.4 253.4 0.000 Confidential for authorized person only 4/ 17 Client : Eni Petroleum Well : SP27-N1 SBMINkrier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4900.0 3312.8 81.4 253.4 0.000 5000.0 3327.8 81.4 253.4 0.000 5100.0 3342.8 81.4 253.4 0.000 5200.0 3357.8 81.4 253.4 0.000 5300.0 3372.7 81.4 253.4 0.000 5400.0 3387.7 81.4 253.4 0.000 5500.0 3402.7 81.4 253.4 0.000 5564.9 3412.4 81.4 253.4 0.000 5600.0 3417.6 81.4 254.4 2.988 5700.0 3432.6 81.4 257.5 2.996 5800.0 3447.6 81.4 260.5 3.006 5900.0 3462.5 81.5 263.5 2.997 6000.0 3477.2 81.5 266.5 2.997 6100.0 3491.9 81.6 269.6 3.009 6200.0 3506.3 81.8 272.6 2.991 6300.0 3520.6 81.9 275.6 3.002 6400.0 3534.5 82.1 278.7 3.005 6500.0 3548.2 82.2 281.7 2.998 6600.0 3561.5 82.4 284.7 3.000 6700.0 3574.5 82.7 287.7 3.003 6800.0 3587.0 82.9 290.7 2.997 6900.0 3599.1 83.2 293.8 3.000 7000.0 3610.7 83.5 296.8 3.003 7100.0 3621.8 83.8 299.8 2.998 7200.0 3632.4 84.1 302.8 3.000 7300.0 3642.4 84.4 305.8 3.004 7400.0 3651.8 84.8 308.8 2.997 7458.6 3657.0 85.0 310.5 2.997 7500.0 3660.6 85.0 310.5 0.000 7600.0 3669.3 85.0 310.5 0.000 7700.0 3678.0 85.0 310.5 0.000 7800.0 3686.7 85.0 310.5 0.000 7900.0 3695.4 85.0 310.5 0.000 8000.0 3704.2 85.0 310.5 0.000 8100.0 3712.9 85.0 310.5 0.000 8158.6 3718.0 85.0 310.5 0.000 8200.0 3721.6 85.0 310.5 0.000 8210.0 3722.5 85.0 310.5 0.000 Confidential for authorized person only 5/ 17 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Formation Data MD Frac. Pore Name Lithology I (ft) (Ib/gal) (lb/gal) 754.0 11.60 8.43 SV-4 Siltstone 1135.0 11.70 8.43 SV-3 Sandstone 1411.0 11.80 8.43 SV-2 Siltstone 1835.0 11.90 8.43 SV-1 Shale 1950.0 12.00 8.43 Permafrost Base Sandstone 2291.0 12.30 8.43 Ugnu Top(UG4) Coal 3011.0 12.30 8.43 UG-2 Coal Bed Marker Coal 4865.0 12.50 8.43 Nik_Itblue_dte Sandstone 5978.0 12.50 8.43 Lower Ugnu Shale 6620.0 12.50 8.43 Schrader Bluff Sandstone 6895.0 12.50 8.43 N Seq Top Sandstone 7142.0 12.50 8.43 N Sand Top Sandstone 7366.0 12.50 8.43 Nik_KigunBlue_dte Sandstone 7581.0 12.50 8.43 N Sand Bottom Sandstone 7677.0 12.50 8.43 N Seq Base Sandstone 8099.0 12.50 8.43 OA Sand Top Sandstone 8162.0 12.50 8.43 OA sbl 2 Sandstone 8210.0 12.50 8.43 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1950.0 1867.2 32 -1.5 8210.0 3722.5 67 0.2 ft degF 30 35 40 45 50 55 60 65 70 75 80 85 0 ` I i I -- I I I - Geoth.Profile -Tubular Fluids - Annulus Temp. Profile At 159 min Confidential for authorized person only 6/ 17 1 I Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing la) Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 6,142'(1,000'above the"N"Top) Original fluid Mud 9.40 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty: 8.86 lbf/100ft2 Displacement Volume 616.4 bbl Total Volume 865.4 bbl TOC 6142.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 5305.4 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 lbf/100ft2 LiteCRETE 179.0 2067.0 6142.0 12.50 Pv:168.266 cP Ty:26.14 lbf/100ft2 Mud 616.4 0.0 9.40 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 WARNING : Differential pressure across casing equipment valve is low. This is remediated with the use of a positive seal Float Collar, which is typically used for these wells. Static Security Checks: Frac 326 psi at 2284.0 ft Pore 109 psi at 2284.0 ft Collapse 2589 psi at 8129.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 62 ton Check Valve Diff Press 42 psi Confidential for authorized person only 7/ 17 Client : Eni Petroleum Well : SP27-N1 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client : Eni Petroleum Well :SP27-N1 String :9-5/8"Intermediate Casing District : Prudhoe Bay, Alaska Country : USA ft lb/gal 0 8 9 10 11 12 13 L -Hydrostatic -Mn.Hydrostatic -Max.Dynamic -Mn.Dynarric ----- Frac Pore 0 0 E O M U o O E O (D U O d O O Fluid Sequence Dynamic Well Security 1/11 MUDPUSH II 70.0 bbl 10.50 lb/gal Herschel:k =5.23E-2 Ibf.s^n/ft2 n =0.324 Ty=12.92 Ibf/100ft2 y LiteCRETE Load 4 179.0 bbl 12.50 lb/gal Bingham PJ=168.266 cP Ty=26.14 Ibf/100ft2 ■Mud 616.4 bbl 9.40 lb/gal Herschel:k =5.97E-3 Ibf.s^n/ft2 n =0.616 Ty=8.86 Ibf/100ft2 Total Depth = 8210.0 ft Top of Cement= 6142.0 ft *Mark of Schlumberger SChI1 ePpr Confidential for authorized person only 8/ 17 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead 0.0 3.0 80 Drop Bottom Plug 0.0 3.0 80 Begin Mixing Slurry LiteCRETE 4.0 179.0 44.8 179.0 80 Mix&Pump Cement Slurry(3 to 7 BPM) 5.0 80 Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Kick-Out Plug 5.0 80 Line Up Rig Pumps Mud 8.5 596.4 70.2 606.4 80 Displace w/Rig Pumps Mud 5.0 10.0 2.0 616.4 80 Slow Rate 5.0 80 Bump Plugs 5.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 80 Bleed off/Check Floats Total 02:38 hr:mn 865.4 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 257 psi at 2284.0 ft Pore 109 psi at 2284.0 ft Collapse 2416 psi at 365.4 ft Burst 4578 psi at 0.0 ft Temperature Results BHCT 73 degF Simulated Max HCT 72 degF Simulated BHCT 62 degF Max HCT Depth 0.0 ft CT at TOC 62 degF Max HCT Time 02:26:05 hr:mn:sc Static temperatures : At Time 00:00 hr:mn 00:01 hr:mn Geo.Temp. Top of Cement 62 degF 62 degF 63 degF Bottom Hole 62 degF 62 degF 67 degF Confidential for authorized person only 9/ 17 Client : Eni Petroleum Well : SP27-N1 MIEN" String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD at the Casing Shoe: O Depth= 8209 ft M tw 1 -Hydrostatic i O Dynarric N -Frac -Pore O 13;O Ci r i of O ' of in 0 cd — _�- O 25 50 75 100 125 150 175 Time(min) ECD at the Surface Casing Shoe: Depth= 2293 ft Fluids at 8209 ft in N i 0 N- Hydrostatic -Dynamic U) Frac Pore 0oni b in r ' 5- J r � I V I Lo oS-J col I �lI O III W - --T T T T T--- O 25 50 75 100 125 150 175 Time(min) Confidential for authorized person only 10/ 17 Client : Eni Petroleum Well : SP27-N1 Scilimberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) BHCT Model: -First Sack Depth - First Sack Terrp. - Last Sack Depth Last Sack Temp. - -N gip_ 83- -r• "fir 411111411-_,_ -co 0 25 50 75 100 125 150 175 Time(min) Surface Pressure Model: Cain Pump Press. Calc.CemHP 0 it O 0 25 50 75 100 125 150 175 Time(min) Confidential for authorized person only 11 / 17 Client : Eni Petroleum Well : SP27-N1 Saline String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Returns Rate: Fluids at 8209 ft _--- — -Q out -Q In CO is N- 0 25 50 75 100 125 150 175 Time (min) Anullar Velocity: Depth= 8209 ft Annular Velocity 8- OD- C •T I 8 0 I -- 0 25 50 75 100 125 150 175 Time(min) Confidential for authorized person only 12/ 17 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.40 lb/gal Rheo. Model : HERSCHEL_B. k : 5.97E-3 Ibf.s^n/ft2 At temp. : 80 degF n : 0.616 Ty : 8.86 lbf/100ft2 Gel Strength : 32.02 Ibf/100ft2 MUD Mud Type : WBM Job volume : 616.4 bbl Water Type : Fresh VOLUME FRACTION Solids :6.0% Oil : 1.0% Water : 93.0% MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 Ibf.s^n/ft2 At temp. : 65 degF n : 0.324 Ty : 12.92 lbf/100ft2 Gel Strength :40.56 Ibf/100ft2 Job volume : 70.0 bbl LiteCRETE Load 4 DESIGN Fluid No: 7 Density : 12.50 lb/gal Rheo. Model : BINGHAM Pv : 168.266 cP At temp. : 50 degF Ty :26.14 Ibf/100ft2 Gel Strength : 57.01 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.471 gal/sk Job volume : 179.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity : 642.30 sk Sack Weight : 100 lb Solid Fraction : 53.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.471 gal/sk Additives Code Conc. Function D167 0.2500%BWOB Fluid loss D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D153 0.1000%BWOB Antisettling Confidential for authorized person only 13/ 17 ISI Client : Eni Petroleum Well : SP27-N1 SrcImnhrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Fluid Rheological Models: Annulus ID: 9.625 in-OD: 12.250 in O r— r MUDPUSH N Mud _ L'ReCRErE Load 4 8- �pQ+ Q V W- 1 R- 8 8 - I 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bbl/min) Annulus ID: 9.625 in Flow Rate : 10.0 bbl/min LIteCRETE Load 4 — MUDPUSH N p — Mud O- r 8 r"- N EL 0 C O .c LL u7_ I 12.2 12.3 12.4 12.5 12.6 12.7 12.8 12.9 13.0 13.1 13.2 13.3 Annulus OD (in) Confidential for authorized person only 14/ 17 Client : Eni Petroleum Well : SP27-N1 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: centralizer placement Top of centralization :3000.0 ft Bottom Cent. MD :8202.3 ft Casing Shoe :8209.0 ft NB of Cent. Used :40 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 6649.0 0 0/0 0.0 6667.7 7609.0 24 1/1 NW-ST-9 5/8-6-ST A3A WO9R 0.0 7595.1 7729.0 0 0/0 0.0 7609.0 8129.0 10 1/1 NW-ST-9 5/8-6-ST A3A WO9R 0.0 7742.9 8209.0 6 3/1 NW-ST-9 5/8-6-ST A3A WO9R 87.1 8135.7 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-ST-9 5/8-6-ST WO9R 9 5/8 14.583 10.882 No Hannover 12.625 768.85 1656.84 A3A ft 0 20 40 60 80 100 o– E — > L— 1 I -- Between Cent. + 1 At Cent. I - Well Pipe Standoff Confidential for authorized person only 15/ 17 Client : Eni Petroleum Well : SP27-N1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: WELLCLEAN II ft 0 50 100 0 25 50 75 100 Q < - -- H r-------- - Std Betw.Cent. -- Mud Contamnation - Cement Coverage - Uncontaminated Slurry • ...).5. it ..... 0 _ §_r- F----------' Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 2 g 3000 3000 z° 3500 3500 3000-I ' -3000 4000 4000 3500- ;3500 4500 4500 4000- -4000 A500 500- 74500 w 5000 5000 s 5500 , 5500 s 5000 5000 0 60008000 . s 5500- -5500 r a � 0 0 41 6000- -€000 6500 i 6500 a - 5500- I'J -6500 7000 7000 r .5 7000- 't± -7000 7500 ° 7500 - . 7500- ,fir • �� ,a -7500 8000 8000 8000- -8000 • F! • ° •a • z 3 0 7 2 MI Mud EJ High _ Low FT LiteCRETE Load 4 0 Medium 1- 1 None FT MUDPUSH II Confidential for authorized person only 16/ 17 Client : Eni Petroleum Well : SP27-N1 Schibrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 7: operator summary Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 642301b 643 sack 100lb D182 3821b 16 sack 251b D046 141 lb 3 sack 501b D031 8199 lb 75 sack 110 lb D167 161 lb 7 sack 251b D065 161 lb 4 sack 50 lb D153 641b 3 sack 251b Mix Water Requirements : Fresh water 148 bbls MIXING PREPARATION MUDPUSH II Volume :70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.747 bbl D182 382.481 lb 6.0000 Ib/bbl of base fluid D046 12.749 lb 0.2000 Ib/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer LiteCRETE Load 4 Volume : 179.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase • Blend: 64744 lb Design Mix Water 83.7 bbl 10.0 bbl LAS Design D972 64229.762 lb Fresh water 83.675 bbl 10.001 bbl D167 160.574 lb 0.2500%BWOB D046 128.460 lb 0.2000%BWOB D065 160.574 lb 0.2500%BWOB D153 64.230 lb 0.1000%BWOB Confidential for authorized person only 17/ 17 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Em E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 EMI E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. 1/01 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 Em E&P Division REVISION STAP-P-1-M-6140 0 1 ifillik LEAK-OFF TEST REPORT Report N' Date: WELL NAME: WELL CO DE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 MudT}pe: FWGELS Rig type: J.UPs Hole Dameter(in): 12"1/4 Weight(KgA): 1.3 R.K.B.elebat on(m): 28 Last Csg.Shoe(m): 797 Marsh Vscosity(sec/Ot): 44 Water Depth(m): 24 C .diameter(n): 131/8 F.V(cps): 19 Pumps: 12-P-160 Grade: J55 Y.P.(b1100 tt): 5 Uners(in): 6.5' Weight(b/t): 61 Gels0b/100 t7: 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W (cci30 min): 10.5 Utholog y Shale . Expected EMW 1.68 Kg/cm2/10 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bd) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 96 2 480 3 076 200 10 2 470 4 100 300 10.5 2 483 5 125 400 11 2 455 8 150 500 11.5 2 460 7 1.75 570 12 2 445 8 200 600 13 2 440 8 200 650 14 2 437 8.5 200 505 15 2 435 Nde: Pumped with a constant low rate of(bbl). \blume pumped(bbl): Glume returned(bbl): (pm) 1000 • 900 800 - stop pump r 700 ` • e 600 - shut in curve S 500 / S •`„—•—•"•—+ • • • 4 U 400 - r 8'minutes I 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(bbd 4 O. Time mins RESULTS: (Press..,,+Press.Lo.)x101Depth=[(1.3x797110)+(430x0.07)]x101797=1.68(Kg/cm2tlOm) Note: I CompanyRepresentatiue I Figure 15-1 - Leak-Off Test Report REV DATE BY CR or, asgws,LREV I DATE BY OK APP DESCRIPTION 1 0 i0/0./10 25 CC CC •' : c Drawing VICINITY MAP SCALE: 1" ' 2 i'lles 1.-; i 16-- -- 1 N ..... ......4.4 -IL%) 1 23 14 19 2',,, -4, THIS - - - ,., ,p V 1 ' ', SURVEY 2.5 30 29 26 4,t1 i -----f— . ............, .-..* ................- -,...,,, - -- ---,--— A.s a kApa3, za 3'.'.. .30 Ir 31 ..5 2 • 1,) 54 :15 "6 ;a.- 31 ir :`,. .5,a, 34 itoTHN T13N 113N ! i 2 ointo Pai -PAD,. till(1°K ;2 1 ' i Ada -- . # Nat 4, V.",IS-3R 1 D 11 ‘5 i.-'' 'a ' • ' .., . 1-• . ,./ \-- cl; — - - ,,, P• ...Nee if KID T upti r,, .._..; b •6 15 V 1 4 p„ ..:, DS-30_ • ets- • 4,4-PAO-1 „ is .i.., I' le, It _ (....... la ) 1 \..1--tr''j k4 D 30-. 'i - EA,.2. - ;000- , i t, - rl - . • -. 1 21 22 1 kt• i 9( ( 1° *' ' Wre 6 4 I . .1111 1 , 3m a 0 it. ,5 _ , -(1• ‘ , er.••pm, . , .„. ,-1 r . : OS 3Nv., il \.), ‘ ,,, • U e. : „ t• „k.. ,L , 25 27 A •kip 01 it •abon 'mr, , • \ v t • (.. r-, . G P '. • -Ni6 ..... . if) i'• . 'it... DRAWING NOTES: 1. GRID COORDINATES SHOWN ARE ALMA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM CPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH. RANGE 9 EAST. UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 :DR COORDINATE VALUES IN NA027. ,,,,,oximmiiklik 4- oF tc, SURVEYOR'S CERTIFICATE 01,73;41:::.Y--.............,6,f.......5: ; „ IN 4.1 71\ \ * # ' 49th = 0 • r .,-. :t I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND • r- . , 0 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 11...t:Of A'.44+44pca".1....1 ALASKA AND THAT THIS PLAT REPRESENTS A SUR IX Y . -A ., 0 t" 1 FRANCIS J CORNING .1 E0 DONE BY ME OR UNDER MY DIRECT SUPERVISION AND 4116,1 -• 7 d' .• i Ar THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT LS-10685 .. o . ... .....• ,40 ..ar S j..(4\•• IQ AS OF OCTOBER 01, 2010 ... / 44 Q' ..... it, PESS'ONAL,,,...• '`ItILIvasIOE.- 00 Rik,/4., IFIAllik/ 2 1 A ... SPY ISLAND DRILL SITE WELL CONDUCTORS • r ;or AS-BUILT LOCATIONS @rnIfl .4VATO. CAC FILL.E 41354309 US operafing DAm DRAWING NO. PART: : 10/01/2010 Eni-3543-d9 I 1 OF 3 1REV REV DATE BY CK 3 APP DESCRIPTION REV DATE BY CK APP DESCRIPTION C) 10/c/10 :)`iS CC CI:2 ^.: C D'CW;^g N Y 5 A.5r.-. NADB3, ltif.' 1� , 000°C° N tD t)r! V` tA * Op i WV D W el' A WV ttW3Na tN � W % O Ip DETAIL A. SCALE: 1"=80' 1 SAH05AG� _ pVEI VW- ' actI C >i0140;01,ii° 1 �(C4 iV Y tot 11:411. DETAIL A 1.E' r c i.L SPY ISLAND DRILL SITE --" ; (SID) .7.-- ___--- ..._------r_A - Ar+0$ LEGENC C S AI,E 200 � 'oWE I—® - LL CONDUCTOR AS-BUILT THIS SURVEY 1 1" - 200' 00r 6q oc SPY ISLAND DRILL SITE F/141 3 '" %I. WELL CONDUCTORS fp���. +�� ��, � AS—BUILT LOCATIONS II11n .nth "A'1, ;' CAD FIE EN �a operra iirnif j DAit /0./20t0 DRAWING NO: Eni-3543—d9 (PAT. 3 1RE• REv' DATE BY CK APP DESCRIPTION RtV' DATE ' CK APP DESCRIPTION 0 ;',./C...IC D' S CC ::. .: . .. C. Dr c kfv.rri Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. 'Y' 'X' _atitude (N) Longitude(W) F.N.L F.E.L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70°33'27.209" 149'54'24.765" 797 1171 12.4 2 6053421.65 1651761.87 70°33'27.1.94" 149'54'25.000" 798 1179 12,4 3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 12,4 4 6053418.56 1651746.17 70'33'27.164" 149'54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70`33'27.149" 149'54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149'54'25.925" 804 1210 12.4 7 6053412.44 1651714.77 70°33'27.104" 149"54'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70°33'27.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70°33'27.074" 149°54'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70'33'27.060" 149'54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149°54'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70°33'27.029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70'33'26.986" 149'54'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70°33'26.971' 149'54'28.453" 821 12% 12.4 15 6053397.31 1651637.12 70'33'26.956" 149°54'28.685" _ 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149'54'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70'33'26.927" 149°54'29.147" 825 1319 12.4 18 6053392.78 1651613.58 70°33'26.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 _ 70°33'26.881" 149'54'29.843" 830 1343 12.4 20 6053388.17 1651590.00 70°33'26.867" 149°54'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70'33'26.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70°33'26.838" 149°54'30.538" 834 _ 1366 12.4 23 6053383.64 1651566.41 70°33'26.823" 149°54'30.773" 836 1374 12.4 24 6053382.12 1651558.61 70°33'26.808" 149°54'31.003" 837 1382 12,4 25 6053377.65 1651535.94 70°33'26.764" 149'54'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70'33'26.750" 149°5431.904" 843 1413 12.4 27 6053374.53 1651520.23 70'33'26.734" 149°54'32.137" 845 1421 12.4 28 6053373.11 1651512.46 70°33'26.720" 149°54'32.366" 846 1428 12.4 29 6053371.56 1651504.49 70°33'26.705° 149'54'32.602" 848 1436 12.4 30 6053370.06 1651496.66 70'33'26.690" 149°54'32.833" 849 1444 12,4 31 6053367.05 1651480.97 70°33'26.661" 149°54'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70°33'26.646" 149°54'33.527' 854 1468 12.4 33 6053363.93 1651465.22 70'33'26.631" 149°54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70'33'26.616" 149°54'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'26.601" 149°54'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149°54'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70°33'26.555" 149°54'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70°33'26.541" 149°54'35.177" 864 1524 12.4 irili* li L, SPY ISLAND DRILL SITE 4. WELL CONDUCTORS • AS-BUILT LOCATIONS (Mil 1/4.„,„.„,'..1 CAD FILE:ENI3543C9 US Oper ILA11c DAT Eojot,2010 DRAWING NO: En l-3543-d 9 PA 3:or 3 I REPO. N +T N O -C 0 5 O "' a > a a a a a a a a a a a a a a a a a a a a a a a a a a a a C .on, y u m 01 N N N N N N N N N N N N N N N N N N N N N N N N N N N N Q Z Qo .d W N N N N N a-1 N s-1 N N N N e-1 N N s-I e-1 N a-I N N N N N N N N e-1 ��-I 0?l 'C L W 7 In C N J aN N N g-I C71 N Ln 0ID ri GI ND NN0OONMaa1nt00Oe1s-I a A 1A CO 1-1 00 D N 0 O ,I N CO o Ou NNN NN NNNNN NNN NMMMMMMMMMMaaNaa N 01 C = C Cp a a aa N LL N N CO 00 000 CO CO 000 CO CO CO CO CO 00 00 00 00 00 00 00 00 00 00 00 00 M W 0000 3 00 o0 17 N 0 M 0 01 N N ut Oo 01 N N M M I. O a M in M N N N a a en N a 00 O a O N 1. 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These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME S Q2..1 -14 / PTD# )-/ ( ( c Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /q l' j tiC�I (� POOL: &kade 61 14-1-f- Check Box for Appropriate etter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 0 , I 3 G m D 0 r -. CO m 'D B 0' ° a v r 0 . .3m y ; 0 _, '3 0 s0 0 moo o `° i.cp 0 0 (0 ` OO COO N O 0 CO 0 = O 7 N N R o O O O - - - -- --C w (A w w w w GJ co w N IV N N N N N N Iv N - _ (O OD V 0) CT . w N ° (0 0) V 0) O A CO N O CO CO V (T CT A W N O CO CO 1 0) CT A w N 0 V CD n c.) b '1 K '" * 0 'co 0o ;v D '� D n 0 'n 'n to n '� D ,g n '" '- 'O o '0) * g ;* 'C '� b z C) 0 0 y 0 co 0 0 O 3. 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C..) . . w CID S = v O 3 7 OO 3 'w 0 c a a< O = sa D 7 0 c - nl Q O O 0D N -D CD O CO 0 CD ❑❑ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: January 1st, 2012 Surface Data Logging End of Well Report SP27-N1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Show Reports 8. Survey Report 9. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI File LAS File GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP27-N1 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23458-00-00 Sperry Job Number: AK-AM-0009098177 Job Start Date: 20 Nov 2011 Spud Date: 2 Dec 2011 Total Depth: 14,155’ MD; 3,745’ TVD North Reference: True Declination: 20.812 Dip Angle: 81.062 Total Field Strength: 57651 nT Date Of Magnetic Data: 25 Nov 2011 Wellhead Coordinates N: North 70° 33’ 27.77” Wellhead Coordinates W: West 149° 54’ 20.75“ Drill Floor Elevation 53.87’ Ground Elevation: 13.1’ Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Jessica Munsell, Zachary Beekman, Dave Mckechnie Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SP27-N1 11/20/2011 - 11/25/2011 Rig performing maintenance. No power is in the unit. 11/26/2011 Rigging up unit. 11/27/2011 Rigging up unit. 11/28/2011 Rigged up unit and gas equipment. 11/29/2011 Finished rigging up unit and gas equipment. Mudloggers Jessica Munsell and Leigh Ann Rasher arrived on location. 11/30/2011 Mudlogger Zachary Beekman left location and Emil Opitz arrived on location. Set up WITS with Canrig. 12/01/2011 Calibrated gas analyzer and gas chromatograph. 12/02/2011 Continued to rig up for drilling. Picked up 16” bit. Cleaned out conductor and drilled to 193’ MD. Pulled out of the hole and made up BHA #2. The average background gas was 5 units. No samples being caught during surface per well plan. 12/03/2011 Continued to make up BHA #2. Ran in the hole and shallow tested the tools – ok. Drilled to 929’ MD. Pulled out of the hole to 838’ MD and circulated bottoms up three times. Pulled out of the hole on elevators. Laid down BHA #2 and picked up BHA #3. Ran in the hole and drilled ahead. The max gas was 44 units at 1020’ MD and the average background gas was 16 units. A max trip gas of 24 units was noted. No samples being caught during surface per well plan. 12/04/2011 Drilled ahead to TD at 2680’ MD / 2480’ TVD. Back reamed out of hole from 2680’ MD to 1297’ MD. The max gas was 575 units at 1767’ MD and the average background gas was 154 units. No samples being caught during surface per well plan. 12/05/2011 Continued to pull out of the hole from 1297’ MD to 924’ MD. Circulated bottoms up one time. Continued running out of the hole to 830’MD and circulated bottoms up two times. Monitor well – static. Pulled out of the hole, laid down BHA #3, and rigged up and ran 13 3/8 casing into the hole. Ran to 1700’ MD and circulated bottoms up once and continued to run casing to 2664’ MD. Rigged up for cementing casing. A max trip gas of 252 units was noted. 12/06/2011 Rigged up cement head. Established circulation, conditioned mud for cement. Pumped cement, reciprocating pipe whilst pumping. Displaced cement with 9.6 ppg mud; casing string began to hang up above desired depth. Decision made to sit above hanger landing point and finish displacement. Tried to bump plug – did not bump. Attempted to set down on hanger, but casing string did not have any downward movement. Tried to work casing string to free – unsuccessful. Pumped 6 more barrels, plug did not bump. Cement in place at 0730 hrs. Nippled down and prepped to install emergency slips. Rigged down landing joint and casing tools. Prepared for cutting casing in emergency slips. A max trip gas of 194 units was noted. 12/07/2011 Cut 13 3/8” casing, tested lower seals for 10 minutes – OK. Nippled up BOP stank and rise, and tested BOP. Changed out bad valve on choke manifold. Continued to test BOP. 12/08/2011 Finished testing BOPs. Shallow tested 13 3/8 casing to 2500 psi for 30 minutes – good. Picked up BHA #4 and ran in the hole. Tagged cement at 2451’ MD. Circulated and conditioned mud. Tested casing to 2500 psi for 30 minutes – good. Tagged top plug at 2461’ MD and cleaned out cement to 2522’ MD. Continued to drill out cement. 12/09/2011 Finished drilling out shoe track. Drilled 30’ of new formation to 2710’ MD. Displaced Spud Mud with LSND. Performed LOT to 13.9 ppg EMW. Drilled ahead. The samples have been light gray, clear, brown, very fine to medium grained, unconsolidated sandstone, with small amounts of siltstone and claystone. The max gas was 95 units at 3028’ MD and the average background gas was 25 units. 12/10/2011 Drilled ahead to 4333’ MD. Circulated bottoms up three times. The decision was made to pull out of the hole due to a MWD tool failure. Back reamed out of the hole per K&M representative to 2396’ MD. There were heavy clays at the shakers at bottoms up. Pulled out of the hole on elevators. Laid down BHA #4 and made up BHA #5. Ran in the hole to 2625’ MD. Prepared to cut and slip drill line. The samples before pulling out of the hole were light gray, clear, very fine to fine grained, well sorted sandstone with a very small percentage of siltstone. The max gas was 83 units at 4264’ MD and the average background gas was 15 units. A max trip gas of 31 units was noted. 12/11/2011 Cut and slipped drill line. SLB calibrated blocks. Ran in the hole to 4333’ MD. Drilled through many concretions, which made for slow ROP sections. The samples were translucent, black, medium to light gray, fine to coarse grained, poorly sorted, unconsolidated sandstone. The max gas was 49 units at 4935’ MD and the average background gas was 19 units. 12/12/2011 Continued to drill ahead. Hard spots encountered throughout this section, slowing down ROP. The samples were light gray, black, translucent, poorly sorted, unconsolidated sandstone with trace amounts of pyrite. The max gas was 39 units at 5709’ MD and the average background as was 13 units. 12/13/2011 Continued to drill ahead. Hard spots continued slowing ROP throughout this section. The samples were medium gray, translucent, fine to medium grained, unconsolidated sandstone. The max gas was 661 units at 5963’ MD and the average background gas was 155 units. 12/14/2011 Drilled ahead to 6553’ MD. Back reamed out of the hole to 2624’ MD. Circulated and conditioned mud. Circulated bottoms up three times as per K&M rep or as hole dictates. Continued to pull out of the hole. The samples before pulling out of the hole were translucent, light gray, fine to medium grained, poorly sorted, unconsolidated sandstone with abundant pyrite. The max gas was 35 units at 6526’ MD and the average background gas was 12 units. A max trip gas of 24 units was noted. 12/15/2011 Finished pulling out of the hole. Laid down BHA #5. Rigged up and tested BOPs, rigged down test equipment. Began picking up BHA #6. 12/16/2011 Finished picking up BHA #6. Ran in the hole to 4800’ MD. Broke circulation and washed to 6553’ MD. Drilled ahead. The samples were light gray, translucent, black, poorly sorted unconsolidated sandstone with pyrite and oil shows. The shows had no odor, 20% light brown stain, 30% patchy yellow fluorescence, with a streaming dull yellow cut. There was brown oil at the shakers at 6850’ MD. The max gas was 447 units at 6945’ MD and the average background gas was 107. A max trip gas of 15 units was noted. 12/17/2011 Drilled ahead to intermediate TD 8261’ MD. Circulated to clean hole, and back reamed out of the hole. The samples before TD were translucent, black, medium to very fine grained, calcareous, unconsolidated sandstone with oil shows. The shows had no odor and no staining, 30% patchy dull yellow fluorescence and a slow yellow white cut. The max gas was 2492 units at 8185’ MD and the average background gas was 250 units. A max trip gas of 172 units was noted. 12/18/2011 Back reamed out of the hole to 2618’MD. Circulated hole clean. Pulled out of the hole on elevators. Laid down BHA #6. Changed out rams and tested them. Rigged down testing equipment. 12/19/2011 Rigged up to run 9 5/8 casing. Picked up show track and backer-loc. Floated 9 5/8 casing to bottom. Installed Hp hose to take air returns through cement head to choke manifold. Started filling casing to half cap at 3 barrels a minute. Max trip gas of 27 units was noted. 12/20/2011 Continued to fill 9 5/8 casing as per well program. Circulated and conditioned mud for cement job. Pumped cement. Bumped plug at 6032 strokes. Nippled down BOPs. Dressed top of casing and installed pack off. Started to nippled up Bops and continued to clean pits. 12/21/2011 Tested 9 5/8 pack off. Changed pipe rams. Nippled up choke line and aligned the stack over the hole. Rigged up and tested BOPs. Rigged down from testing blow down choke and kill line. Pulled test plug/installed wear bushing. Picked up BHA #7 as per Schlumberger DD and MWD. 12/22/2011 Trip in hole with BHA #7 and shallow test MWD. Single in hole to 5610' MD. Run in hole from 5610' to 7692' MD. Wash down from 7952' MD to 8149' MD. Pressure test casing. Cut and slip drill line. Displace with 9.4 OBM as of midnight. Mudlogger Dave McKechnie arrived on location. 12/23/2011 Drill shoe track and rat hole from 8146' MD to 8261' MD. Drill ahead from 8261' MD to 8285' MD. Circulate and condition mud for FIT/LOT. Rig up and perform successful LOT. Drill ahead from 8507' MD to 8638' MD. Back ream out of hole from 8638’ MD to 8154’ MD due to excess torque. Drill ahead from 8638’ MD to 8820’ MD as of midnight. Mudloggers Jessica Munsell and Leigh Ann Rasher left location. 12/24/2011 Drilling ahead from 8879’ MD to 10645’ MD as of midnight. Max gas for the past 24 hours was 1812u at a depth of 9801’ MD. 12/25/2011 Drilling ahead from 10645' MD to 12802' MD as of midnight. Max gas for the past 24 hours was 956u at a depth of 11641’ MD. 12/26/2011 Drill ahead from 12805' MD to TD at 14155' MD/3745' TVD. Circulate the hole clean standing back one stand for the first four bottoms up. Continue to circulate the hole clean standing back 2 stands for the next 5 bottoms up. Currently we are back reaming out of the hole as of midnight. The max gas was 1612 units at a depth of 13,689’ MD and the average background was around 200 units. 12/27/2011 Backream out of the hole to 12899’ MD at 550 gpm, 130 rpm, and 2400 psi. Backream from 12899’ to 6500’ MD at 550 gpm, 130 rpm, and 1960 psi at four minutes per stand. Circulate three annular volumes at 550 gpm. Pump a dry job. Pull out of the hole to 6000’ MD at four minutes per stand. Three minutes per stand to 5000’ MD and 1.5 minutes per stand to 290’. Pre job safety meeting prior to laying down nuke sources as of midnight. 12/28/2011 Lay down 8 ¾” BHA. Pull wear ring. Rig up and test BOPE’s. Install wear bushing. Rig up GBR 5 ½” casing equipment. Run 5 ½” 15.5 ppf slotted liner. 140 joints slotted, 6 joints solid and 2 swell packers run to 6040’ MD. Pick up crossover, seal bore, crossover and liner packer as of midnight. 12/29/2011 Run in the hole with 5 ½” liner to 6165’ MD. Circulate 5 bbls at 2.5 bpm. Run in the hole with liner on 5” drill pipe to 8218’ MD. Circulate pipe volume at 3.5 bpm. Run in the hole to 14102’ MD. Drop the ball and ovserve on seat. Set packer per Baker representative. Release from the packer. Displace FazePro OBM to 9.00 lb/gal 3% KCL/NaCl Brine. Lay down 5” drill pipe from 8028’ MD to 1488’. 212 joints laid down. 12/30/2011 Continue laying down 46 joints of 5” drill pipe. Run in hole with 37 stands of 5” drill pipe. Slip and cut drill line. Lay down 111 joints of 5” drill pipe. Rig up and remove wear ring. Load floor with ESP and GBR equipment. Rig up slick line. Load the pipe shed with tubing in prep to run tubing with the ESP pump assembly. 1231/2011 Secure motor splice and perform electrical checks. Continue to trip in hole with 4 ½” completion tubing to 7294’ MD. Testing lines every 1000’. Pick up hanger and make up tubing hanger. Make final splice of ESP cable and test the conductivity. Test was good. Land 4 ½” completion string. Test upper and lower hanger body seals at 5000 psi for 10 minutes as of midnight. Serviced gas gear. Began running in the hole with 4 ½” tubing at 06:15. 01/01/2012 Nipple down BOPE. Nipple up production tree and test. Shear out valve in upper GLM. Displace above SOV to diesel. Secure well. Rig down and move. This is the final Sperry daily report for this well. Rigged down the unit for rig move. ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air Trip 24 hr Recap: YP Cor Solids (lb/100ft2) 1,5009.00 mg/lml/30min API FL 1 Cht Silt Siltst 8.70 Chromatograph (ppm) Ss 5.3 Lst 160' 23 ClystCly Gas Summary 24 0 Sh 22.0 22 1.117 1 2-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools 16 Size Hughes MX-1 193' TuffGvlCoal C-5n 2.0 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max M/U BHA #2Rig Activity: Flow In (spm) 305.3 $2,810.00 $26,610.00 Report For:Ross/W alls/BuchananTotal Charges: 160' 193' 33' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)176'165.3 MWD Summary md. in Drilling All Circ Continue to R/U to begin drilling SP27-N1. Clean out conductor and drill to 193' MD. POOH. M/U BHA #2. % - 5 - 4.23 Hours Depth in / out Footage W OB RPM Condition 160' to 3 5 5 Logging Engineers:Emil OpitzReport By:Emil Opitz / Jessica Munsell 193' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 17 18 0 0 0 0 Background Maximum Minimum Average 0 0 0 0 0 0 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 Units* 0 0 0 Depth 0 ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air 0 0 Units* 0 0 0 Depth 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 17 1158 Area: Location: 96% 654 155 SPP (psi) Gallons/stroke 1082 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 1202' Depth Daily Charges: 145.0 Logging Engineers:Emil OpitzReport By:Emil Opitz / Jessica Munsell 29 44 3 4.23 Hours Depth in / out Footage W OB RPM Condition 193' to in Drilling All Circ Continue to M/U BHA #2. RIH, shallow test tools - ok. Drill to 929' MD. BROOH to 838' MD. CBU 3x. POOH on elevators % - 16 - md. NOTE: No samples being caught during surface per well plan. Max @ ft Current ROP (ft/hr)456'265.7 MWD Summary 193' 1202' 1009' Flow In (gpm) Current Pump & Flow Data: - Drilling AheadRig Activity: Flow In (spm) 760.0 $2,810.00 $29,420.00 Report For:Ross/W alls/BuchananTotal Charges: AvgMin Max Max 2.5 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 1020' 259' 16 Size Hughes MX-1 1012' (ppb Eq)cP PV PWD MBT Tools ARC 825; PowerPulse 825 ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 2 3-Dec-2011 24:00:00Time: Report #: Date: Sh 17.5 36 1.117 Gas Summary 4790 0 19 ClystCly 160' 9.10 Chromatograph (ppm) Ss 4.9 Lst 1 Cht Silt Siltst YP Cor Solids (lb/100ft2) 3,3009.00 mg/lml/30min API FL Trip 24 24 hr Recap: ROP . . Mud Data:Density (ppg)Viscosity Depth ft out (sec/qt) Bit # Lithology (%): (current) *10000 units = 100% Gas In Air Trip 346 24 hr Recap: YP Cor Solids (lb/100ft2) 2,0008.50 mg/lml/30min API FL 1 Cht Silt Siltst 9.70 Chromatograph (ppm) Ss 5.6 Lst 160' 28 ClystCly Gas Summary 51063 0 Sh 18.0 33 1.117 3 4-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools ARC 825; PowerPulse 825 1767' 1293' 16 Size Hughes MX-1 2680' TuffGvlCoal C-5n 4.0 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max POOHRig Activity: Flow In (spm) 576.8 $2,810.00 $32,230.00 Report For:Ross/W alls/BuchananTotal Charges: 1202' 2680' 1478' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)1921'265.7 MWD Summary md. NOTE: No samples being caught during surface per well plan. in Drilling All Circ Drill ahead to TD of 2680' MD. BROOH from 2680' to 1297' MD. % - 154 - 4.23 Hours Depth in / out Footage W OB RPM Condition 1202' to 69 575 23 Logging Engineers:Emil OpitzReport By:Emil Opitz / Jessica Munsell 2680' Depth Daily Charges: 0.0 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 0 0 SPP (psi) Gallons/stroke 0 @ Yesterday's Depth: 2052 17045 0 0 0 0 Background Maximum Minimum Average 0 0 0 0 0 0 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 Units* 0 0 0 Depth 0 . . Density (ppg)Viscosity Depth ft out (sec/qt) *10000 units = 100% Gas In Air EVAMAR Make W eight Grade Lithology (%) (current) Gas Summary Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) 20" 13 3/8" 160' 0 0 Units* 0 0 0 Depth 0 C-4i C-4n C-5iC-1 C-2 C-3 0 0 0 0 00 Background Maximum Minimum Average 0 0 0 0 0 0 0 Area: Location: 96% 246 61 SPP (psi) Gallons/stroke 164 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 2680' Depth Daily Charges: 0.0 Report By:Emil Opitz 40 4.23 Hours Depth in / out Footage WOB RPM Condition 2680' to in Drilling All Circ Continued to BROOH to 830' MD, monitor well - static, POOH. L/D BHA. R/U CSG. Run 13 3/8 CSG in hole. R/U for % -- md. Max @ ft Current ROP (ft/hr)0'0.0 MWD Summary 2680' 2680' 0' Flow In (gpm) Current Pump & Flow Data: - CasingRig Activity: Flow In (spm) 0.0 $2,810.00 $35,040.00 Report For:Ross/W alls/BuchananTotal Charges: AvgMin Max Max 3.5 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 16 Size Hughes MX-1 2680' (ppb Eq)cP PV PWD MBT Tools ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 4 5-Dec-2011 24:00:00Time: Report #: Date: Sh 15.40 18.0 34 1.117 0 0 25 ClystCly 160' 2680' 2520' 9.60 40.0 Chromatograph (ppm) 20.0 Ss 5.6 Lst 1 Cht Silt Siltst YP 0-0-NO-A-E-I-NO-TD Cor Solids (lb/100ft2) 2,0008.60 mg/lml/30min API FL Trip 252 24 hr Recap: . . Density (ppg)Viscosity Depth ft out (sec/qt) *10000 units = 100% Gas In Air 194 24 hr Recap: Trip YP 0-0-NO-A-E-I-NO-TD Cor Solids (lb/100ft2)mg/lml/30min API FL 1 Cht Silt Siltst 40.0 Chromatograph (ppm) 20.0 Ss Lst 160' 2680' 2520' ClystCly 0 0 Sh 15.401.117 5 6-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools 16 Size Hughes MX-1 TuffGvlCoal C-5n Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max Cutting CasingRig Activity: Flow In (spm) 0.0 $3,110.00 $38,150.00 Report For:Keener/Walls/BuchananTotal Charges: 2680' 2680' 0' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)0'0.0 MWD Summary md. issue and working on resolving it. We are also awaiting on GCI to come out and troubleshoot and repair our communication equipment; we have been having intermittent phone and data service in our unit for the duration of this well. landing point and finish displacment. Tried to bump plug - did not bump. Attempted to set down on hangar, but casing string did not have any downward movement. Tried working casing string to free - unsuccessful. Pumped 6 more barrels, plug did not bump. Cement in place @ 0730hrs. N/D and prep to install emergency slips. R/D landing joint and casing tools. Prepare for cutting casing in emergency slips. in Drilling All Circ R/U cement head. Establish circulation, condition mud for cement. Pump cement, recriprocating pipe whilst pumping. % -- 4.23 Hours Depth in / out Footage W OB RPM Condition 2680' to 2680' Depth Daily Charges: 0.0 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0 0 0 Background Maximum Minimum Average C-4i C-4n C-5iC-1 C-2 C-3 0 Depth 0 0 0 0 0 00 0 0 Units* 0 0000 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) We, Sperry, have experienced power outages in our unit on 3 occasions today, one lasting for over 3 hours. The rig is aware of the Report By:Emil Opitz Gas Summary Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary Weight Grade Lithology (%) (current) 20" 13 3/8" 160' 2664' EVAMAR Make 68.0 L-80 . . Density (ppg)Viscosity Depth ft out (sec/qt) *10000 units = 100% Gas In Air L-80 Make 68.0 Weight Grade Lithology (%) (current) 20" 13 3/8" 160' 2664' Gas Summary Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz 0 0 Units* 0 0000 0 Depth 0 0 0 0 0 00 C-5iC-1 C-2 C-3 Maximum Minimum Average 0 0 00 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 2680' Depth Daily Charges: 0.0 4.23 Hours Depth in / out Footage W OB RPM Condition 2680' to in Drilling All Circ Cut 13-3/8" casing, test lower seals for 10 minutes - OK. Nipple up BOP stack and riser. Test BOPs. Change out bad % -- md. Max @ ft Current ROP (ft/hr)0'0.0 MWD Summary 2680' 2680' 0' Flow In (gpm) Current Pump & Flow Data: - Testing BOPRig Activity: Flow In (spm) 0.0 $3,410.00 $41,560.00 Report For:Keener/Walls/BuchananTotal Charges: AvgMin Max Max Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n Size 2680' (ppb Eq)cP PV PWD MBT Tools ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 6 7-Dec-2011 24:00:00Time: Report #: Date: Sh 17 0 0 C-4i C-4n 21 ClystCly 9.50 Chromatograph (ppm) Ss LstChtSiltSiltst EVAMAR YP Cor Solids (lb/100ft2) 9.20 mg/lml/30min API FL Trip 24 hr Recap: Background . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 2680'Spud Mud Depth Mud Type 24 hr Recap: Background Trip YP Cor Solids (lb/100ft2) 9.50 mg/lml/30min API FL 2 Cht Silt Siltst EVAMAR 9.60 Chromatograph (ppm) Ss Lst 2680' 0 C-4i C-4n 18 0.942 20 7 8-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 46 12 1/4" Size Hughes VM-3 Milltooth TuffGvlCoal C-5n Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max Drill out cementRig Activity: Flow In (spm) 0.0 $3,410.00 $44,970.00 Report For:Keener/Walls/BuchananTotal Charges: 2680' 2680' 0' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)0'0.0 MWD Summary md. in Drilling All Circ Finish testing BOPs. P/U BHA#4 & RIH. Tag cement @ 2451' MD. Circulate and condition mud. Test casing to % -- 4.23 Hours Depth in / out Footage W OB RPM Condition 2680' to 2680' Depth Daily Charges: 0.0 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 596 141 SPP (psi) Gallons/stroke 962 @ Yesterday's Depth: 0 0 0 0 0 Maximum Minimum Average C-2 C-3 0 Depth 0 0 0 0 0 00 0 Units* 0 0000 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 160' 2664' Gas Summary ShClystCly Lithology (%) (current) 20" 13 3/8" Make 68.0 W eight Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air Grade L-80 20" 13 3/8" Make Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Units* 0 000848 0 Depth 0 0 0 0 0 00 C-2 C-3 Maximum Minimum Average 0 02624 12063 Area: Location: 96% 706 167 SPP (psi) Gallons/stroke 1174 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 4071' Depth Daily Charges: 82.2 95 8 4.23 Hours Depth in / out Footage W OB RPM Condition 2680' to in Drilling All Circ Finish drilling out shoe track. Drill 30' of new hole to 2710' MD. Displace Spud Mud to LSND. Perform LOT to 13.9ppg % - 25 - md. Max @ ft Current ROP (ft/hr)3037'250.4 MWD Summary 2680' 4071' 1391' Flow In (gpm) Current Pump & Flow Data: - Drill AheadRig Activity: Flow In (spm) 425.3 $3,410.00 $48,380.00 Report For:Keener/Walls/BuchananTotal Charges: AvgMin Max Max 4.5 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 0 Size Hughes VM-3 Milltooth 160' 2664' ShClystCly 3028' 3617' Gas Summary Lithology (%) (current) (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 8 9-Dec-2011 24:00:00Time: Report #: Date: 9.15 5.5 28 0.942 1051 12 1/4" 0 C-4i C-4n 0 2680' 68.0 Weight 9.30 Chromatograph (ppm) Ss 4.0 Lst 2 15 Cht Silt Siltst 85 EVAMAR YP Cor Solids (lb/100ft2) 1,3009.20 mg/lml/30min API FL Trip 24 hr Recap: 10Background 4001'LSND Depth Mud Type . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 4333'LSND Depth Mud Type 31 24 hr Recap: Background Trip YP 1-0-WT-1-I-E-NO-DTF Cor Solids (lb/100ft2) 1,6009.70 mg/lml/30min API FL 2 3 Smith GFS20B Insert 10 Cht Silt Siltst 90 EVAMAR 9.20 120.0 Chromatograph (ppm) 25.0 Ss 4.2 Lst 2680' 4333' 1653' 4333' 0 C-4i C-4n 13.30 12.5 25 0.942 1357 12 1/4" 9 10-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 12 1/4"1.117 Gas Summary Lithology (%) (current) 68.0 Weight Size Hughes VM-3 Milltooth 160' 2664' ShClystCly TuffGvlCoal C-5n 0 4.8 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max Cut and Slip Drill LineRig Activity: Flow In (spm) 418.9 $3,410.00 $51,790.00 Report For:Keener/Walls/BuchananTotal Charges: 4071' 4333' 262' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)4250'213.3 MWD Summary md. in Drilling All Circ Drill ahead to 4333' MD. Circulate 3x B/U. MWD tool failure, decision made to POOH. BROOH per K&M rep. to 2396' MD % - 15 - 4.23 Hours Depth in / out Footage WOB RPM Condition 4071' to 83 3 4333' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 4264' 4256' 0 01389 8480 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 000304 C-2 C-3 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 20" 13 3/8" Make Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 5399'LSND Depth Mud Type 24 hr Recap: 2Background Trip YP Cor Solids (lb/100ft2) 1,7009.40 mg/lml/30min API FL 3 Cht Silt Siltst 100 EVAMAR 9.30 Chromatograph (ppm) Ss 3.5 Lst 4333' 0 0 C-4i C-4n 0 13.0 23 1.117 1253 12 1/4" 10 11-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 Gas Summary Lithology (%) (current) 68.0 Weight Size Smith GFS20B Insert 160' 2664' ShClystCly TuffGvlCoal C-5n 0 5.8 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max Drilling AheadRig Activity: Flow In (spm) 513.8 $3,410.00 $55,200.00 Report For:Keener/Walls/BuchananTotal Charges: 4333' 5470' 1137' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)5335'225.4 MWD Summary md. in Drilling All Circ Cut and slip drill line. SLB Calibrated blocks. RIH and begin drilling from 4333' MD. Drilling through many % - 19 - 4.23 Hours Depth in / out Footage WOB RPM Condition 4333' to 49 5 5470' Depth Daily Charges: 2.6 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 905 114 SPP (psi) Gallons/stroke 1654 @ Yesterday's Depth: 4935' 5470' 1597 5965 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 000268 C-2 C-3 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 20" 13 3/8" Make Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air Grade L-80 20" 13 3/8" Make Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Units* 0 000238 C-2 C-3 0 Depth 0 0 0 0 0 00 Maximum Minimum Average 0 904 46615709' 5837' Area: Location: 96% 783 185 SPP (psi) Gallons/stroke 1329 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 5914' Depth Daily Charges: 1.4 39 4 4.23 Hours Depth in / out Footage W OB RPM Condition 5470' to in Drilling All Circ Continue to drill ahead. Hard spots encountered slowing ROP throughout this section. % - 13 - md. Max @ ft Current ROP (ft/hr)5516'194.4 MWD Summary 5470' 5914' 444' Flow In (gpm) Current Pump & Flow Data: - Drilling AheadRig Activity: Flow In (spm) 595.4 $3,410.00 $58,610.00 Report For:Keener/Walls/BuchananTotal Charges: AvgMin Max Max 6.0 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 0 Size Smith GFS20B Insert 160' 2664' ShClystCly Gas Summary Lithology (%) (current) 68.0 Weight (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 11 12-Dec-2011 24:00:00Time: Report #: Date: 12.5 22 1.117 1152 12 1/4" C-4i C-4n 0 0 0 4333' 9.20 Chromatograph (ppm) Ss 3.6 Lst 3 Cht Silt Siltst 100 EVAMAR YP Cor Solids (lb/100ft2) 1,6009.50 mg/lml/30min API FL Trip 24 hr Recap: 3Background 5911'LSND Depth Mud Type . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 6412'LSND Depth Mud Type 24 hr Recap: 4Background Trip YP Cor Solids (lb/100ft2) 1,6009.60 mg/lml/30min API FL 3 Cht Silt Siltst 100 EVAMAR 9.40 Chromatograph (ppm) Ss 3.6 Lst 4333' 25 4 C-4i C-4n 6 13.0 20 1.117 1151 12 1/4" 12 13-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 Gas Summary Lithology (%) (current) 68.0 Weight Size Smith GFS20B Insert 160' 2664' ShClystCly TuffGvlCoal C-5n 0 7.5 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max Drilling AheadRig Activity: Flow In (spm) 333.5 $3,410.00 $62,020.00 Report For:Keener/Smith/BuchananTotal Charges: 5914' 6414' 500' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)5944'18.3 MWD Summary md. in Drilling All Circ Continue to drill ahead. Hard spots continue slowing ROP throughout this section. % - 155 - 4.23 Hours Depth in / out Footage WOB RPM Condition 5914' to 661 4 6414' Depth Daily Charges: 21.2 Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 609 144 SPP (psi) Gallons/stroke 928 @ Yesterday's Depth: 5963' 6362' 11712 83552 123Maximum Minimum Average 0 Depth 0 0 1 0 0 00 Units* 0 000264 C-2 C-3 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 20" 13 3/8" Make Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air Grade L-80 20" 13 3/8" Make Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Units* 0 000337 C-2 C-3 0 Depth 0 0 0 0 0 00 Maximum Minimum Average 20 1190 40166526' 6454' Area: Location: 96% SPP (psi) Gallons/stroke 0 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 6553' Depth Daily Charges: 35 5 4.23 Hours Depth in / out Footage W OB RPM Condition 6414' to in Drilling All Circ Drill ahead to 6553' MD. BROOH to 2624' MD. Circulate and condition mud. CBU 3x as per K&M rep or as hole dictates % - 12 - md. Max @ ft Current ROP (ft/hr)6454'21.8 MWD Summary 6414' 6553' 139' Flow In (gpm) Current Pump & Flow Data: - POOHRig Activity: Flow In (spm) 79.8 $3,410.00 $65,430.00 Report For:Keener/Smith/BuchananTotal Charges: AvgMin Max Max 7.5 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 0 Size Smith GFS20B Insert 160' 2664' ShClystCly Gas Summary Lithology (%) (current) 68.0 Weight (ppb Eq)cP PV PWD MBT Tools Xceed 900, PowerPulse 825, ARC 825 ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 13 14-Dec-2011 24:00:00Time: Report #: Date: 13.5 24 1.117 1257 12 1/4" C-4i C-4n 3 4 0 4333' 9.30 Chromatograph (ppm) Ss 3.6 Lst 3 Cht Silt Siltst 100 EVAMAR YP Cor Solids (lb/100ft2) 2,7009.30 mg/lml/30min API FL Trip 24 24 hr Recap: Background 6553'LSND Depth Mud Type . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 6553'LSND Depth Mud Type 24 hr Recap: Background Trip YP 3-5-W T-G-E-2-RG-PR Cor Solids (lb/100ft2) 2,5009.30 mg/lml/30min API FL 3 4 RR Hughes Mill Tooth VM-3 Cht Silt Siltst EVAMAR 9.40 120.0 Chromatograph (ppm) 25.0 Ss 3.7 Lst 4333' 6553' 2220' 6553' 0 0 C-4i C-4n 0 59.90 13.5 23 1.117 1150 12 1/4" 14 15-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools 12 1/4"0.942 Gas Summary Lithology (%) (current) 68.0 Weight Size Smith GFS20B Insert 160' 2664' ShClystCly TuffGvlCoal C-5n 0 7.5 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max RIH BHA#6Rig Activity: Flow In (spm) $3,410.00 $68,840.00 Report For:Keener/Smith/BuchananTotal Charges: 6553' 6553' 0' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr) MWD Summary md. in Drilling All Circ Finish POOH. L/D BHA #5. Test BOPs. PJSM for P/U BHA #6. P/U BHA #6 and RIH. % -- 4.23 Hours Depth in / out Footage WOB RPM Condition 6553' to 6553' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke 0 @ Yesterday's Depth: 0 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 C-3 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 20" 13 3/8" Make Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air Grade L-80 20" 13 3/8" Make Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 26 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Units* 98 000359 C-2 C-3 23 Depth 98 0 59 68 0 5852 Maximum Minimum Average 668 7477 521246945' 6745' Area: Location: 96% 910 215 SPP (psi) Gallons/stroke 2374 @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 7474' Depth Daily Charges: 110.0 447 3 4.23 Hours Depth in / out Footage W OB RPM Condition 6553' to in Drilling All Circ Finish P/U BHA#6. RIH w/ BHA#6 to 4800' MD. Break Circ and wash to 6553' MD. Drill ahead. % - 107 - md. Max @ ft Current ROP (ft/hr)6909'174.0 MWD Summary 6553' 7474' 921' Flow In (gpm) Current Pump & Flow Data: - Drilling AheadRig Activity: Flow In (spm) 617.0 $3,410.00 $72,250.00 Report For:Keener/Smith/BuchananTotal Charges: AvgMin Max Max 7.6 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 0 Size Hughes Mill Tooth VM-3 160' 2664' ShClystCly Gas Summary Lithology (%) (current) 68.0 Weight (ppb Eq)cP PV PWD MBT Tools PowerDrive900, Telescope, ARC 825 ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 15 16-Dec-2011 24:00:00Time: Report #: Date: 14.5 25 0.942 1455 12 1/4" 10 C-4i C-4n 219 101 62 6553' 9.40 Chromatograph (ppm) Ss 3.2 Lst 4 RR Cht Silt Siltst 90 EVAMAR YP Cor Solids (lb/100ft2) 3,5009.20 mg/lml/30min API FL Trip 15 24 hr Recap: 72Background 7474'LSND Depth Mud Type . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 8261'LSND Depth Mud Type 172 24 hr Recap: Background Trip YP Cor Solids (lb/100ft2) 3,4009.60 mg/lml/30min API FL 4 RR Cht Silt Siltst 80 EVAMAR 9.55 Chromatograph (ppm) Ss 3.0 Lst 6553' 168 190 20 C-4i C-4n 3978 14.0 24 0.942 1258 12 1/4" 16 17-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools PowerDrive900, Telescope, ARC 825 Gas Summary Lithology (%) (current) 68.0 Weight Size Hughes Mill Tooth VM-3 160' 2664' ShClystCly TuffGvlCoal C-5n 21 7.7 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max BROOHRig Activity: Flow In (spm) 443.2 $3,410.00 $75,660.00 Report For:Keener/Smith/BuchananTotal Charges: 7474' 8261' 787' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr)8164'127.3 MWD Summary md. in Drilling All Circ Drill to intermediate TD 8261'MD. BROOH. % - 250 - 4.23 Hours Depth in / out Footage WOB RPM Condition 7474' to 2492 34 8261' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% 905 114 SPP (psi) Gallons/stroke 2124 @ Yesterday's Depth: 8185' 7784' 9826 192073 3480Maximum Minimum Average 74 Depth 3189 36 179 1868 59 146142 Units* 2607 2718171514 C-2 C-3 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 1073 20" 13 3/8" Make Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air Grade L-80 20" 13 3/8" Make Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Units* 0 0000 C-2 C-3 0 Depth 0 0 0 0 0 00 Maximum Minimum Average 0 0 0 Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: Current Depth: 24 Hour Progress: 8261' Depth Daily Charges: 4.23 Hours Depth in / out Footage W OB RPM Condition 8261' to in Drilling All Circ BROOH to 2618' MD. Circulate hole clean. POOH on elevators. L/D BHA #6. Change out rams. Test rams. R/D % -- md. Max @ ft Current ROP (ft/hr) MWD Summary 8261' 8261' 0' Flow In (gpm) Current Pump & Flow Data: - BROOHRig Activity: Flow In (spm) $3,410.00 $79,070.00 Report For:Keener/Smith/BuchananTotal Charges: AvgMin Max Max 7.9 Bit Type TFA - pH Chlorides -Min -Avg TuffGvlCoal C-5n 0 Size Hughes Mill Tooth VM-3 160' 2664' ShClystCly Gas Summary Lithology (%) (current) 68.0 Weight (ppb Eq)cP PV PWD MBT Tools ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 17 18-Dec-2011 24:00:00Time: Report #: Date: 17.80 15.0 24 0.942 1150 12 1/4" C-4i C-4n 0 0 0 6553'8261' 1707' 9.40 120.0 Chromatograph (ppm) 25.0 Ss 3.0 Lst 4 RR Cht Silt Siltst EVAMAR YP 2-1-WT-A-E-2-HC-TD Cor Solids (lb/100ft2) 3,0009.40 mg/lml/30min API FL Trip 24 hr Recap: Background 8261'LSND Depth Mud Type . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 8261'LSND Depth Mud Type 27 24 hr Recap: Background Trip YP 2-1-WT-A-E-2-HC-TD Cor Solids (lb/100ft2)mg/lml/30min API FL 4 RR Cht Silt Siltst EVAMAR 120.0 Chromatograph (ppm) 25.0 Ss Lst 6553'8261' 1707' 0 0 C-4i C-4n 0 17.800.94212 1/4" 18 19-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools Gas Summary Lithology (%) (current) 68.0 Weight Size Hughes Mill Tooth VM-3 160' 2664' ShClystCly TuffGvlCoal C-5n 0 Bit Type TFA - pH Chlorides -Min -Avg AvgMin Max Max CasingRig Activity: Flow In (spm) $3,410.00 $82,480.00 Report For:Keener/Smith/BuchananTotal Charges: 8261' 8261' 0' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current ROP (ft/hr) MWD Summary md. in Drilling All Circ Float 9 5/8" casing to bottom. % -- 4.23 Hours Depth in / out Footage W OB RPM Condition 8261' to 8261' Depth Daily Charges: Rig: Job No.: Current Depth: 24 Hour Progress: Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 C-3 C-5iC-1 Logging Engineers:Emil Opitz / Jessica Munsell (max)(current) Report By:Emil Opitz Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 20" 13 3/8" 9 5/8" Make Grade L-80 . . Density (ppg)Viscosity out (sec/qt) *10000 units = 100% Gas In Air 8261'LSND Depth Mud Type 24 hr Recap: Background Trip YP 2-1-WT-A-E-2-HC-TD Cor Solids (lb/100ft2) 3,0009.20 mg/lml/30min API FL 3.3 Lst 4 RR Cht Silt Siltst 120.0 Chromatograph (ppm) 25.0 EVAMAR 6553'8261' 1707' 9.40 0 0 C-4i C-4n 0 17.80 15.0 16 0.942 1150 12 1/4" 19 20-Dec-2011 24:00:00Time: Report #: Date: ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg (ppb Eq)cP PV PWD MBT Tools Gas Summary Lithology (%) (current) Ss 8245' ShClystCly 68.0 Weight Coal C-5n 0 Size Hughes Mill Tooth VM-3 160' 2664' -Min -Avg TuffGvl AvgMin Max Max 7.6 Bit Type TFA - pH Chlorides Nipple up BOPRig Activity: Flow In (spm) $3,410.00 $85,890.00 Report For:Keener/Smith/BuchananTotal Charges: 8261' 8261' 0' Flow In (gpm) Current Pump & Flow Data: - ROP (ft/hr) TUSPLFT/JQQMFEPXO#01T%SFTTUPQPGDBTJOHBOEJOTUBMMQBDLPGG4UBSUUPOJQQMFVQ#01TBOEDPOUJOVFUPDMFBOQJUTBTPGNJEOJHIU Continue to fill 9 5/8" casing as per well program. Circulate and condition mud for cement job. Pump cement. Bump plug at 6032 % -- md. RPM Condition 8261' to in Drilling All CircMWD Summary 4.23 Hours Depth in / out Footage WOB Rig: Job No.: Current Depth: 24 Hour Progress: 8261' Depth Daily Charges: Max @ ft Current Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 0 0Maximum Minimum Average 0 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 C-3 C-5iC-1 Logging Engineers:Zach Beekman / Jessica Munsell (max)(current) Report By:Zach Beekman Mud Data ROP Set AtSize 178.9 X-65 Bit # Casing Summary 0 Grade L-80 20" 13 3/8" 9 5/8" Make . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9.5/8" Make Grade L-80 ROP Set At Size 178.9 X-65 Bit # Casing Summary Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 8261' Depth Daily Charges: Rig: Job No.: to Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 8261' in Drilling All Circ % -MWD Summary ROP (ft/hr) Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current $92,710.00 Report For: Keener/Smith/Buchanan Total Charges: 8261' 8261' 0' Current Depth: 24 Hour Progress: Avg Min Max Max Drilling cement Rig Activity: Flow In (spm) $3,410.00 7.9 Bit Type TFA - Alkal Lime -Min - Avg Tuff Gvl Coal Size Hycalog SKH616M-EID 160' 2664' 8245' Sh Clyst Cly Lithology (%) (current) 68.0 Weight Ratio cP PV PWD Oil / Water Tools ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 0.902 15 51 8.75 21 22-Dec-2011 24:00:00 Time: Report #: Date: 31.6 19 Lst 8261' EVAMAR 9.40 Ss 5.0 API FL 4 Cht Silt Siltst YP Cor Solids (lb/100ft 2) 32.60 Mud (lb/bbl) ml/30min 8261' FazePro Depth Mud Type * 10000 units = 100% Gas In Air 0 Logging Engineers: Emil Opitz / Jessica Munsell (max) (current) Report By: Emil Opitz C-2 C-3 C-5i C-1 0 0 00 Units* 0 0000 Maximum Minimum Average 0 Depth 0 0 00 0 0 down from 7952' MD to 8149' MD. Pressure test casing. Cut and slip drill line. Displace with 9.4 OBM as of midnight. Trip in hole with BHA #7 and shallow test MWD. Single in hole to 5610' MD. Run in hole from 5610' to 7692'MD. Wash md. C-5n 0 Gas Summary 0 C-4i C-4n 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" Make Grade L-80 ROP Set At Size 178.9 X-65 Bit # Casing Summary Area: Location: 96% 457 108 SPP (psi) Gallons/stroke 1444 @ Yesterday's Depth: 8879' Depth Daily Charges: 156.0 Rig: Job No.: to Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 8261' in Drilling All Circ % -MWD Summary ROP (ft/hr) 8479'15.6 Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current $96,120.00 Report For: Keener/Smith/Buchanan Total Charges: 8261' 8879' 618' Current Depth: 24 Hour Progress: Avg Min Max Max Drilling ahead Rig Activity: Flow In (spm) 373.0 $3,410.00 - Bit Type TFA - Alkal Lime -Min - Avg Tuff Gvl Coal Size Hycalog SKH616M-EID 160' 2664' 8245' Sh Clyst Cly Lithology (%) (current) 68.0 Weight Ratio cP PV PWD Oil / Water Tools ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 0.902 19 54 8 3/4" 22 23-Dec-2011 24:00:00 Time: Report #: Date: 12.40 31.0 21 Lst 8261' 618' EVAMAR 9.40 70.0 25.0 Ss NA API FL 4 10 Cht Silt Siltst 90 YP Cor Solids (lb/100ft 2) 32.20 Mud (lb/bbl) ml/30min 8261' FazePro Depth Mud Type * 10000 units = 100% Gas In Air 47 Logging Engineers: Zach Beekman / Dave Mckeknie (max) (current) Report By: Zach Beekman C-2 C-3 C-5i C-1 91 22 41 70 Units* 184 26 22 13 680 Maximum Minimum Average 20 Depth 197 34 79 36986 125790 564 8554' 8683' 1052 14 Condition mud for FIT/LOT. Rig up and perform successful LOT. Drill ahead from 8507' MD to 8638' MD. Back ream out of hole Drill shoe track and rat hole from 8146' MD to 8261' MD. Drill ahead from 8261' MD to 8285' MD. Circulate and 411 md. from 8638' MD to 8154' MD due to excess torque. Drill ahead from 8638' MD to 8820' MD as of midnight. C-5n 9 Gas Summary 308 C-4i C-4n 176 107 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) 10645' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 21.60 Mud (lb/bbl) ml/30min 4 10 Cht Silt Siltst 90 9.40 125.0 25.0 Ss NA Lst 8261' 2384' EVAMAR 25.00 29.0 18 51 8 3/4" 23 24-Dec-2011 24:00:00 Time: Report #: Date: API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg Weight Ratio cP PV PWD Oil / Water Tools 0.902 15 Lithology (%) (current) 68.0 160' 2664' 8245' Sh Clyst Cly Tuff Gvl Coal - Bit Type TFA - Alkal Lime -Min - Avg Min Max Max Drilling ahead Rig Activity: Flow In (spm) 389.0 $3,410.00 $99,530.00 Report For: Keener/Smith/Buchanan Total Charges: 8879' 10645' 1766' Current Depth: 24 Hour Progress: Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg ROP (ft/hr) 9577'86.2 % -MWD Summary RPM Condition 8879' in Drilling All Circ Mud Data - 4.23 Hours Depth in / out Footage WOB Daily Charges: Rig: Job No.: to Size Hycalog SKH616M-EID Area: Location: 96% 541 129 SPP (psi) Gallons/stroke 2125 @ Yesterday's Depth: ROP Set At Size 178.9 X-65 Bit # Casing Summary 10645' Depth 20" 13 3/8" 9 5/8" Make Grade L-80 * 10000 units = 100% Gas In Air 24 hr Recap: 700 Background Trip Chromatograph (ppm) 165 C-4i C-4n 275 C-5n 1 607 md. 9801' MD. Drilling ahead from 8879' MD to 10645' MD as of midnight. Max gas for the past 24 hours was 1812u at a depth of 65 1812 Gas Summary 9801' 10208' 64397 204497 731 406 Maximum Minimum Average 42 Depth 308 7 136 163 2 78 117 Units* 270 330152 C-2 C-3 C-5i C-1 Logging Engineers: Zach Beekman / Dave Mckeknie (max) (current) Report By: Zach Beekman 83 . . Density (ppg) Viscosity out (sec/qt) 10802' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 21.80 Mud (lb/bbl) ml/30min 4 10 Cht Silt Siltst 90 8 3/4" 9.40 130.0 13.0 Ss NA Lst 8261' 4541' EVAMAR 40.70 30.0 16 51 24 25-Dec-2011 24:00:00 Time: Report #: Date: API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg Weight Ratio cP PV PWD Oil / Water Tools 0.902 16 Lithology (%) (current) 68.0 160' 2664' 8245' Sh Clyst Cly Tuff Gvl Coal - Bit Type TFA - Alkal Lime -Min - Avg Min Max Max Drilling ahead Rig Activity: Flow In (spm) 435.0 $3,410.00 $102,940.00 Report For: Keener/Smith/Buchanan Total Charges: 10645' 12802' 2157' Current Depth: 24 Hour Progress: Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg ROP (ft/hr) 12311'102.0 % -MWD Summary RPM Condition 10645' in Drilling All Circ Mud Data - 4.23 Hours Depth in / out Footage WOB Daily Charges: 23.0 Rig: Job No.: to Size Hycalog SKH616M-EID Area: Location: 96% 440 104 SPP (psi) Gallons/stroke 1683 @ Yesterday's Depth: ROP Set At Size 178.9 X-65 Bit # Casing Summary 12802' Depth 20" 13 3/8" 9 5/8" Make Grade L-80 * 10000 units = 100% Gas In Air 24 hr Recap: 150 Background Trip Chromatograph (ppm) 471 351 C-5n 67 466 md. 11641' MD. Drilling ahead from 10645' MD to 12802' MD as of midnight. Max gas for the past 24 hours was 956u at a depth of 69 956 Gas Summary 11641' 12748' 46762 108123 990 658 Maximum Minimum Average 90 Depth 418 149 262 228 115 162 231 Units* 387 120 140 124 5258 C-2 C-3 C-5i C-1 C-4i C-4n Logging Engineers: Zach Beekman / Dave Mckeknie (max) (current) Report By: Zach Beekman 123 . . Density (ppg) Viscosity out (sec/qt) Grade L-80 Bit # Casing Summary 14155' Depth 20" 13 3/8" 9 5/8" Make ROP Set At Size 178.9 X-65 Area: Location: 96% 545 130 SPP (psi) Gallons/stroke 2346 @ Yesterday's Depth: 0.0 Rig: Job No.: to Size Hycalog SKH616M-EID Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 12802' in Drilling All Circ % -MWD Summary ROP (ft/hr) 14114'56.9 Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg Report For: Keener/Smith/Buchanan Total Charges: 12802' 14155' 1353' Current Depth: 24 Hour Progress: Daily Charges: Min Max Max BROOH Rig Activity: Flow In (spm) 525.0 $3,410.00 $106,350.00 11.4 Bit Type TFA - Alkal Lime -Min - Avg Tuff Gvl Coal 160' 2664' 8245' Sh Clyst Cly 0.902 15 Lithology (%) (current) 68.0 cP PV PWD Oil / Water Tools API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: 50 25 26-Dec-2011 24:00:00 Time: Report #: Date: Well: Avg Ratio 29.0 17 Weight Lst 8261' 14155' 5894' EVAMAR 48.10 9.40 130.0 13.0 Ss NA 4 10 Cht Silt Siltst 90 8 3/4" YP Cor Solids (lb/100ft 2) 21.80 Mud (lb/bbl) ml/30min 14155' FazePro Depth Mud Type * 10000 units = 100% Gas In Air 122 Report By: Zach Beekman C-5i C-1 C-4i C-4n Logging Engineers: Zach Beekman / Dave Mckechnie (max) (current) Units* 397 89 94 72 3485 C-2 C-3 81 Depth 427 117 238 226 102 143 213 734 Maximum Minimum Average 58433 171154 1079 13689' 12875' 1612 Gas Summary 43 four bottoms up. Continue to circulate the hole clean standing back 2 stands for the next 5 bottoms up. Currently we are backreaming Drill ahead from 12805' MD to TD at 14155' MD/3745' TVD. Circulate the hole clean standing back one stand for the first 575 md. out of hole as of midnight. C-5n 62 502 361 Chromatograph (ppm) Trip 24 hr Recap: 200 Background . . Density (ppg) Viscosity out (sec/qt) 14155' FazePro Depth Mud Type YP Cor Solids (lb/100ft 2) 21.60 Mud (lb/bbl) ml/30min 4 Cht Silt Siltst 8 3/4" 9.40 130.0 13.0 Ss NA Lst 8261' 14155' 5894' EVAMAR 48.10 66/34 19 Weight 50 26 27-Dec-2011 24:00:00 Time: Report #: Date: Well: Avg Ratio API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: cP PV PWD Oil / Water Tools 0.902 15 Lithology (%) (current) 68.0 160' 2664' 8245' Sh Clyst Cly Tuff Gvl Coal $3,410.00 $109,760.00 11.3 Bit Type TFA - Alkal Lime 14155' 14155' 0' Current Depth: 24 Hour Progress: Daily Charges: L/D 8 3/4" BHA Rig Activity: Current Avg Report For: Keener/Smith/Buchanan Total Charges: Min Max Max Flow In (spm) Flow In (gpm) Current Pump & Flow Data: - Max @ ft -Min - Avg ROP (ft/hr) -MWD Summary Condition 14155' in Drilling All Circ % Mud Data - 4.23 Hours Depth in / out Footage WOB Rig: Job No.: to Size Hycalog SKH616M-EID Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: ROP Set At Size 178.9 X-65 14155' Depth 20" 13 3/8" 9 5/8" Make Grade L-80 Bit # Casing Summary RPM * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip Chromatograph (ppm) 0 0 C-5n 0 md. of hole to 6,000' MD at four minutes per stand. Three minutes per stand to 5,000' MD and 1.5 minutes per stand to 290'. Pre job safety meeting prior to laying down nuke sources as of midnight. 550 gpm, 130 rpm, and 1960 psi at four minutes per stand. Circulate three annular volumes at 550 gpm. Pump a dry job. Pull out Backream out of the hole to 12,899' MD at 550 gpm, 130 rpm, and 2400 psi. Backream from 12,899' to 6,500' MD at Gas Summary 0 0 0Maximum Minimum Average 0 0 Depth 0 0 0 0 0 00 000 C-2 C-3 C-4i C-4n Logging Engineers: Zach Beekman / Dave Mckechnie (max) (current) Units* 0 0 Report By: Zach Beekman 0 C-5i C-1 . . Density (ppg) Viscosity out (sec/qt) 40.0 Bit # Casing Summary RPM 13 3/8" 9 5/8" Make Grade L-80 ROP Set At Size 178.9 X-65 14155' Depth Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Size Hycalog SKH616M-EID 20" % Mud Data - Hours Depth in / out Footage WOB Condition 14155' in Drilling All Circ -MWD Summary Avg ROP (ft/hr) Max Max Flow In (spm) Flow In (gpm) --Min - Current Avg Report For: Ross/Wimmer/Buchanan Total Charges: Min Current Pump & Flow Data: Max @ ft 4.23 14155' 14155' 0' Current Depth: 24 Hour Progress: Daily Charges: M/U SLZXP Packer Rig Activity: Rig: Job No.: $2,810.00 $112,570.00 11.3 Bit Type TFA - Alkal Lime Tuff Gvl Coal 160' 2664' 8245' Sh Clyst Cly 0.902 15 Lithology (%) (current) 68.0 cP PV PWD Oil / Water Tools to API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: 52 27 28-Dec-2011 24:00:00 Time: Report #: Date: Well: Avg Ratio 66/34 19 Weight 8261' 14155' 5894' EVAMAR 48.10 9.40 130.0 13.0 Ss NA Lst 4 Cht Silt Siltst 8 3/4" YP Cor Solids (lb/100ft 2) 21.60 Mud (lb/bbl) ml/30min 14155' FazePro Depth Mud Type * 10000 units = 100% Gas In Air C-5i C-1 Logging Engineers: Zach Beekman / Dave Mckechnie (max) (current) Units* 0 0 Report By: Zach Beekman 000 C-2 C-3 0 Depth 0 0 0 0 0 00 0Maximum Minimum Average 0 0 0 Gas Summary C-4i C-4n 0 Run 5 1/2" 15.5 ppf slotted liner. 140 joints slotted, 6 joints solid and 2 swell packers run to 6040' MD. Pick up crossover, seal bore, Lay down 8 3/4" BHA. Pull wear ring. Rig up and test BOPE's. Install wear bushing. Rig up GBR 5 1/2" casing equipment. md. crossover and liner packer as of midnight. C-5n 0 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" Make Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Casing Summary Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: 14155' Depth Daily Charges: Rig: Job No.: to Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 14155' in Drilling All Circ % -MWD Summary ROP (ft/hr) Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current $115,380.00 Report For: Ross/Wimmer/Buchanan Total Charges: 14155' 14155' 0' Current Depth: 24 Hour Progress: Avg Min Max Max Lay Down 5" DP Rig Activity: Flow In (spm) $2,810.00 Bit Type TFA - pH Chlorides -Min - Avg Tuff Gvl Coal Size 160' 2664' Sh Clyst Cly Lithology (%) (current) 68.0 Weight (ppb Eq) cP PV PWD MBT Tools ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg 28 29-Dec-2011 24:00:00 Time: Report #: Date: Lst EVAMAR 9.00 Ss API FL Cht Silt Siltst YP Cor Solids (lb/100ft 2) mg/l ml/30min 14155' Brine Depth Mud Type * 10000 units = 100% Gas In Air 0 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Report By: Zach Beekman C-2 C-3 C-5i C-1 0 0 00 Units* 0 0000 Maximum Minimum Average 0 Depth 0 0 00 0 0 Circulate pipe volume at 3.5 bpm. Run in the hole to 14102' MD. Drop the ball and observe ball on seat. Set packer per Baker Run in the hole with 5 1/2" liner to 6165' MD. Circulate 5 bbls at 2.5 bpm. Run in the hole with liner on 5" drill pipe to 8218' MD. md. representative. Release from the packer. Displace FazePro OBM to 9.00 lb/gal 3% KCL/NaCl Brine. Lay down 5" drill pipe from 8028' MD to 1488'. 212 joints laid down. C-5n 0 Gas Summary 0 C-4i C-4n 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background . . Density (ppg) Viscosity out (sec/qt) 14155' Brine Depth Mud Type YP Cor Solids (lb/100ft 2) mg/l ml/30min Cht Silt Siltst 9.00 Ss Lst EVAMAR 29 30-Dec-2011 24:00:00 Time: Report #: Date: API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: Well: Avg Weight (ppb Eq) cP PV PWD MBT Tools Lithology (%) (current) 68.0 160' 2664' Sh Clyst Cly Tuff Gvl Coal Bit Type TFA - pH Chlorides -Min - Avg Min Max Max Connect 1/4" TEC Rig Activity: Flow In (spm) $2,810.00 $118,190.00 Report For: Ross/Wimmer/Buchanan Total Charges: 14155' 14155' 0' Current Depth: 24 Hour Progress: Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg ROP (ft/hr) % -MWD Summary RPM Condition 14155' in Drilling All Circ Mud Data - 4.23 Hours Depth in / out Footage WOB Daily Charges: Rig: Job No.: to Size Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: ROP Set At Size 178.9 X-65 Bit # Casing Summary 14155' Depth 20" 13 3/8" 9 5/8" Make Grade L-80 40.0 * 10000 units = 100% Gas In Air 24 hr Recap: Background Trip Chromatograph (ppm) 0 C-4i C-4n 0 C-5n 0 md. tubing in prep to run tubing with the ESP pump assembly. joints of 5" drill pipe. Rig up and remove wear ring. Load floor with ESP and GBR equipment. Rig up slick line. Load the pipe shed with Continued laying down 46 joints of 5" drill pipe. Run in hole with 37 stands of 5" drill pipe. Slip and cut drill line. Lay down 111 Gas Summary 0 0 0 0Maximum Minimum Average 0 Depth 0 0 0 0 0 00 Units* 0 0000 C-2 C-3 C-5i C-1 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Report By: Zach Beekman 0 . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" Make Grade L-80 40.0 ROP Set At Size 178.9 X-65 Bit # Casing Summary 14155' Depth Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Daily Charges: Rig: Job No.: to Size Mud Data - 4.23 Hours Depth in / out Footage WOB RPM Condition 14155' in Drilling All Circ % -MWD Summary ROP (ft/hr) Flow In (gpm) Current Pump & Flow Data: - Max @ ft Current Avg $2,810.00 $121,000.00 Report For: Ross/Wimmer/Buchanan Total Charges: 14155' 14155' 0' Current Depth: 24 Hour Progress: - Avg Min Max Max Land 4 1/2" tubing Rig Activity: Flow In (spm) Bit Type TFA - pH Chlorides -Min Tuff Gvl Coal 160' 2664' Sh Clyst Cly Lithology (%) (current) 68.0 Well: Avg Weight (ppb Eq) cP PV PWD MBT Tools API FL ENI Petroleum SP27-N1 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009098177 Customer: 30 31-Dec-2011 24:00:00 Time: Report #: Date: Lst EVAMAR 9.00 Ss Cht Silt Siltst YP Cor Solids (lb/100ft 2) mg/l ml/30min 14155' Brine Depth Mud Type * 10000 units = 100% Gas In Air 0 Logging Engineers: Zach Beekman / Dave McKechnie (max) (current) Report By: Zach Beekman C-2 C-3 C-5i C-1 0 0 00 Units* 0 0000 Maximum Minimum Average 0 Depth 0 0 0 0 0 0 0 Gas Summary lines every 1000'. Pick up hanger and make up tubing hanger. Make final splice of ESP cable and test conductivity. Test was good. Land Secure motor splice and perform electrical checks. Continue to trip in hole with 4 1/2" completion tubing to 7294' MD. Testing md. 4 1/2" completion string. Test upper and lower hanger body seals at 5000 psi for 10 minutes as of midnight. 0 C-5n C-4i C-4n 0 0 Chromatograph (ppm) Trip 24 hr Recap: Background WE L L N A M E : SP 2 7 - N 1 LO C A T I O N : Spy Island OP E R A T O R : En i P e t r o l e u m AREA:North Slope MU D C O : MI S w a c o STATE:Alaska RI G : Do y o n 1 5 SPUD:2-Dec-11 SP E R R Y J O B : AK - A M - 0 0 0 9 0 9 8 1 7 7 TD:26-Dec-11 BI T RE C O R D MW D BH A # SD L RU N # Bi t # B i t T y p e B i t Si z e De p t h In ( f t ) De p t h Ou t ( f t ) Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 2 1 0 0 1 H u g h e s M X - 1 M il l t o o t h 1 6 " 16 0 9 2 8 7 6 8 5 . 3 0 1 . 1 1 7 1 3 8 . 9 20 40 7 5 0 6 0 0 N / A Drilled out to make room for HWDP, drill bit did not come out of hole 3 1 0 0 1 R R H u g h e s M X - 1 M il l t o o t h 1 6 " 92 8 2 6 8 0 1 7 5 2 1 0 . 1 0 1 . 1 1 7 1 7 3 . 0 20 40 1 8 5 0 8 0 0 O- O - N O - A - E - I - N O - T D New BHA started per Co Man. Drilled to casing point on plan achieving 4 2 0 0 2 H u g h e s V M - 3 M il l t o o t h 1 2 . 2 5 " 26 8 0 4 3 3 3 1 6 5 3 1 3 . 3 0 0 . 9 4 2 1 2 4 . 7 25 12 0 1 7 0 0 9 0 0 1- 0 - W T - 1 - I - E - N O - D T F POOH - Xceed lack of directional control 5 3 0 0 3 S m t i h G F S 2 0 B I n s e r t 1 2 . 2 5 " 4 3 3 3 6 5 5 4 2 2 2 1 5 9 . 9 0 1 . 1 1 7 3 7 . 1 25 12 0 1 7 0 0 9 0 0 3- 5 - W T - G - E - 2 - R G - P R POOH - Low ROP 6 4 0 0 2 R R H u g h e s V M - 3 M il l t o o t h 1 2 . 2 5 " 65 5 4 8 2 6 1 1 7 0 7 1 7 . 8 0 0 . 9 4 2 95 . 9 25 1 2 0 2 3 6 0 9 0 0 2- 1 - W T - A - E - 2 - H C - T D Intermediate TD reached 7 5 0 0 4 R e e d H y c a l o g S K H 6 1 6 M - E I D P D C 8 . 7 5 " 8 2 6 1 1 4 1 5 5 5 8 9 4 4 8 . 1 0 0 . 9 0 2 12 3 . 3 25 1 4 5 2 4 8 0 5 4 5 0 - 2 - B T - T - X - I - N O - T D P r o d u c t i o n T D r e a c h e d W E L L N A M E : L O C A T I O N : OP E R A T O R : A R E A : MU D C O : S T A T E : RI G : S P U D : SP E R R Y J O B : T D : Mu d R e c o r d W a t e r B a s e d M u d R e c o r d 16 0 ' t o 2 , 6 8 0 ' 2, 6 8 0 ' t o 8 , 2 6 1 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l m g / l C a + + 2- D e c 1 9 3 8 . 7 0 - 2 3 2 2 1 0 / 2 3 / 2 9 5 . 3 6 8 / 4 5 / 3 6 / 2 6 / 1 1 / 1 0 1 / - 2 . 0 1 / 9 7 - 0 . 0 5 9 . 0 2 2 . 0 0 . 5 / . 4 5 1 5 0 0 4 0 P / U 1 6 " B H A 3- D e c 1 1 0 7 9 . 1 0 - 1 9 3 6 1 8 / 3 6 / 4 3 4 . 9 7 4 / 5 5 / 4 6 / 3 6 / 2 0 / 1 8 1 / - 2 . 5 . 5 / . 9 7 0 . 2 5 0 . 0 5 9 . 0 1 7 . 5 0 . 6 / . 6 2 3 3 0 0 1 2 0 D r i l l 1 6 " S u r f a c e 4- D e c 2 6 8 0 9 . 7 0 - 2 8 3 3 2 4 / 6 1 / 7 0 5 . 6 8 9 / 6 1 / 5 0 / 3 7 / 2 0 / 1 8 1 / - 4 . 0 . 5 / 9 5 . 5 0 . 3 0 0 . 0 1 8 . 5 1 8 . 0 . 0 1 / . 4 5 2 0 0 0 8 0 B a c k r e a m 5- D e c 2 6 8 0 9 . 6 0 - 2 5 3 4 2 2 / 5 8 / 6 7 5 . 6 8 4 / 5 9 / 5 2 / 4 1 / 2 0 / 1 8 1 / - 3 . 5 . 5 / 9 6 0 . 3 0 0 . 0 1 8 . 6 1 8 . 0 . 0 2 / . 4 5 2 0 0 0 8 0 R / D F r a n k s T o o l 6- D e c 2 6 8 0 9 . 6 0 - 2 1 1 7 9 / 2 1 / 2 9 - 5 9 / 3 8 / 3 0 / 2 1 / 8 / 6 - - - - - 8 . 4 - - - - C e m e n t C a s i n g 7- D e c 2 6 8 0 9 . 5 0 - 2 1 1 7 9 / 2 0 / 2 9 - 5 9 / 3 8 / 3 0 / 2 1 / 8 / 6 - - - - - 9 . 2 - - - - T e s t B O P s 8- D e c 2 6 8 0 9 . 2 0 4 8 7 2 1 9 / 1 1 / 1 2 5 . 8 3 5 / 2 8 / 2 5 / 1 9 / 1 0 / 9 1 / - 4 . 0 1 / 9 5 - 0 . 2 0 9 . 5 - . 2 0 / 1 . 2 0 4 0 0 4 0 D r i l l C e m e n t , S w i t c h t o L S N D 9- D e c 4 0 2 3 9 . 3 0 5 1 1 0 2 6 1 2 / 2 0 / 2 4 4 . 0 4 8 / 3 6 / 3 3 / 2 6 / 1 3 / 1 1 1 / - 4 . 5 3 / 9 3 0 . 3 0 0 . 1 5 9 . 2 5 . 5 . 1 5 / 1 . 2 5 1 3 0 0 8 0 D r i l l A h e a d 10 - D e c 4 3 3 3 9 . 2 0 5 7 1 3 2 5 1 3 / 2 1 / 2 5 4 . 2 5 1 / 3 8 / 3 2 / 2 5 / 1 4 / 1 2 1 / - 4 . 8 3 / 9 2 . 2 0 . 2 0 0 . 3 0 9 . 7 1 2 . 5 . 2 5 / 2 . 0 0 1 6 0 0 8 0 S l i p / C u t D r i l l L i n e 11 - D e c 5 4 6 0 9 . 3 0 5 3 1 2 2 3 1 3 / 2 0 / 2 4 3 . 5 4 7 / 3 5 / 3 0 / 2 4 / 1 4 / 1 2 1 / - 5 . 8 3 / 9 1 . 2 0 . 3 0 0 . 2 7 9 . 4 1 3 . 0 . 2 0 / 1 . 9 5 1 7 0 0 6 0 D r i l l A h e a d 12 - D e c 5 9 1 2 9 . 2 0 5 2 1 1 2 2 1 2 / 1 8 / 2 2 3 . 6 4 4 / 3 3 / 2 8 / 2 2 / 1 3 / 1 1 1 / - 6 . 0 3 / 9 1 0 . 3 0 0 . 2 8 9 . 5 1 2 . 5 . 2 5 / 2 . 0 0 1 6 0 0 6 0 D r i l l A h e a d 13 - D e c 6 4 2 9 9 . 4 0 5 1 1 1 2 0 1 2 / 1 6 / 2 2 3 . 6 4 2 / 3 1 / 2 6 / 2 0 / 1 2 / 1 0 1 / - 7 . 5 3 / 9 0 0 . 3 0 0 . 2 0 9 . 6 1 3 . 0 . 1 8 / 1 . 7 0 1 6 0 0 6 0 D r i l l A h e a d 14 - D e c 6 5 5 3 9 . 3 0 5 7 1 2 2 4 1 2 / 1 9 / 2 2 3 . 6 4 8 / 3 6 / 3 0 / 2 4 / 1 2 / 1 0 1 / - 7 . 5 3 / 9 0 0 . 2 0 0 . 1 3 9 . 3 1 3 . 5 . 1 3 / 1 . 8 0 2 7 0 0 8 5 B a c k r e a m 15 -De c 65 5 3 94 0 50 11 23 11 / 1 8 / 2 2 37 45 / 3 4 / 3 0 / 2 3 / 1 2 / 9 1/ - 75 3/ 9 0 02 0 01 4 93 13 5 15 / 1 9 0 25 0 0 70 P/U BHA #6 In t e r m e d i a t e S e c t i o n Sp y I s l a n d No r t h S l o p e Al a s k a 2- D e c - 1 1 26 - D e c - 1 1 SP 2 7 - N 1 En i P e t r o l e u m MI S w a c o Do y o n 1 5 Su r f a c e S e c t i o n MI S p u d M u d LS N D AK - A M - 0 0 0 9 0 9 8 1 7 7 15 D e c 65 5 3 9 .40 50 11 23 11 / 1 8 / 2 2 3 .7 45 / 3 4 / 3 0 / 2 3 / 1 2 / 9 1/ 7 .5 3/ 9 0 0 .20 0 .14 9 .3 13 .5 . 15 / 1 .90 25 0 0 70 P/U BHA #6 16 - D e c 7 5 4 8 9 . 4 0 5 5 1 4 2 5 1 2 / 1 9 / 2 4 3 . 2 5 3 / 3 9 / 3 3 / 2 6 / 1 3 / 1 1 1 / - 7 . 6 3 / 8 9 0 . 2 0 0 . 1 0 9 . 2 1 4 . 5 . 1 4 / 2 . 2 0 3 5 0 0 8 5 D r i l l A h e a d 17 - D e c 8 2 6 1 9 . 5 5 5 8 1 2 2 4 1 5 / 1 9 / 2 2 3 . 0 4 8 / 3 6 / 3 1 / 2 5 / 1 3 / 1 2 1 / - 7 . 7 3 / 8 9 0 . 2 0 0 . 1 4 9 . 6 1 4 . 0 . 2 0 / 2 . 2 0 3 4 0 0 8 5 B a c k r e a m O u t o f H o l e 18 - D e c 8 2 6 1 9 . 4 0 5 0 1 1 2 4 1 4 / 1 7 / 2 4 3 . 0 4 6 / 3 5 / 2 8 / 2 3 / 1 2 / 1 1 1 / - 7 . 9 3 / 8 9 0 . 2 0 0 . 1 5 9 . 4 1 5 . 0 . 1 9 / 2 . 0 0 3 0 0 0 4 0 P O O H , T e s t R a m s 19 - D e c 8 2 6 1 9 . 4 0 4 9 1 0 2 2 1 4 / 1 6 / 2 3 3 . 1 4 2 / 3 2 / 2 8 / 2 2 / 1 2 / 1 2 1 / - 7 . 8 3 / 8 9 0 . 2 0 0 . 1 5 9 . 4 1 5 . 0 . 1 5 / 1 . 9 0 3 0 0 0 4 0 R I H w i t h 9 5 / 8 C a s i n g 20 - D e c 8 2 6 1 9 . 4 0 5 0 1 1 1 6 1 0 / 1 5 / 1 8 3 . 3 3 8 / 2 7 / 2 5 / 1 8 / 8 / 7 1 / - 7 . 6 3 / 8 9 0 . 1 0 0 . 1 0 9 . 2 1 5 . 0 . 1 1 / 1 . 9 0 3 0 0 0 4 0 N / U B O P 21 - D e c 8 2 6 1 9 . 4 0 5 0 1 1 1 6 1 0 / 1 5 / 1 8 3 . 3 3 8 / 2 7 / 2 5 / 1 8 / 8 / 7 1 / - 7 . 6 3 / 8 9 0 . 1 0 0 . 1 0 9 . 2 1 5 . 0 . 1 1 / 1 . 9 0 3 0 0 0 4 0 R / U B H A # 7 Oi l B a s e d M u d R e c o r d 82 6 1 ' t o 1 4 , 1 5 5 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e C or r . So l i d Oi l / W a t e r Oi l P m L i m e S a l t C l - Em u l St a b i l i t y S d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l l b / b b l % W t m g / L m g / l % v o l 22 - D e c 8 2 6 1 9 . 4 0 5 1 1 5 1 9 8 / 9 / 9 5 . 0 4 9 / 3 4 / 2 8 / 2 1 / 9 / 8 - / 1 9 . 0 6 4 / 3 6 5 6 2 . 6 0 3 . 3 8 2 8 . 8 7 8 3 0 0 0 4 5 4 - R I H w i t h B H A # 7 23 - D e c 8 7 7 0 9 . 4 0 5 4 1 9 2 1 9 / 1 0 / 1 1 - 5 9 / 4 0 / 3 2 / 2 5 / 1 0 / 9 - / - 8 . 9 6 5 / 3 5 5 7 2 . 2 0 2 . 8 6 2 7 . 7 3 7 6 0 0 0 8 8 1 - D r i l l i n g 8 3 / 4 " H o l e 24 - D e c 1 0 6 4 5 9 . 4 0 5 1 1 5 1 8 9 / 9 / 1 0 - 4 8 / 3 3 / 2 7 / 1 9 / 8 / 7 - / - 1 1 . 6 6 6 / 3 4 5 7 1 . 6 0 2 . 0 8 2 5 . 0 7 6 2 0 0 0 8 6 5 0 . 2 0 D r i l l A h e a d 25 - D e c 1 2 8 0 2 9 . 4 0 5 1 1 6 1 6 8 / 9 / 9 - 4 8 / 3 2 / 2 6 / 1 8 / 8 / 7 - / - 1 1 . 6 6 5 / 3 5 5 6 1 . 8 0 2 . 3 4 2 4 . 4 4 6 2 0 0 0 7 6 0 0 . 3 0 D r i l l A h e a d 26 - D e c 1 4 1 5 5 9 . 4 0 5 0 1 5 1 7 8 / 8 / 9 - 4 7 / 3 2 / 2 6 / 1 8 / 7 / 6 - / - 1 1 . 4 6 6 / 3 4 5 7 1 . 8 0 2 . 3 4 2 6 . 2 6 6 6 0 0 0 7 8 0 0 . 2 0 T D w e l l 27 - D e c 1 4 1 5 5 9 . 4 0 5 0 1 5 1 9 8 / 9 / 1 0 - 4 9 / 3 4 / 2 7 / 2 0 / 9 / 7 - / - 1 1 . 3 6 6 / 3 4 5 7 1 . 6 0 2 . 0 8 2 6 . 5 5 6 7 0 0 0 8 1 0 0 . 2 0 L a y d o w n 8 3 / 4 " B H A 28 - D e c 1 4 1 5 5 9 . 4 0 5 2 1 5 1 9 8 / 9 / 1 0 - 4 9 / 3 4 / 2 7 / 2 0 / 9 / 7 - / - 1 1 . 3 6 6 / 3 4 5 7 1 . 6 0 2 . 0 8 2 6 . 5 5 6 7 0 0 0 8 0 0 0 . 2 0 M a k e u p S L Z X P P a c k e r 13 3 / 8 " S u r f a c e @ 2 , 6 8 0 ' M D Ca s i n g R e c o r d Pr o d u c t i o n S e c t i o n 20 " C o n d u c to r @ 1 6 0 ' M D 9 5 / 8 " I n t e r m e d i a t e @ 8 2 6 1 ' M D Fa z e P r o Marker MD INC AZ TVD TVDSS Top of Permafrost 838.00 6.34 296.73 837.27 781.07 Base of Permafrost 1692.00 18.79 298.97 1667.96 1611.76 Top West Sak 2408.00 37.98 290.91 2300.03 2243.83 Tuffaceous Shale 3674.00 70.19 255.89 2959.11 2902.91 Hue_1 3998.00 70.93 257.14 3065.82 3009.62 Hue_2 4340.00 70.48 258.62 3179.04 3122.84 Top of 9 7/8" Liner 4498.00 70.66 258.38 3231.52 3175.32 SCP 4659.80 71.14 259.64 3285.15 3228.95 Brook 2B 7643.00 70.31 258.35 4266.47 4210.27 Torok Top 9797.00 70.95 257.43 4978.08 4921.88 Torok Base 10382.00 70.92 245.48 5168.77 5112.57 Top of 7" Liner Tieback Seal 10829.00 70.75 228.12 5315.31 5259.11 Torok SH_1 10930.00 70.71 223.66 5348.78 5292.58 ICP1 10978.00 71.07 222.82 5364.53 5308.33 Top HRZ 12244.00 74.04 182.90 5750.02 5693.82 Base HRZ 12713.00 74.33 172.43 5877.78 5821.58 Kalubik Marker 13008.00 75.28 162.55 5955.25 5899.05 Top Kup C 13236.00 76.37 154.36 6009.32 5953.12 LCU 13239.00 76.36 154.27 6010.03 5953.83 BCU 13834.00 78.98 142.75 6137.29 6081.09 T1 13991.00 79.90 140.87 6166.08 6109.88 Top Nuiqsut_D1 14061.00 80.24 139.76 6178.14 6121.94 Top Nuiq::Nuiq_1_D1 14080.00 80.34 139.74 6181.35 6125.15 ICP2 14106.00 80.53 139.63 6185.67 6129.47 T2 14425.00 87.03 141.78 6220.09 6163.89 Nuiq_1::Nuiq_2_D1 14460.00 86.99 141.07 6221.91 6165.71 SP27-N1 Interpolated Tops Nuiq_2::Nuiq_3_D1 14573.00 86.08 138.46 6228.41 6172.21 Nuiq_3::Nuiq_4_D1 14760.00 86.09 136.94 6240.14 6183.94 Nuiq_4::Nuiq_5_D1 14863.00 85.03 135.86 6248.45 6192.25 T3 15000.00 86.65 136.08 6258.99 6202.79 T4 (Invert #1)15212.87 90.00 139.92 6266.33 6210.13 T5 15400.00 94.40 140.79 6257.82 6201.62 Nuiq_5::Nuiq_4_U2 15400.00 94.40 140.79 6257.82 6201.62 Nuiq_4::Nuiq_3_U2 15493.00 94.11 140.01 6251.08 6194.88 Nuiq_3::Nuiq_2_U2 15601.00 94.38 138.81 6242.75 6186.55 Nuiq_2::Nuiq_1_U2 15677.00 93.95 137.93 6237.38 6181.18 T6 15700.00 94.29 137.49 6235.72 6179.52 T7 (Revert #2)15854.23 90.00 141.21 6228.00 6171.80 T8 16000.00 85.64 144.07 6235.08 6178.88 Nuiq_1::Nuiq_2_D3 16105.00 85.00 143.72 6243.50 6187.30 Nuiq_2::Nuiq_3_D3 16196.00 84.24 140.01 6252.04 6195.84 Nuiq_3::Nuiq_4_D3 16319.00 84.30 138.72 6264.79 6208.59 Nuiq_4::Nuiq_5_D3 16430.00 85.80 139.96 6274.53 6218.33 T9 16500.00 85.94 139.87 6279.50 6223.30 T10 (Invert #2)17098.72 90.00 141.12 6312.80 6256.60 T11 17205.40 94.00 142.93 6308.93 6252.73 Nuiq_5::Nuiq_4_U4 17510.00 94.70 139.62 6287.67 6231.47 Nuiq_4::Nuiq_3_U4 17580.00 94.97 139.42 6281.76 6225.56 Nuiq_3::Nuiq_2_U4 17707.00 94.55 139.67 6271.24 6215.04 Nuiq_2::Nuiq_1_U4 17785.00 94.95 139.38 6264.78 6208.58 T12 17800.00 94.68 139.42 6263.51 6207.31 T13 (Revert #3)18090.59 90.00 141.14 6248.33 6192.13 T14 18310.00 85.91 140.91 6259.03 6202.83 Nuiq_1::Nuiq_2_D5 18475.00 84.67 140.54 6271.26 6215.06 Nuiq_2::Nuiq_3_D5 18557.00 84.45 140.12 6279.03 6222.83 Nuiq_3::Nuiq_4_D5 18715.00 86.58 140.22 6291.15 6234.95 Nuiq_4::Nuiq_5_D5 18861.00 87.03 141.20 6298.87 6242.67 Nuiq_5::Transition Zone 19511.00 86.39 140.03 6346.96 6290.76 Nuiq_5::Nuiq_Base_D5 19775.00 85.00 140.20 6365.91 6309.71 T15 -TD 19947 00 84 88 140 35 6382 31 6326.11T15 TD 19947.00 84.88 140.35 6382.31 6326.11 Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3654 1 3625 Andrew Buchanan 16-Dec-11 N Sands 6800 6955SP27-N1 Spy Island ENI Petroleum Emil Opitz 1 Dt h ft C1 C1 C1 C1 Interpretation: GU i t 2886818 No producible oil within these zones based upon gas and chromatograph data collected. 3000Md C h l i d ( / L ) Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Gas Units 288 315 36 29373 105 72 32501 69 6818 229 465 55 139410 279 472 49 3128 423 17 212 3000Mud Chlorides (mg/L) = 1000 NPH Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = Gas Units 50850 636 1274 668 6945 52124 447 32 Mud Chlorides (mg/L) =3000 80 268 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Gas Units 64 313 795 29 98 61 219 7165 98 34 Mud Chlorides (mg/L) =3000 190 37 1374 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 79 410 32267 226 218 212 143 55 148 152 53 33769 1502 21 435 25 247 203 205 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 381 Gas Units 184 80 130 19421 233 30309 156 211 55 406 25 7276 254 307 218 53 165 31811 1502 Mud Chlorides (mg/L) =3000 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 218 53 165 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3738 2 3733 Andrew Buchanan 17-Dec-11 OA Sands 8055 8260SP27-N1 Spy Island ENI Petroleum Emil Opitz 1 Dt h ft C1 C1 C1 C1 Interpretation: GU i t 9678063 No producible oil within these zones based upon gas and chromatograph data collected. 3500Md C h l i d ( / L ) Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Gas Units 967 1752 20 84473 49 35 86817 54 8063 1272 2498 57 712441 1732 1580 21 2344 1559 85 1187 3500Mud Chlorides (mg/L) = 1000 NPH Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = Gas Units 151949 2837 2344 2858 8139 154293 1922 21 Mud Chlorides (mg/L) =3500 54 47 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Gas Units 2542 2492 60 20 2153 57 3283 8185 2627 85 Mud Chlorides (mg/L) =3500 3263 2096 72 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 4 55 3459 189729 3958 74 61 48 57 2550 3104 85 192073 2344 20 3480 21 3978 2607 3189 100.0 1000.0 NPH 4 Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 1876 Gas Units 54 51 43 6820 2215 96258 1424 1481 57 1897 21 8199 2235 1311 1882 85 1797 98602 2344 Mud Chlorides (mg/L) =3500 10.0 NPH Oil Gas C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1882 85 1797 1.0 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Reports Report Prepared By: Formation: Report Delivered To: Date Drilled: 3 Andrew Buchanan 23-Dec-11 OA1 SandsZach Beekman 8261 9400SP27-N1 Spy Island ENI Petroleum Dt h ft C1 C1 C1 C1 1 Interpretation: GU i t No producible oil within these zones based upon gas and chromatograph data collected. Md C h l i d ( / L ) Hydrocarbon Ratios Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Gas Units 1172149 303 168 63293 469 425 275 117 135 550 275 43008 106301 230 342 193 63 54 Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 120313 501 564 125790 63 5477 Mud Chlorides (mg/L) = 476 240 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 173 695 55 184 83 308 197 24 1191 Mud Chlorides (mg/L) = 253 101 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons 4 177 345 98502 557 286 99 1247 99555 79 53 100004 1502 21 370 25 198 134 152 100.0 1000.0 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 1073 Gas Units 548 905 311235 770 290 21 568 344 399 55 1098 25 589 457 53 404 312737 1502 Mud Chlorides (mg/L) = 10.0 NPH Oil Gas C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons 457 53 404 1.0 NPH DIRECTIONAL SURVEY REPORT Eni Petroleum SP27-N1 Nikaitchuq North Slope Borough Alaska United States AK-XX-0009098177 Measured Vertical Depth Inclination Direction Depth Latitude Departure (feet) (degrees) (degrees) (feet) (feet) (feet) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.37 320.60 100.00 0.25 N 0.20 W 175.00 0.20 248.43 175.00 0.39 N 0.48 W 270.00 1.11 184.86 269.99 0.59 S 0.71 W 362.00 2.64 170.31 361.94 3.57 S 0.43 W 456.00 4.44 161.31 455.76 9.15 S 1.10 E 549.00 5.43 157.63 548.41 16.63 S 3.93 E 643.00 6.74 156.66 641.88 25.80 S 7.81 E 736.00 10.37 158.86 733.83 38.63 S 12.99 E 764.12 11.69 158.55 761.43 43.64 S 14.94 E 857.61 15.02 160.63 852.38 63.89 S 22.43 E 941.04 16.65 163.44 932.64 85.55 S 29.42 E 1035.50 18.46 164.37 1022.70 112.92 S 37.31 E 1129.39 20.96 167.33 1111.08 143.63 S 45.00 E 1222.57 21.79 167.64 1197.85 176.78 S 52.35 E 1317.10 23.55 166.92 1285.08 212.32 S 60.38 E 1410.31 24.87 163.44 1370.09 249.24 S 70.19 E 1503.58 24.67 162.35 1454.78 286.59 S 81.68 E 1594.63 25.30 164.29 1537.31 323.43 S 92.71 E 1689.93 24.46 162.82 1623.77 361.88 S 104.05 E 1783.79 23.19 163.83 1709.63 398.20 S 114.94 E 1876.35 25.55 164.29 1793.93 434.92 S 125.42 E 1970.46 29.02 167.25 1877.56 476.74 S 135.95 E 2063.74 28.72 175.06 1959.28 521.15 S 142.88 E 2156.46 28.67 183.84 2040.65 565.56 S 143.31 E 2249.80 30.60 191.43 2121.81 611.20 S 137.10 E 2344.28 31.27 199.20 2202.88 657.95 S 124.26 E 2436.23 31.08 205.95 2281.57 701.84 S 106.02 E 2529.57 34.15 209.92 2360.20 746.23 S 82.41 E 2607.04 38.77 211.16 2422.49 785.85 S 59.00 E 2697.46 40.40 212.34 2492.17 834.84 S 28.67 E 2718.90 40.55 212.92 2508.48 846.56 S 21.17 E 2762.85 40.98 213.90 2541.77 870.51 S 5.36 E 2855.83 41.59 217.80 2611.65 920.21 S 30.56 W 2900.19 41.75 220.57 2644.79 943.07 S 49.19 W 2950.34 42.87 222.93 2681.87 968.24 S 71.67 W 3042.86 45.11 228.44 2748.46 1013.05 S 117.66 W 3136.03 47.33 233.12 2812.94 1055.52 S 169.77 W 3229.52 48.93 235.74 2875.34 1095.99 S 226.40 W 3322.88 52.64 240.17 2934.37 1134.28 S 287.71 W 3416.60 56.50 244.91 2988.71 1169.41 S 355.46 W 3510.13 60.40 249.30 3037.66 1200.34 S 428.87 W 3602.57 64.35 250.63 3080.52 1228.38 S 505.81 W 3696.58 68.34 251.19 3118.23 1256.53 S 587.17 W 3789.79 71.46 251.78 3150.26 1284.32 S 670.16 W 3883.01 73.07 251.71 3178.65 1312.13 S 754.48 W 3976.31 76.05 252.24 3203.49 1339.95 S 839.99 W 4069.76 78.35 252.17 3224.19 1367.80 S 926.75 W 4162.68 81.95 251.06 3240.09 1396.67 S 1013.61 W 4256.62 86.00 252.20 3249.94 1426.11 S 1102.25 W 4350.03 84.89 251.95 3257.36 1454.76 S 1190.84 W 4443.80 82.88 249.07 3267.35 1485.86 S 1278.73 W 4537 65 82 72 247 96 3279 12 1519 96 S 1365 36 W 4537.65 82.72 247.96 3279.12 1519.96 S 1365.36 W 4630.34 83.08 248.00 3290.57 1554.45 S 1450.63 W 4723.56 82.68 247.50 3302.13 1589.47 S 1536.25 W 4816.75 83.23 247.50 3313.56 1624.87 S 1621.69 W 4910.83 82.78 247.41 3325.01 1660.67 S 1707.94 W 5004.26 82.98 247.57 3336.59 1696.16 S 1793.58 W 5097.73 82.77 247.73 3348.19 1731.43 S 1879.36 W 5190.83 82.41 250.13 3360.20 1764.62 S 1965.51 W 5285.04 82.50 252.82 3372.57 1794.29 S 2054.05 W 5378.46 79.92 253.51 3386.84 1821.03 S 2142.41 W 5472.85 81.54 255.88 3402.05 1845.61 S 2232.26 W 5566.79 81.04 258.00 3416.28 1866.59 S 2322.70 W 5660.16 80.31 259.89 3431.41 1884.26 S 2413.13 W 5752.63 80.38 260.43 3446.92 1899.84 S 2502.94 W 5846.45 79.11 261.54 3463.62 1914.31 S 2594.12 W 5940.48 79.71 265.77 3480.91 1924.52 S 2685.96 W 6033.74 80.18 265.97 3497.19 1931.13 S 2777.55 W 6127.45 80.27 270.37 3513.11 1934.08 S 2869.83 W 6220.66 81.80 274.00 3527.64 1930.56 S 2961.81 W 6313.43 82.30 277.52 3540.47 1921.34 S 3053.21 W 6407.05 81.37 280.90 3553.77 1906.52 S 3144.68 W 6500.71 80.87 282.52 3568.23 1887.74 S 3235.28 W 6587.05 80.73 285.68 3582.04 1866.98 S 3317.93 W 6680.08 78.33 287.79 3598.94 1840.64 S 3405.53 W 6774.34 75.87 292.44 3620.00 1809.07 S 3491.78 W 6865.61 78.23 295.00 3640.45 1773.29 S 3573.20 W 6959.13 83.19 297.45 3655.55 1732.51 S 3655.95 W 7053.65 86.48 302.06 3664.06 1685.80 S 3737.64 W 7147.16 86.09 306.27 3670.12 1633.41 S 3814.83 W 7240.42 85.85 307.49 3676.68 1577.58 S 3889.24 W 7334.17 85.74 308.46 3683.55 1520.05 S 3962.95 W 7427.19 85.74 309.44 3690.46 1461.74 S 4035.09 W 7520.70 85.74 312.24 3697.41 1400.76 S 4105.63 W 7614.05 85.89 313.73 3704.22 1337.29 S 4173.73 W 7707.28 86.01 311.02 3710.81 1274.62 S 4242.43 W 7800.56 85.96 307.96 3717.34 1215.45 S 4314.23 W 7894.14 86.18 308.35 3723.75 1157.77 S 4387.64 W 7987.37 86.19 310.21 3729.96 1098.88 S 4459.65 W 8080.70 86.63 310.80 3735.80 1038.38 S 4530.47 W 8174.23 89.30 310.59 3739.12 977.44 S 4601.33 W 8215.96 90.23 312.55 3739.29 949.75 S 4632.55 W 8257.40 91.11 313.71 3738.81 921.42 S 4662.79 W 8351.17 88.72 312.01 3738.95 857.65 S 4731.52 W 8444.61 90.61 317.94 3739.49 791.64 S 4797.58 W 8538.59 90.24 318.16 3738.80 721.74 S 4860.41 W 8631.89 89.85 321.32 3738.72 650.55 S 4920.69 W 8724.82 90.77 321.40 3738.22 577.97 S 4978.72 W 8818.08 88.71 321.36 3738.64 505.11 S 5036.93 W 8910.85 87.20 312.67 3741.96 437.35 S 5100.07 W 9004.45 89.03 305.78 3745.04 378.24 S 5172.50 W 9098.69 89.31 300.74 3746.41 326.57 S 5251.27 W 9191.82 91.27 304.17 3745.94 276.61 S 5329.83 W 9284.99 89.45 302.85 3745.35 225.18 S 5407.51 W 9378.67 91.57 303.33 3744.52 174.04 S 5485.99 W 9471.57 90.86 303.32 3742.55 123.01 S 5563.60 W 9565.40 90.22 302.21 3741.66 72.23 S 5642.49 W 9658.71 91.11 300.63 3740.58 23.59 S 5722.11 W 9752.54 92.64 301.50 3737.51 24.79 N 5802.44 W 9845.12 91.93 300.35 3733.82 72.33 N 5881.79 W 9938.57 90.48 300.82 3731.86 119.87 N 5962.22 W 10032.73 92.47 303.89 3729.43 170.24 N 6041.72 W 10126.29 92.40 308.31 3725.45 225.30 N 6117.23 W 10219.36 88.41 311.78 3724.80 285.16 N 6188.45 W 10313.16 86.56 308.81 3728.91 345.75 N 6259.92 W 10406.66 90.62 308.52 3731.21 404.14 N 6332.88 W 10499.76 90.29 308.47 3730.47 462.08 N 6405.75 W 10591.89 90.04 308.54 3730.21 519.44 N 6477.84 W 10686.35 89.77 309.52 3730.37 578.93 N 6551.22 W 10780.60 90.59 309.97 3730.07 639.19 N 6623.69 W 10874.98 90.38 309.54 3729.27 699.54 N 6696.24 W 10968.55 88.57 308.25 3730.13 758.29 N 6769.06 W 11062.43 87.34 306.62 3733.48 815.31 N 6843.55 W 11156.06 87.17 304.34 3737.96 869.59 N 6919.71 W 11248.73 88.10 302.31 3741.79 920.46 N 6997.07 W 11341.91 88.53 302.21 3744.53 970.17 N 7075.83 W 11435.14 88.52 303.03 3746.93 1020.41 N 7154.33 W 11528.14 90.65 303.81 3747.60 1071.63 N 7231.94 W 11621.80 90.14 301.26 3746.95 1121.99 N 7310.90 W 11715.83 91.26 298.12 3745.81 1168.56 N 7392.56 W 11808.92 89.55 293.85 3745.15 1209.33 N 7476.22 W 11902.13 88.08 286.78 3747.08 1241.66 N 7563.55 W 11995.60 89.65 283.53 3748.93 1266.09 N 7653.74 W 12088.36 87.39 287.50 3751.33 1290.89 N 7743.07 W 12181.87 88.42 289.79 3754.74 1320.76 N 7831.60 W 12275.65 89.77 294.05 3756.23 1355.76 N 7918.57 W 12368.75 91.52 297.77 3755.18 1396.43 N 8002.29 W 12462.49 95.31 299.40 3749.60 1441.19 N 8084.44 W 12555.92 95.15 301.82 3741.08 1488.56 N 8164.51 W 12648.93 93.94 302.48 3733.71 1537.90 N 8243.01 W 12742.49 91.71 301.79 3729.10 1587.60 N 8322.13 W 12834.93 90.74 299.65 3727.12 1634.80 N 8401.58 W 12929.49 90.13 297.24 3726.40 1679.84 N 8484.71 W 13022.60 93.00 304.36 3723.86 1727.46 N 8564.60 W 13116.35 91.75 310.53 3719.97 1784.38 N 8638.93 W 13209.51 90.85 316.86 3717.85 1848.69 N 8706.24 W 13302.75 90.37 322.13 3716.86 1919.56 N 8766.77 W 13395.67 90.21 326.06 3716.39 1994.81 N 8821.25 W 13488.97 89.71 326.03 3716.45 2072.20 N 8873.37 W 13582.38 90.03 325.93 3716.67 2149.62 N 8925.63 W 13675.93 89.07 326.15 3717.40 2227.21 N 8977.88 W 13769.68 87.67 327.94 3720.07 2305.83 N 9028.86 W 13863.33 85.75 327.87 3725.44 2385.04 N 9078.53 W 13956.70 85.94 329.69 3732.21 2464.67 N 9126.80 W 14050.45 86.79 327.86 3738.15 2544.68 N 9175.30 W 14094.41 87.78 327.15 3740.23 2581.71 N 9198.89 W CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID) A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 14094.41 FEET IS 9554.31 FEET ALONG 285.68 DEGREES (GRID) Date Printed:20 January 2012 0 1000 2000 3000 4000 5000 6000 7000Dep t h Prognosed Actual SP27-N1 Days vs. Depth 4 Dec 2011 Reached surface TD at 1430 hrs 2680' MD / 2480' TVD 20 Dec 2011 R& L d 9 5 / 8 i 5 Dec 2011 Run & Land 13 3/8 casing to 2664' MD 8 Dec 2011 RIH, tested casing, and cleaned out cement to 2522' MD 28 Nov 2011 SDL rig up unit and gas equipment 2 Dec 2011 Pre Spud meeting and prepare to RIH 10 Dec 2011 Drilled to 4333' MD POOH due to MWD failure 16 Dec 2011 Drilled to 6553' MD POOH due to slow ROP 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 4 8 1 21 62 02 42 8 Me a s u r e d D Rig Days Run & Land 9 5/8 casing to 8261' MD 26-dec-2011 Drilled to TD 17 Dec 2011 Reached intermediate TD at 1200 hrs 8260' MD / 3739' TVD Surface Data Logging After Action Review Employee Name: David Mckechnie Date: 12-30-2011 Well: SP27-N1 Hole Section: Production What went as, or better than, planned: Even with temperatures well below freezing, the new poly-flow line and heat trace held up to the elements without so much as a sign of freezing. Difficulties experienced: As well as the new heat trace performs, moisture from condensation is still an issue. We blow as much often as we can between connections, but it still has potential to pose a problem if we enter extended time drilling. It would be a difficult balance to keep the lines and gear dry while trying not compromise the gas data while drilling Recommendations: If we can get a small drop jar installed with the poly-flow lines within the unit, it would give us a great advantage in keeping our lines and equipment dry all around. Innovations and/or cost savings: Upon completion of SP27-N1, sample catchers were released from the Island immediately with dozens of samples yet to be processed and shipped. Mud Loggers on site completed this task at no extra charge to the client.
