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New Plugback Esets 7/3/2024 Well Name API Number PTD Number ESet Number Date 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141APB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141APB3 50-029-22967-75-00 208-016 T39109 7-16-2008 2K-08APB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08APB3 50-103-20111-71-00 211-049 T39111 6-13-2011 2K-08B PB1 50-103-20111-73-00 211-152 T39112 2-15-2012 2K-08B PB2 50-103-20111-74-00 211-152 T39113 2-15-2012 2K-08B PB3 50-103-20111-75-00 211-152 T39114 2-15-2012 3K-105L1 PB1 50-029-23479-72-00 212-166 T39115 3-12-2013 3K-105L1 PB2 50-029-23479-73-00 212-166 T39116 3-12-2013 3K-105L1 PB3 50-029-23479-74-00 212-166 T39117 3-12-2013 SP22-FN01 PB3 50-629-23478-72-00 212-162 T39118 3-20-2013 V-214 PB2 50-029-23275-71-00 205-134 T39119 1-29-2007 V-214 PB3 50-029-23275-72-00 205-134 T39120 1-29-2007 V-214 PB4 50-029-23275-73-00 205-134 T39121 1-29-2007 SP22-FN01 PB3 50-629-23478-72-00 212-162 T39118 3-20-2013 STATE OF ALASKA AAA OIL AND GAS CONSERVATION COM41,ION EC E I V E C REPORT OF SUNDRY WELL OPERATION APR 2 5 2017 1.Operations Abandon LI Plug Perforations LJ Fracture Stimulate U Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ACG t,r" a! oved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ESP change out❑✓ 2.Operator Eni US Operating Co.Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 0 Exploratory 0 212-162 3.Address: 3800 Centerpoint Dr.Ste 300,Anchorage,AK, Stratigraphic ❑ Service ❑ 6.API Number: 99503 50--629-23478-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: 391283, 388574,388572 SP22-FN1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Schrader Bluff Oil Pool 11.Present Well Condition Summary: Total Depth measured 22,923 feet Plugs measured N/A feet true vertical 3,408 feet Junk measured N/A feet Effective Depth measured 21,929 feet Packer measured N/A feet true vertical 3,782 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 3082 13.375" 3082 2434 5210 2480 Intermediate 12095 9.625" 12095 3699 6890 4790 Production Liner 9834 5.5" 21929 3782 Slotted Slotted Perforation depth Measured depth 12,095-21,929 feet Tir,1•j �pp True Vertical depth 3,699-3,782 feet Tubing(size,grade,measured and true vertical depth) 4.5 L-80 9,503 3,475 Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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: 532.3 43.9 1354 55 231 Subsequent to operation: 346 41.6 1462 -10 259 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ [] WAG ❑ GINJ ❑ 3USP❑ SPLUG 0 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: 317-037 Authorized Name: Marc Kuck Contact Name: Amjad Chaudhry Authorized Title: Drilling&Completion Engineering Manager Contact Email: amiad,chaudhrvAenipetroleum.com Authorized Signature: Date: .�✓, 47/2-. Contact Phone: 907-865-3379 QCS-fc 47 Form 10-404 Revised 4/2017 / 'f��, RB ('k/MAY - 3 2017 Submit Original Only • 0 •2 M H N O 00 0 U co N �� H � U Q) W 3 m �- � � a) �-o Z = m pco ' u to — cri N � � a' 0 � 0 1 I .6 � � a.0O W v �i O \ Z O C O z L L 3. . -4 N 7. ^ 0 0on 03 U i I *. .� .� N X � !!^^ J (n I �F CpC o� ^N .Q 0 V a6 a, ,mil... G E eM-1 ei eNi N �x M X __ ,.....-10- - p (n E _W � >, D �--1 -,,, 0 xj � � L cn � c m i Q a) m Q \ a) 0 Q I I I, o c a I -0 a 0 i ' co I L .0 N Cn O LO — > m U CO n- O Y c E U - C Z E W EC) 'a a a a �a CD nim o � � � > (/) aX M •a CD W '��0 o •C Q H Q N N C (.,) : �) 0p ° E oNop H 00 co— u) v a I—• ct3o CL E _ o > ,- tiM (0a2 2 E r, D CO a) 0 sk. of U �' V) 03 00 > ~ 0) M 0 N LL! O - U °? ' H • a) L C 2 • tS X 0 0 � M � ((3(I) � � � � � �I 1 c O) 0 c a H O .n ._ � Oo c c vi rn ca o I- O c6 U co- Q to O O a) N cc; M U .2 0 0 N U a) p) a 0 o am U U u) cn O c 4- (� 0 ,A O_ Q. O -' CO Q o L_ rn � fir- E \ �.. Q� 3 c . nUo iflc� °) • Ec200 N ' L Q O C 0 co 0 2 ._ x O (N co O • Z 0 Q 1 0 y O N • C Cr) O "ztZ U) NN \.,, 4.827' /'- . 0ern0t .D o o, /v0 00 0i § 11111111111M N N a-i .-1 .i willillt �� O . H „, (13 `' ''' ',,,,...1.ii. iiii `' 0)* .-1 N M CT to -55 It 4:t gt lt ii ( 00 M 'cr cnU L Y Y �C .2 1..7, CIa U :: N Ea a a a a °1 a o a_. iv v a m 5na co' C o vi vi in vi i� r• V Cr eSI CO u, v, J, 4, ch U oili ri Y 2 Well Name: SP22-SOR • Daily Report Wellbore Name: SP22-FN1 Date: 4/3/2017 , Well Code: 26945 e Report#: 1 en 11 Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(tt) Water Depth(R) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool Oft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Temperature('F) Wind Days LTI(days) Days RI(days) POB Clear 2 3 ENE(0 28 MPH WC 24 63.0 Daily Summary Operations 24h Forecast RDMO wire line equipment.Move mat boards,scrape and level pad..replace mat boards and herculde.MIRU on SP22-FNl with sub&pit complex M/U interconnectsstart steam,air through out rig.Bulhead annulus with 720 bbls 9.9 brine.monitor well if dead set BPV,N/D tree&NIU BOP's Test ROPE 24h Summary Sled rig floor,move sub and pit complex and stage making room for slick line operations.Prep rig. Operation at 07.00 Prepping pad for mat boards Time Log Start End Cum Dur Time Time Our(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 0690 06:30 0.50 0.50 MOB A 2 P Rig Accepted at 06:00 4/3/2017,Cont skidding rig floor. 06:30 07:30 1.00 1.50 MOB A 2 P PJSM,move pits away from sub,simops lift stomper off well hay beam. 07 30 09:30 2.00 3.50 MOB A 2 P Move sub off welt SP16-FN3 and crab over to stage.crab pit complex over and stage. 09:30 12:00 2.50 600 MOB A 1 P P/U rig mats and stage,complete MP2 work orders,clean Y strainers on accumulatorcheck and fill accumulator pre-charge bladder bottles.organize and clean through out rig,stage handling equipment inside parts house. 12.00 00:00 12.00 18.00 MOB A 1 P Change out pop off and 2"bleeder on MP#1.change out rubber on mix pump valve,install new hand rails on pipe shed, install ladder extension in mud pits,repair locking pin on moving system,general housekeeping and MP2 work orders,replace chain on roll up door in mud pits.Organize and clean shop,re-check koomey bottle bladders holding 10009. Projected handover to production 4-12-2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv siddrilling@enipetroleum.corn 907-885-0715 Eni representative Mike Grubb ENI Drilling Supv. siddrilling@enipetroleum corn 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrgcierksdoyon15@enipetroleum.cow 907-885-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig 15@doyondrilling.corn 907-685-0716 Tool Push Dave Sena Doyon Drilling Tour Pusher rg/5@doyondrilling.com Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) TVD Bot.(ftKB) Run Date LINER 512 4.83 L80 12,009.9 21,929.0 2/27/2013 ffijoit Well Name: SP22-FDR • Daily Report • Wellbore Name: SP22-FN1 Well Code: 26945 Date: 4l4/2017 a Report#: 2 en o Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N' Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. _DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature('F) Wind Days LTi(days) Days RI(days) POB Clear 7.7 ENE @ 30 MPH gusting to 37 MPH WC.19 75.0 Daily Summary Operations 24h Forecast Con( bullhead annulus with a total of 720 bbls 9.9 brine.monsor well it dead set BPV.N/D tree&N/U BOP's flood stack and choke,shell test stack.Test BOPE,monitor wellpull lest dart.R/D test equipment.R/U to pull ESP completion 24h Summary Move rig mals&herc lde.grade and level padre lay herculite and mats.move sub and pit complex over well SP22-FN1.reconnect lines and turn on steam and air throughout rig.lake on fluid to pits,start well kill operations Operation at 07.00 Bleeding well and taking on brine to pits Time Log Start End Cum Our Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03:00 3.00 3.00 MOB A1 P While Halliburton wire line operations under way work on MP2 work orders,general housekeeping. 0300 0830 3.50 6 5 MOB A1 P Move rig mats.and stage for move,remove herculite.grade,level and scratch pad.remove snow in front of well houses. 08.30 0830 2.00 8.50 MOB A1 P PJSM,spread hurculite and lay mats. 08.30 10.30 2.00 10.50 MOB A2 P PJSM,crab pits and sub down the well row.retrieve and lay mats,walk sub down transition to new rig mat layout. 10-30 12:00 1.50 12.00 MOB A 2 P PJSM,begin spotting sub over SP22-FN1. 12:00 73.30 1.50 13.50 MOB A2 P PJSM,cont spotting sub over SP22-FN1,lower stompers on to Samson beam W/500 psi 13:30 14-30 1.00 14.50 MOB B2 P PJSM,Skid rig floor. 14.30 76:30 2.00 16.50'MOB A2 P PJSM,Spot pit complex. 16 30 2000 3,50 20.00 MOB A 20 P Finish berming rig,spot and berm slop tank.secure stairways and entry ways.R/U choke line.HP mud line.flow line,ready pits to take on fluid,post permit to drill and well sign. 2000 22:30 2.50 22.50 MOB A 8 P Take on 870 bbls 9.9 brine,prime mud pumps.R/U to kill well. 2230 00:00 1.50 24 00 MOB M9 P PJSM,Bullhead 350 bbls of 9.9 ppg brine @ 8 BPM,1000 psi,3500 stks of the 720 bbls needed do IA for well kill. Projected handover to production 4/12/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici ENI Drilling Manager Eni representative Marc Kuck ENI Engineer Manager Eni representative Bruno Ravagli ENI Superintendent Eni representative Bruce Simonson ENI Drilling Supssiddnlling@enipelroleum cow 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv, siddrilling@enlpetroleum.corn 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrgclerksdoyonl5(@enipetroleum.cow 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rgl5@doyondril)ing com 907-685-0716 Tool Push Dave Sena Doyon Drilling Tour Pusher rg15@doyondrilling.com Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(in) ID(In) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date LINER 51/2 4,83 L80 12,009.9 21,9298 2/27/2013 Well Name: SP22- R • Daily Report .. iptwooit Wellbore Name: SP22-FN1 Well Code: 26945 Date: 415/2017 • Report#: 3 en fl Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N` Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation Off Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(h) 53 50 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Clear 14 3 ENE @ 38 MPH Gusting to 45 MPH WC-8- 68.0 Daily Summary Operations 24h Forecast Cont to R/U to pull ESP completion string,check well for pressure.pull BPV.RID landing p8.pull hanger free&pull to floor,LID hanger&landing int.POOH WI 4 1/2"12.6#L-80 Hyd 563 tubing. 24h Summary Kill well.N/D tree.NIU BOPE,perform body test on stack,Test BOPE.begin R/U to pull ESP completion. Operation at 07.00 PJSM to pull hanger. Time Log Start End Cum Dar Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 PREP M 9 P PJSM Cont.bullheading down IA @ 8 bpm,1.030 PSI.Total volume pumped 720 bbl 9.9 ppg Brine.Blow down Circ,Equip. 01.00 03:00 2.00 3.00 PREP M 1 P Monitor well.Initial IA Press,4.5 PSI,Tub 24.5 PSI.After 1 hour IA Press,-1.8 PSI,TUB 18.5 PSI.SIMOPS C/O rubber gasket on#1 Pop Off. 0300 04.00 1.00 4.00 PREP M 1 P Bleed down Tubing and IA to 0 PSI.Test mud lines to 3.000 PSIgood.Take on 290 bbl 9.9 ppg Brine to pits C/O Pump#1 Pop Off.Test Gas alarms.Hook up Tiger Tank. 04 00 05:00 1.00 5.00 PREP M 1 P Shut in bleed line and monitor IA and Tub Press.Both tubing and IA show-1 PSI on digital gauge.Both still positive gas venting,Decision made to pump tubing volume. 05:00 05:30 0,50 5.50 PREP M 9 P Bull head tubing volume 150 bbl 9 ppg Brine.Stage pumps up to 3.5 bpm ICP 1,590 PSI FCP 1.480 PSI.SIMOPS work on #1 Boiler feed pump. 0530 10:00 4.50 10.00 PREP M 1 P Shut in blow down Circ.Equip.Monitor IA Press.At 2.4 PSI.Vent Gas to bleed tank.Tubing on Vacum.SIMOPS R/U to test BOPE,Grease choke and stack. 10:00 12:00 2.00 12.00 PREP C 5 P Pull Tree cap and install BPV.N/D Tree and install blanking plug.Obtain Well Head RKBS.NIU HP Riser and set ROPE on riser.Install choke hose.Total fluid pumped in well 523 bbl. n 12:00 14:00 2.00 14.00 PREP C 5 P Cont.to NIU BOP,RILDS on riser install flow nipple,flow line,kill line,turn buckles,inflate air boots, y1r/"/ 14.00 15:00 1.00 15.00 PREP C 5 P Cont RID to test BOPE.M/U test int,blanking plug and hanger,fill stack and choke with water&work out air.flow check flow �C/1 line with water. df'� 15.00 16:00 1.00 16.00 PREP C 1 P Open IA to perform body test,minimal air/gas coming out of IA R/U to bleed trailer and vent IA. /Or_'% 16:00 17.00 1.00 17.00 PREP C 12 P Perform body test,good. ���///aaa"' 17:00 21:30 4.50 21.50 PREP C 12 P PJSM,Begin BOP test,test all choke valves 1-14 to 250/3500 psi,test annular to 250/3500 psi W/4 1/2"test int,test upper& lower rams WI 4 1/2"test jnt to 250/3500 psi and blind rams 250/3500 psi,test TT525 4 1/2"FOSV&TT525 dad valve, manual kill and choke,HCR kill and choke,kill line Demco,upper&lower IBOP's to 250/3500 psi,test man&super choke to 1500 psi,perform koomey test with start man=1500 psi.sys=2950 psi,ann=1000 psi,after function man=1500 psi.sys= 1450 psi.ann=1000 psi,200 psi increase=37 sec.,full sys charge=201 sec..5 bottle average 2400 psi,all tests charted successful.AOGCC Matt Herrera waived Witness to BOP Test. 21:30 22:00 0.50 22.00 PREP C 1 P RID B/D test equipment. 22:00 00:00 2.00 24.00 PREP L 1 P Hang ESP sheave and install elephant trunk,string ropes though sheaves,bring thread protector to the floor,lay herculite in front of spooling unit,Total losses for the day 523 bbls. Protected handover to production 4/12/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici ENI Drilling Manager Eni representative Marc Kuck ENI Engineer Manager Eni representative Bruno Ravagli ENI Superintendent Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. sidtlnllhig@enipetroleum.com 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyonl5@enipetroleum.com 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling corn 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher rig15@doyondrilling cum Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(11KB) TVD Bot.(ttKB) Run Date LINER 51/2 4.83 L80 12,009.9 21,929.0 2/27/2013 0.0.0* Well Name: SP22-IOR • Daily Report Wellbore Name: SP22-FN1 Date:Well Code: 26945• Report#:14017 2n fi Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange Off RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0 00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("FI Wind Days LTI(days) Days RI(days) POB Clear 17 2 ENE @ 38 MPH Gusting to 45 MPH WC-8 82,0 Daily Summary Operations 24h Forecast Cont to POOH W/4.5"completion string.L/D shroud&ESP assembly.clear rig floor.Clear pipe shed of ESP components&tubing.load pipe shed WI new 4 5"12 68 L.80 hyd 563 tubing.Strap and rabbit&tally, load new ESP components.R/U to RIH W/new ESP assembly. 24h Summary Cont to R/U to RIH.BOLDS pull hng to rig floor.LID hanger and landing int.POOH Fl 9.664'to 858'MD,after visual inspection of tubing found both box and pin end were washed and pitted. Operation at 07.00 POOH W/ESP completion @ 96'MD Time Log Start End Cum Dur Time Time •Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2-50 PREP A 1 P PJSM Cont.rigging ropes through sheave,elephant trunk.GBR Power pac and PIU Power Tongs. 02:30 03:30 1.00 3.50 PREP L 1 P Pull test dart and BPV.M/U Landing Joint as per Vetco Grey Rep onsite.Adjust Stack to hole center. 03.30 05:30 2.00 5.50 W 0 L •20 P PJSM Table top well control drill conducted with all personnel.BOLDS.Pull Hanger free at 205K,String PW 143K.Test ESP and Penetrator.Terminate CAP and ESP lines.Prep ESP and CAP for pulling over sheave and connect to Spooling Unit.L/D Hanger and Landing Joint.Fill hole with 10 bbl 9.9 ppg Brine.no returns. 05.30 07:30 2.00 7.50 W.O. L 1 P Work on rigging up elephant trunk to sheave. - 07.30 13:00 5.50 13.00 W.O. L 4 P PJSM POOH 4.5"HYD 583 Tubing,CAP and ESP lines Fl 9624'to 8.000'MD.Filling double metal displacement total 28.8 bbl and 10 bbl every hour.While pulling CAP tube was balled up and running on wrong side of Cannon clamp,found 15'loop in CAP tube at joint#210.PW 140K.SLK 90K.Found almost all tubing to have washed pitting on box and pin end.Whole string will be replaced. 13:00 14:00 1.00 14 00 W.O. L 5 P Cut out PFT Splice on ESP cable and attach back together with splice barrel. 14:00 1630 2.50 16.50 W.O. L ▪4 P Cont POOH WI 4.5"12.63 L-80 Hyd 563 tbg F 8,000'to 6,000'MD.adding double disp every 10 jnts and10 BPH to hole.cab disp 7.2 double=14.4 16.30 17:30 1.00 17.50 W.O. L 9 P RN&pump tbg volume 90 bbis @ 4 BPM.2,000 psi.R/D BID circ equipment. 17:30 21:00 3.50 21.00 W.O. L '4 P Cont POOH W 4.5"completion string F/6.000'to 3,031'MD, adding double disp every 10 jots and10 BPH to hole,cab disp 7.2 double=14.4 21 00 21:30 0.50 21.50 W.O. L 9 P Circ tbg volume 45 bbls @ 4 BPM,1650 psi,no returns,RID BID circ equip.455 ttl strokes. 21.30 22:30 1.00 22.50 W.O. L ••4 P Cont POOH WI 4.5"ESP completion F/3,031'to 1.666'MD. adding double disp every 10 jots and10 BPH to hole,calc disp 5.4 double=10.8 22:30 23:00 0.50 23.00 W.O. L ▪9 P Pump 25 bbls tubing volume @ 4 BPM,1400 psi,no returns,260 01 stroke,R/D B/D circ equip. 2300 00:00 1.00 24.00 WO L ▪4 P Cont POOH W/4.5"ESP completion string FI 1.868'to 856'MD,adding double disp every 10 jilts.adding 10 BPH to hole,talc disp 3.6 double disp=7.2.change out ESP spool.Losses for tour 351 bbls Total losses for the day 451 bbls, Projected handover to production 4/11/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-07t5 Eni representative Mike Grubb ENI Drilling Supv. siddrilling@enipetroleum coin 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl5@enipetroleumcom 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher ng15@doyondrilling corn Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(ftKB) Run Date LINER 51/2 4.83 L80 12009.9 21,929.0 2/27/2013 r^°* Well Name: SP22-lOR • Daily Report Wellbore Name: SP22-FN1 Well Code: 26945• RetP ort#:15017 2 n° Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Clear 13 2 E @ 34 MPH Gusting to 45 MPH WC-14 65.0 Daily Summary Operations 24h Forecast P/U M/U shroud&ESP components.M/U&test ESP cable&cap tube.RIM W/4.5"ESP completion string. 24h Summary POOH W/45"ESP completion string.L/D ESP components&shroud.RID equipment from trip out of hole.unload and load new 4.5"12.69 L-EO Hyd 563 tubing strap.rabbi)&tally.CO spools in spooler unit Operation at 07.00 Assembling ESP components Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01.30 1.50 1.50 W.O. 'L 5 P Cont.C/O Baker Spool.SIMOPS strap and prep tubing for removal.Clear cannon clamps from rig floor. 01.30 '03.30 2.00 3.50 W.O. L 4 P POOH 4.5"Tubing.ESP and CAP lines Fl 856'to 53'MD.Cont.to fill double displacement and t0 bph 9.9 ppg Brine.Calc. Dis.3.2 bbl,Dbl Dis 6.8 bbl Tubing still appeared to have pitting and wash in box and pin ends. 03.30 06.00 2.50' 6.00 W.O. ''L 4 P Lay down Tubing stop and pack off in tubing joint.Halliburton Slickline was unable to get to location due to weather.Remove pump with rig and motor from shroud,L/D shroud. 06.00 '10:30 4.50' 10.50 W.O. *L 5 P Spool excess cable and CAP to spooling unit.Remove elephant trunk from ESP Sheave.Remove old pump and Equip.from Pipe Shed.Clear and clean rig floor.Bring Baker Job box,cannon clamps and GBR Volant tool to rig floor.M/U Volant to TDS- 8 as per GBR onsite. 10:30 1200 ' 1.50 12.00 W.O. 'A 1 'U Unload 4.5"12.6#L-80 HYD 563 tubing in Pipe Shed.Tour losses to hole 132 bbls 12:00 18:00 ' 6.00' 18.00 W.O. •A 1 U Cont unload tubing FI pipe shed,load new tubing in pipe shed and process.Bring canon clamps to rig floor.Cont filling hole 10 BPH. 18.00 "00.00 6.00 24.00 W.O. A 1 U Cont loading,strap and rabbit new tubing in pipe shed,change spools in spooler unit.load pipe shed W/ESP components and shroud.Cont filling hole every hour W/10 bbls 9.9#brine. tour losses 120 bbls,Total losses for the day 252 bbls. Projected handover to production 4/11/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative 'Oliver Amend ENI Drilling Supv 907-685-0715 Eni representative Mike Grubb ENI Drilling Supvslddnlling@enipetroleum cam 907-685-0715 Em representative Mitch Billington ENI Rig Clerk akrigclerksdoyon 15@enipetroleum cam 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher rg15@doyondrilling com Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(11KB) Bottom OMB) TVD Bot.(ftKB) Run Date LINER 51/2 4.83 L80 12,009.9 21.929.0 2/27/2013 Well Name: SP22-•OR . Daily Report Wellbore Name: SP22-FN1 Date: Well Code: 26945 Report#: 6 17 2n fl Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0 00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 OOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Clear 5.3 NE @ 30 MPH Gusting to 42 WC-19' 63.0 Daily Summary Operations 24h Forecast Coot RIH WI ESP completion string filling hole 10 BPH W/9 90 brine and complete tubing volume every 3.000' 24h Summary Load pipe shed WI ESP assembly&shroud,P/U M/U ESP assembly&shroud.M/U MLE&ESP cable splice&test.M/U cap 3/8 to 1/4"cap tube and test.Re-test due to high pressure to open valve.RIH WI 4 5" ESP completion string to 2167 MD Operation at 07.00 RIH W/4 1/2"ESP completion at 4,015'MD Time Log Start End Cum Dur Time Time Our(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 COMP K1 P PJSM Cont.to load Pipe Shed W/Pump,Motor and Shroud. 01-00 02.30 1.50 2.50 COMP K1 P PJSM Held well control drill W/personnel.Break out gas dispersion tube from X/O.L/D 3.5"dispersion tube and M/U 7" Shroud. 02 30 05.00 2.50 5.00 COMP K 5 P P/U Motor and seals.Fill with oil and Cont.to M/U intake and upper pump. 05:00 0700 2.00 7.00 COMP K 5 P Pull up to motor and connect 14"TEC wee to well lift motor gauge to Press,discharge sub.Connect'''A"lines and check valve to motor centralizer.Phase 2 weather conditions_ 0700 08.00 1.00 8.00 COMP K 5 P Connect G`TEC wire to the discharge Press.sub and test to 250 PSI, 08.00 10:00 2.00 10.00 COMP K 4 P M/U first joint of 4.5-563 HYD Tubing to top of DGU.PJSM Pull ESP and CAP lines through sheave to rig floor. 10:00 12:00 2.00 12.00 COMP K 5 P Perform MLE splice to ESP.with ENI Rep onsite.Convert/,"CAP line to 3/8"CAP line on reel.Losses for tour 121 bbls 12-00 13:30 1.50 13.50 COMP K 5 P Cont W/MLE splic to ESP power cable,(ENI Electrician witnessed splice)convert 1/4"cap line to 3/8"cap tube. 13 30 14:00 0.50 14.00 COMP K1 P PJSM W/all essential personnel.discussed well control role and responsibility Expressed specific overhead hazards around ESP and CAP lines hanging in Derrick 14.00 15.00 1.00 1500 COMP K 5 P Install pothead clamp P/U and remove safety clamp. 1500 2000 5.00 20.00 COMP K 12 P Perform test on ESP cable and cap tube test as per Baker procedure,cap tube pressure to open valve was high at 4,000 psi re-testing multiple times with same results.consultation to Baker rep Caleb Conrad was done.confirmation from Caleb to proceed was given to proceed to RIH. 2000 0000 4.00 24 00 COMP K 4 P RIH W/4 1/2"12.6#L-80 Hyd 563 tubing string as per tally to 2.167'MD.optimum M/U 3800 ft lbs,filling well every hour WI 10 bbls 9.9#brine and complete tubing volume every 3,000'.Losses for tour 120 bbls.Total losses for the day 241 bbls. Projected handover to production 4/10/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supvsiddrdkng@empetroleum com 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrgclerksdoyonl5@enipetroleum.com 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rg15@doyondnllmg corn 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher rg15@doyondrillmg.com Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) TVD Bot.)ftKB) Run Date LINER 51/2 4.83 L80 12009.9 21,929.0 2/27/2013 Well Name: SP22-0R . Daily Report Wellbore Name: SP22-FNI DaWell Code: 26945 Ret ort#:17• 017 en Job: WORKOVER Page:1 of 1 Well Header Permit/Concession W Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Clear 13 2 NE@2OMPH VV.-6 62.0 Daily Summary Operations 24h Forecast Make final ESP cable splice to tubing hanger.Terminale CAP tube.Land hanger.RID ROPE.R/U Tree and testperform final checks.Freeze protect well and turn over well. 24h Summary RIH F/2.167'to 9.547'MD as per tally.Perform all checks.P/U Hanger and terminate lines. Operation at 07.00 Land Hanger and N/D Stack. Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 COMP K4 P PJSM,Cont.RIH W/4.5"1-80 12.6#HYDRIL 563 F/2167'T/3000'. 0130 02:00 0.50 2.00'COMP K •9 P Pump Tubing volume(pump 45bbls@4BPM=850psi)Perform electrical tests on ESP cable and test cap tube every 1000'. 02.00 03:30 1.50 3.50 COMP K4 P Cont RIH FI3,015'T/4.015'MD. 03.30 04:00 0.50 4.00 COMP K '12 P Perform electrical test on ESP cable. 04.00 05:30 1.50 5.50 COMP K4 P Cont.RIH P14015'T/5041'MD. 05:30 06:00 0.50 6.00'COMP K '12 P Perform electrical test on ESP cable. 06:00 07.30 1.50 7.50 COMP K4 P Cont.RIH F/5,041'T/6,030'MD. 07:30 08:00 0.50 8.00'COMP K •9 P Pump Tubing volume(pump 91bbls @ 38PM=1 600psi)Perform electrical tests on ESP cable every 1000'. 08.00 09:00 1.00 9.00 COMP K4 P Cont.RIH F/6,030'T/7,013'MD. 09.00 09:30 0.50 9.50 COMP K •4 P Perform electrical test on ESP cable. 0930 11:00 1.50 11.00 COMP K4 P Cont.RIH F/7.013'TI 7.810'MD. 11 00 13.00 2.00 13.00 COMP K 20 P Change out ESP spool at 7.810'MD and splice new spool w/barrel connectors to run over sheave.Losses 257 bbl for tour. 13.00 13:30 0.50 13.50 COMP K4 P Cont.RIH F/7_813 T/8.100'MD. 13.30 15:00 1.50 15.00 COMP K '20 P Splice ESP cable on onrig floor.Pump tubing Vol.@ 2/bpm 1,480 PSI.RIH to 8.140'submerge splice with 5 bbls of brine pumped from trip tank.Test ESP.good test. 15.00 15:30 0.50 15.50 COMP K4 P Cont.RIH F/8.140'to 8,225'MD. 15-30 19:00 3.50 19.00'COMP K '25 U Trouble shoot and repair Spooking unit as per ENI Electrician.Found Brake breaker needed repair. 19.00 21.00 2.00 21.00 COMP K4 P Cont.to RIH F/8.225'to 9,547'MD. 21.00 22.00 1.00 22.00 COMP K •4 P Test ESP cable.pull air slips and change out elevators. 22.00 23.30 1.50 23.50 COMP K4 P PJSM,M/U X-O pup.tubing hanger and landing joint w/TlWvalve installed 2330 00.00 0.50 24 00 COMP K4 P Testing CAP line,Install penetrator on hanger 511 bbls losses for the day. 229 cannon clamps 2 splice clamps 2 protectorizer clamps 8 pump clamps Projected handover to production 4/10/17 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative •Oliver Amend ENI 'Drilling Supv 907-685-0715 Eni representative Mike Grubb ENI Drilling Supvslddnllingi empetroleum corn 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rg15@doyondrilhng cool 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher ng15c,3^doyondnlhng.com Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(RKB) Run Date LINER 51/2 4.83 L80 12,009.9 21,929.0 2/27/2013 Well Name: SP22-•OR • Daily Report . liy.6.0t, Wellbore Name: SP22-FN1 Well Code: 26945• Ret ort#:OB 017 2n 0 Job: WORKOVERp Page:1 of 1 Well Header Permit/Concession N` Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RK8-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature('F) Wind Days LTI(days) Days RI(days) POB Overcast 15 5 N @ 14.4 MPH W.C.1 64.0 Daily Summary Operations 24h Forecast Continue w/Clean Rig.and Rig down operations. 24h Summary Test ESP Cap&Line.Land Hanger.N/D BOPE.N/U Tree&Adapter.Test Tree&Adapter,Rig Clean Up&Rig Down Operations. Operation at 07.00 COntinue w/Clean Rig,and Rig Down Operations Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01.00 1.00 1.00 COMP K 12 P PJSM,test ESP cable and CAP line. 01.00 02.30 1.50 2.50 COMP K 4 P PJSM.Tie off ESP cable and CAP line and cut.Prepare and splice ESP cable with ENI electrician wittness.Make CAP line connection and feed thru tubing hanger. 02.30 03:30 1.00 3.50 COMP K 12 P Pressure test CAP line.Terminate CAP line Test ESP cable. 03.30 05.00 1.50 5 00 COMP K 4 P Land out tubing hanger(P/U-155k,S/0-100k).Test hanger body seals to 5000psi fort0 minutes,good test. 05.00 05.30 0.50 5.50 COMP K 4 P Pull landing joint and lay down in pipe shed. 030 07:00 1.50 7 00 COMP K 7 ' 5. P Flush mud pumps and surface lines,Pump 30 bbls thru choke and poor boy degasser and blow down lines.Rinse BOP stack and Vaacum out. 07.00 09.00 2.00 9.00 COMP C 1 •P PJSM,open doors,pull rams,and grease ram cavitys.sim-ops L/D Casing Tools,and ESP sheaves on rig floor. 09.00 11:00 2.00 11.00 COMP C 5 P COntinue to open doors,pull rams,and grease cavitys. 11:00 1200 1.00 12.00 COMP C 5 ,P PJSM,N/D Stack 1200 13:30 1.50 13.50 COMP K 1 'P Continue clearing rig floor,send out baker centriliff job bones.splice cable.false table,vetco hanger protector.wear ring& running tool,baker fishing valve,rams from POPE 1330 14:30 1.00 14.50 COMP K 1 P Clean drip pan&Rotary table 1490 16:00 1.50 16.00 COMP C 5 P PJSM,obtain well bay permits N/D BOPE&Riser. 16:00 18:00 2.00 18.00 COMP C 5 P Prep Well Head,N/U Tree PT Hanger void&Pack off test T/5000 psi,pull BPV install TWC. 18.00 23:00 5.00 23.00 COMP C 5 P Fill Tree w/diesel,R/U&PT tree 500 psi 010 min.PT swab&wing valve 500 psi,for 5 min.2,000 psi f/5 min.3000 psi f/5 min.. pull TWC install BPV. 23.00 0000 1.00 24.00 COMP C 5 ,P R/D test equipment,Begin performing final checks on ESP&Cap Tubes. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. '907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. siddrilling@empelroleum corn 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Paul Holley ENI ENI Safely Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnllmg.com 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher rig15@doyondrilling coin Last Casing Seat Cas.Type OD(in) ID(in) Grade Top IftKB) Bottom(ftKB) TVD Bot.(ftKB) Run Date LINER 51/2 4.83 L80 12.009.9 21,929.0 2/27/2013 Well Name: SP22-•OR • Daily Report Wellbore Name: SP22-FN1 Well Code: 26945 Re en El Job: WORKOVER Date:ort 4/11/2017 Report Page:1 of 1 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Ca Inc. DEVELOPMENT WELL Rotary Table Elevation(B) Water Depth(N) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature CF) Wind Days LTI(days) Days RI(days) POB Fog 162 N@ 2MPH WC 16 62.0 Daily Summary Operations 24h Forecast Continue Rig Down Operations 24h Summary Cleaned rig floor rig mats.stack.manifolds pumps and sumps Slip&Cut drill linebreak down hope stack and crane out of mezzaninedisassemble top drive. Operation at 07.00 Continuing Rig Down Operations. Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 200 COMP K 12 P PJSM Cont.to test ESP and CAP as per Baker procedure.SIMOPS clean Pits and remove rig malts. 02.00 06.00 4.00 6.00 MOB A 1 P Clean rig floor and cellar area.Scrub stack and clean up around tree.Cont.to clean Pits-Fix cellar alarm float.Clean out suction manifolds on Mud Pumps.Clean out sumps in Pit Room. 06:00 11:30 5.50 11.50 MOB A 1 P Post well sign back in Well Bay.Clean up around SP12.Cont.cleaning around rig 11.30 12.00 0.50 12.00 MOB A 1 P Town Hall Safety Meeting.Discuss JSEA's,injuries,PPE.attitude,ownership on doing the job safely and staying focus on the task al hand. 12.00 15:00 3.00 15.00 MOB A 1 P PJSM.THA Review,slip&cut 7 wraps of drilling line.59',slipped an extra 30 wraps for a total of 51 wraps to lay down top drive,inspected brakes. 15:00 19:00 4.00 19 00 MOB A 1 P r PJSM,break down BOP stack and crane out of mezzanine. 19.00 00:00 5.00 24 00 MOB A 1 P PJSM,remove bails.BIO and remove saver sub,both iboy's&remove pipe handler.link tilt arms,link tilt actuator,put locking rings ibop actuator.Link tiff links and rams in wood crate and send all ityems off rig floor.put top drive in service mode. Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Oliver Amend ENI Drilling Supv 907-685-0715 Eni representative Mike Grubb ENI Drilling Supvsiddrilling@enipetroleum cow 907-685-0715 Em representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rg15@doyondrilling.com 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher rg15@doyondrilling.com Last Casing Seat Cas.Type 00(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(ttKB) Run Date LINER 51/2 483 L80 12.009,9 21929.0 2/27/2013 fes. fill* Well Name: SP22-•OR Daily Report Wellbore Name: SP22-FN1 Well Code: 26945 #:Date: 12017 #: 10 e n ll Job: WORKOVER Page:1 of 1 Well Header PermitlConcession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(N) Water Depth(N) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 0.00 16.75 36.85 33.50 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy 11 5 N @ 21 MPH WC-7 59.0 Daily Summary Operations 24h Forecast Continue Rig Down Operations 24h Summary Rig Down Operations Operation at 07.00 Rig Down Operations. Time Log Start End Cum Our Time Time Our(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 MOB A 2 P PJSM L/D subs and sub rack,cement line.kelly hose and rig tongs.Drain top-drive gear oil R/D flow line.hole fill and mud manifold.Replac water valves in pit module. 06.00 12:00 6.00 12.00 MOB A 2 P PJSM R/D mud lines.LID&TIO top-drive and unplug service loop.LID long bails.remove weather stripping on beaver slide. cleanout cuttings box.remove hoses in pump room,remove guard on service loop box in derrick.drain hydraulic lines on service loop. 1200 1800 600 18.00 MOB A 2 P PJSM Disconnect service loops from top-drive and remove.Remove stand pipe.cement line and mud manifold.Install stops on top-drive rails,disconnect wiring in VFD yop-drive house. 18.00 00:00 6.00 24.00 MOB A 2 P PJSM,Disconnect service loops ft junction box in derrick,lower top drive onto stops,remove upper rollers.disconnect coomey lines and store. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supvsiddnlling@enipetroleum com 907-685-0715 907-320 00511 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rigl h@doyondrilling.coin 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher rig15@doyondrilling.com Last Casing Seat Cas.Type OD lint ID(in) Grade Top(11KB) Bottom(ftKB) TVD But.(NKB) Run Date LINER 51/2 4.83 L80 12.0099 21,929.0 2/27/2013 sr Tit I//7;4.s THE STATE Alaska Oil and Gas �i+t� �► Of A L1 A l�i �15JL��1 1 � Conservation Commission __ 1 1 5 } = 333 West Seventh Avenue GOVERNOR BILL WALKER rti Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck Drilling and Completion Engineering Manager Eni US Operating Co. Inc. 3800 Centerpoint Dr., Ste. 300 SCANNED MAt'' &Hi?, Anchorage,AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP22-FN1 Permit to Drill Number: 212-162 Sundry Number: 317-038 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 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, Cathy P Foerster Chair DATED this I day of February,2017. RDDMS Lv FEB - 3 2017 RECEIVED , • STATE OF ALASKA • JAN 2 4017 • ALASKA OIL AND GAS CONSERVATION COMMISSION 2.t/l/? APPLICATION FOR SUNDRY APPROVALS ,AOGGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well Q . Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q - Change Approved Program El Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out n ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Eni US Operating Co.Inc. Exploratory ❑ Development 0, 212-162 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-629-23478-00-00 I 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A SP22-FN1 • Will planned perforations require a spacing exception? Yes ❑ No 0 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0391283, 0388574, 0388572 Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Tot�Col� njt�,�/1 D(ft: Total py�i�h D(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 2.C� 3;.82' ?IA 21929 3782 600 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 3082 13.375" 3082 2434 5210 2480 Intermediate 12095 9.625" 12095 3699 6890 4790 Production Liner 9834 5.5" 21929 3782 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12095-21,929 & 3,699-3,782 4.5" L80 9,600 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary El Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development Q ' Service ❑ 14.Estimated Date for 3/12/2017 15.Well Status after proposed work: Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Amjad Chaudhry Email an'Uad.chaudhry( .enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager 907-865-3379 Signature Phone 907-865-3322 Date 1/23/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. � ll- 03 � Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ ASF -2_/, IR Other: s.. 3t; c,r, t, 60P �, Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: ,'Q --404 RBDMS DA ,v - 3 2017 APPROVED BY Approved by:61/447/ ?9. 1-,—___0_40.7 THE COMMISSION Date:Z —/— / 7 n n ^- Submit Form and J Form 10-403 ed 11/2015 81RciaB4tPs�liI tOr 12 months frotr thi date of approval. / attachments in Duplicate • • RECEIVED 411.10, if* - , ��• Enii �� itF II rc urn AOGGC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: marc.kuck@enipetroleum.com January 23`d ,2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for SP22-FN1 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP22-FN1. SP22-FNlwas completed on Spy Island on March 4th, 2013 with an electric submersible pump set at a depth of 9,664' MD. This ESP producer was completed without a packer. The well was started up for production in March 2013 We are swapping out TTC-ESP to the conventional ESP system. The estimated date for beginning this work is March 12th, 2017. 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 Amjad Chaudhry at 907- 865-3379. Sincerely, Marc Kuck Well Operations Project Manager • SP22-FN1 Workover— Summary Page PTD#: 212-162 Current Status Producing with ESP Lift 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 1000 psi (3,696' 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 February 2013. Well type: Producer Estimated start date: March 12th 2017 Drilling rig: Doyon 15 Completion Engineer: Amjad Chaudhry: amjad.chaudhry@enipetroleum.com Work: 907-865-3379 III • Procedure: 1. MIRU Doyon 15. 2. Shear upper GLM valve and pump in bullheading 8.6 ppg KCl brine through tree. Pump in bullheading 8.6 ppg KC1 brine in IA. Ensure well is killed. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. ,/' 4. Pull tubing to upper GLM. 5. Shear lower GLM valve and pump in bullheading 8.6 ppg KC1 brine. 6. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 7. Circulate out remaining production fluid. 8. Continue POOH and lay down ESP assembly. 9. Perform a CO run 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: III 4-W 12.6 ppf Production Tubing e n n petroleum 2.266'MD.1.932'TVD 45°Inc-GLM.KBMG. 4-W'x 1" with 2.000 psi STS-1 SOV installed SP22-FN1 4-1/2"x-cplg cable clamps,for ESP Fishbone Power Cable.(113/8"Chem In)Line Oil Producer with Iiii with 2500 psi check valve at bottom ESP Lift 9,460'MD,3,466'TVD,82°Inc-GLM,KBMG, 4-1/2"x 1", As Comp with 3IPI N .100 psi STS-1 SOV installed 9.560'MD.3.480'TVD-Discharge Gauge Sub 3/4/2013 9.664'MD.3,494'TVD,82°Inc-Bottom of Motor 110 Centralizer Centrilift,TTC-ESP. 134-stage 380P18SXD pump. Surf.Casing 513 GSB3 seals,, 150 HP MSP325 motor 13-3/8".68# - 9,679'MD 32#Shroud Assembly with cable and 3,082'MD,2,434'TVD chemical injection line feed-thrus 60°Inc. �� 11,933'MD.3,696'TVD-Baker SLXP Liner Hanger/Packer �'/-7 HAL 5-V,Oil Swell 5-W Silver Bullet Ecc. \ Packer Nose Guide Shoe Item M0(ft) \- IIIIN -.11 .11.1' '=Mir 5-1/2"Swell Pkr 81 21849 5-1/2"Swell Pkr#2 20546 5-1/2"Swell No 83 18190 5-1/2"Swell Pkr#4 15249 5-1/2"Swell Pkr#5 13500 Interm Casing MD(ft) Slotted Liner, 9-5/8".40# Plug Back 83/4" From To 5-1/2"15.5 ppf 12.095'MD.3.699'TVD PB1 13280 14550 21,929'MD.3.782'TVD 87°Inc. P82 14880 16360 95°Inc. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - L to ez Well History File Identifier Organizing (done) t/` /Two-sided III 111111 II III II III ❑ Rescan Needed III 111111 I III III v/Two-sided • AN DIGITAL DATA OVERSIZED (Scannable) r Items: ❑ Diskettes, No. ❑ Maps Greyscale Items: ❑ Other, No/Type: ther Items Scannable by a Large Scanner ov,v, S�Vc,, ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: alb Date: /s/ I, Project Proofing I I IIII 11111 BY: Date: ' f 7 I /s/ Scanning Preparation 9 x 30 = X70 + a = TOTAL PAGES a%,/ (Count does not include cover sheet) BY: Date: I /s/ Production Scanning III litlilliN 11111 Stage 1 Page Count from Scanned File: oC 902 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date:I/I 7 P.1. /s/ yt Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO r' BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 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W O O I(/) N CO CO o ,N m m r 4m m m 1 H : I I • •_ • •= i Z Y ! I I Ce 7 _ l U U U U U O F- u m 0) F- c co 0 .2 N Q C U C .co d y 0. 0 O E d E 0 O E o a5 ! E i E a Z 0 a 0 0 I 0 McMains, Stephen E (DOA) From: Cesari Michele <Michele.Cesari @enipetroleum.com> Sent: Thursday, August 15, 2013 11:26 AM To: McMains, Stephen E (DOA) Cc: Buchanan Andrew Subject: SP22-FN] Periscope Steve, I spoke with Andrew, our senior operations geologist,and he said that Periscope is just a gamma ray and resistivity log, so you should have it already. Feel free to contact him if you need more information. Thank you. Regards, Michele Cesari Jr Completion Engineer Anchorage, AK Office (Anchorage): (907) 865-3338 Cell: (907) 230-9701 Email: Michele.cesari @enipetroleum.com This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1 , STATE OF ALASKA ALAor A OIL AND GAS CONSERVATION COMMI06ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development El Exploratory ❑ GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: $ Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Sus or - t 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 3 2013 212-162 3.Address: 6.Date Spudded: �� 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 1/26/2012 50-629-23478-00-00. 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4451 FSL 1366 3 FEL S19 T14N R9E UM 1/9/2013 SP22-FN1 • Top of Productive Horizon: 8.KB(ft above MSL): 53.6. 15.Field/Pool(s): 2827 FSL 697 FEL 14 T14N R8EUM GL(ft above MSL): 13.08• Nikaitchuq/Schrader Bluff Oil Pool• Total Depth: 9.Plug Back Depth(MD+TVD): 3972 FSL 3436 FEL 10 T14N R8EUM N/A C ib.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation:3238583,3y�'S�� �� iJSurf rQ 511543.56 y- 6053633.08 Zone- 4 22,923'MD/3,408'TVD . ADL 391283,0388574,0388572 y- 6057279.37 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total bep1 - .87 y-6063706.86 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U. No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 2,006'MD/1,750'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/Periscope N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 36.85 160 36.85 160 Driven N/A N/A 13.375 68 L-80 36.85 3082 36.85 2434 16 10.7 ppg ASL:482 bbls N/A 12.5 ppg DeepCRETE:64 bbls 9.625 40 L-80 35.53 12095 35.53 3699 12.25 12.5 ppg DeepCRETE:230 bbls N/A 5.5 15.5 L-80 11933 21929 3696 3782 8.75 Slotted Liner N/A 24.Open to production or injection? Yes❑ No pi If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5 9664 N/A 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED RECEIVED 27. PRODUCTION TEST APR 16 2013 Date First Production: ESP Method of Operation(Flowing,gas lift,etc.): AO<.f�V 2/3/2013 Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio:scf/bbl 3/14/2013 24 Test Period -1014.7 77.6 70.6 128/128 76 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 263 0 24-Hour Rate - 1014.7 77.6 70.6 18.6 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No El. Sidewall Cores Acquired? Yes ❑ No El . If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS APR 18 2013 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7/.._ ‘.7.1z Submit original only ?kb 151%115 G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? H Yes I.1 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. SV4 768 760 SV3 1161 1110 SV2 1478 1361 Permafrost-Base 2006 1750 SV1 2253 1923 Ugnu Top 2730 2248 UG-2 Coal Bed Marker 3882 2734 Lower Ugnu 8057 3272 Schrader Bluff Top 9776 3509 N Sequence Top 10910 3662 N top 10533 3610 N bottom 10597 3618 N Sequence base 10910 3662 OA sand top 12413 3719 N bottom 22731 3504 N top 22772 3484 Formation at total depth: OA sand 21800 3761 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michele Cesari Printed Name: Ja -- Title: Drilling and Completion Engineering Manager Signature'' d ,�, Phone Contact: (907)865-3338 Date: 4/15/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Q U U a� W `a- +-• QC10 •3 a c1 -•,I- — Z = > � air avu LL O vJ p in °u,' " , U) inN 0 0) NN73aU4 \ Z N 4 L W O W Q �' U I RS C O °' v. 3 I a c = u 0L, m m M 0 U.ZI 3 >` 0 . ` ate 1 8 � N1010 D 0 X L X `n o I a 0 D •0 d E .Q (/) a) O E - �; °° � N a) -c m 1 1 M Y a) U a) � N a I co Y 0 (0 0 Q a ' ea m m -, L N to a� o0 (� N U CO 1 a 0 C i 3 .-1 N m C E rn M = = a a a a a QQ '- O (/) C Crn o n J C N 1 W •E2 o c Q N � N O M C) 1 O E N Ot3 , W 0 M . ) Q C U -0 m p ,a ,. va Q •c 2 .» � °' Q0 > Q � M I- in ..e RS M i � ° o ca U > 7 c Q LI— M O U M?o ~ (/)C Cv) N m Q CO U � - n , c a) = O 70 ' C U) .e Co c cM c� OCO V U N N U U M Q O CAUUIf) 0 co c L a) to Q 0 Cfl o CL CO 1 C7)_ la O E 0\O Q (4 Q c) 0 )111111' L In Cb CL C2 � I- UUCO OM Coin Co Q •N x a) CV tt +J O CV 2 Q g L C7) 3 p N _N 00 d 3 r'CV 0 4 N N \\ #7 110\"" 0 �■ 0 co in M ...Nis?' N N .-1 .-1 a1 MI (6 F• TS N M T I CT M Ys st xt u xt a N c a_a, U N d d N N Q oO vii A vii vii vii ii C) N N N N N c cr N N N N ai a-1 0 CO 1A_ U) t!1 1!1 u1 O as M 2 _ if* Eni E&P Division I Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • Date:1/24/2013 - Report#: 1 APIIUWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator I ENI Share)%) !Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date (Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-FN1PB1 DRILLING 1/27/2013 1 23,383.0 28,469.00 175.50 162.2 -2.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) !Weather 'Wind 0.0 103.0 -16.0 Cloudy,WC-35` NNW @ 11 MPH Daily summary operation 24h Summary Move off of SP05-FN7 location and move over SP22-FN1 location. Operation at 07.00 R/U on SP22-FN1. 24h Forecast Complete R/U on Well SP22-FN1. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gal) Time Log Stan End Cum Time Time Dur(hr( Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -02.30 2.50 2.50 MOB A 2 'P 'Run#5 RIH 8 set new shear valve and test to 650 psi.POOH and change tools.#6 RIH and retrieve slip-stop catcher. 02.30 04:00 1.50 4.00 MOB A 2 P 'R/D Howco wire line and Lil Red. 04:00 07:30 3.50 7.50 MOB A 2 'P Loader prepping pad,demob lines,blow down steam and water and lower pipe shed supports. 07:30 08:30 1.00 8.50 MOB A 2 P PJSA Skid rig floor. 08:30 '10:30 2.00 10.50 MOB A 2 'P 'Set herculite and matts for rig move. 10:30 '12:00 ' 1.50 12.00 MOB A 2 'P 'Move pit complex down pad.P/U stomper on sub complex. 12:00 15:00 3.00 15.00 MOB A 2 P 'Move sub complex off Well SP05-FN7 and spot over Well SP22-FN1. f 15:00 20:00 ' 5.00 20.00 MOB A '2 P 'Install diverter line sections.Spot pit complex.Clean SP05-FN7 location. 20:00 00:00 4.00 24.00 MOB A 2 P PJSA Skid rig floor over Well SP22-FN1.Set liner for rock washer 8 Pump module#3. Daily Contacts Position Contact Name Company ' Title E-mail Office Mobile _ Eni representative 'Mike Ross ENI Senior Dulling Supv SIDDnlling @enipetroleum.com '907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com :907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/23/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) D Eni E&P Division 'Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUO •" Date:1/25/2013 - Report#: 2 API/UWI:50-629-23478-00-00 2" page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) - Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) 'Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 1 23,383.01 28,469.00 175.50 162.2 -1.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 0.0 110.0 -20.0 Cloudy,WC-41` NW @ 10.MPH Daily summary operation _ 24h Summary Continue spotting complexes and rigging up. Operation at 07.00 Rigging up Diverter system. 24h Forecast Complete R/U and N/U diverter system and test.Process 5"DP and P/U,M/U and rack in derrick.Load BHA and prep for M/U.Make spud mud and bring to rig pits. 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 04:00 4.00 4.00 MOB A 2 P Connect steam,spotl03 pump complex. 04:00 05:30 1.50 5.50 MOB 'A '2 P Spot rock washer complex and R/U service lines. 05:30 12:00 6.50 12.00 MOB A '2 P Setting suitcases on manifold side.Berming around rig.R/U interconnects and service lines. 12:00 '18:00 6.00 18.00'MOB -A 2 P R/U suitcases on rock washer side.Remove divener section from SP05-FN7. 18:00 00:00 ' 6.00 24.00 MOB A 2 P Load Vetco equipment to rig and M/U as per Vetco.M/U staring head and test to 500 psi f/10 min.Install riser and test to 500 psi f/10 min.Install divener bag and test connection to 500 psi f/10 min. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Dolling Tour Pusher og15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/23/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) r Eni E&P Division 'Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Repo..}` Well Code:26945 Field Name:NIKAITCHUO • Date:1/26/2013 - Report#: 3 APIIUWI:50-629-23478-00-00 2" "ll page 1 of 1 Wellbore name: SP22-FN1 PB1 Well Header Permit/Concession N° Operator I ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(Mr) DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23.383.0 I 28,469.00 175.50 162.2 0.00 Daily Information End Depth(f1KB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB 'Temperature(°F) Weather Wind 0.0 102.0 -19.0 Cloudy,WC-41' W @ 10 MPH Daily summary operation 24h Summary Complete R/U on Well SP22-FN1.Perform diverter test.Witness waived by Bob Noble.P/U&M/U BHA#1. Operation at 07.00 Dnll ahead as per SLB with 16"BHA. 24h Forecast Spud well and drill ahead as per SLB. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Ib/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 MOB A 2 P PJSA Pressure test suitcases.Loading 5"DP to pipe shed. 01'.00 04:00 3.00 4.00 MOB A 20 P PJSA Install riser and flowline.Prep cellar and rig floor for P/U DP. 04:00 05:00 1.00 5.00 MOB A 20 P PJSA Load SLB tools into pipe shed. 05:00 06:00 1.00 6.00 MOB A 20 P PJSA R/D completion sheaves from derrick f/SP05-FN7 well.Left in derrick due to weather. 06:00 12:00 6.00 12.00 MOB A 20 P PJSA P/U 8 M/U 5"DP and rack in derrick. 12:00 13:00 1.00 13.00 MOB A 20 P Complete diverter line make up.Load 5"HWDP into pipe shed and process. 13:00 14:00 1.00 14.00 MOB A 20 P PJSA Perform dummy run w/Vetco 13 3/8"hanger and landing joint. 14:00 15:30 ' 1.50 15.50 MOB A 12 P PJSA Function test diverter bag and knife valve.Witness waived by Bob Noble. 15:30 16:00 0.50 16.00 MOB A 20 'P PJSA Mob BHA to rig floor. 16:00 19:00 3.00 19.00 MOB E 20 P PJSA M/U HWDP,jars and NMFlex DC and rack in derrick. 19:00 20:30 ' 1.50' 20.50 MOB E 25 "P PJSA Slip 8 cut 106'of drilling line,service top-drive,saver sub and backup wrench. 20:30 21:30 1.00 21.50 MOB E 7 P PJSA flood conductor and check for leaks.Prime all rig mud pumps and pressure test lines to 3500 psi. 21:30 22:00 0.50 22.00 MOB E 20 P Pre-Spud Meeting with all parties. 22:00 00:00 2.00' 24.00 MOB E 20 'P PJSA M/U BHA#1 as per SLB. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/23/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2 Eni E&P Division I Well Name:SP22-FN7 OR VIII* ENI Petroleum Co.Inc. Daily Report` Well Code:26945 Field Name:NIKAITCHUQ •� Date:1/27/2013 - Report#: 4 API/UWI:50-629-23478-00-00 211 11 Welibore name: SP22-FN1PB1 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share VA) I Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(it) 53.60 13,08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 1.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 931.0 910.5 771.00 5.77 133.6 101.0 -22.0 Cloudy,WC-52° WSW @ 17 MPH Daily summary operation 24h Summary Clean out conductor w/BHA#1.Doll 16"surface hole to 931'MD. Operation at 07.00 Drilling ahead with 16"surface hole @ 1,180'MD. 24h Forecast Drill ahead to 13 3/8"casing point @ 3.079'. Lithology 'Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 7 P PJSA Wash&ream out conductor @ 600 gpm,500 psi,40 rpm,5k wob,2k tq. 01:30 03:30 2.00 3.50 DRILL E 20 P PJSA POOH and PU Gyro data and RIH. 03:30 05:00 1.50 5.00 DRILL E 12 P Perform shallow hole test and correlate Gyro w/MWD. 05:00 08:30 3.50 8.50 DRILL E 3 P Ddg f/160'-313'MD @ 614 gpm,609 psi,40 rpm,10-15k wob.3k tq,11.69 ECD. 08:30 10:00 1.50 10.00 DRILL E 4 P PJSA POOH and M/U BHA#2 and RIH. 10:00 12:00 2.00 12.00'DRILL E 3 P Ddg f/313'-402'MD @ 619 gpm,821 psi,40 rpm,15-20k wob,4k tq,10.59 ECD,1.88 ADT,1.31 AST,.57 ART,1.88 Bit/ Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P Ddg 5 402'-714'MD(707'TVD)@ 600 gpm,870 psi,40 rpm,10-20 k wob,4k tq on/off,110k puw,110k sow,110k rotw, Max Gas 4,10.10 ECD,1.61 ADT,1.53 AST,.08 ART,3.49 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P Ddg f/714'-931'MD(911'TVD)@ 650 gpm,970 psi,40 rpm,10-20k wob,4k tq on/off.120k puw/sow/rotw,Max Gas 5, 10.06 ECD,2.28 ADT,1.83 AST,.45 ART,5.77 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon l5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/23/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) 'Fluid Type I Fluid Density(Ib/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Ill* Eni E&P Division 'Well Name:SP22-FN1 OR EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • Date:1/2812013 - Report#: 5 APIIUWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 212-162 ENI PETROLEUM I 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDES(days) SP22-FN1PB1 DRILLING 1/27/2013 I 23,383.0 28469.00 175.50 162.2 2.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,705.0 2,233.4 1,774.00 12.43 142.7 114.0 -29.0 Fair,WC-53° SW @ 8 MPH Daily summary operation 24h Summary Drilling 16"surface hole to 2705'MD(2241'TVD). Operation at 07.00 Drilling ahead with 16"surface hole @ 2,852'MD. 24h Forecast Cont.drilling to+/-3100'casing point.BROOH as per K&M schedule and LD BHA.R/U to run 13 3/8"casing. Lithology 'Shows MAASP Pressure(psi) I 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 06:00 6.00 6.00 DRILL E 3 P Ddg f/931'-1334'MD(1254'TVD)@ 645 gpm,1150 psi.40 rpm,20-25k wob,6-8k tq on,132k puw.125k sow,128k rotw, Max Gas 21,10.23 ECD,3.27 ADT,2.41 AST,.86 ART.9.04 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL -E 3 P Ddg f/1334'-1700'MD(1530'TVD)@ 641 gpm,1300 psi,40 rpm,20k wob,6-8k tq on,125k puw,125k sow,130k rotw, Max Gas 81,10.47 ECD,2.89 ADT,1.59 AST,1.30 ART,11.93 Bit/Jars. • 12:00 18:00 6.00 18.00 DRILL E 3 P Ddg f/1700'-2667'MD(2214'TVD)@ 750 gpm,1580 psi,40 rpm,20-30k wob,8k tq on,5-6k tq off,148k puw,132k sow, , 137k rotw,Max Gas 280,10.63 ECD,3.0 ADT,1.27 AST,1.73 ART,14.93 Bit/Jars, • • 18:00 00:00 6.00 24.00 DRILL E 3 P DrIg f/2667'-2705'MD(2241'TVD)@ 700 gpm,1600 psi,40 rpm,20-30k wob,8-10k tq on.7k tq off,150k puw,132k sow.137k rotw,Max gas 172,10.57 ECD,3.27 ADT.1.22 AST,2.05 ART,18.2 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Pete Adams ENI HOE 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CONDUCTOR 20 18.250 X65 0.0 160.0 1/23/2013 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) Eni E&P Division I Well Name:SP22-FN1 OR fill* ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ o Date:1/29/2013 - Report#: 6 API/UWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° I Operator ENI Share)%) 'Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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(flihr) I DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 3.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,097.0 2,441.3 392.00 4.02 97.5 114.0 -36.0 Clear,WC-52° ISW©5 MPH Daily summary operation 24h Summary Drill to casing point picked by Geologists @ 3097'MD.Perform cleanup cycle and BROOH as per K&M schedule. Complete BROOH. Operation at 07.00 L/D BHA#2. 24h Forecast R/U and run 13 3/8"casing as per tally and circulate&cement inplace. Lithology 'Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. - 00:00 08:30 8.50 8.50 DRILL E 3 P Ddg f/2705'-3097'MD(3026'TVD)@ 800 gpm,1800 psi,40 rpm.22k wob,8-10k tq on.5-10k tq off,155k puw,132k sow.141k rotw,Max Gas 52.10.12 ECD,4.02 ADT,2.59 AST,1.43 ART,22.22 Bit/Jars. 08:30 10:00 1.50 10.00 DRILL E 12 -P PJSA Take check shots with MWD and cluster shot surveys with Gyro Data.Place Gyro Data tool in sleep mode. ' 10:00 12:00 2.00 12.00 DRILL E 7 P Perform cleanup cycle as per K&M f/3097'-2975'@ 850 gpm,1700 psi,80 rpm,4-6k tq.155k puw,131k sow. 12:00 18:00 6.00 18.00 DRILL E 4 P BROOH f/2975'-1840'@ 850 gpm,1560 psi,80 rpm.7-8k tq,140k puw,125k sow,NOTE;Hole unloaded 200%cuttings @ 1985'&1565'. 18:00 00:00 6.00 24.00 DRILL E 4 P BROOH f/1840'-683',@ 850 gpm,1450 psi,80 rpm,4-5k tq,Max Gas 700. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl 5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Pete Adams ENI HSE 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 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) I 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: SP22-FN1 OR EN/Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUQ • APIIUWI:50-629-23478-00-00 2 raj*^„ Date:1/30/2013 - Report#: 7 II II�I page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator I ENI Share(%( 'Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) -Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG __ Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD..'Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2, 4.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) IPOB Temperature(°F) Weather [Wind 3.097.0 2,441.3 0.00 113.0 -22.0 Cloudy,WC-50' NE @ 20 MPH Daily summary operation 24h Summary BROOH and L/D BHA#2.R/U and run 13 3/8"68#L-80 BTC casing and land on Vetco hanger to 3082'.Circulate and condition mud,PT cmt lines and pump 100 bbls of Mud Push II followed w/10.7 lead cement. Operation at 07.00 Rigging down from cement job. 24h Forecast R/D f/cement job.Nipple up BOPE.P/U DP and rack back in derrick. Test BOPE. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 4 P PJSA.BROOH f/683'-300'@ 850 gpm,1200 psi,80 rpm,3 tq,105k rotw.Monitor well-static. 02:00 04:30 2.50 4.50'DRILL E 5 P PJSA.L/D BHA#2 as per Schlumberger rep f/300'MD. 04:30 05:00 0.50 5.00'DRILL G 1 P PJSA.Clean and clear rig floor of BHA equipment.Prep for P/U Volant casing running tool. 05:00 06:30 ' 1.50 6.50'DRILL 'G 1 P PJSA.P/U and M/U 13-3/8"casing running equipment and R/U for running 13-3/8"casing as per plan. 0630 10:00 3.50 10.00 DRILL G 4 P PJSA.P/U and M/U 13-3/8"casing shoe track to 162'MD.Check floats(Witnessed by Company Rep onsite/Baledok as required. 10:00 12:00 2.00 12.00 DRILL G 4 P PJSA.Continue to RIH w/13-3/8"68#L-80 BTC casing as per well plan 1/162'MD to 791'MD.SOW 115k.Fill every joint and top off every 10 joints. 12:00 17:00 5.00 17.00 DRILL G 4 P Run 13 3/8"casing f/791'-3045'as perprogram.j7 joints&15 centralizers total. 17:00 18.00 1.00 18.00 DRILL G 4 P M/U Vetco hanger and landing it.Break circulation @ 2 bpm.130 psi and wash down and land casing @ 3082'MD.290k puw,180k sow. 18:00 21:00 3.00 21.00 DRILL H 7 P Circulate and condition mud through Volant tool @ 2-6 bpm,130-230 psi. 21:00 21:30 0.50 21.50 DRILL H 20 P PJSA for cement job while circulating. 21:30 22:30 1.00 22.50 DRILL H 7 P R/U and continue circulating through cement line @ 6 bpm.220 psi. 22:30 00:00 1.50 24.00 DRILL H 7 P PT cement lines to 1000/3500 psi.Rig pump 100 bbls of 10.1 ppg Mud Push II @ 5 bpm,180 psi.Drop bottom plug and SLB cementers pump 10.7 ppg lead slurry @ 5&bpm,600 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoy on15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Pete Adams ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division Well Name:SP22-FN1 OR fill* ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ •" Date:1/3112013 - Report#: 8 APIIUWI:50-629-23478-00-00 2" page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 5.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather (Wind 3,097.0 2,441.3 0.00 107.0 -18.0 Cloudy,WC-42° NE @ 15 MPH Daily summary operation 24h Summary Complete cement job w/68 bbls circulated to surface.CIP @ 0330 hrs.RID and N/D diverter sys.and R/U Vetco Multibowi assy and test.N/U BOPE. - Operation at 07.00 P/U 5"DP. 24h Forecast P/U 8 M/U 5"DP and rack in derrick.Test BOPE as per regulations.M/U BHA#3 and RIH and perform surface test. Lithology Shows (/-- MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum J Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL H 7 P Complete pumping 482 bbls of 10.7 ppg Arctic Set Lite lead cement @ 5.5 bpm followed w/64 bbls of 12.5 ppg LiteCrete tail cmt.Pump out Top plug wl 10 bbls fresh water followed w/437 bbls treated spud mud @ 5 bpm,slow to 3 bpm 400 psi and bump plug to 900 psi and hold f/5 min.Floats good.CIP @ 0330 hrs.Circulated 68 bbls of cement to surface. 03.30 04:00 0.50 4.00 DRILL H 20 P PJSA Unscrew Vetco landing jt.from casing hanger and L/D. 04:00 04:30 0.50 4.50 DRILL H 20 P PJSA R/D and clear floor of Volant tools and GBR casing equipment. 04.30 06:00 1.50 6.00 DRILL H 20 P PJSA R/U and run Johnny Wacker to clean stack.Clean drip pan. 06:00 09:00 3.00 9.00 DRILL C 20 P PJSA Remove bell nipple and N/D Diverter sys.Remove riser and Vetco prep to install wellhead equipment. 09:00 12:00 3.00 12.00 DRILL C 20 P PJSA Install Vetco Multibowl assy.and orient as per Rep.Test lower seals to 5000 psi Witnessed by Co-Rep. 12:00 14:30 2.50 14.50 DRILL C 20 P PJSA Install valves on multibowl assy,N/U hi-pressure riser and prep for stack. 14:30 18:00 3.50 18.00 DRILL C 20 P PJSA N/U BOPE. 18:00 19:30 1.50 19.50 DRILL E 20 P PJSA R/U and LID HWDP from derrick. 1930 22:00 2.50 22.00 DRILL 'E 20 P Load and process 5"DP in pipe shed. 22.00 00.00 2.00 24.00 DRILL 'E 20 P PJSA P/U 8 M/U 5"DP in mousehole and rack in derrick. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling @enipetroleum.com 907-685-0715 -715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl 5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Pete Adams ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) -Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • APIIUWI:50-629-23478-00-00 2/1/2013 - Repo #: 9 page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° 'Operator I ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 1 23,383.0 28469.00 175.50 162.2 6.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,097.0 2,441.3 0.00 118.0 -20.0 Partly Cloudy,WC- NE @ 23 MPH 48' Daily summary operation 24h Summary P/U 5"DP.R/U&test BOPE witnessed by AOGCC Rep Jeff Jones.M/U BHA#3 and RIH and perform shallow hole test. Operation at 07.00 Performing casing test. 24h Forecast RIH w/BHA#3 to TO Float Collar.CBU and perform casing test to 2500 psi f/30 min.Pull 5 stds.cleaning DP of burrs.Perform stripping drill with Doyon ng hands.RIH and set drilling parameters and drill shoe track and 20'of new hole.Perform LOT/FIT and document results.Drill ahead. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 09.00 9.00 9.00 DRILL E 20 P PJSA P/U&M/U 5"DP and rack in derrick. 09:00 17:30 8.50 17.50 DRILL E 12 P PJSA R/U to test BOPE.Test witnessed by AOGCC Rep Jeff Jones.Test BOPE to 300/3500 psi(annular to 2500)as per State regulations. 17:30 18:30 1.00 18.50 DRILL E 25 P PJSA R/D&B/D test equipment.Install bell guide on top-drive and grease IBOP valves. 18:30 '19;00 0.50 19.00 DRILL E 20 P PJSA Pull test plug and set wear bushing. 19:00 '2030 1.50 20.50 DRILL E 20 P PJSA Load BHA tools and equipment to rig floor.Inspect saver sub. 20:30 23.30 3.00 23.50 DRILL E 4 P PJSA Install mousehole.P/U&M/U BHA as per SLB and RIH. 2330 0000 0.50 24.00 DRILL E 12 P PJSA Perform shallow hole test as per SLB @ 600 gpm.470 psi.100k puw,100k sow.100k rotw.30 rpm,1k tq.Blow down top-drive. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Dave Evans 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 Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.021 1,645.8 f Eni E&P Division [Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • Date:2/212013 - Report#: 10 API/UWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB•Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name IRig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) SP22-FN1P61 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 7.00 Daily Information End Depth(f1KB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,702.0 2,686.4 605.00 3.02 200.3 119.0 -11.0 Cloudy/Windy,WC- NNE @ 36 MPH 41' Daily summary operation 24h Summary RIH to top of float collar and circulate&condition mud.PT 13 3/8"casing to 2500 psi for 30 min.Drill shoe track&20'of new hole and displace well to 9.25 ppg LSND mud.Perform formation integrity test to 13.0 ppg FIT.Set parameters and drill ahead as per SLB. Operation at 07.00 Drilling ahead in 12-1/4"intermediate hole @ 4,076 MD. 24h Forecast Drill ahead in 12-1/4"intermediate hole as per SLB. Lithology Shows MAASP Pressure(psi) IMud Weight(lb/gal) 9.30 - 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 RIH w/BHA#31/252'-2957',145k puw,115k sow. 02:30 03:30 1.00 3.50 DRILL E 7 P PJSA Circulate&condition mud and prep.for casing test @ 550 gpm,500 psi. 03:30 05:00 1.50 5.00 DRILL E 12 P PJSA Pressurel3 3/8"casing to 2500 psi and monitor for 30 min.R/D test equipment. ✓ 05:00 08:00 3.00 8.00 DRILL E 4 P PJSA Pull 7 stds of pipe&perform kick while drilling drill,stripping drill and well kill drill.Blow down from drill and RIH w/7 stds and obtain SPR @ 2954'MD(2369'ND)w/9.3 ppg MW. #1 @30-70,@40-90 #2 @30-60,@40-80 #3 @ 30-60,@ 40-80. 08:00 12:30 4.50 12.50 DRILL E 3 P PJSA DrIg shoe track f/2957'-3082'@ 617 gpm,720 psi,50 rpm,6-10k tq,150k puw,118k sow,135k rotw.Ddg new hole to 3117'. 12:30 14:30 2.00 14.50 DRILL E 7 P PJSA Circulate and displace well w/50 bbls.viscosified water @ 3 bpm followed w/9.25 ppg LSND mud @ 10 bpm,320 psi,50 rpm,7k tq,146k puw,124k sow,136k rotw.Rack back stand to 3051'and Blow down top-drive. 14:30 16:30 2.00 16.50 DRILL E 25 P PJSA Cut&slip 51'of drill line,adjust brakes,grease draw works,blocks and top-drive. 1630 17:00 0.50 17.00 DRILL E 7 P PJSA CBU @ 800 gpm,1000 psi,50 rpm,7k tq,136k rotw. 17:00 18:00 1.00 18.00 DRILL E 9 P PJSA R/U and perform FIT test to 13.0 ppg equivalent.BD lines and R/D. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSA Ddg f/3117'-3702'MD(2689'ND)@ 905 gpm,1270 psi,190 rpm,4-10k wob,5-10k tq on,5-6k tq off,142k puw. 126k sow,136k rotw,Max Gas 26,9.47 ECD,3.02 ADT,3.02 Bit,63.42 Jars. Daily Contacts Position • Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-605-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 Eni E&P Division , 'Well Name:SP22-FN1 OR 1011)11111i1 1 ENI Petroleum Co.Inc. Daily Repot 1 Well Code:26945 Field Name:NIKAITCHUQ • Date:2/3/2013 - Report#: 11 APIIUWI:50-629-23478-00-00 en 0 page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 8.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,689.0 3,084.7 2,987.00 12.85 232.5 120.0 -18.0 Mostly Cloudy,WC- NNE @ 25 MPH 47" Daily summary operation 24h Summary Drilling 12.25"intermediate hole f/3702'-6689'MD(3081'TVD). Operation at 07.00 Drilling ahead in 12-1/4"intermediate hole @ 7,120'MD. 24h Forecast Drill to casing point @ 12,170'. Lithology Shows MAASP Pressure(psi) Mud Weight(113/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00- 6.00 DRILL E 3 P Ddg f/3702'-4355'MD(2790'TVD)@ 907 gpm,1420 psi,195 rpm,4-6k wob,8-10k tq on,5-7k tq off.146k puw,122k sow.135k rotw,Max Gas 5,9.58 ECD,3.63 ADT,6.65 Bit,67.05 Jars. 06:00 12:00 6.00- 12.00 DRILL E 3 P Ddg f/4355'-4920'MD(2853'TVD)@ 900 gpm,1500 psi,198 rpm,4.8k wob,8-10k tq on,6-8k tq off,148k puw,118k sow,137k rotw,Max Gas 8,9.59 ECD,2.89 ADT,9.54 Bit,69.94 Jars. 12:00 18:00 ' 6.00- 18.00 DRILL E 3 P Ddg f/4920'-5849'MD(2962'TVD)@ 900 gpm,1710 psi,140-200 rpm,4-12k wob,10-11k tq on,6-8k tq off,155k puw, 114k sow,135k rotw,Max Gas 16,9.83 ECD,3.55 ADT,13.09 Bit,73.49 Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P Ddg 5 5849'-6689'MD(3081'TVD)@ 900 gpm,1910 psi,140-200 rpm,4-12k wob,12-13k tq on,6-8k tq off,155k puw, 112k sow,139k rotw,Max Gas 20,10.01 ECD,2.78 ADT,15.87 Bit,76.27 Jars. - Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv -SIDDrilling @enipetroleum.com 907-685-0715 .715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 f Eni E&P Division `Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ Date:2/4/2013 - Report#: 12 APIIUWI:50-629-23478-00-00 e n" page 1 of 1 Wellbore name: SP22-FN1 PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 9.00 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) 'Weather Wind .. 9,023.0 3,405.3 2.334.00 13.95 167.3 117.0 -23.0 Partly Cloudy.WC- NW @ 5 MPH 34" Daily summary operation 24h Summary Drill 12.25"intermediate hole f/6689'-9023'MD. Operation at 07.00 Drilling ahead in 12.25"intermediate hole @ 9,390'MD. 24h Forecast Drill to casing point @ 12,170'. Lithology I Shows MAASP Pressure(psi) Mud Weight(lb/gal) 1 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 DrIg f/6689'-7393'MD(3179'ND)@ 902 gpm,2030 psi,190 rpm.4-8k wob,10-12k tq on,7-10k tel off,162 puw,112k sow.143k rotw,Max Gas 6,10.11 ECD.3.27 ADT,19.14 Bit,70.54 Jars. 06:00 12:00 6.00 12.00'DRILL E 3 'P DrIg f/7393'-7910'MD(3252'ND)@ 904 gpm,2100 psi,160-190 rpm.6-8k wob,11-12k tq on,10k tq off,165k puw, 115k sow,145k rotw,Max Gas 25,10.01 ECD,3.5 ADT,22.64 Bit,83.04 Jars. 12:00 '18:00 6.00 18.00 DRILL E 3 P Ng If 7910'-8444'MD(3325'TVD)@ 900 gpm,2010 psi,140-200 rpm,4-12k wob.12-15k tq on,8-9k tq off,170k puw. 115k sow,146k rotw,Max Gas 45,9.89 ECD,3.84 ADT,26.48 Bit.86.88 Jars.Note;1600-1730 hrs-SLB MWD computer hard drive problems. 18:00 00:00 6.00 24,00'DRILL E '3 P DrIg f/8444'-9023'MD(3403'ND)@ 900 gpm,2060 psi,140-200 rpm,8k wob,13k tq on,8k tq off,174k puw,109k sow, 150k rotw,Max Gas 29,9.4 ECD,3.34 ADT,28.82 Bit,90.22 Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Dolling Supv SIDDnlling @enipetroleum.com -907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(Ib/gal) I P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 01411 Eni E&P Division (Well Name: SP22-FNI OR EN/Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUQ • Date:2/5/2013 - Report#: 13 APIIUWI:50 629-23478-00-00 e "ii page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 10.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,863.0 3,520.0 840.00 5.71 147.1 117.0 -35.0 Mostly Cloudy,WC- W @ 8 MPH 55` Daily summary operation 24h Summary Drill intermediate hole F/9,023'to 9,863'MD(3.519'TVD)Due to Schlumberger ARC tool failure.BROOH F/9,863'to 4,914'MD. Operation at 07.00 BROOH @ 4,200'MD. 24h Forecast BROOH F/4.200 MD to BHA#3.due to Schlumberger ARC tool failure.Swap out ARC and Bit and RIH W/BHA#4.RIH to 9,863'MD and Cont.to drill ahead to Csg.point @ 12.170'MD. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06'00 6.00 6.00 DRILL E 3 P PJSA Drill F/9,023'to 9.583'MD(3,482'ND)920 GPM,2,170 PSI,181 RPM,TQN 14-15K,TQF 16K,WOB 2-12K,HST 183K,SLK 104K,ROT 149K.ECD 9.95 ppg W/9.3 ppg MW.Max Gas 25 units.ADT 4.38 hrs,Bit Hrs 34.20,Jar Hrs 94.60. Monitor well Static. 06:00 09.00 3.00 9.00 DRILL E 3 P PJSA Drill Fl 9,583'to 9,863'MD(3,519'ND)909 GPM,2.240 PSI,190 RPM,TON 15-16K,TQF 12K,WOB 8K,HST 180K,SLK 105K,ROT 151K.ECD 9.98 ppg W/9.35 ppg MW.Max Gas 24 units.ADT 1.33 hrs,Bit Hrs 35.53,Jar Hrs 95.93.Monitor well Static. ' SPR @ 9,863'MD(3,519'ND)W/9.35 ppg MW MP#1 30-280,40-310 MP#2 30-280,40-310 MP#3 30-280,40-310 09.00 10:30 1.50 10.50 DRILL E 6 TD01 PJSA Due to Schlumberger ARC tool failure it was determined to POOH to replace tool.As per K&M Rep onsite CBU while racking back one stand Fl 9,863'to 9,770'MD.900 GPM.2,150 PSI,120 RPM.TQF 12K,HST 180K,SLK 107K. 10.30 12:00 1.50 12.00 DRILL E 6 TD01 PJSA BROOH as per K&M BROOH schedule F/9,770'to 9,587'MD 900 GPM,2,120 PSI,120 RPM.TOP 12K,HST 178K, SLK 105K,ROT 150K. 12:00 18:00 6.00 18.00 DRILL E 6 TD01 PJSA BROOH as per K&M BROOH schedule F/9,587'to 7,252'MD 900 GPM,2,010 PSI,100-120 RPM,TRQ 11K. Pumps on ROT WT 138K,High torque spikes observed F/7,150'to 7,131'MD.Reamed thru areas 2X. 18:00 00:00 6.00 24.00 DRILL E 6 TD01 PJSA BROOH as per K&M BROOH schedule Fl 7,252'to 4,914'MD 900 GPM.1,710 PSI,100-120 RPM,TRQ 8K,Pumps on ROT WT 132K,High torque spikes observed F/5,165'to 4,914'MD.Reamed thru areas 2X. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15 @e nipetroleum.com 907-685-0722 907-268-9054 Eni representative Mike Nelson EM HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dnlling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0,0 3,082.0 1/30/2013 Last Leakoff Test Depth(f1KB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 111* Eni E&P Division Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report` Well Code:26945 Field Name:NIKAITCHUQ •" Date:2/6/2013 - Report#: 14 APIIUWI:50-629-23478-00-00 • 2" page 1 of 1 Wellbore name: SP22-FN1 PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-FN1PB1 DRILLING 1/27/2013 23,383.0 I 28,469.00 175.50 162.2 11.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,863.0 3,520.0 0.00 109.0 -36.0 Partly Cloudy WC- SW @ 14 MPH 64' Daily summary operation 24h Summary BROOH as per K&M F/4,914'MD to BHA#3.Had trouble pulling BHA#3 thru Wear Bushing and BOPE due to clay balling on Bit.L/D BHA#3.P/U M/U BHA#4 and load sources. Operation at 07.00 RIH W/BHA#4 @ 2,989'MD. 24h Forecast P/U M/U BHA#4 and shallow test as per MWD.RIH filling D.P.every 20 stands.Continue drilling ahead F/9,863'MD to intermediate TD 12,170'MD. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 6 TD01 PJSA BROOH as per K&M BROOH schedule F/4,914'to 3,798'MD 900 GPM.1,500 PSI.105 RPM,TQF 8-16K,HST 168K,SLK 105K,ROT 136K.Encountered high torque spikes and reamed thru twice as per K&M schedule.Monitor well, static. 06.00 12:00 6.00 12.00 DRILL E 6 TD01 PJSA BROOH as per K&M BROOH schedule F/3,798'to 2,306'MD 900 GPM.1,400 PSI.90 RPM.TQF 4-5K.HST 132K. SLK 125K.ROT 128K.Encountered high torque spikes and reamed thru twice as per K&M schedule.Stop reaming thru spots twice F/3,500'to BHA.Monitor well,static. 12.00 13:30 1.50 13.50 DRILL E 6 TD01 PJSA BROOH as per K&M BROOH schedule F/2,306'to 1.100'900 GPM.1.270 PSI,80 RPM.TRF 3-4K,ROT 115K, HST 120K,SLK 112K, 13.30 14:00 0.50 14.00 DRILL E 7 TD01 PJSA CBU 4.5X as per K&M Rep.900 GPM,1,270 PSI,80 RPM,TRQ 3-4K.Blow doom Top Drive. 14.00 14.30 0.50 14.50 DRILL E 4 TD01 PJSA POOH on Elevators F/1,100'to BHA#3.HST 115K, SLK 115K.Calculated displacement 7.5 bbl,actual Disp.7.5 bbl. 14.30 1700 2.50 17.00 DRILL E 4 TD01 PJSA L/D BHA#3 as per Schlumberger DD Rep. 17:00 18:30 1.50 18.50 DRILL E 20 TD01 Observed 10K over pull while pulling Exceed STAB thru Well Head.Contacted CO Rep and Vetco Grey Rep to discuss options.Decision was made to P/U 10-20K and rotate the string.Was able to free up Exceed STAB from Well Head. Looked to be Clay balled up on STAB preventing it from pulling thru Well Head. 18.30 2000 1.50 20.00 DRILL E 20 TD01 Inspect and clean Bit and STAB.LID ARC,Exceeed and Bit.Damages seen on surface: Bit 1/16 under with chipped and worn teeth,Xceed upper stab under and over cut and lost tiles,Xceed lower stab worn and 1/16 under initial gauge,ILS 1/2"under initial gauge of 12,Hi Tool 15/16"under initial gauge of 12 1/16,NM Stab 1 5/6"under initial gauge of 12 1/8, NM flex collars hard bands wom,Float Sub wear band wom 1/16 under initial gauge of 8 3/t6. 20:00 21:00 1.00 21.00 DRILL E 19 TD01 PJSA Pull Wear Bushing as per Vetco Rep and inspect for damage.Install Wear Bushing,no damage. 21:00 21:30 0.50 21.50 DRILL E 20 TD01 PJSA Service Drawworks,Top Drive,Blocks and Crown. 21:30 00:00 2.50 24.00 DRILL E 20 TD01 PJSA P/U M/U BHA#4 as per Schlumberger DD and MWD Rep. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Alex Dunlop 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 133/8 12.415 L80 0.0 3,082.0 1/30/2013 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) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 Eni E&P Division (Well Name:SP22-FN1 OR ffi* EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUQ • APIIUWI:50-629-23478-00-00 enn I Date:2/712013 - Report#: 15 " II' page 1 of 1 Wellbore name: SP22-FN1 PB1 Well Header Permit/Concession N° Operator ENI Share)%) 1Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 12.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,633.0 3,622.7 770.00 4.25 181.2 108.0 -36.0 Scattered Clouds WC NE @ 4 MPH -49, Daily summary operation 24h Summary P/U M/U BHA#4 as per SLB DD and MWD.Perform shallow test as per SLB MWD.RIH F/293'to 2,999'MD.Slip and cut drilling line and service rig.RIH F/2,999'10 8,100'MD lost down weight.Wash and rotate F/8,100'to 9,863'MD.Shoot survey and fix Exceed comunication issue.Doll ahead F/9,863'10 10,633'MD(3,623'ND)as per well plan and K&M Rep onsite. Operation at 07.00 Drilling ahead @ 10,995'MD 24h Forecast Drill ahead as per well plan F/10,633'10 12,170'MD 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 01:00 1.00 1.00 DRILL E 20 TD01 PJSA P/U M/U BHA#4 as per Schlumberger DD and MWD Rep onsite.F/134'to 293'MD.Obtain BHA weight as per K&M Rep onsite.HST 98K,SLK 112K,ROT 105K. 01:00 01:30 0.50 1.50 DRILL E 20 TD01 PJSA Fill BHA#4 and perform shallow hole test as per Schlumberger MWD Rep onsite,successful test. 01:30 '04:00 2.50' 4.00 DRILL E 4 TD01 PJSA RIH W/BHA#4 F/293'to 2,999'MD,HST 142K,SLK 138K,filling every 20 stands during RIH.Monitor well,static. 04:00 06:00 2.00 6.00 DRILL E 20 TD01 PJSA Slip and cut drilling line,adjust brakes on Drawworks,service Top Drive,Drawworks and raveling Equip. 06:00 10:30 4.50 10.50 DRILL E 4 TD01 PJSA RIH W/BHA#4 F/2,999'to 8,100'MD HST 185K,SLK 98,filling D.P.every 20 stands.Monitor well.static.Lost down weight and decision was made to wash&rotate to bottom, 10:30 12:00 1.50 12.00 DRILL E 4 TD01 PJSA Wash&rotate F/8,100'to 8,789'MD 300 GPM.410 PSI,40 RPM,TOF 10-12K,HST 160K.SLK 105K,ROT 135K. Monitor well,static.Calculated displacement observed,no losses. 12:00 15:00 3.00 15.00 DRILL E 4 TD01 PJSA Wash and rotate F/8,789'MD to 9.863'MD 300 GPM,430 PSI,40 RPM,TRO 11K,ROT 150K.Slow ream speed to 350 FPH for formation logging.increase pump rate @ 9,720'to 800 GPM,2,090 PSI.Tag bottom @ 9,863'MD. 15:00 15:30 0.50 15.50 DRILL E 20 TD01 Shoot on bottom survey.Exceed survey failed,trouble shoot and found surface comunication sodtware was not reading the Exceed tool.Reconfigure sodtware and shoot survey with good comunication.Take SPR,send down links as per SLB DD. SPR @ 9,858'MD(3,350'ND)W/9.4 ppg MW. MP#1 30-240,40-270 MP#2 30-240,40-270 MP#3 30-240,40-270 15.30 18:00 2.50 18.00 DRILL E 3 P PJSA Drill ahead F/9,863'to 10,091'MD(3,551'ND)900 GPM,2,480 PSI,140 RPM,TON 16-17K,TQF 10-11K.WOB 4- 12K,HST 182K,SLK 114K,ROT 151K,ECD 10.34 ppg W/9,4 ppg MW.Max Gas 32 units.ADT 1,24 Hrs,Jar Hrs 1,24,Bit Hrs 1.24.Well static. 18:00 '00:00 6.00 24.00 DRILL E 3 P PJSA Drill ahead F/10,091'to 10,633'MD(3,623'ND)900 GPM,2.580 PSI,140-200 RPM,TON 16-17K,TOF 10-11K, WOB 4-12K,HST 182K,SLK 114K,ROT 151 K,ECD 10.34 ppg W/9.4 ppg MW,Max Gas 32 units.ADT 3.01 Hrs,Jar Hrs 4.25,Bit Hrs 4.25.Well static. ' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyon 15 @ enipetroleum.com 907-685-0722 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 • Tool Push Alex Dunlop 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 j CASING 13 3/8 12.415 L80 0.0 3,082.0 1/30/2013 Y Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type !Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 3,0820 2433.84 LSND 9.30 470.0 13.02 1,645.8 fD Eni E&P Division !Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • Date:2/8/2013 - Report#: 16 APIIUWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 I 23,383.0 28,469.00 175.50 162.2 13.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12.140.0 3,707.2 1.507.00 6.54 230.4 108.0 -28.0 Scattered Clouds WC Calm -28' Daily summary operation 24h Summary Drill ahead F/10,633'to 12.140'MD(3,700'TVD).Circ.K&M clean up cycle and BROOH as per K&M schedule to 10,115'MD. Operation at 07.00 BROOH @ 8,684"MD. 24h Forecast BROOH as per K&M schedule F/10,115'MD. Lithology Shows MAASP Pressure(psi) !Mud Weight(Iblgal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA Drill F/10,633'to 11,212'MD(3,685'TVD)900 GPM,2,740 PSI,140-180 RPM,TON 16-17K.TQF 10-11K,WOB 8- 12K,HST 190K,SLK 110K,ROT 154K.ECD 10.59 ppg WI 9.45 ppg MW.Max Gas 216 units.ADT 2.75 hrs,Bit His 7.0, Jar Hrs 7.0.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill F/11,212'to 11,897'MD(3,694'TVD)850 GPM,2,480 PSI,160 RPM,TQN 17-18K,TQF 11-12K,WOB 8-12K. HST 191K,SLK 109K,ROT 151K.ECD 10.74 ppg W/9.5 ppg MW.Max Gas 63 units.ADT 2.78 hrs,Bit Hrs 9.78,Jar Hrs 9.78.Monitor well,static. SPR @ 11,863'MD(3,694'TVD)W/9.5 ppg MW. MP#1 30-300,40-340 MP#2 30-300,40-340 MP#3 30-300,40-340 1200 14'30 2.50 14.50 DRILL E 3 P PJSA Drill F/11,897'to 12,140'MD(3,700'TVD)850 GPM.2,590 PSI,160 RPM,TON 17-18K,TQF 11K,WOB 10-12K, HST 189K,SLK 106K,ROT 151K.ECD 10.81 ppg W/9.55 ppg MW.Max Gas 39 units.ADT 1,01 hrs,Bit Hrs 10.79,Jar Hrs 10.79.Monitor well,static,Shoot surveys as per SLB DD and take SPR. SPR @ 12,140'(3,700'TVD)W/9.55 ppg MW. MP#1 30-280,40-320 MP#2 30-280,40-320 MP#3 30-280,40-320 14:30 16:00 1.50 16.00 DRILL E 6 P PJSA L/D top single,CBU 1X while racking back one stand of D.P.F/12,116'to 12,023'MD 900 GPM,2,880 PSI,120 RPM,TO 13K,ROT 142K.ECD 10.65 ppg W/9.55 ppg MW.Monitor well for 10 Min.,static. 16:00 18:00 2.00 18.00 DRILL E 6 P PJSA BROOH as per K&M schedule F/12,023'to 11,749'MD,900 GPM.2,650 PSi,120 RPM.TRO 12K.ECD 10.55 ppg W/9.55 ppg MW. 18:00 00:00 6.00 24.00 DRILL E 6 P PJSA BROOH as per K&M schedule F/11,749'to 10,115'MD,900 GPM,2,450 PSi,120 RPM.TRO 12K.ECD 10.55 ppg W/9.55 ppg MW.Monitor well.static.Max Gas 99 units. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher ng15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 3,082.0 1/30/2013 - Last Leakoff Test Depth(ftKB) l TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) !Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,6458 Eni E&P Division I Well Name:SP22-FN1 OR IP* ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • API/lW:50-629-23478-00-00 Date:2/9/2013 - Repo #: 17 e ii page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° !Operator ENI Share(%( !Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) !Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 I 28,469.00 175.50 162.2 14.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,140.0 3,707.2 0.00 119.0 -18.4 Blowing Snow WC- ENE @ 35 MPH 48' Daily summary operation 24h Summary BROOH as per K&M BROOH schedule F/10,115'to BHA#4.Unload nuclear sources&UD BHA#4.No losses to formation. Operation at 07.00 Testing 9 5/8"Rams 24h Forecast C/O rams to 9 5/8"Csg.Rams and test to 250 PSI low and 3,500' PSI High for 5 Min.P/U M/U Tesco Csg.Equip.P/U M/U 9 5/8"Csg.Shoe and F.C.and test float.Float in hole as per K&M RIH Csg. procedure to 12,120'MD leaving 20'of rat hole. 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 6 P PJSA BROOH as per K&M BROOH schedule F/10,115'to 7,446'MD 900 GPM,2,150 PSI,120 RPM,TOF 11K,HST 175K,SLK 110K,ROT 146K.Monitor well,static.No losses to hole. 06:00 12:00 6.00 12.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/7,446'to 5,430'MD 900 GPM,1,800 PSI,120 RPM,TOF 9K,HST 158K, SLK 110K,ROT 138K.Monitor well,static.No losses to hole. 12:00 19:30 7.50 19.50 DRILL E 6 P 'PJSA BROOH as per K&M BROOH schedule F/5,430'to 538'MD 900 GPM,1,070 PSI,80-120 RPM,TQF 3K,ROT 120K. Monitor well,static.No losses to hole.Max Gas 20 units.SLM out of hole no change in strap. 19:30 20.00 0.50 20.00 DRILL E 7 P CBU 4X 900 GPM,1,050 PSI,80 RPM.TOE 3K,ROT 120 K.Hole did not unload or show any sign of large cutting over the Shakers. 20:00 20:30 0.50 20.50 DRILL E 4 P PJSA Blow down Top Dove,POOH on elevators to BHA#4.Monitor well for 10 Min.,static. 20.30 23:30 3.00 23.50 DRILL E 20 P 'PJSA W/Schlumberger DD and MWD Rep onsite.L/D BHA#4 and remove nuclear sources.BHA came out almost completely in gauge. 23.30 00:00 0.50 24.00 DRILL E 20 P PJSA Clear,clean and unload BHA from the rig floor. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Dulling Tour Pusher og15 @doyondrilling.com 907-685-0716 Last Casing seat Ca s.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 3,082.0 1/30/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 Y fill* Eni E&P Division .. (Well Name:SP22-FNi OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUQ • Date:2/10/2013 - Report 18 APIIUWI:50629-23478-00-S0 2 i h page 1 of 1 Wellbore name SP22-FN1 PB1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(it) 53.60 13.08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 I 23,383.0 28469.00 175.50 162.2 15.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 12,140.0 3,707.2 0.00 119.0 -17.0 Clear WC-39° NE @ 13 MPH Daily summary operation 24h Summary Cont.L/D BHA#4.CIO and test 9 5/8"Rams 250 PSI low&3,500 PSI high.Set 9 5/8"modified Wear Bushing.R/U M/U Tesco running tools as per Tesco Rep onsite.P/U M/U 9 5/8"Shoe Track and test.(Good)Float in hole 9 5/8"Csg.as per K&M RIH schedule to 7,482'MD.Started rotating 9 5/8"Csg at 30 RPM F/7,482'to 10,174'MD.No losses to formation.Down time due to Skate debris plugging hydraulic pump regulator. Operation at 07.00 RIH W/9 5/8"Casing at 11,807'MD 24h Forecast Float in 9 5/8"Csg.as per K&M RIH schedule and Tesco running tool F/10,174'to TD 12,120'MD.R/D Tesco running tool and Equip.P/U M/U Cement Head and fill 9 5/8"Csg.as per well program. Circ.and condition mud for cement job.Pump cement as per Schlumberger cement plan forward.Pump 20 bbl LSND for infectivity in 13 3/8"X 9 5/8".Set Emergency Slips as per Vetco Grey Rep. Lithology Shows MAASP Pressure(psi) !Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 20 P PJSA Clean and clear rig floor of BHA#4 tools and clear ice due to extreme cold and wind condition. 02:00 03:30 1.50 3.50 DRILL C 5 P PJSA Change out variable top rams ove to 9 5/8"Csg.rams. 03:30 04:00 0.50 4.00 DRILL C 20 P PJSA Pull Wear Ring and set Test Plug as per Vetco Grey Rep onsite. 0400 05.00 1.00 5.00 DRILL C 12 P PJSA R/U lest Equip.and test 9 5/8"Csg.rams to 250 PSI low and 3.500 PSI high for 5 Min.Test was charted. 05:00 05:30 0.50 5.50 DRILL C 20 P PJSA Pull Test Plug and replace with modified Wear Bushing for running 9 5/8"Csg.as per Vetco Grey Rep onsite. 05:30 08:00 2.50 8.00 DRILL G 20 P PJSA with all involved parties.P/U M/U Tesco Csg.Drive System for 9 5/8"Csg.,Tesco Reps onsite. 0800 10.00 2.00 10.00 DRILL G 4 P PJSA with all involved parties.P/U M/U 9 5/8"Shoe Track and test as per well plan,floats were good.Witness by CO Rep onsite.P/U M/U 163'MD SLK 85K.Transfer LSND fluid to Mud Plant for storage for casing displacement. 10:00 12:00 2.00 12.00 DRILL G 4 P PJSA RIH 9 5/8"Csg.as per detail&K&M RIH schedule W/K&M Rep onsite.Use Tesco Drive System W/Tesco Reps onsite.Float Csg.F/163'to 1,262'MD.SLK 89K No losses to formation. 12:00 15.00 3.00 15.00 DRILL G 4 P PJSA Float 9 5/8"Csg.F/1,262'to 4.160'MD as per K&M RIH schedule W/Tesco running tool.Gather parameters @ 3.078'MD as per K&M,SLK 75K,ROT WT 92K,TRQ 3-5K @ 30 RPM.No losses to formation.WIF injection pump has a wash in the body of there high pressure pump.They are running with the other pump and working on getting fluid end replaced. 15:00 16:00 1.00 16.00 DRILL G 25 TR99 Skate failure due to debris from filter,C/O plugging Hydraulic pump PSI Regulator. 16:00 18:00 2.00 18.00 DRILL G 4 P PJSA Float 9 5/8"Csg.as per K&M RIH schedule F/4,160'to 6,000'MD SLK 62K.No losses to formation. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA Float 9 5/8"Csg.as per K&M RIH schedule Fl 6.000'to 7,482'MD,lost all down WT.Aquire rotating parameters @ 7,482'MD 30 RPM,IRO 7-8K,ROT WT 82K.Continue to rotate casing as per K&M Rep F/7,482'to 10,174'MD.30 RPM, TRQ 8K,ROT WT 78K.Correct displacement,no losses to formation.250 Jnts RIH of 9 5/8"Csg. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 -715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -34 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type I Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lblgal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND J 9.30 470,0 13,02 1,645.8 Eni E&P Division 'Well Name:SP22-FNI OR fliii* EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ •" " Date:2/11/2013 - Report#: 19 API/UWI:50-629-23478-00-00 2 page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° !Operator ENI Share(%) Well Configuration type 212-162 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) !Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDES(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 16.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,140.0 3,707.2 0.00 114.0 -18.9 Mostly Cloudy WC- Calm 20" Daily summary operation 24h Summary Float and rotate 9 5/8"Csg.as per K&M RIH schedule,W/Tesco Drive System F/10,174'to 12.122'MD.R/U M/U Cement Head and fill 9 5/8"casing as per MI Swaco and Well Plan.R/D Cement Head and load plugs.R/U Cement Head and conditon mud as per MI Swaco Rep to 18 YP.Press.test lines 560 PSI low,3,100 PSI high W/Schlumberger pump.Rig pumped 100 bbl 10.5 ppg Mud Push II @ 5 bpm.Drop lower plug and Schlumberger pumped 230 bbl 12.5 ppg Lite Crete Cement.Drop top plug W/10 bbl water F/Schlumberger.Rig pumped 906 bbl 9.4 ppg LSND,bumped plug and CIP @ 23:10.Checked Float and no losses during cement job.Perform injectivity in 13 3/8"X 9 5/8"Csg.W/23 bbl and bleed back 3 bbl. Operation at 07.00 Work on setting emergency slips for the 9 5/8"Csg. 24h Forecast • R/D Cement Head and P/U long Bails.N/D Stack and pick up to set emergency slips.Set and test emergency slips as per Vetco Grey.Cut 9 5/8"Csg.P/U and L/D landing joint and cut 9 5/8"Csg.N/U BOPE stack.Freeze protect well.R/U to P/U 4.5"D.P.P/U M/U 4.5"D.P.and rack back in Derrick. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 DRILL G 4 P PJSA Float in 9 5/8"Csg.as per K&M RIH schedule F/10,174'to 12,122'MD 30 RPM,TRO 8K,ROT WT 78K.No losses to formation.Total of 307 Joints of 9 5/8"casing ran. 04:30 05:30 1.00 5.50 DRILL G 4 P PJSA P/U M/U Landing Joint as per Vetco Grey Rep onsite.R/D Tesco Drive System W/Tesco Rep onsite. 05:30 12:00 6.50 12.00 DRILL G 9 P PJSA R/U WU Cement Head with out plugs.As per well plan and MI Swaco plan forward fill 9 5/8"Csg.@ 2-4 bpm,fill 1/2 of Csg.volume(460 bbl)and stop for 10 Min.Fill to 3/4 9 5/8"Cog.volume(234 bbl)and stop for 10 Min.Hole fill across the top of the well with no losses to formation. 12.00 14:00 2.00 14.00 DRILL G 9 P PJSA As per well plan and MI Swaco plan forward fill 9 5/8"Csg.@ 2-4 bpm,top off Csg.volume(222 bbl)and stop for 10 1 Min.Cont.to top off 3X to ensure all air is out.Hole fill across the top of the well with no losses to formation. 14:00 14:30 0.50 14.50 DRILL H 20 P PJSA Break down lines and R/D Cement Head as per Schlumberger Rep onsite.Load upper and lower plugs in Cement Head.R/U Cement Head and lines to condition mud. �/ 14:30 19:30 5.00 19.50 DRILL G 8 P PJSA Circ.@ 1/2 bpm,280 PSi,stage up pumps to 8 bpm,ICP 580 PSI,FCP 460 PSI.CBU 2.5X as per MI Swaco Rep to at ?e 18 YP.No losses to formation.SIMOPS load 363 Jnts 4.5"D.P.in Pipe Shed. 19:30 23:30 4.00 23.50 DRILL H 9 P PJSM W/all personal for cement job.Press.test lines to 560 PSI low and 3,100 PSI high.(Good)Rig pumped 100 bbl 10.5 ppg Mud Push II @ 5 bpm 340 PSI,Drop bottom plug.Schlumberger cementers pumped 230 bbl of 12.5 ppg Lite Crete @. 5 bpm,352 ICP,159 FCP.Drop top plug and kick it out with 10 bbl water F/Schlumberger.Use rig pumps to put cement in ' place @ 8 bpm ICP 250 PSI.At 880 bbl away PSI 750 slowed pumps to 3 bpm.ICP 500 PSI,plug bumped @ 906 bbl(total 916 bbls) FCP 580 PSI,Press.up to 1,090 PSI for 5 Min.Bleed off Press.and check Float.(Good)CIP @ 23.10.R/D ' lines.No losses to formation. 23:30 00.00 0.50 24.00 DRILL G 9 P PJSA Perform infectivity test as per detail in the 13 3/8"X 9 5/8"Csg.Break over @ 500 PSI,FCP 480 PSI @ 2 bpm.Total bbl pumped 23 bbl,bleed back 3 bbl. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon 15 @enipetroleum.com 907-685-0722 Eni representative Mike Nelson ENI HSE Michael.Nelson @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Alex Dunlop 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 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9,30 470.0 13.02 1,645.8 1119* Eni E&P Division I Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • Date:2/12/2013 - Report#: 20 API/UWI:50-629-23478-00-00 (r " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.851 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 17.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather (Wind 12,140.0 3,707.2 0.00 112.0 16.0 Overcast WC-16° Calm Daily summary operation 24h Summary R/D Cement Head.Empty Landing Joint and Stack of LSND.N/D BOPE.Pull 100K over string weight and set Emergency Slips in Multi Bowl.Cut 9 5/8"Csg and L/D Landing Joint and 9 5/8"Csg.Set 9 5/8"Pack off and test to 2,472 PSi for 10 Min.(Good)N/U BOPE and C/O 9 5/8"Rams to 3.5"X 6"Variable Rams.Freeze Protect 9 5/8"X 13 3/8"Annulus with 184 bbl Diesel at 1.5 bbm,final OA Press. 300 PSI.Service Rig,C/O Saver Sub and Shot Pin Assy.R/U P/U M/U 4.5"D.P.and stand back in Derrick.(265 Joints) Operation at 07.00 R/U to Test BOP's 24h Forecast Continue to P/U M/U 4.5"D.P.from Pipe Shed.Test BOPE as per AOGCC,witness waived by Lou Grimaldi @ 2-12-13 09:28.Slip and Cut drilling.P/U M/U BHA#5 as per Schlumberger Rep onsite.RIH to Float Collar and Circ.LSND to break over.Displace well to 9.45 ppg Faze Pro. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL H 20 P PJSA R/D Cement Head W/Schlumberger Rep onsite.R/U long Bails for setting Emergency Slips.Clean and clear rig floor. 01:00 01:30 0.50 1.50 DRILL G 20 P PJSA Remove fluid from landing joint and blow down cement line,kill line,choke line and prep for N/D stack for setting Emergency Slips.Remove fluid from BOPE stack. 01:30 03:00 1.50 3.00 DRILL C 20 P PJSA Perform N/D BOPE stack. 03:00 07:00 4.00 7.00 DRILL C 20 P PJSA Vetco Grey Rep onsite,Set 9 5/8"Csg.in tension W/100K over string weight&perform setting Emergency Slips in Multi Bowl,Cut 9 5/8"Csg.L/D landing joint and cut 9 5/8"Csg.Remove modified Wear Ring&install 9 5/8"Csg.Pack Off Assy.Test to 2,472 PSI for 10 Min.Witnessed by driller.(Good) 07:00 08:30 1.50 8.50 DRILL C 20 P PJSA Perform N/U BOPE.SIMOPS begin Freeze Protect W/Little Red Services on the 9 5/8"X 13 3/8"Annulus. 08:30 10:00 1.50 10.00 DRILL C 5 P PJSA Change out 9 5/8"Csg.Rams to variable 3.5"X 6"Rams.SIMOPS Freeze Protect well. 10:00 11:00 1.00 11.00 DRILL C 9 P PJSA Freezr Protect W/Little Red Services in the 9 5/8"X 13 3/8"Annulus.08:50 1.5 bpm 400 PSI.09:16 1.5 bpm 40 bbls away 800 PSI,09:56 1.5 bpm 100 bbl away 900 PSI,10:45 1.5 bpm 184 bbl away 1000 PSI.Final OA 300 PSI. 11:00 12:00 1.00 12.00 DRILL E 20 P PJSA Service Top Drive.Drawvwrks and Traveling Equip. 12:00 14:00 2.00 14.00 DRILL E 20 P PJSA C/O TT 525 Saver Sub and Shot Pin Assy.on Top Drive. 14:00 14:30 0.50 14.50 DRILL E 20 P PJSA R/U to P/U 4.5"D.P.from Pipe Shed with Mouse Hole. 14.30 00:00 9.50 24.00 DRILL E 20 P PJSA P/U M/U 265 joints 4.5"D.P.from Pipe Shed with Mouse Hole and stand back in Derrick.Take on 700 bbls of new 9.45 ppg Faze Pro from Mud Plaant W/a 53 Vis. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv - °907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com :907-685-0722 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Alex Dunlop 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 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 f I Eni E&P Division I Well Name:SP22-FN1 OR EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUQ • Date:211312013 - Report#: 21 APIIUWI:50-629-23478-00-00 2" r'[I page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) .RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 18.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,140.0 3,707.2 0.00 108.0 -23.0 Partly Cloudy WC- ENE @ 10 MPH 45" Daily summary operation 24h Summary P/U M/U 4.5"D.P.from Pipe Shed and rack back in Derrick.Load Pipe Shed W/BHA#5 tools.Service rig.Test BOPE as per AOGCC,test waived witness by Louis Grimaldi 2-12-13 09:28 am.Perform rig tasked while loading software in MWD tools.P/U M/U BHA#5 as per Schlumberger DD and MWD Rep onsite.RIH BHA#5 on 4.5"D.P.to 559'MD. Operation at 07.00 TIH©4,633'MD 24h Forecast RIH F/559'to-12,036'MD F.C.Circ.LSND BU and test 9 5/8"Csg.to 3,000 PSI for 30 Min.Displace LSND W/new 9.4 ppg Faze Pro as per MI Swaco plan forward.Drill out F.C.and Shoe track,drill 20'new hole to 12,160'MD.Perform 13.0 ppg FIT or LOT as per AOGCC.Clean surface Equip.of LSND.Drill ahead as per Schlumberger DD and K&M drilling procedure. Lithology Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 9.40 Time Log - Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02.30 2.50 2.50 DRILL E 20 P PJSA P/U M/U 4.5"D.P.from Pipe Shed and rack back in Derrick,full @ 115 Stands of 4.5"D.P.Left 18 joints in shed to pick up after BHA#5. 02:30 03:00 0.50 3.00 DRILL E 20 P PJSA Lubricate Top Drive,Drawworks and Travel Equip. 03:00 04:00 1.00 4.00 DRILL E 20 P PJSA Clean and clear rig floor of 4.5"D.P.handling Equip. 04:00 05:30 1.50 5.50 DRILL C 12 P PJSM on testing BOPE and R/U test Equip.Set test plug as per Vetco Rep onsite. • 05:30 12:00 6.50 12.00 DRILL C 12 P PJSA BOPE test waived witness by Louis Girmaldi on 2-12-13 09:28 AM.Test BOPE as per AOGCC.Test Annular Bag 250/2,500 PSI low&high for 5 Min.All remaining testing at 250/3,500 PSI low and high for 5 Min.Test Choke Manifold valves#1-18.Test Upper&Lower IBOB,test 5"525 Dart&TIW,test 4.5"NC-46 Dart&TIW,with 5"test joint.Perform Koomey draw down,start Press.3,000 PSi 200 PSI increase 42 Sec.Full system charge in 210 Sec.=2,975 PSI.5 reserve Nitrogen bottles=2,400 PSI average Press.Test Blind Rams 250-3,500 PSI low&high.Change out 5"test joint to 4.5"test joint and re-test Annular Bag 250/2,500 PSI for 5 Min.Tets upper and lower Pipe Rams 250-3,500 PSI low and high. 12:00 14:30 2.50 14.50 DRILL C 12 P PJSA Test Annular Preventer W/5.5"test joint 250-2,500 PSI low&high.Test upper 3.5"X 6"Variable Ram&lower 4.5" X 7"W/5.5"test joint to 250/3,500 PSI low&high.Test A&B Manual Choke&Super Choke to 1,500 PSI.Volume test Poor Boy.Blow down&R/D test Equip.SIMOPS load BHA#5 in Pipe Shed. 14:30 15:30 1.00 15.50 DRILL C 20 P PJSA Pull test plug and set Wear Ring as per Vetco Grey Rep onsite. 15:30 16:30 1.00 16.50 DRILL E 20 P PJSA Load floor of BHA#5 Equip. 16:30 19:00 2.50 19.00 DRILL E 20 'P PJSA CIO hoses on Skate,adjust Kelly hose,wrap hose protector on Kelly hose.Weld hand rail on stairs on roof of rig Clean Centrifuge,weld in safety hand holes on BOP drip pan around high Press.user.SIMOPS Schlumberger MWD upload software into tools. 19:00 20.30 1.50 20.50 DRILL E 20 P PJSA Cut and slip drilling line,adjust brakes and brake band rollers.Adjust hook load cell. 20:30 23:30 3.00 23.50 DRILL E 20 P PJSA P/U M/U BHA#5 as per Sclumberger DD&MWD.Load nuclear sources as per Schlumberger MWD Rep onsite. Make all call to Rig Crew and ENI Security. 23:30 00:00 0.50 24.00 DRILL E 4 P PJSA RIH BHA#5 on 4.5"D.P.to 559'MD HST 95K,SLK 95K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv, 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyon15 @enipetroleum.com 907-685-0722 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 Eni E&P Division Report e If,* y a I We11 Name:SP22-FN1 OR Dil Rp ENI Petroleum Co.Inc. Well code:SP22 Field Name:NIKAITCHUQ •" Date:2/14/2013 - Report#: 22 APIIUIM:50-629-23478-00-00 2" page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DES(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 19.00 Daily Information End Depth(ttKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,160.0 3,714.9 20.001 0.01 2,000.0 110.0 -15.0 Overcast WC-38° ENE @ 15 MPH Daily summary operation 24h Summary Cont.to single in W/BHA#5 F/559'to 844'MD.RIH on elevators Fl 844'to 1,697'MD and perform shallow hole test as per Schlumberger MWD.(Good)RIH F/1,697'to 8,030'MD.Filling every 20 stands.Circ.BU and add lubricant to LSND due to high friction.RIH on elevators F/8,030'to 10,139'MD HST 190K,SLK 75K.filling every 20 stands RIH.Wash to bottom F/10,139'to 11,941'MD due to friction and drag,50 RPM,200 GPM,430 PSI,TRQ 15K,ROT 143K.Circ.BU and perform 9 5/8"Csg.test W/3.000 PSI for 30 Min.Displace LSND W/9.45 ppg Faze Pro as per MI Swaco plan forward. CBU and prepare for FIT or LOT. Operation at 07.00 Drill ahead 8.75"hole @ 12,328'MD 24h Forecast Perform FIT to 13 ppg EMW.Drill ahead as per multi lateral plan to 23,383'MD. Lithology Shows MAASP Pressure(psi) 'Mud Weight(1b/gall 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00.30 0.50 0.50 DRILL E 4 P PJSA Single in hole WI 4.5"D.P.W/BHA#5 F/559'W 884'MD. 00:30 01:30 1.00 1.50 DRILL E 4 P 'RIH on elevators with stands from the Derreck F/884'to 1,697'MD. 01:30 02:00 0.50 2.00 DRILL E 7 P Fill pipe,Shallow test MWD @ 400 GPM,600 PSI.(Good) 02:00 07:00 5.00 7.00 DRILL E 4 P RIH on elevators F/1,697'to 8,030'MD,filling pipe every 20 stands.SIMOPS load Pipe Shed with 4.5"linear. 07:00 09.00 2.00 9.00 DRILL E '7 P Circ.bottoms up while adding lubricant to mud to help break friction.Pump rate 280 GPM.670 PSI,HST 190K,SLK 75K. 09:00 10:00 1.00 10.00 DRILL E 4 P 'RIH on elevators F/8.030'to 10,139'MD,HST 190 K,SLK 75K.Filling every 20 stands while RIH. 10:00 12.00 2.00 12.00 DRILL E 4 P PJSA Wash F/10,139'to 10,328'MD due to weight tranfer.Flow rate 170 GPM,430 PSI,50 RPM,TRO 15K,ROT 140K. '12:00 1430 2.50 14.50 DRILL E 4 P PJSA Wash downF/10,328'to 11,941'MD 210 GPM,630 PSI,50 RPM,TRQ 21K,ROT 143K. 14:30 15:30 1.00 15.50 DRILL E .7 P PJSA Circ.BU as per detail,550 GPM,2,520 PSI,blow down Top Drive. 15:30 17.00 1.50 17.00 DRILL E 12 P PJSA R/U test Equip.PT lines to 3.800 PSI.Test 9 5/8"Csg.to 3,000 PSI for 30 Min.Test witnessed by CO Rep.R/D test Equip. 17:00 19.30 2.50 19.50 DRILL E 7 P PJSA P/U a stand and wash to 12,032'MD.Displace LSND W/9.45 ppg Faze Pro W/50 bbl Hi Vis spacer @ 5 bpm,480 PSI,pump 50 bbl LVT spacer @ 5 bpm.630 PSI.801 bbl Faze Pro @ 13 bpm,2,250 PSI,50 RPM.TRQ 9K,ROT 142K. 19:30 20:30 1.00 20.50 DRILL E 7 P PJSA Clean surface Equip.in pits and drip pan due to LSND and interface. • 20:30 23.00 2.50 23.00 DRILL E 3 P PJSA Take SPR's,drill out F.C.and Shoes track plus 20'of new hole.Tag F.C.@ 12,036'MD,Shoe @ 21,122'MD.Tag bottom @ 21,140'MD drill out to 12.160'MD,440 GPM.2,370 PSI,50-80 RPM.TRQ 14K,HST 175K.SLK 108K,ROT 138K,MW 9.4 ppg,ECD 10.69 ppg.Take survey as per Schlumberger DD. SPR @ 12,029'MD(3,700'TVD)W/9.4 ppg MW MP#1 30-290,40-460 MP#2 30-290,40-460 MP#3 30-290,40-460 • 23:00 00:00 1.00' 24.00 DRILL E 8 P PJSA Circ.BU while pulling into 9 5/8"Csg.@ 12,122'MD 540 GPM,3,300 PSI,70 RPM,TRQ 10K,HST 172K,SLK 110K,ROT 138K. Daily Contacts Position Contact Name Company Title E-mail Office ' Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 - Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyon15 @enipetroleum.com 907-685-0722 Eni representative Pete Adams ENI HSE 907-685-0721 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dnlling Tour Pusher rig15 @doyondnlling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) L Run Date CASING 95/8 8.835 L-80 -3.4 12,122.012/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 3,082.0 2,433.84 LSND 9.30 470.0 13.02 1,645.8 ffi* Eni E&P Division (Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUQ • Date:2/15/2013 - Report#: 23 APIIUWI:50-629-23478-00-00 ei� page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° !Operator ENI Share(%) !Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) !RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(/1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 20.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) !POB Temperature(°F) Weather Wind 13,988.0 3,761.2 1.828.00 12.80 142.8 101.0 -15.0 Overcast WC-27° NE @ 5 MPH Daily summary operation 24h Summary Circ.hole clean and have balanced 9.4 ppg Faze Pro in and out.Shut down and R/U test Equip,perform FIT to 13.0 ppg EMW.R/D test Equip.Drill ahead 8 3/4"multi lateral F/12,160'to 13,988'MD (3,733'TVD)for the first plug back.Max Gas 1,145 units.No losses to formation. Operation at 07.00 Drill ahead 8 3/4"multi lateral @ 14,450'MD 24h Forecast Drill 8 3/4"multi lateral as per well plan F/13,988'to 14,550'MD for first plug back.Back ream as per K&M BROOH schedule to 13,280'MD.Drill ahead F/13,280'to-16,738'MD of plug back#2. 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 00:30 0.50 0.50 DRILL E 7 P PJSA Circulate&reciprocate hole clean&balance mud WT.9.4 ppg,540 GPM,3,320 PSI,70 RPM,TRQ 10K,HST 178K, SLK 112K,ROT 138K. 00:30 01:00 0.50 1.00 DRILL E 12 P PJSA R/U test Equip.for FIT of LOT. 01:00 02:00 1.00 2.00 DRILL E 12 'P PJSA Perform FIT as per well plan.Pumped 2.8 bbl Faze Pro @ 5 SPM,Shut in @ 699 PSI for 25 Min.Start Press.699 PSI end Press.610 PSI after 25 Min.EMW 13.0 ppg W/9.4 ppg MW.R/D test Equip. 02:00 06:00 4.00 6.00 DRILL E 3 P PJSA Drill 8 3/4"F/12,160'to 12,617'MD(3,732'TVD)as per SLB DD and K&M drilling parameters.550 GPM,3,320 PSI, 130 RPM,TRN 13-20K,TQF 10K,WOB 10-12K,HST 210K,SLK 112K,ROT 138K.ECD 11.3 ppg W/9.4 ppg MW.Max Gas 727 units.ADT 2.32 Hrs,Bit Hrs 2.32,Jar Hrs 2.32. 06:00 12.00 ' 6.00 12.00 DRILL E 3 P PJSA Drill 8 3/4"F/12,617'to 12,967'MD(3,746'TVD)as per SLB DD and K&M drilling parameters.545 GPM,3,450 PSI, 130 RPM,TRN 13-20K,TQF 10K,WOB 10K,HST 186K,SLK 75K,ROT 148K.ECD 11.2 ppg W/9.4 ppg MW.Max Gas 1000 units.ADT 3.05 Hrs.Bit Hrs 5.37,Jar Hrs 5.37. SPR @ 12,871'MD(3,744'MD)W/9.4 ppg MW. MP#1 30-340,40-440 MP#2 30-340,40-440 MP#3 30-340,40-440 12:00 18:00 ' 6.00 18.00 DRILL E 3 P PJSA Drill 8 3/4"F/12,967'to 13,520'MD(3,740'TVD)as per SLB DD and K&M drilling parameters.550 GPM,3.380 PSI. 140 RPM.TRN 16K,TQF 11K,WOB 2-14K,HST 200K,SLK n/a,ROT 145K.ECD 11.32 ppg W/9.4 ppg MW.Max Gas 1145 units.ADT 4.19 Hrs.Bit Hrs 9.56,Jar Hrs 9.56. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8 3/4"F/13,520'to 13,988'MD(3,733'TVD)as per SLB DD and K&M dolling parameters.550 GPM,3.420 PSI, 140 RPM.TRN 15K,TQF 12K,WOB 2-14K,HST 204K,SLK n/a,ROT 145K.ECD 11.23 ppg W/9.4 ppg MW.Max Gas 923 units.ADT 3.24 Hrs,Bit Hrs 12.80,Jar Hrs 12.80. SPR @ 13,804'MD(3,731'MD)W/9.4 ppg MW. MP#1 30-300,40-430 MP#2 30-310,40-440 MP#3 30-310,40420 Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv .SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon 15 @ enipetroleum.com 907-685-0722 Eni representative Pete Adams ENI HSE 907-685-0721 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12.122.0 2/10/2013 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) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 Eni E&P Division 'Well Name:SP22-FNi OR 05* ENI Petroleum Co.Inc. Daily Repo.,+L Well Code:26945 Field Name: NIKAITCHUQ • Date:2/16/2013 - Report#: 24 API/UWI:50 629-23478-00-00• en page 1 of 1 Wellbore name SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 21.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) I Avg ROP(ft/hr) I POB Temperature(°F) Weather 'Wind 13,988.0 3,761.2 0.00 101.0 -16.0 Overcast WC-32° NE @ 7 MPH Daily summary operation 24h Summary Drill ahead F/13,988'to 14,550'MD as per K&M and Schlumberger DO for Plug back#1.Circ.hole clean and BROOH as per K&M BROOH schedule to 13,150'MD.Wash down to 13,337'MD taking data ponts and uploading data from Schlumberger MWD.Start side track F/13,280'to kick of point @ 13,300'MD.Drill ahead as per K&M and Schlumberger DD F/13,300'to 14,614'MD. Operation at 07.00 Drill ahead 8 3/4"multi lateral @ 15,205'MD 24h Forecast Drill ahead Plug Back#2 as per K&M and Schlumberger DD F/14,614'MD to—16,738'MD. 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 05:00 5.00 5.00 DRILL E 3 P PJSA Drill 8 3/4"plug back#1 as per K&M&Schlumberger DD F/13,988'to 14,550'MD(3,728'TVD)545 GPM,3,360 PSI,140 RPM,TQN 10-20K,TQF 11K,WOB 8-12K,HST 210K,SLK 71K,ROT 150K.ECD 11.2 ppg W/9.4 ppg MW.Max Gas 940 units.ADT 3.7 Hrs,Bit Hrs 16.50,Jar Hrs 16.50. 05:00 10:00 ' 5.00 10.00 DRILL E 6 P PJSA Circ.hole clean while back reaming F/14,550'to 13,150'MD as per K&M BROOH schedule.Rack back first stand once half bottoms up had been completed.Continue to back ream @ 10 Min.per stand for 3 stands.550 GPM,3,340 PSI, 140 RPM,TRQ 15-16K,ROT 135K.Observe well(Static) 10:00 11:30 1.50' 11.50 DRILL E 6 P Wash down F/13.150'to 13,337'MD @ 400 GPM,2,800 PSI,50 RPM.TRQ 15K.Obtain MWD data while circulating @ 13,337'MD come up to 13,322',13,307',13,292',13,277'&13,247'MD.Set depth and continue to upload data for MWD @ 540 GPM,3,200 PSI,120 RPM&TRQ 12-13K. 11:30 12:00 0.50 12.00 DRILL E 3 P Start side track @ 13,280'10 13,287'MD(3,752'TVD)545 GPM,3,250 PSI,120 RPM,TRN 14K,WOB 2 K,HST 210K, SLK 72K,ROT 150K.ECD 11.2 ppg W/9.4 ppg MW.Max Gas 940 units.ADT 015 Hrs,Bit Hrs 16.55,Jar Hrs 16.65, 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill side track F/13,287'to kick of point @ 13,300'MD(3,751'TVD)470 GPM,2,4700 PSI,120 RPM,TON 14K, WOB 2-4K.Establish drilling rates and drill ahead to 13,897'MD(3,752'TVD)540 GPM,3,380 PSI,140 RPM,TON 15K, TQF 10K, HST 195K,SLK 71K,ROT 145K.Max Gas 1,092 units.ADT 4.1 Hrs,Bit Hrs 20.75,Jar Hrs 20.75. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8 3/4"plug back#2 as per K&M&Schlumberger DD F/13,897'to 14,614'MD(3.746'TVD)540 GPM,3.450 PSI,140 RPM,TQN 16K,TQF 11K.WOB 2-10K,HST 205K,SLK 71K,ROT 145K.ECD 11.2 ppg W/9.4 ppg MW.Max Gas 1,183 units.ADT 3.7 Hrs,Bit Hrs 16.50,Jar Hrs 16.50. SPR @ 14,551'(3,747'TVD)W/9.4 ppg MW MP#1 30-310,40-490 MP#2 30-310,40-510 MP#3 30-310,40-510 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl5 @enipetroleum.com 907-685-0722 Eni representative Pete Adams ENI HSE 907-685-0721 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 1 Eni E&P Division I Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • Date:2/17/2013 - Report#: 25 APIIUWI:50-629-23478-00-00 2'r rr page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM I 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53 B0 13.08 36.85 33.50 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..4 Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 28,469.00 175,50 162.2 22.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 14,942.0 3,745,7 1.808.00 8.45 214.0 104.0 -38.0 Clear WC-66' SW @ 13 MPH Daily summary operation 24h Summary Drill ahead 8 3/4"plug back#2 F/14,614'to 16,360'MD(3,723'TVD)as per K&M,Sclumberger DD and well plan.BROOH as per K&M BROOH schedule F/16,360'to 14,741'MD.Lost 39 bbl during back reaming to formation.Wash and ream F/14,741'to 14,880'MD and start kick off point.Drill 8 3/4"plug back#3 F/14,880'to 14,942'MD(3,745'TVD).No losses during drilling plug back#3. Operation at 07.00 Drill ahead 8 3/4"plug back#3 @ 15,306'MD. 24h Forecast Cont.drilling 8 3/4"plug back#3 as per K&M and Schlumberger DD as per well plan.F/14,942'to 19,306'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8 3/4"Plug Back#2 as per K&M&Schlumberger DD F/14.614'to 15,453'MD(3,734 TVD)545 GPM,3.450 PSI,140 RPM,TQN 15-17K,TQF 11K,WOB 8-12K,HST 208K,SLK 72K,ROT 150K.ECD 11.2 ppg W/9.4 ppg MW.ADT 2.79 Hrs,Bit Hrs 26.39,Jar Hrs 26.39. SPR @ 15,298'MD(3,739'MD)W/9.4 ppg MW. MP#1 30-340,40-500 MP#2 30-330,40-490 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8 3/4"Plug Back#2 as per K&M&Schlumberger DD F/15,453'to 16,048'MD(3,728 TVD)500 GPM,3,150 PSI,140 RPM,TON 15-17K,TQF 11K,WOB 8-12K,HST 208K,SLK 72K,ROT 150K.ECD 11.5 ppg W/9.4 ppg MW.Max Gas 1.613 units.ADT 2.11 Hrs,Bit Hrs 28.50,Jar Hrs 28.50. 12:00 1500 3.00 15.00 DRILL E 3 P PJSA Drill 8 3/4"Plug Back#2 as per K&M 8 Schlumberger DD F/16.048'to 16,360'MD(3,723 TVD)540 GPM,3.530 PSI,140 RPM,TQN 17K,TQF 12K,WOB 2K,HST 218K,SLK 72K,ROT 147K.ECD 11.58 ppg W/9.5 ppg MW.Max Gas 1.400 units.ADT 2.53 Hrs.Bit Hrs 31.03,Jar Hrs 31.03. SPR @ 16,360'MD(3,723'TVD)W/9.4 ppg MW. MP#1 30-350,40-470 MP#3 30-350,40-480 15:00 18:00 3.00 18.00 DRILL E 6 P PJSA Monitor well for 10 Min,static.Establish BROOH rates @ 550 GPM,3,530 PSI,140 RPM,15K TRQ.BROOH as per K&M BROOH schedule,Circ.1/2 BU@ 550 GPM,120-140 RPM while racking back 1 stand.BROOH 4 stands @ 10 Min. per stand.Stage up to 5-6 Min.per stand until 1 stand above kick off point.F/16,360'to 15,859'MD monitor well for 10 Min.HST 190K.ROT 140K. 18:00 21:00 3.00 21.00 DRILL E '6 P PJSA BROOH as per K&M BROOH schedule F/15,859'to 14,741'MD,550 GPM,3,400 PSI,140 RPM.TRQ 15K. Calculated displacement 13 bbl.actual displacement 52 bbl.Lost 39 bbl to formation during BROOH.Max Gas 450 units. 21:00 00:00 3.00 24.00 DRILL E 3 P 'PJSA P/U one stand from Derreck and establish drilling rates,wash and ream F/14,741'to 14,880'MD and start kick off, 550 GPM,3,400 PSI,140 RPM,TRQ 14K.Begin kick off @ 14,880'MD as per Sclumberger DD @ 475 GPM,2,700 PSI, 160 RPM,TRQ 16K.Cont.drilling ahead to 14,942'MD(3,745'TVD)475 GPM,2,700 PSI,160 RPM,HST 190K,SLK 72K, ROT 140K,WOB 2K,TRN 15K,TRF 15K.Max Gas 120 units.ECD 10.9 ppg W/9.4 ppg MW.ADT 1.02 Hrs,Bit Hrs 32.05, Jsr Hrs 32.05.No dynamic losses seen during drilling. Daily Contacts _ Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Pete Adams ENI HSE 907-685-0721 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling 'Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 ' Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2.500.6 fI Eni E&P Division [Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • Date:2/18/2013 - Report#: 26 API/UWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1PB1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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..J Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB1 DRILLING 1/27/2013 23,383.0 I 28,469.00 175.50 162.2 23.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 17,726.0 3,732.2 2.784.00 11.33 245.7 107.0 -45.0 Overcast WC-67° W @ 7 MPH Daily summary operation 24h Summary Drill ahead as per K&M and Schlumberger DD 8 3/4" Plug Back#3 F/14,942'to 17,726'MD.No losses to formation.Adding water for Rheology due to oil/water ratio. Operation at 07.00 Drill ahead 8 3/4"plug back#3 @ 18,099'MD. 24h Forecast Cont.drilling 8 3/4"plug back#3 as per K&M and Schlumberger DD as per well plan.F/17,726'to 19,306'MD. Lithology 'Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill ahead 8 3/4"Plug Back#3 as per K&M and Schlumberger DD F/14,942'to 15,643'MD(3,745'ND)545 GPM, 3.650 PSI,140 RPM,TQN 15-17K,TQF 11K.WOB 8-12K,HST 200K,SLK 72K,ROT 150K.ECD 11.3 ppg W/9.4 ppg MW.ADT 2.69 Hrs.Bit Hrs 34.74,Jar Hrs 34.74. 0600 12:00 6.00 12.00 DRILL E 3 P PJSA Drill ahead 8 3/4"Plug Back#3 as per K&M and Schlumberger DD F/15,643'to 16,426'MD(3,737'ND)530 GPM. 3.490 PSI,140 RPM,TQN 15-17K,TQF 11K.WOB 8-12K,HST 203K,SLK 72K,ROT 150K.ECD 11.5 ppg W/9.4 ppg MW.Max Gas 1,654 units.ADT 3.37 Hrs,Bit Hrs 38.11.Jar Hrs 38.11.No losses to formation.Running water for Rheology due to oiVwater ratio. SPR @ 16,138'MD(3,737'TVD)W/9.4 ppg MW MP#1 30-330,40-480 MP#2 30-330,40-480 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill ahead 8 3/4"Plug Back#3 as per K&M and Schlumberger DD F/16,326'to 17,165'MD(3,735'TVD)525 GPM, 3.470 PSI,140 RPM,TQN 17K,TQF 12K,WOB 2-10K.HST 210K.SLK 72K,ROT 149K.ECD 11.62 ppg W/9.4 ppg MW.Max Gas 1,516 units.ADT 2.78 Hrs,Bit Hrs 40.89,Jar Hrs 40.89. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill ahead 8 3/4"Plug Back#3 as per K&M and Schlumberger DD F/17,165'to 17,726'MD(3,733'TVD)525 GPM, 3,580 PSI,140 RPM,TQN 16K,TQF 12K,WOB 2-10,HST 212K,SLK 72K,ROT 149K.ECD 11.8 ppg W/9.4 ppg MW. Max Gas 1,432 units.ADT 2.49 Hrs,Bit Hrs 43.38,Jar Hrs 43.38.No losses to formation, SPR @ 17,165'MD(3,735'TVD)W/9.4 ppg MW MP#1 30-380,40-510 MP#2 30-390,40-510 MP#3 30-380,40-490 Daily Contacts Position Contact Name _ Company Title Email Office - Mobile• • Drilling Supt. James Wright ENI Drilling Superintend Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9,40 693.0 13.00 2,500.6 • Eni E&P Division (Well Name: SP22-FN1 OR fflAiiil ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • 2^n Date:2/19/2013 - Report#: 27 API/UWI:50-629-23478-00-00 'I l)ii page 1 of 1 Wellbore name: SP22-FN1 PB3 Well Header PermitiConcession N° Operator ENI Share)%) Well Configuration type 212-162 _ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB3 DRILLING 1/27/2013 23,383.0 28469.00 175.50 162.2 24.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 19,306.0 3,734.6 1.580.00 12.03 131.3 111.0 -30.0 Clear WC-60' NE @ 18 MPH Daily summary operation 24h Summary Ddg.Plug Back#3 f/17,726'-19,306'MD(3735'TVD)Plug Back#3 TD Operation 0107.00 BROOH @ 17,916'MD 24h Forecast BROOH to 17,847'.RIH to 17.940'and perform open hole kick off and ddg.Leg#4. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg.Plug Back#3 f/17,726'-18,142'MD(3737'TVD)@ 524 gpm,3650 psi,140 rpm,8-12k wob,15-17k tq on.11k tq off,210k puw,72k sow,150k rotw,11.5 ECD,4.52 ADT,47.90 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg.Plug Back#3 f/18,142'-18,660'MD(3737'TVD)@ 524 gpm,3750 psi,140 rpm,8-12k wob,15-20k tq on,11- 12k tq off,220k puw,72k sow,146k rotw,Max Gas 1655,12.0 ECD,2.38 ADT,50.28 Bit/Jars.SPR's @ 18,193'MD (3717'TVD)w/9.4 ppg MW. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg.Plug Back#3 f/18,660'-19,127'MD(3723'TVD)@ 510 gpm,3700 psi,140 rpm,4-11k wob,18k tq on,12k tq off,225k puw,sow-N/A,145k rotw,Max Gas 1800,12.36 ECD,2.19 ADT,52.47 Bit/Jars. 18.00 2130 3.50 21.50 DRILL E 3 P PJSA Ddg.Plug Back#3 to TD of 19.306'(3735'TVD)@ 510 gpm,3640 psi,140 rpm,2-8k wob.18k tq on,13k tq off,22 puw,sow-N/A,145k rotw,Max Gas 440,12.23 ECD,2.94 ADT,55.41 Bib Jars.Note:@ 19,033'MD crossed fault and went out of OA sands.Observed 20 bbl loss. 21:30 22:30 1.00 22.50 DRILL E 7 P @ 19.306'MD set MWD and tool parameters.Monitor well f/15 min. 22:30 00:00 1.50 24.00 DRILL E 4 P BROOH f/19,306'-19,223'MD @ 500 gpm,3600 psi,140 rpm,16k tq.35 bbls,total losses for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. James Wright ENI Drilling Superintend Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyon15 @ enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Chad Johnson Doyon Dulling Tool Pusher dg15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) TVD(11KB) Fluid Type 'Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 ft* Eni E&P Division I Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO •" Date:2/20/2013 - Report#: 28 API/UWI:50-629-23478-00-00 2" page 1 of 1 Wellbore name: SP22-FN1PB4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth 01KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB4 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 25.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 19,750.0 11 466.4 1.800.00 10.99 163.8 112.0 -29.0 Mostly Cloudy,WC- ENE @ 19 MPH 57- Daily summary operation 24h Summary Ddg.Plug Back#4 5 17,950'-19,750'MD. Operation at 07.00 Ddg.Plug Back#4 @ 20.245'MD. 24h Forecast Cont.drilling PB#4 to TD of 21,801'.Perform cleanup cycle and BROOH to 100'above PB 10. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(1b/gall II 9.40 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 BROOH f/19,223'-17,822'@ 500 gpm.3690 psi,132k rotw,15-18k tq. 03:30 04:00 0.50 4.00 DRILL E 4 P Wash down to 17,950'@ 400 gpm,2200 psi,100 rpm,15k tq,138k rotw. 04.00 0600 2.00 6.00 DRILL E 3 P Start side track of Plug Back#4 @ 17,950'-18,023'MD(3726'TVD)525 gpm,3690 psi,140 rpm,1-3k wob,200k puw, 72k sow,132k rotw,15-17k tq on,10-12k tq off,11.9 ECD,1.36 ADT,56.77 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill Plug Back#4 to 18,752'MD(3731'ND)@ 525 gpm,3690 psi,140 rpm,8-12k wob,17-19k tq on,11-13k tq off,199k puw,72k sow,138k rotw,Max Gas 1684,12.2 ECD,2.91 ADT,59.68 Bit/Jars. 12:00 18:00 ' 6.00 18.00 DRILL E 3 P PJSA Dig.Plug Back#4 f/18,752'-19,290'MD(3746'ND)@ 510 gpm,3610 psi,140 rpm,2-14k wob,220k puw,sow- NA,143k rotw,19-21k tq on,13k tq off,Max Gas 1600,12.17 ECD,4.29 ADT,64.46 Bit/Jars. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSA Ddg.f/19,290'-19,750'MD(3740'ND)@ 510 gpm,3750 psi,140 rpm,2-18k wob,18-19k tq on,13k tq off,215k puw,sow-NA,143k rotw,Max Gas 1400,12.27 ECD,2.43 ADT,66.89 Bit/Jars,20 bbl total fluid loss for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. James Wright ENI Dulling Superintend Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15 @doyondnlling.com 907-685-0716 Eni representative Davide Simeone ENI Drilling Manager Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(f1KB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2.500.6 Eni E&P Division I Well Name:SP22-FN1 OR - PI* ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ ii• Date:2/21/2013 - Report#: 29 API/UWI:50-629-23478-00-00 2" page 1 of 1 Wellbore name: SP22-FN1 PB4 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1PB4 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 26.00 Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,555.0 11,480.7 1.805.00 11.01 163.9 108.0 -27.0 Mostly Cloudy,WC- ENE @ 19 MPH 62' Daily summary operation 24h Summary Drilling PB#4 f/19,750'-21,555'MD. Operation at 07.00 DrIg.Plug Back#4 @ 21,635'MD. 24h Forecast Complete drilling PB#4 to 21.801',perform cleanup cycle and BROOH to 117,850'.Setup for open hole sidetrack as per SLB. 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 PJSA Ddg.Plug Back#4 f/19,750'-20,434'MD(3726'TVD)@ 512 gpm,3690 psi,140 rpm.6-12k wob,15-17k tq on,10- 12k tq off,215k puw,72k sow,144k rotes.12.3 ECD,3.29 ADT,70.18 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Dig f/20,434'-20,899'MD(3735'ND)@ 512 gpm,3790 psi,140 rpm,6-12k wob,18-20k tq on,13-14k tq off, 215k puw,72k sow,141k rotw,Max Gas 1934,12.4 ECD,2.7 ADT,72.88 Bit/Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg 5 20,899'-21,292'MD(3741'TVD)@ 500 gpm,3760 psi,140 rpm,2-14k wob,19-20k tq on,15k tq off,228k puw,sow-NA,140k rotw,Max Gas 1800,12.48 ECD,2.63 ADT,75.51 Bit/Jars. 18:00 0000 6.00 24.00 DRILL E 3 P PJSA DrIg.f/21.292'-21,555'MD(3735'TVD)@ 512 gpm,3790 psi,140 rpm,2-14k wob,18-22k tq on,14-15k tq off, 215k puw,72k sow,141k rotw,Max Gas 1934,12.2 ECD,2.39 ADT,77.90 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Eni representative Davide Simeone ENI Dulling Manager Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) !ND(ftKB) Fluid Type !Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.401 693.0 13.00 2,500.6 if* Eni E&P Division ,} I Well Name:SP22-FNI OR ENI Petroleum Co.Inc. Daily Repo Well Code:26945 Field Name:NIKAITCHUQ • Date:2/22/2013 - Report#: 30 APIIUWI:50-629-23478-00-00 • 2" " page 1 of 1 Wellbore name: SP22-FN1 (P10) • Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) IDFS(days) SP22-FN1(P10) DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 27.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21.800.0 11 486.3 759.00 11.58 65.5 103.0 -30.0 Cloudy,Blowing NE @ 30 MPH Snow,WC-68' Daily summary operation 24h Summary Complete PB#4 @ 21.800'.BROOH to 20,157'and drill f/20,200'-20,714'MD. Operation at 07.00 Ddg.ahead in 8.75"production hole @ 21,087'MD. 24h Forecast Complete final drilling in P10 to 23,383'MD. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 07:30 7.50 7.50 DRILL E 3 P PJSA Complete PB#4.Ddg.f/21,555'-21,800'MD(3760'TVD)@ 500 gpm,3690 psi,140 rpm.6-20k wob,18-22k tq on, 14-16k tq off,215k puw,72k sow,141k rotw,Max Gas 1850,12.3 ECD,4.61 ADT,80.12 Bit/Jars. 07:30 13:00 5.50 13.00 DRILL E 4 P PJSA Monitor well for 10 min:breathing.SPR's taken.BROOH f/21,800'-20,157'MD @ 500 gpm,3600 psi,140 rpm,18k tq. 13:00 15:00 2.00 15.00 DRILL E 3 P RIH to 20,198'MD and set side track drilling @ 510 gpm,3680 psi,160 rpm and trough to 20,240'MD. 15:00 18:00 3.00 18.00 DRILL E 3 P PJSA Dig.If 20,240'-20,387'MD(3745'TVD)@ 510 gpm,3650 psi,140 rpm,2-14k wob,19k tq on,17k tq off,205k puw, sow-NA,143k rotw,Max Gas 1300,12.12 ECD,2.89 ADT,83.01 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Ddg.f/20.387'-20,714'MD(3745'TVD)@ 504 gpm,3670 psi,140 rpm,10-19k wob,19-22k tq on.15k tq off,210k puw,sow-NA,143k rotw,Max Gas 1940,12.14 ECD,4.08 ADT,87.10 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis,Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8,835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500,6 if* Eni E&P Division (Well Name:SP22-FN1 OR 1 ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ Date:2/23/2013 - Report#: 31 APIIUWI:50-629-23478-00-00 2" " page 1 of 1 Wellbore name: SP22-FN1 (P10) Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 ILAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1(P10) DRILLING 1/27/2013 I 23,383.0 28,469.00 175.50 162.2 28.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21.960.0 12,963.2 1.246.00 10.73 116,1 105.0 -24.0 Mostly Cloudy, NE @ 32 MPH Blowng Snow,WC- 61 Daily summary operation 24h Summary DrIg.f/20.714'-21,960'MD. Operation at 07.00 Drig.ahead 8.75"hole @ 22,280'MD. 24h Forecast Drig through fault area and up thru the N-Sands to est TD @ 23,383'. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.50 - Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00- 6.00 DRILL E 3 P PJSA Ddg.f/20.714'-21,182'MD(3752'TVD)@ 507 gpm.3800 psi,140 rpm,8-10k mob,18-20k tq on,17k tq off,208k puw,141k rotw,Max Gas 2014,12.15 ECD,1.75 ADT,88.85 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg 9 21,182'-21,462'MD(3765'TVD)@ 505 gpm,3800 psi,140 rpm,2-10k wob,19-20k tq on,17k tq off,210k puw,142k rotw,Max Gas 1800,12.32 ECD,2.56 ADT,91.41 Bit/Jars.20 bbl total fluid losses for tour. 12:00 18:00 6.00 18.00 DRILL 'E 3 P PJSA DrIg.f/21,462'-21,735'MD(3779'TVD)@ 500 gpm,3730 psi,140-160 rpm,2-20k wob.23k tq on,17k tq off,220k puw,143k rotw,Max Gas 1800,12.21 ECD,3.98 ADT,95.35 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drig.f/21,7735'-21,960'MD(3784'TVD)@ 500 gpm,3780 psi,140-160 rpm,2-20k wob,20k tq on,17k tq off, 220k puw,143k rotw,Max Gas 700,12.38 ECD,2.44 ADT,97.79 Bit/Jars,7 bbl total fluid losses for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv -SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(lb/gal) 'P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 I D Eni E&P Division 'Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • APIIUWI:50-629-23478-00-00 2^I"'o Date:2/24/2013 - Report#: 32 page 1 of 1 Wellbore name: SP22-FN1 (P10) Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date •Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) SP22-FN1(P10) DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.21 29.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22.923.0 12.592.4 963.00 7.23 133.2 113.0 -22.0 Mostly Cloudy, NE @ 26 MPH Blowing Snow,WC- 54' Daily summary operation 24h Summary Ddg.1/1,960'-22,923 MD TD.BROOH to 20,997'. Operation at 07.00 BROOH @ 19,788'MD. 24h Forecast BROOH as hole allows to 11,880'and CBU X 6.Monitor well.POOH on elevators. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 • Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg.f/21,960'-22,395'MD(3664'TVD)@ 502 gpm.3900 psi,140 rpm,14k wob 23k tq on,19k tq off,250k puw, 138k rotw,Max Gas 330,12.75 ECD,4.48 ADT,102.27 Bit/Jars. 06:00 13:00 7.00 13.00 DRILL E 3 P PJSA Ddg.f/22,395'-22,923'MD(3408'TVD)@ 500 gpm,3830 psi,140 rpm,2-10k web,24k tq on,17k tq off,230k ROW, 138k rotw,Max Gas 111,12.8 ECD,2.75 ADT,105.02 Bit/Jars. 13:00 14:00 1.00 14.00 DRILL E 19 P Monitor well.Breathing-58 bbl loss&14 bbl gain. 14:00 15:00 1.00 15.00 DRILL E 4 P Perform K&M cleanup cycle @ 450 gpm,3200 psi,140 rpm,18k tq,BROOH f/22,923-22,771'. 15:00 15:30 0.50 15.50 DRILL E 19 P Monitor well.Breathing 47 bbls. 1530 18:00 2.50 18.00 DRILL E 4 P BROOH f/22,771'-21,900'@ 350 gpm,2110 psi,120 rpm,18k tq. 18:00 19:30 1.50 19.50 DRILL E 7 -P Perform cleanup cycle @ 400 gpm,2100 psi,140 rpm.16k tq,reciprocate to 21,838'. 19:30 20:30 1.00 20.50 DRILL E 19 P Monitor well @ 21,900'.Breathing 24.5 bbls. 20:30 0000 3.50 24.00 DRILL E 4 P BROOH f/21,900'-20,997'@ 450 gpm,3200 psi,140 rpm,18-21k tq,195k puw,133k rotw.311 bbl total fluid losses for tour. Daily Contacts Position Contact Name ' Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv, SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(1b/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 Eni E&P Division I Well Name:SP22-FNt OR Itfl* ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO Date:2125/2013 - Report#: 33 API/l1WI:50-629-23478-00-00 2r' i H page 1 of 1 Welibore name: SP22-FN1 (P10) Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Welibore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..-Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1(P10) DRILLING 1/27/2013 23,383.0 28.469.00 175.50 162.2 30.00 Daily Information End Depth(f1KB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22.923.0 12,592.4 0.00 113.0 -15.0 Mostly Cloudy, E @ 30 MPH Blowing Snow WC- 46 Daily summary operation 24h Summary BROOH f/20,997'-12.221'. Operation at 07.00 CBU @ 11,874'MD. 24h Forecast Complete BROOH to 11,800'and CBU X 6 or until hole is clean.Monitor well and slip&cut dog.line.POOH on elevators and LD BHA. 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 06:00 6.00 6.00'DRILL 6 4 P PJSA BROOH f/20,997'-18.943'@ 450 gpm,3050 psi,120 rpm,17k tq,200k puw,143k rotw. 06:00 12:00 i 6.00' 12.00 DRILL E 4 P PJSA BROOH f/18,943'-16,983'@ 475 gpm,2950 psi,120 rpm,17k tq,185k puw,95k sow,140k rotw,30 bbls total fluid losses for tour. 12:00 18:00 ' 6.00 18.00'DRILL E 4 P PJSA BROOH f/16,983'-14.554'@ 450 gpm,2500 psi,120 rpm.12k tq.168k puw,115k sow,137k rotw. 18:00 00:00 6.00 24.00 DRILL E 4 P PJSA BROOH f/14,554'-12,221'@ 450 gpm,2450 psi,120 rpm,14k tq,18 bbls total fluid losses for tour. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Em representative Mike Ross ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Em representative Russ Wimmer ENI Dolling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(kKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 -3.4 12,122.0 2/10/2013 Last Leakoff Test Depth(RKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 Eni E&P Division Well Name:SP22-FN1 OR EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • API/UWI:50-629-23478-00-00 2 1119*o^ Date:2/26/2013 - Report#: 34 II II II page 1 of 1 Wellbore name: SP22-FN1 (P10) Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) I Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1(P10) DRILLING 1/27/2013 23,383.01 28,469.00 175.50 162.2 31.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,923.0 12,592.4 0.00 113.0 -16.0 Partly Cloudy.WC- NE @ 10 MPH 37, Daily summary operation 24h Summary BROOH to 11,941'.Circulate hole clean.Cut and slip drlg line and service rig.POOH on elevators and LD BHA#5. Operation at 07.00 Testing BOPE. 24h Forecast Complete LD BHA and clear rig floor.RU and test BOPE.Witness waived by Jeff Jones AOGCC Rep.RD from test and RU to run 5.5"liner. 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 PJSA BROOH f/12,221'-11,941'@ 450 gpm,2375 psi,120 rpm,12k tq,168k puw,108k sow.142k rotw. 01:00 07.00 6.00 7.00 DRILL E 7 P PJSA CBU X 6 until well was clean @ 450-550 gpm,3275 psi,120 rpm,12k tq,168k puw,108k sow. 07:00 09:30 2.50 9.50 DRILL E 25 P PJSA Cut and sip 170'of drilling line,service draw works,top-drive,traveling equip.,crown and adjust brakes. 09:30 11:00 1.50 11.00 DRILL E 4 P PJSA POOH on elevators f/11,941'.11,468',175k puw,110k sow. 11:00 12:00 1.00 12.00 DRILL E 20 P PJSA Pump dry job and blow down top-drive.Monitor well. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA POOH and LD 4.5"DP f/11,468'-5301',160k puw,140k sow. 18:00 19:00 1.00 19.00 DRILL E 20 P PJSA clear&clean rig floor. 19.00 21:30 2.50 21.50 DRILL E 4 P PJSA POOH and stand back 4.5"DP f/5301'-370',140k puw.120k sow,25bb1 total fluid losses for tour. 21 30 00:00 2.50 24.00 DRILL E 4 P PJSA Unload nukes and LD BHA#5 to 113'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Pete 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 4.825 L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(RKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12.120,0 3.701,67 Faze Pro 9.40 693,0 13.00 2,500.6 011191* Eni E&P Division .} I Well Name:SP22-FN1 OR EN!Petroleum Co.Inc. Daily Repo Well Code:26945 Field Name:NIKAITCHUQ • APIIUWI:50-629-23478-00-00 2^r, Date:2/27/2013 - Report#: 35 II "II page 1 of 1 Wellbore name: SP22-FN1 Well Header Permit/Concession N° Operator I ENI Share)%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1 DRILLING 1/27/2013 23,383.0 I 28,469.00 175.50 162.2 32.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP)ft/hr) POB Temperature(°F) Weather Wind 22,923.0 12,592.4 0.00 115.0 -11.0 Partly Cloudy.WC- NNE @ 16 MPH 36" Daily summary operation 24h Summary LD BHA#5.Test BOPE,AOGCC Rep.Jeff Jones waived witness.RU and running 5.5"Liner to 3363'. Operation at 07.00 RIH w15.5"15.58 L-80 HYD521 slotted liner as per plan @ 6,393'MD. 24h Forecast MU&Run 5.5"Liner and RIH w/5"DP and set on depth.Set Baker packer and release.Displace well to 9.0 ppg KCL brine. 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 PJSA Complete LD BHA#5. 01:00 02:00 1.00 2.00 DRILL E 20 P PJSA clean and clear rig floor. 02:00 03:00 ' 1.00 3.00 DRILL C 20 P PJSA remove wear ring and install test plug. 03:00 11:00 8.00 11,00 DRILL 'C 12 P PJSA RU and test BOPE as per regulations w/4.5"&5.5"test joints.Witness waived by AOGCC Rep Jeff Jones.RD& Blow down test equipment&choke&kill lines. 11:00 12:00 1.00 12.00 DRILL C '20 P PJSA remove test plug and install wear ring.4 bbl total fluid losses for tour. 12:00 14:30 2.50 14.50 DRILL E 25 P PJSA C/O saver sub,service IBOP valves.Service rig. 14:30 15:30 1.00 15.50 DRILL E 20 P PJSA Transfer 5"DP stands in derrick to mitigate pinch points. 15:30 17:00 1.50' 17.00 DRILL G 20 P PJSA RU to run 5.5"Liner. 17:00 00:00 7.00 24.00 DRILL G 4 P PJSA PU&MU 5.5"15.58 L-80 HYD521 Slotted liner as per plan to 3363',110k puw.110k sow. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile•Eni representative Jack Keener ENI Senior Dolling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondolling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB( Run Date LINER 51/2 4.825'L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) !Fluid Type I Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(Ib/gal) 'Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 Eni E&P Division !Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name: NIKAITCHUO • APIIUWI:50-629-23478-00-00 2 II^ Date:212812013 - Report#: 36 I' II n page 1 of 1 Wellbore name: SP22-FN1 Well Header Permit/Concession N° 'Operator ENI Share(14) !Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(1tKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP22-FN1 DRILLING 1/27/2013 I 23,383.0 28,469.00 175.50 162.2 33.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ftlhr) POB Temperature(°F) Weather [Wind 22.923.0 12,592.4 0.00 117.0 -9.0 Cloudy,WC-36° I NNE @ 23 MPH Daily summary operation 24h Summary PU&MU 5.5"liner and RIH on DP to 21.305'. Operation at 07.00 Set 5.5"liner hanger and test. 24h Forecast Set 5.5"liner as per tally to 21,929'.Set Baker packer/hanger as per Baker Rep and test.Release from liner hanger and pull out of liner.Displace well to 9.0 ppg brine and monitor well.POOH LDDP. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL G 4 P PJSA PU&MU 5.5"15.5#L-80 HYD521 slotted liner w/swell packers as per tally f/3363'-9965',140k puw,105k sow. 08:30 09:30 1.00 9.50 DRILL G 20 P PJSA PU&MU Baker ZXP Liner packer/hanger assy.,inspect and install Pal mix in tieback sleeve and let set 30 min. 09:30 12:00 2.50 12.00 DRILL G 4 P PJSA RIH w/slotted liner on 5"DP f/9965'-11,875',160k puw,115k sow. 12:00 18:00 6.00 18.00 DRILL G 4 P PJSA RIH w/5.5"liner on DP to 17,660'filling every 20 stands.110k sow. 18:00 19:30 1.50 19.50 DRILL G 4 P PJSA RIH w/liner to 19,346'.At 18,000'fluid returns trending down to no returns @ 19,346'. 19:30 20:00 0.50 20.00 DRILL G 7 P At 19,346'break circulation @ 2.5 bpm,210 psi,full returns. 20:00 00:00 4.00 24.00 DRILL G 4 P PJSA rotate liner in hole from 19,346'.21,305'to mitigate fluid losses @ 45rpm,15k tq,150k rotw. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher 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 4.825 L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 12.120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 • Eni E&P Division Well Name:SP22-FN1 OR VI* EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • APIIUWI:50-629-23478-00-00 2^n Date:3/1/2013 - Report#: 37 II "�) page 1 of 1 Wellbore name: SP22-FN1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) - Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1 DRILLING 1/27/2013 23,383.0 28,469.00 175.50 162.2 34.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,923.0 12,592.4 0.00 117.0 -15.0 Partly Cloudy,WC- NE @ 18 MPH 41° Daily summary operation 24h Summary RIH and set liner @ 21,929',TOL @ 11,934',test to 1500 psi and release.Displace well to 9.05 ppg KCL brine.POOH 5"LDDP and Baker running tool.RU and LD 4.5"DP from derrick. Operation at 07.00 PU Baker Centrilift completion equipment. FINAL DRILLING REPORT. 24h Forecast Finish LD 4.5"DP and clear floor.Pull wear bushing.Bring Baker Centrilift equipment into pipe shed to warm,inspect and strap.Hang Baker&Howco sheaves and install cable and wire.Load parts and equipment to ng floor.Hold PJSA and start running 4.5"completion tubing as per tally. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.05 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 G 4 P PJSA RIH rotating w/5.5"Liner on 5"DP 1/21,305'to 21,939',45 rpm,16k lq,145k rotw.Pull up to setting depth 21.929'. 01:30 03:30 2.00' 3.50 DRILL G 7 P PJSA break circulation,drop Baker packer seating ball and pump down @ 2 bpm,200 psi. 03:30 04:30 1.00 4.50 DRILL G 19 P PJSA Seat ball in Baker liner Packer assy.and presure up to 3000/3500/4000/for 5 min each.bleed pressure and RU to pressure down annulus to 1500 psi for 10 charted min.PU drill string and verify HRDE running tool was released.Rack back stand on DP.TOL @ 11,934'. 04:30 09.00 4.50 9.00 DRILL G 7 P PJSA on Brine Displacement.Pump 45 bbls LVT,75 bbls.citric acid treated brine followed wl 865 bbls of 9.05 ppg KCL bane @ 5 bpm,150 psi. 09:00 10.00 1.00 10.00 DRILL G 20 P PJSA clean surface equipment,prepare to POOH LDDP and monitor well. 10:00 12.00 2.00 12.00 DRILL G 4 P PJSA POOH LOOP 1/11,851'-10,210',200k puw,112k sow. 12:00 20.00 8.00 20.00 DRILL G 4 P PJSA POOH LDDP f/10,210'-surface,rack back 24 stands in derrick,LD Baker running tool. 20:00 21:00 1.00 21.00 DRILL E 20 P Clear and clean rig floor.Install mouse hole and RU to LD 4.5"DP. 21:00 00:00 3.00 24.00 DRILL E 20 P PJSA LD 4.5"DP in mouse hole from demck. Daily Contacts Position - Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.825 L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.401 693.0 13.00 2,500.6 fil* Eni E&P Division (Well Name:SP22-FN1 OR EN!Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • API/UWI:50-629-23478-00-00 2^n I Date:3/212013 - Report#: 38 II f'I page 1 of 1 Welibore name: SP22-FN1 Well Header Permit/Concession N° Operator EM Share)%) Well Configuration type 212-162 I ENI PETROLEUM 100.00 HORIZONTAL ,_ Rotary Table Elevation(it) Ground Level(ft) Water Depth(N) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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(it/hr) DFS(days) SP22-FN1 DRILLING 1/27/2013 23,383.01 28,469.00 175.50 162.2 35.00 Daily Information End Depth(itKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) IPOB Temperature(°F) Weather Wind — — 22,923.0 12,592.4 0.00 117.0 Daily summary operation 24h Summary Operation at 07.00 24h Forecast xxx Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.05 Time Log - Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Dolling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15 @doyondrilling.corn 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.825 L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 1/1141411 Eni E&P Division { I Well Name:SP22-FN1 OR ENI Petroleum Co.Inc. Daily Repot.. Well Code:26945 Field Name: NIKAITCHUO • API/UWI:50-629-23478-00-00 2 r, Date:3/2/2013 - Report#: 1 II II�I page 1 of 1 Wellbore name: SP22-FN1 Well Header Permit/Concession N° 'Operator I ENI Share(%) Well Configuration type 212-162 ENI PETROLEUM _ _ 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1 COMPLETION 23,383.0 0.00 Daily Information IIEn•Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 119.0 -24.0 Partly Cloudy,WC- NE @ 20 MPH 52° Daily summary operation 24h Summary Stage and prep Baker equipment for completion.Place Baker spooler and Howco wire line units inplace and hang sheaves and string up cables.MU TTC assy.and install Baker pump assy.and test.MU ESP tubing completion and RIH to 204'. Operation at 07.00 RIH w/4.5"12.68 L80 HYD 563 ESP completion tubing @ 1,469'MD. 24h Forecast RIH w/4.5"12.68 L80 HYD 563 ESP completion tubing as per tally and test cable every 1000'. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.05 Time Log __ Start End Cum Time Time Dar(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00100 02:30 2.50 2.50 COMP K 20 P PJSA complete LD 4.5"DP. 0230 03:00 0.50 3.00 COMP 'K 19 P PJSA RU and clean stack wl Johnny Wacker.RD same. 03:00 03:30 0.50 3.50 COMP K 19 P PJSA Remove Vetco wear bushing. 03:30 04:00 ' 0.50 4.00 COMP 'K 20 P PJSA Clears clean rig floor. 04:00 09:00 5.00 9.00 COMP K 20 P PJSA Stage and PU Baker completion equipment. 09:00 14:30 ' 5.50 14.50 COMP 'K 20 P PJSA PU&MU TTC,XO and joint of 4.5"tubing.RU Howco ■ireline and install Baker pump assy.,install pack off and test to 1000 psi for 15 min.Pull test tool and install tubing stop. 14.30 15:00 0.50 15.00 COMP 'K 20 P PJSA RD Howco wire line. 15:00 18:00 3.00 18.00 COMP K 20 P PJSA Pull tubing assy.out of hole and rack in derrick.PU&MU 7"motor shroud.PU&MU and service motor and seal assy.MU pump and pull ESP assy.out of hole.Install motor centralizer&chemical check valve on bottom of motor. • 18:00 20:30 2.50 20.50 COMP K 20 P PJSA Install TEC line.cap tube and MLE as per Baker. 20.30 23:00 2.50 23.00 COMP K 20 P PJSA MU TEC plug and install into DGU sub.PU&MU joint#2 and splice MLE to ESP cable and splice Cap tube. 23-.00 00:00 1.00 24.00'COMP K 4 P PJSA RIH w/4.5"12.6#L-80 H563 tubing as per tally to 204'. • Daily Contacts Position Contact Name Company Title E-mail Office Mobile ' Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 • Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Malls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bemie Leas ENI Rig Clerk akngclerksdoyonl5 @enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15 @doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.825 L80 12005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(Iblgal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 Eni E&P Division I Well Name:SP22-FN1 OR fit* ENI Petroleum Co.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUQ • APIIUWI:50-629-23478-00-00 2^Ei Date:3/3/2013 - Report#: 2 �I II page 1 of 1 Wellbore name: SP22-FN1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 212-162 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 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) SP22-FN1 COMPLETION - 23,383.0 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 118.0 -18.0 Partly Cloudy.WC- NE @ 30 MPH 50" Daily summary operation 24h Summary RIH w/4.5"ESP completion and MU Vetco hanger and landing jt.Install Baker penetrator and splice ESP and cap line. Operation at 07.00 Nipple down BOPE and clear and clean rig floor. 24h Forecast Land 4.5"completion on Vetco hanger and test to 5000 psi for 10 min.Pull landing jt.&install BPV.ND stack and riser.NU Vetco adapter and tree assy.Test tree/void and packoff to 5000 psi.Baker check ESP cable.RU Lil Red and test lines.Pressure up&shear Upper GLM and displace well w/155 bbls diesel.RU Howco wireline BOPsI Lubricator and swap out shear valves.RD same and secure well leaving BPV out.Release rig from well. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.05 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 COMP K 4 P PJSA RIH w/4.5"12.69 L-80 H563 ESP tubing completion ft 204'-2640'performing test every 1000'.105k puw,100k sow. Note;Cap Tube splice @ 1357'. 06:00 12:00 6.00 12.00 COMP K 4 P PJSA RIH w/4.5"ESP completion f/2640'-5609'. 12:00 16.00 4.00 16.00 COMP K 4 P PJSA RIH w/4.5"ESP completion to 7645'. 16:00 17.00 1.00 17.00 COMP K 20 I P PJSA swap spools in spooling unit and snake cables together. 17:00 17.30 0.50 17.50 COMP K 4 P RIH wl completion to 8000'and get new cable to rig floor. 17:30 19.30 2.00 19.50 COMP K 20 P Splice ESP cable as per Baker Centrilift. 19:30 22.00 2.50 22.00 COMP K 4 P PJSA RIH w/4.5"completion to 9625'. 22:00 22.30 0.50 22.50 COMP K 20 'P PJSA PU&MU Vetco hanger and landing joint. 22:30 '00:00 1.50 24.00 COMP K 20 P PJSA install Baker penetrator and splice ESP and Cap tube.Note:236 jts.4.5"tbg,3-Protectorlizers,221 Clamps. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Mails Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 51/2 4.825 L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 Eni E&P Division .. Well Name:SP22-FN1 OR VI* EN/PetroleumCo.Inc. Daily Report Well Code:26945 Field Name:NIKAITCHUO • API/UWI:50-629-23478-00-00 3/4/2013 - Repo #: 3 page 1 of 1 Wellbore name: SP22-FN1 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 212-162 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.60 13.08 36.85 33.50 Rig Information Contractor Rig Name I Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth)TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) SP22-FN1 COMPLETION 23,383.0 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 111.0 -12.0 Partly Cloudy,WC- ENE @ 32 MPH 56" Daily summary operation 24h Summary Land 4.5"ESP completion and test Vetco hanger seals to 5000 psi.ND BOPE and NU Adapter/Tree and test to 5000 psi.Baker test ESP Cable.RU Howco wire line and test to 2500 psi.RIH and C/O shear valves and test.Release Rig @ 2400 hrs. Operation at 07.00 Prep.rig for move to SI32-W2. FINAL COMPLETION REPORT. 24h Forecast RD from well SP22-FN1 and prepare to move to SI32-W2. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.05 Time Log Start End Cum Time Time Dur(hr)_Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 00 1.00 1.00 COMP K 4 P PJSA Complete ESP F.Cap line connections on hanger and land hanger as per tally.RILDS and test seals to 5000 psi for 10 min. 01:00 01:30 0.50 1.50 COMP K 20 P PJSA Pull and LD landing jt.Vetco install BPV. 01:30 05.30 4.00 5.50 COMP K 20 P PJSA ND BOPE and simops clear and clean rig floor. 05:30 09.30 4.00' 9.50 COMP K 20 P PJSA NU Vetco adapter&tree.Pull BPV&install test plug and test tree to 5000 psi f/30 min. Test tubing void/packoff to 5000 psi f/10 min.Pull test plug. 09:30 14:30 5.00 14.50 COMP K 9 P PJSA RU Lil Red and shear upper GLM shear valve @ 1800 psi.Pump 160 diesel down tubing up IA @ 1.15 bpm,450-535 psi.Blow down&RD lines. 14:30 16:00 1.50' 16.00 COMP K 12 P PJSA RU Howco wire line BOPS and lubricator.RU wire line sheave and build tool string.PT Lub.w/Lil Red to 2500 psi. 16:00 17:30 1.50 17.50 COMP K 19 P Run#1 and set slip stop catcher @ 2389'.POOH and C/O tools. 17:30 18:30 1.00 18.50 COMP K 19 P Run#2 Pull sheared valve f/GLM @ 2273'.POOH. 18:30 22:30 4.00' 22.50 COMP K 19 P Run#3Redress tool w/new shear valve and pump 5 bbls diesel thru GLM and set valve.PT to 650 psi leaking.Work valve and retest failed.Release from valve and POOH,C/O tools and RIH Run#4 and retrieve valve. 22:30 00:00 1.50 24.00 COMP K 19 P Redress tool w/new shear valve and RIH#5 and set and test valve @ 2273'. Release rig from SP22-FN1 @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office ) Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDrilling @enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling @enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Matls Coordinator Francis.Bowe @enipetroleum.com 907-685-0718 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15 @ enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Millea ENI HSE Steve.Millea @enipetroleum.com 907-685-0721 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15 @doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15 @doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(kKB) Bottom(ftKB) Run Date LINER 5112 4.825 L80 12,005.3 21,929.0 2/27/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 12,120.0 3,701.67 Faze Pro 9.40 693.0 13.00 2,500.6 U, N N N N N m CD N N00 Nm m o y O O aO O O N i ri O N Will No i !I pi o n O O !MI _ J aiN pp p iiN0 Np p A AAAA0 A p A AAA 00000 N MMOM a W eW Mm Od4,044 40e40 0404t 04 tot edddi4 W o44t tootm detot m pp aa l�[pp py1 p n O Cr01 tr0I N N O A N O O O N O O)n m V f O N A n O d OND O N n.d-m N W 3 O O l' O A O V O N E D n N z nrdnnR Rnnnn nnnnn P:PEnEOD 'm ENDIErDm NFZET mmmmm Sg:ZA mmmgia M nr.nnr nrnn nrr rrrnn 'i,4,17, nn nnm N 2 N N N ',7.1, NN N N NNN N N N 2 2 2 N N N N N 2 N N NNN N N NNN 2 N N N 2 N Q N 2 N N N N N N N NNN N N NNN 2 N 2 N NNN N N NNN N N NNN N N NNN 2 N 0 0 0 0 0 00000 O 0 0 0 0 00000 0 0 0 0 0 00000 0 0 0^0 00000 0 0 0 0 0 21 a O N C 2 2 N m N Z“3 2A N O Nrm7 NA M M N N D N r M p O m NN 2:1.m NE e 0 424 N M E NN y N N N N y N N O N N a M p m O V M M N N 0 0 1 0 0 0 0 o 0 0 NNN in N 2 2 2 2 2 N N 2 N N N NNN N YIN 2 in 2 N N N N N O.in Lo N N NNN N !..2 2 F 82.1w4. r r 2 M,7 E R 2 8 M N r m 2N N m N,„M O N r m N OO d 2;7.4E4 m M r M N M m g g O 0 OMa iia 0 Mil lal NNOrFA Orn 7.3 1 0S0 0 0 , 0N 2 N MN N M N N N N N N N N N N 22N N N O20 N N N ANN N N N N N h N N yyN M N aN N 82888 88888 88088 8888 8 0888 88888 88888 88888 88888 ;'-p M N m em M m n O O m N gmr OO O r Od O 22284 N m mrd m m'N m N Mm m N O OOOO 66,-:MM O'V V(V . �EV N r D 64646 fV�f.)N C d M�C t.7 O G fV O r 66666 -08020 2,T222 o e - AOm V A 142:Eg M 208 442:!S N V NNA M N2M A4224 O O O O O O O o N 1066n: N C N- h N O Mr.,V ,....2,.: A N H I:,- 6 fV g a 0 2 O g O m . . , . q / 0T: M A 8 8;,2 r N M„rD 6g,00 C j m N = 800:2 Ao422 ,V ANc NDN n g,%442 42242 rA 0 0:e 22 E Nr “,!8 N, 0000 0 '-' N NOO7 X^0 N N NN A V 2 n AON^ Ep N . 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O2mr 0)O NN M 2NN 20,, NMI. 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U n m m y N yy N 2224.°2 aa m G m N m M 2 I- a Nm ll 2 Oil 0i 2 r; v a2 uu'i2 0100 00000000 M tn) 00 000 00000 0000 M M aaaaaaaa m g, m W= 4 m O '4'8484 O r r O O M r 88281"2 m m N 8 G tC r` mn m O .CV Mt0 01 C>O1 G Ntp W � m m Nm m n r r m m m m m m m m 0 0 O m ~ N N m m M M M N M M M M R R M E i:> :, N Y Y W SO m n m m p pp m N m d d N m m m O O^0000 0 0 0 0 ¢ j ` N of N N m 0 m m d.m m. .T U F2 F N m O�-m N 0 p a "'dm Md MNMO Z�W N N N m m m® m Si m m m A 0 0 0 0 0 . O yE N N N N N N N N N N M M M M M M 0 . iD O O N aCC m I M ~1T Z O M V V a^ m Z I- N N � N J~O U LL d M J W WO m d M ::::0r :000! N Oi 0 aC m m N O M d.N�m N d N O O d 6 J . N , me n ^m oiwicric,iati m G 1g U= N m O N I n mN O 7 N M N N N� n m Y N M N N N N N N N N N N N V N m O C O O _ Y � O Y 6 6 J N 11 g =I P O O W`` Eo iii m o t O o 0m O 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@Halliburton.com Re: Eni Well —SP22-FN1, SP22-FN1 PB1, SP22-FN1 PB2, SP22-FN1 PB3, & SP22-FN1 PB4 AFE # 5989 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports �+ 1 Final Data Listing on CD-ROM 4 a 1 Sets of Final Logs—for each well contains: • 2" Color Log — Formation Evaluation TVD---- • 2" Color Log — Formation Evaluation MD/ • 2" Color Log — Drilling Engineering MD • 2" Color Log — Gas Ratio M� Received By: Aboz GvA- Print Name Si n Name Ajar L l3 Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. 2�2■G Z M Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SP22-FN1 BP4 Date Dispatched: 15-Mar-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP22-FN1 BP4 Log 1 2 in MD 1 2 in TVD 1 5 in MD 1 5inTVD 1 Received By: 4 Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hechetoslb.com Hector Echeto Fax:907-561-8317 Transmittal#:6316 .Z�Z X62 •• 01) 22�1� Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SP22-FN1 PB3 Date Dispatched: 15-Mar-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP22-FN1 PB3 Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5 in TVD 1 Received By: ritetki-v■-- Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchananaenipetroleum.com Transmittal#:6316 2�2�4C Z IMP2 (D Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SP22-FN1 PB2 Date Dispatched: 15-Mar-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP22-FN1 PB2 Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5inTVD 1 Received By: )/i4& cA--- Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchananaenipetroleum.com Transmittal#:6316 II Z�2 kCZ Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SP22-FN1 PB1 Date Dispatched: 15-Mar-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP22-FN1 PB1 Log 1 2inMD 1 2inTVD 1 5 in MD 1 5 in TVD 1 Received By: 6efieL— Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchananenipetroleum.com Transmittal#:6316 411. z2_4G.55 $cblumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No SP22-FN1 Date Dispatched: 15-Mar-13 Installation/Rig DOYON 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs SP22-FN1 Log 1 2 in MD 1 2 in TVD 1 5 in MD 1 5inTVD 1 Received By: / / �1� ) Please sign and return one copy to: JJ D&M,2525 6ambetl Street,Suite 400 Anchorage,Alaska 99503 hechetot slb.com Hector Echeto Fax:907-561-8317 Transmittal#:6316 n w( A 6.A- `t.'- f) Z f Z --1-&-7"' Spy Island Nikaitchuq Field 2n° pekrolleum North Slope - Alaska SP22-FN1 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle a X-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A N o GR/Res ,■ Surface Csa Dir/PWD v o 13-3/8" i° ° 68# MW(ppg) Wellbore Stability n Mud Motor B/Permafrost 2,000' 1,747' FL,r L-80,BTC 8.8 -9.5 Lost Circulation W Hole Cleaning in Casing Sections • KOP:200' Casing Wear DIS: Surface T/Tail Cement 2,514' 2,108' 0-3.5 0/100' 01 Hole Angle 59.05 Deg 13-3/8"Csg 3,019' 2,424' 16" 50°F WBM GR/RES/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(ppg) Hole Cleaning • L-80,Hydril 563 8.8-9.5 Torque&Drag • Casing Sections Tangent Angle: _ Casing Wear • 87.00 Deg BHA Expense Intermediate TOC 9,396' 3,455' ',""1 Pick-up Top of Sand j N Top 10,396' 3,595' sEC • Hole Angle TOL 12,120' 3,752' 87.00 Deg 9-5/8"Csg 12,320' 3,761' 12.25" 85"F WBM GR/RES I I ADN/PeriSCOPE Wellbore Stability n --�I I mI I S, I�.'' Slotted Liner Hole Cleaning n c) 5-1/2" Torque&Drag P� E 1E1 �Y 15.5# MW(ppg) Casing Sections Xceed 675 I I L-80,Hydril 521 8.7-9.4 Casing Wear fD I I BHA Expense I I El 1E1 I I Liner shoe 5 1/2"Liner 22,000' 3,772' —" 121.,■fogl Hole Angle N-Sand evaluation }-: :).-;,. 93.18 Deg TD 23,397' 3,538' 8-3/4" 85°F MOBM Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 19, 2012 3:50 PM To: 'Buchanan Andrew'; Borri Luca; Liantonio Gisella Cc: Gentil Pablo; Davies, Stephen F (DOA) Subject: RE: SP22-FN1 Directional Plan (212-162) Andrew, Thanks for the explanation ... we will consider the four planned sidetracks (PB1, PB2 , PB3 PB4) as plug-backs that will collapse. They will all be within zone and not require cement plugs to isolate. All the log and directional data must be submitted with the well 10-407 completion report. Each PB will have a unique API number(70 series) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Buchanan Andrew [mailto:Andrew.Buchanan @enipetroleum.com] Sent: Wednesday, December 19, 2012 3:31 PM To: Schwartz, Guy L (DOA); Borri Luca; Liantonio Gisella Cc: Gentil Pablo Subject: SP22-FN1 Directional Plan Good afternoon Guy, In this well,we are planning to drill 4 plug backs. These plug backs will not be lined and therefore will collapse in on themselves over time. Only the main weilbore will be lined and remain open for the productive life of the well. The intention is to determine if the additional lateral footage will have a positive impact on initial production. Depending on the results from this well,we are considering dual laterals in future wells. In that case, both laterals will be lined. The belief is that we could achieve better water flood conformance and ultimately better oil recovery. This is seen as a cost effective first step in determining the feasibility of a dual lateral program. If you have any questions or need clarification on the plan, please feel free to contact me. Regards, Andrew Buchanan Sr. Operations Geologist Eni Petroleum Ph: 907-865-3388 Cel: 907-250-6545 x eni_petroleum_pms-very small 12/19/2012 -3400 -3440 -3480 -3520 -3560 -3600 -3640 -3680 -3720 -3760 -3800 -3840 y N N N - N O -O O - • - O tO- -O N ' N � O -O O -O O- -00 O -O O N O I O 1 O - - O O - O N- -N O) -O) O - O O - O m 1 • O - •- - • v M / - CD ci...45.1 ("1 _-r- L i -o O co o- -O - 1` �p \ - N"'" I • Z - 0 M CID_ co O • - O• - N _o N _N _ v/ �M.. O - cY -O N a N N- - N O - -O O - -O O - O O " -O O_ -O co O O_ co CO - CO I 004£- 044£- 094£- OZ9C- 0990- 009£- 049E- 099£- OZLE- 09LE- 009C- 048£- ,,*,.�jj�• THE STATE Alaska Oil and Gas N4'►--�� °fALASKA Conservation Commission D t GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Davide Simeone Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP22-FN1 ENI US Operating Co. Inc. Permit No: 212-162 Surface Location: 4451.4' FSL, 1366.3' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 3963' FSL, 3937' FEL, SEC. 10, T14N, R8E, UM Dear Mr. Simeone: 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, Cathy . Foerster Chair DATED this Z-I day of November, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA AL! ■OIL AND GAS CONSERVATION COMM iN PERMIT TO DRILL 20 MC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil U • Service- Winj ❑ Single Zone 0 . 1c.Specify if well is proposed for: Drill 0 • 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 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co. Inc. Bond No. RLB0008627 • SP22-FN1 • 3.Address: 6.Proposed Depth: ✓ 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 23397 • TVD: 3538 Nikaitchuq/Schrader Bluff • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): � �� Surface: 4451.4 FSL 1366.3 FEL S19 T14N R9E UM • ADL 0391283,0388574 r��, 0388572• x� ?'I - ys 7/ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2962 FSL,843 FEL,S14 T14N R8E UM ADL 417493 12/5/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3963 FSL,3937 FEL,S10 T14N R8E UM 1280 1380'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 54.1 • 15.Distance to Nearest Well Open Surface:x- 511544 • y- 6053633 • Zone- 4 GL Elevation above MSL: 13.1 - to Same Pool: 2100'to 5P30-W1 16.Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 114.00 degrees Downhole: 1673 psig • Surface: 1267 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 . 1382 TOTAL sx ✓ 16" 13-3/8" 68 L-80 BTC 2984 35 35 3019 2424 LEAD:1146 sx 10.7 ppg ASL TAIL:236 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 12287 33 33 12320 3761 938 TOTAL sx 938 sx 12.5 ppg DeepCrete 8-3/4" 5-1/2" i 15.5 _ L-80 Hydril 521 9880 12120 3752 22000 3772 - 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): I Casing Length Size Cement Volume MD TVD Conductor/Structural D Surface Intermediate Production OCT 2 2412 roduction I Liner AO CC Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 10/26/2012 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni 907-865-3328 Printed Name D. ide Simeone Title Well Operation Project Manager Signature UA)o( Phone (907)865-3320 Date 10/26/2012 • Commission Use Only Permit to Drill API mber: C 7 ,,/ Permit Approval See cover letter for other Number: �� 50- 2-�- !i5 7 -ce;cc,Date: II I VI I Itio- 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: Q` Other: 35j Sc- ��f 1 G5 Samples req'd: Yes❑ No0'� Mud log req'd: Yes ❑ No �JJ�v/ p _� HzS measures: Yes❑ No[ Directional svy req'd: Yes [ No ❑ x_ 2s0a ,p S 4,,,.....-L,_ t e. APPROVED BY THE COMMISSION v, DATE: //_2_9�� � ,COMMISSIONS 0RIF rr 1�- s 7/2009) This permit is valid for 24 months from the dat of approval(20 AAC 25.005(8)) S biliti I �� volt Enii ' tir4 sir _eat RECEWED 3800 Centerpoint Drive Suite 300 0 C T 2 9 2012 Anchorage,Alaska 99503 AOGCC Davide Simeone Phone(907)865-3320 Email: Davide.Simeone @enipetroleum.com October 26,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer SP22-FN1 Dear Commissioners, Eni US Operating Co. Inc. hereby applies for a Permit to Drill for the Offshore Producer well SP22-FN1. This well will be drilled and completed using the rig Doyon 15. • The Reservoir team at EniPetroleum would like to utilize the end of the production wellbore of SP22-FN1 to further delineate the Schrader Bluff Reservoirs in an area that is currently undefined. The proposed plan is to drill the lateral in the defined primary fault block then turn the wellbore west to further evaluate The N/OA sands. The planned well path will not breach the Schrader Bluff Top ( i.e. we will not exit the TOP of N-Sand sequence,we always remaining within the Schrader Bluff Oil Pool). . The lateral section upon exiting the defined primary fault block from 22 000'-23,397' MD will be not • cased/completed. Attached are the plan view and the cross section. The planned spud date could be as early as 12/5/2012. Please find attached for the review of the Commission forms 10-401, the information required by 20 ACC 25.005. If you have any questions or require further information,please contact Luca Borri 907-865-3328. Sincerely, tAi Davide � -. :fie- . Well 0 r:r:tion Project Manager eoss000 eoss000 eoeAno so�000 soeoo, & a u. a.AJ o sos+mo eos2CW eceo u , /7' f (I Aodt p / ii ,i l�' /f1 AllerAir- )4_,0„,.. " 4M4 P ' 1 __.....„4,,,,_ Ary,i0IV.4 A .. ---04---44-..fr, ...t ,247,130,1%,1P ,, :9,,,y/ , .- .. ryitr,,,L., , /" J a Acire:- / f: ,.7 r 0 1)- ,...14eArel // IN ! 1 '-1W/IA 0 o i 5• :,/,.7..V . r N .1 o 5, 2 v rn c m rvi E N y a E 1 e a a_ 0 ig P / m" .' m I Y a E d " ooaoo■ y OWiDW WOiDOD o00rD09 WoLDW OWODW WOD9W OOOiDDD `OOOiSW arxvar, cc b -3300 -3400 -3500 -3600 -3700 -3800. -3900 _ .00 r E 6, 0 F 1 , 5 1 5 7 7 7 1 S 4 a i l b 1 $ f . iiiiiiII S 8 8 R R 1 R Irmmi 2. �< Vi 0 z z' i 1 II 8 I g I 1- $ N Cll. g V) V V 0 O O N g O L g N FS C 6 m \ $ m 0 ? Q � QQ ffi ffi �.'' .. !Ilk 00EE- 0041- 0091- 0091- 0000- 0091- ••6• ihtik imit EnH Petrol- urn Application for Permit to Drill SP22-FN 1 Saved:23-Oct-12 Application for Permit to Drill Document Producer Well SP22-FN1 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 21005(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 AAC 21005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 21005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 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 6 (LSND) 6 Lateral Mud Program 6 (MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 21005(c)(9) 6 10. Seismic Analysis 7 5C8F09D0.doc Page 1 of 9 Printed:23-Oct-12 .... lisok ' Eni tr Eni R) =:trileum Application for Permit to Drill SP22-FN 1 Saved:23-Oct-12 Requirements of 20 AAC 25.005(c)(10) 7 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 7 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005(c)(14) 9 15. Attachments 9 Attachment 1 Drilling Procedure 9 Attachment 2 Directional Plan 9 Attachment 3 Drilling Hazards Summary 9 Attachment 4 BOP and Diverter Configuration 9 Attachment 5 Cement Loads and CemCADE Summary 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 Attachment 8 Casing Design Program 9 5C8F09D0.doc Page 2 of 9 Printed:23-Oct-12 los, Ens trIeum ,Lenir Application for Permit to Drill SP22-FN1 Saved:23-Oct-12 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(6). 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: SP22-FN1 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 4451.4 FSL 1366.3 FEL S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1'AMSL Northing: 6,053,633' Easting:511,544' Pad Elevation 13.1'AMSL . Location at Top of Productive Interval 2962 FSL, 843 FEL, S14 T14N R8E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12,320' Northing: 6,057,413' Easting: 501,703' Total Vertical Depth, RKB: 3,761' Total Vertical Depth, SS: 3,707' Location at Total Depth 3969 FSL, 3937 FEL, S10 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 23,397' Northing: 6,063,696' Easting: 493,323' Total Vertical Depth, RKB: 3,538' Total Vertical Depth, SS: 3,484' 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 2: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 5C8F09DO.doc Page 3 of 9 Printed:23-Oct-12 �. it C=SI triIeum Application for Permit to Drill SP22-FN 1 Saved:23-Oct-12 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 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). • The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,687'TVDss)(0.45 - 0.11 psi/ft) • = 1267 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 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 5C8F09DO.doc Page 4 of 9 Printed:23-Oct-12 .► • ii _IL Eni irk Ieum ,,,„, . .- , .. Application for Permit to Drill SP22-FN1 Saved:23-Oct-12 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (/b/ti) Grade Connection (ft) (ft) (It) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 1607 160' Pre-Installed 1382 TOTAL sx 13-3/8 16 68 L-80 BTC 2984' 35 / 35 3019'/ 2424' LL: 236 sx 2x 10.7 ppg ppg Cr ✓ TAIL: 236 sx 12.5 ppg DeepCrete 938 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 12287' 33/ 33 12320'/ 3761' 938 sx 12.5 ppg DeepCrete TOC: 9,396'MD/3,455'TVD 8-3/4"OA 5-1/2 Sand 15.5 L-80 Hydril 521 9880' 12120'/ 3752' 220007 3772' Liner in Open Hole-no cement Lateral 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); ,i Please see Attachment 4: BOP and Diverter Configuration. 5C8F09DO.doc Page 5 of 9 Printed:23-Oct-12 L . :_ V* Enii \•J leum : :-Jtii , Application for Permit to Drill SP22-FN1 Saved:23-Oct-12 8. 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 (lb/I00 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 8.7-9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity 45 - 60 (CP) (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 - 18 (lb/100 st) (CP) HTHP Fluid loss Yield Point 18.24 (ml/30 min c <5.0 (lb/100 sf) 200psi&100°F , API Filtrate 4 - 6 Oil/Water 60/40 (cc/30 min)) Ratio Chlorides(mg/0 <500 Electrical >600 pH 9.0- 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. 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 AAC 25.033(f) Not applicable: Application is not for an exploratory or stratigraphic test well. 5C8F09D0.doc Page 6 of 9 Printed:23-Oct-12 Enil -: trolleuim Application for Permit to Drill SP22-FN1 Saved:23-Oct-12 10. 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 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 12. 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 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 MC 25 005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Please refer also to Attachment 1—Drilling Procedure 1) Move in / rig up Doyon 15. 2) RU Di erter and test as per AOGCC requirements. 3) Spud and directionally drill 16"hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5) Install and test wellhead to 5000 PSI. 6) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 7) Pressure test casing to 2500 psi per AOGCC regulations. Record results. •' 8) PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. • 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. Min LOT= 11 ppg. 10) Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. 12) RU casing drive system. 5C8F09DO.doc Page 7 of 9 Printed:23-Oct-12 Enii . 1` L. Application for Permit to Drill SP22-FN1 Saved:23-Oct-12 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8"Emergency Slips. 15) Install 9-5/8"packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17) Pressure test casing to 3000 psi per AOGCC regulations. Record results. 18) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 19) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. Min FIT= 12 ppg. 20) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming. 21) RU to run 5-1/2"slotted liner 22) PU and run 5-1/2"slotted liner to TD. 23) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. 24) RU tubing running equipment and run 4-1/2"tubing. Land tubing. Set BPV 25) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). • 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. 26) Pull BPV and set TWCV. 27) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 28) Pull TWCV. 29) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 30) Set BPV and secure tree and wellhead. 31) RDMO 5C8F09D0.doc Page 8 of 9 Printed:23-Oct-12 j Enii tlrHeum Application for Permit to Drill SP22-FN 1 Saved:23-Oct-12 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Cement Loads and CemCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 Casing Design Program I 1 I 5C8F09D0.doc Page 9 of 9 Printed:23-Oct-12 em us operating WELL SP22-FN1 Drilling Procedure SP22-FN 1 Spy Island Conductor slot #22 Reservoir location #FN1 Producer (Schrader Bluff) Nikaitchuq Project SP22-FN1 Drilling Wellplan Page 1 of 40 10/23/12 If* • 2nd us ope11 fing WELL SP22-FN 1 Spy Island Nikaitchuq Field e n° pthoOeum North Slope - Alaska SP22-FN1 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle o ° X-65 . 0° 20"Conductor Shoe 160' 160' Driven Welded N/A GR/Res • :i Surface Csa Dir/PWD $ 0 13-3/8" n 68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 2,000' 1,747' 1-80,ETC 8.8-9.5 Lost Circulation Hole Cleaning '^ Casing Sections KOP:200' ° Casing Wear DLS: Surface Ti Tail Cement 2,514' 2,108' Ari 0-3.5°/100' N ut 0 0 to 0 m m v ri n Hole Angle • m Cu 59.05 Deg 13-3/8"Csg 3,019' 2,424' 16" 50°F WBM GR/RES/PWD • jnter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 87.00 Deg BHA Expense Intermediate TOC 9,396' 3,455' Pick-up Top of Sand M N Top 10,396' 3,595' iO c o =- o m 30 p v -_ n m ' Hole Angle TOL 12,120' 3,752' m ■,1 .',. 87.00 Deg 9-5/8"Csg 12,320' 3,761' 12.25" 85'F WBM GR/RES ADN/PeriSCOPE Wellbore Stability 6 Lost Circulation ii Slotted Liner Hole Cleaning 5-1/2" Torque&Drag m 15.5# MW(ppg) Casing Sections az Xceed 675 1-80,Hydril 521 8.7-9.4 • Casing Wear BHA Expense — Liner shoe __5 1.0"Liner __ 22,000' 3,772' Hole Angle N-Sand evaluation 93.18 Deg TD 23,397' 3,538' 8-3/4" 85°F MOBM SP22-FN1 Drilling Wellplan Page 2 of 40 10/23/12 • em US perating WELL SP22-FN1 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 30 ATTACHMENTS 33 Recommended Drilling Practices 34 Health, Safety & Environment 35 Safety Meeting Topics 36 Well Shut In Procedure While Running Production Tubing 38 Conductor Broach—Contingency Cementing Plan 39 TAM PORT COLLAR Utilization Decision Tree 40 SP22-FN1 Drilling Wellplan Page 3 of 40 10/23/12 • e i us operating WELL SP22-FN1 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"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SP22-FN1 Drilling Wellplan Page 4 of 40 10/23/12 W" • em us . pera1nng WELL SP22-FN1 I 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. The Reservoir team at EniPetroleum would like to utilize the end of the production wellbore of SP22-FN1 to further delineate the Schrader Bluff Reservoirs in an area that is currently undefined. The proposed plan is to drill the lateral in the defined primary fault block then turn the wellbore west to further evaluate The N/OA sands. The planned well path will not breach the Schrader Bluff Top ( i.e. we will not exit the TOP of N-Sand sequence, we always remaining within the Schrader Bluff Oil Pool). The lateral section upon exiting the defined primary fault block from 22,000'-23,397' MD will be not cased/completed. 3.Land Intermediate casing point within 100' radius of the planned directional target. 4. 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. 5. Target Greater than 90%within the OA sand Reservoir. 6. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD—Require GR/Res/Dir to achieve TD. SP22-FN1 Drilling Wellplan Page 5 of 40 10/23/12 NF us operating WELL SP22-FN1 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPf) Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators, and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. ➢ Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SP22-FN1 Drilling Wellplan Page 6 of 40 10/23/12 ....*- enn 0 us operrafin9 WELL SP22-FN1 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) Measured True Formation Tops Depth, ft Vertical Comments Depth, ft SV-4 782 773 SV-3 1168 1122 SV-2 1489 1376 B/Permafrost 2000 1747 SV-1 2258 1929 Ugnu Top (UG4) 2709 2242 13-3/8" Csg 3019 . 2424 • SCP UG-2 Coal Bed Marker 4295 2736 Fault 1 7389 3172 Lower Ugnu 8411 3315 Schrader Bluff Top 9915 3527 N Sequence Top 10082 3551 N Top 10396 3595 ReCalc Intermediate Cement w/Actual N Bottom 10566 3619 N Sequence Base 11163 3691 OA Sand Top 11935 3741 OA-2 Top 12312 3761 9-5/8" Csg 12320 3761 ICP 5 1/2" Liner 22000 3772 TD 23397 3538 Total Depth SP22-FN1 Drilling Weliplan Page 7 of 40 10/23/12 • 2r�1� us operating WELL SP22-FN1 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth PH (ppg) Reading Loss (mg/I) (mU3Omin) 110'— 1800' 8.8 -9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800'—C.P. 9.2—9.5 • 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional LWD GR/Resistivity • Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppj) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections • Ensure lecithin is added to the mud system. SP22-FN1 Drilling Wellplan Page 8 of 40 10/23/12 em us *perating WELL SP22-FN1 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 GWD if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: D Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM D. Avoid anti-collision boundaries D Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. D Consider adding 0.5%Drilzone for screen blinding in shallow intervals right below the conductor. 5. Surface casing point: D Landed in good shale found in this area between 2000' SSTVD and 2150' SSTVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). D Inside the upper Ugnu(UG-4). D 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 D 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. SP22-FN1 Drilling Wellplan Page 9 of 40 10/23/12 em us operating WELL SP22-FN1 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from:While backreaming out of the hole in the transition from horizontal to vertical, have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. SP22-FN1 Drilling Wellplan Page 10 of 40 10/23/12 en us operating WELL SP22-FN1 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PPf) Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) OD WT Opt. (in) (PP1) 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. 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 SP22-FN1 Drilling Wellplan Page 11 of 40 10/23/12 eni us (sperating WELL SP22-FN1 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 _Vetco Gray 13-3/8"mandrel hanger 13-3/V landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 18 13-3/8"Tandem Rise Weatherford SP22-FN1 Drilling Wellplan Page 12 of 40 10/23/12 1141 2n 11 us operating WELL SP22-FN1 Surface Centralizer Placement 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. Do not allow centralizer to float between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. A SP22-FN1 Drilling Wellplan Page 13 of 40 10i23%12 10* enO us operating WELL SP22-FN 1 Surface Cementing Program Section Casing Size Type of Fluid/ Cmt Volume Properties Mudpush 11 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 476 bbls Yield 2.33 ft3/sk Tail Slurry (DeepCRETE) 63 bbls Density 12.5 ppg Top of Tail @L 2.514' MD field 1.50 ft'/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. ➢ To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool ➢ If necessary,rack TAM running tool in derrick and ready to run ➢ Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. ➢ Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than%z the shoe joint volume). SP22-FN1 Drilling Wellplan Page 14 of 40 10/23/12 101* eno uLsoprng WELL SP22-FN 1 D Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. • The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. > In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. D Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8" 5M BOP stack and test per the AOGCC Permit to Drill(attached) > Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low > Do not test BOPE against casing. D Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC SP22-FN 1 Drilling Wellplan Page 15 of 40 10/23/12 t ern o us operrafing WELL SP22-FN1 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120-140 RPM 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note: All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. D 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. D PU into casing and perform LOT. D If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. III SP22-FN1 Drilling Wellplan Page 16 of 40 10/23/12 If* 2rnnn us opera ns —WELL SP22-FN1 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Measured Formation Tops Depth, ft Vertical Comments Depth, ft SV-4 782 773 SV-3 1168 1122 SV-2 1489 1376 B/Permafrost 2000 1747 SV-1 2258 1929 Ugnu Top (UG4) 2709 2242 13-3/8" Csg 3019 2424 SCP UG-2 Coal Bed Marker 4295 2736 Fault 1 7389 3172 Lower Ugnu 8411 3315 Schrader Bluff Top 9915 3527 N Sequence Top 10082 3551 N Top 10396 3595 ReCalc Intermediate Cement w/Actual N Bottom 10566 3619 N Sequence Base 11163 3691 OA Sand Top 11935 3741 OA-2 Top 12312 3761 9-5/8" Csg 12320 3761 ICP 5 1/2" Liner 22000 3772 TD 23397 3538 Total Depth SP22-FN1 Drilling Wellplan Page 17 of 40 1(1 21 12 # us operating WELL SP22-FN1 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density PV 6 RPM API FL pH Drill Solids MBT (ppg) Reading (m1/30min) (%) Intermediate: 9.2—9.4 . 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Tool Make Up Joint Body DP Tensile Pipe (P� Grade Type Joint Joint �i� Torque al Yield Torsional oY'eld al w onin� Capacity (in) ID(in) (ft.lbs) (kips) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300' TVD from the top of the uppermost OA sand and at least 200' MD in length. b. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). c. Shallow test MWD tools. d. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off'slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. SP22-FN1 Drilling Wellplan Page 18 of 40 10/23/12 ft* us operating WELL SP22-FN 1 Intermediate Drilling 1. Directionally Drill 12-1/4"hole • Use the following Parameters: • Flow rate of 900 GPM • 120— 140 RPM 2. Casing Point: Land Intermediate casing 50' into the 0A2 sand reservoir 3. LOW ROP: Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-S 1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. ➢ Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. SP22-FN1 Drilling Wellplan Page 19 of 40 10/23/12 2nd us operating WELL SP22-FN1 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (pp.l) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydri1 **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max OD ( � Grade Conn. Type Torque, ft- Make Up Make Up Yield Torque (in) lbs Torque Torque • 9-5/8 40 L-80 Hydril 10,800 13,000 N/A 75.000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go ). Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. D Draw a longitudinal line across the pin and box and reapply the published target torque. D If the drawn line does not move more than 1/2"after the second torque application,continue running the rest of the string normally using the published target torque. D If the drawn line moves more than'h"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than 1/2",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than'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 1/2". SP22-FN1 Drilling Wellplan Page 20 of 40 10/23/12 • em us operating WELL SP22-FN1 • It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order 1 Float shoe—Davis-Lynch Model 501-DV-PVTS Baker-Lock down jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydroforms(Floating) Volant 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. ➢ Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000' MD and check flow through floats. Circulate bottoms up each time. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights every 10 joints 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. SP22-FN1 Drilling Wellplan Page 21 of 40 10/23/12 . en u us operating WELL SP22-FN1 Intermediate Centralizer Placement I IMII 10' 9-5/8"x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: MP • On Stop collar 5'above Float shoe. • No centralizer on next joint • On Stop collar 10'above Float Collar. Hi • From 4th joint to+/-1000'above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500' above N sand oil bearing zone J0°. 11111 . J. t II■11 J l■ SP22-FN1 Drilling Wellplan Page 22 of 40 10/23/12 I en CIS operr hmg WELL SP22-FN 1 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 251 bbls Density 12.5 ppg Top of Cement @ 9,396'MD (938 sacks) Yield 1.50 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than Y2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! ➢ Cement volume is based on 50%excess and at least 1000'of annular fill above top of the N sand(highest known hydrocarbon bearing zone). Refer to attached cement detail sheet for volumes. 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps and LSND water-based drilling mud. ➢ Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. ➢ Pump cement at 5 bpm and displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the fmal displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger ➢ Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. ➢ Do not exceed 80%of intermediate casing collapse ➢ Record test on IADC report and in WellView SP22-FN1 Drilling Wellplan Page 23 of 40 10/23/12 • 2rnn� us operahng WELL SP22-FN1 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. • 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite SP22-FN1 Drilling Wellplan Page 24 of 40 10/23/12 411 ( rn0 ills operrahng WELL SP22-FN1 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. ➢ 8-3/4"PDC D Rotary Steerable ➢ Flow rate: 550 GPM D 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 Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid D Do not contaminate new OBM in rig pits D Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50' of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. > PU into casing and perform LOT. > If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). D If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. D Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. > Plot on LOT form in N drive SP22-FN1 Drilling Wellplan Page 25 of 40 10/23/12 4110W 2rnli us operralt ng WELL SP22-FN1 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Formation Tops Measured Vertical Comments Depth, ft Depth,ft SV-4 782 773 SV-3 1168 1122 SV-2 1489 1376 B/Permafrost 2000 1747 SV-1 2258 1929 Ugnu Top (UG4) 2709 2242 13-3/8" Csg 3019 2424 SCP UG-2 Coal Bed Marker 4295 2736 Fault 1 7389 3172 Lower Ugnu 8411 3315 Schrader Bluff Top 9915 3527 N Sequence Top 10082 3551 N Top 10396 3595 ReCalc Intermediate Cement w/Actual N Bottom 10566 3619 N Sequence Base 11163 3691 OA Sand Top 11935 3741 OA-2 Top 12312 3761 9-5/8" Csg 12320 3761 ICP 5 1/2" Liner 22000 3772 TD 23397 • 3538 • Total Depth SP22-FN1 Drilling Wellplan Page 26 of 40 10/23/12 • eni US operating �J WELL SP22-FN1 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP Oil:water Stability (ppg) (ml/30min) miVolts Production 9.2 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/ADN/PeriSCOPE Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile WT Conn. Joint Body Torsion Torsional capacity Pipe ON) type type OD Joint ID(in) Torque al Yield Yield w/corm. Capacity (in) ID(in) (Albs) (ft lbs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt. and consider tripping without circulating or without rotating past the sidetrack point. SP22-FN1 Drilling Wellplan Page 27 of 40 10/23/12 flOS 2rnnri us operra ing WELL SP22-FN1 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ The Reservoir team at EniPetroleum would like to utilize the end of the production wellbore of SP22-FN1 to further delineate the Schrader Bluff Reservoirs in an area that is currently undefined.The proposed plan is to drill the lateral in the defined primary fault block then turn the wellbore west to further evaluate The N/OA / sands.The planned well path will not breach the Schrader Bluff Top(i.e.we will not exit the TOP of N-Sand ✓ sequence,we always remaining within the Schrader Bluff Oil Pool).The lateral section upon exiting the defined primary fault block from 22,000'-23,397'MD will be not cased/completed. 0 ` 00>�. 0➢¢' 4000 S00 6400 4409 7200 8000 S4 9640 0100 ';2% '7 13910 9600 14f 09 14404 310 2 1 A 8 „,____,,.• TD23,397'MD rr x 5 Si"liner shoe 22.000'MD ! "°— `�, S 1 0-- .. 1.i:i, M p, b4011 M' `emu' ^�F f 440 1091 1100 !On oo�^ -�+� • , ' rot ' 1ste ' are '''1y ' ■aa ' ' am ' eke ,A0o1 9�0' '-- ' eke . +OIo ' 11490 ' r)490 ' Irlet ' 'am ' War '•,dee ' mien *MIX AIM OM 1909 ISM M. ®9 J0�1 63/99 119191 MX 6COX 1.03 DM \\ ' 5 5,"liner shoe 22,000'MD N,„ ,. , -11F-41, . , ,.., , IIPI,Mt , . TD 23,397 MO ��� �� � ,AL g\ _,�� \ \` l �\ \ ►,� �\�. -, N.p.7410 ■,itiek\ I9.': ! -CI— pi'. , NiNeoa7t>.:\ *,,:11•41 ( 1 1® � 6�M 9>K 1,19, �lS�crs�ader Bluff OA development Y+. __�._:.. � Za...T 1.1411104012 1f° SP22-FN1 Drilling Wellplan Page 28 of 40 10/23/12 • eni us operating WELL SP22-FN1 D Geosteering will be required to remain in the target boundary 100%of the time D Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. D Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: D At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM D Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe: the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE: 2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue 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. D Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA D When out of hole,down load the recorded tool data and send to the Geologist in town SP22-FN1 Drilling Wellplan Page 29 of 40 10/23/12 2n0 us operraCfing WELL SP22-FN1 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(pp?) Grade Type (in) ID(in) Drift(in) (psi) (psi) skips) 5-1/2 15.5 L-80 H5 21 l 5.713 4.950 4.825 4990 7000 242 Production Liner Connection Make Up Torque (ft-lbs) Mm' Target Max. OD WT Make Up Yield (in) (PPfI Grade Conn. Type Torque, ft- Make Up Make Up Torque lbs Torque* Torque 5-1/2 15.5 L-80 Hydril 521 4600 8100 N/A 24,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 5-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. • DO NOT run E-CD subs on drill pipe while running liner string. SP22-FN1 Drilling Wellplan Page 30 of 40 10/23/12 • em us operating WELL SP22-FN1 • Torque ratings for string components: String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 5-1/2" 15.5#Hydril 521 24,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 6795 mch rel,3 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with "pal mix" and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE, PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO. and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt. immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. SP22-FN1 Drilling Wellplan Page 31 of 40 10/23/12 eni us operating WELL SP22-FN1 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero, close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 6,795 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 ppg KC1 brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. SP22-FN1 Drilling Wellplan Page 32 of 40 10/23/12 efil us .perming WELL SP22-FN1 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 SP22-FN1 Drilling Wellplan Page 33 of 40 10/23/12 2nd us op rating WELL SP22-FN1 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling.°After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. SP22-FN1 Drilling Wellplan Page 34 of 40 10/23/12 I 2no us operains WELL SP22-FN 1 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. • 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper • personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves • with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume ' only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SP22-FN1 Drilling Wellplan Page 35 of 40 10/23/12 fifOs 2nd us operahing WELL SP22-FN1 Safety Meeting Topics Move In,Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. > A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface > A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. > A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ' Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. > Hole cleaning best practices,flow rates. > Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. > Hole cleaning best practices,flow rates. > Stuck pipe,Lost circulation. SP22-FN1 Drilling Wellplan Page 36 of 40 10/23/12 ir- • em us *perr l&nng WELL SP22-FN1 D. 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. SP22-FN1 Drilling Wellplan Page 37 of 40 10/23/12 en us operating WELL SP22-FN1 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. SP22-FN1 Drilling Wellplan Page 38 of 40 10/23/12 To* e o us operenng WELL SP22-FN1 Conductor Broach — Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID:(36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20'below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200'below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50' below the conductor. POOH to 20' inside the conductor. 6. Mix and displace+/-80 bbls of Artic Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40'below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. SP22-FN1 Drilling Wellplan Page 39 of 40 10/23/12 lii* -- •eno• us ®perei nng WELL SP22-FN1 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 /X\ -' Top of Cement - L /44 /of Top ent Cement ontinue with Port below Port pletion ar Collar (1000'TVD) .{1000'.ND) � • X Indicators of Cement Top Perform Top Job as per ► Open Port Collar 1. Observation of Tracers in Spacer ahead of lead cement If Top Job is ineffective or P requirements of using drillpipeg 2. Calculated Displacement AOGCC unacceptable to AOGCC P 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface • ,_ - Nipple Up and Circulate Cement Test BOP's to Surface and close Port Collar • Continue with Nipple Up and Completion Test BOP's -- -- Continue with Completion L SP22-FN1 Drilling Wellplan Page 40 440 10/23/12 Schlumherger corn jj SP22-FN1 (P5)Alternate TD Proposal Geodetic Report (Def Plan) Report Date: October 16 2012-02.31 PM Survey l DLS Computation: Minimum Curvature/LUMnald Client En!Petroleum Vertical Section Atlmu6t 302.988•(True North) • Field: Nikstchuq Vertical Section Origin: 0.000 ft,0.000 ft Structure l Slot Spy bad/SP22 TVD Reference Datum: Rotary Tubb Were SP22.PN1 TVD Reference Elevation: 54.100 above MSL ^ ^ � Borehole: SP22-FN7 Seabed 1 Ground Elevation: 19,152•above MSL �I� t U U I O 4f Il�4],1.1,,11''I,I.', In\`(l\U/I4`I�4] O UWIIAPM: Unknown/50 Magnetic Declination: 20.152° car L Survey Name: SP22-FN7(P5)Apmate TD Total Gravity Field Strength: 1002,6923 rap(9,8 based) • Survey Date: December03,2010 Total Magnetic Field Strength: 57616.469 nT Tort I AHD I DPI/ERD Ratio: 240.329•/21774.154 8/7.507/5.714 Magnetic Dip Angle: 81.070' • Coordinate Reference System: NAD27 Alaska State Pbne,Zone 04,US Feel Declination Date: December 31,2012 Location Let/Long: N 70°33'27.87505 1,W 149°54'19.15451" Magnetic Declination Modal: BOOM 2012 Location Grid N/E YOI: N 6053633.0808US,E 511543.560 8U5 North Reference: True North • CRS Grid Convergence Angle: 0.0893• Grid Convergence Used: UM. Grid Scab Factor: 0.99990015 Total Corr Meg North->True North: 20.1525• Local Coord Referenced To: Wel Head Eacluebn Zorn Commends MD Intl Atlm True TVDSS TVD VSEC NS EW TF DLS Directional Exclusion Zone No(BUS) Lasting (R) (°) (°) (9) (8) (8) (9) (9) (°) (°11009)Difficulty Index Alert Angle (BUS) (8115) RTE 0.00 0.00 300.00 -54.10 0.00 0.00 0.00 0.00 300M N/A 0.00 8.93 6053633.08 • 511543.58 e 100.00 0.00 30000 45.90 100.00 0.00 0.00 0.00 300M 0.00 0.00 8.93 6053633.08 511543.56 KOP U11.5/100 200.0D 0.00 300.00 145.90 200.00 0.00 0.00 0.00 300M 0.00 000 8.93 6053633.08 511543.56 Bld 3.5/100 300.00 1.50 900.00 245.89 209.99 1.31 0.65 -1.13 300M 1.50 0.29 8.80 6053633.73 611642.43 400.00 5.00 300.00 345.71 399.81 6.97 3.49 5.04 300M 3.50 1.54 9.45 6053636.56 511537.51 • 500.00 8.50 300.00 445.00 499.10 18.70 9.36 48.22 HS 3.50 2.20 11.20 6053642.42 511527.33 ' 600.00 12.00 300.00 543.39 607.49 36.47 18.26 41.63 HS 3.50 2.64 13.64 6053651.29 511511.91 700,00 15.50 300,00 640,51 694.61 60.20 30.14 42.21 110 3,50 2.97 16.45 6059663.14 511481.31 • S0-4 782.06 18.97 300.00 71900 779.10 84.07 42.00 -72.81 HS 3.50 3.10 18.93 8059675.08 511470.50 800.00 19,00 300.00 736.00 790.10 89,81 44.97 -77.89 HS 3.50 3.24 19,49 6053677.92 511465.61 90000 22.50 900.00 829.50 883.60 125,19 62.68 -108,56 HS 3.50 9.46 22.65 6053695.58 511434.91 1000.00 26.00 300.00 920.66 974.76 166.20 83.21 -144.13 46 3.50 3.65 25.90 6053716.06 511309.32 1100.00 29.50 300.00 1009.14 1063.24 212.69 106.19 -18444 HS 3.50 3.81 29.21 6053739.27 511358.97 SV.3 1168.10 3118 300.00 1067.70 1121.80 247.40 129.87 -214.54 HS 350 3.92 31.48 6053750.80 511928.84 1200.00 33.00 300.00 1094.62 1148.72 264.49 132.42 -229.36 HS 3,50 3.96 3255 6053765.13 511314.01 1300.00 36.50 300.00 1176.77 1230.87 321.40 160.92 -278.72 H6 3.50 4.09 35.91 6053793.55 511284.62 1400.00 10.00 300.00 125529 1309.39 383.22 191.87 432.33 HS 3.50 4.22 39.30 6053824.41 511210.97 Cry 0.5/10D 1458.33 42,04 300.00 1299.30 1353.40 421,45 211.01 465,48 95 3.50 4,28 1129 6053843,50 511177,76 SV-2 1488.03 42.10 300.00 132290 1976.10 441.94 221.27 58325 HS 0.50 431 41.43 605385973 511100.00 1500.00 42,25 300.00 133020 138430 449.37 224.99 489.70 HS 0.50 4.31 41.49 6053857.44 51115355 160000 42.75 300.00 1103,92 1458.02 516.84 258.77 448,20 HS 0.50 4.39 41.97 6053891.13 511095.00 1700.00 4325 300,00 1477.06 1531,16 584.94 292.87 407,27 HS 0.50 445 42.46 6053925.13 51103589 1800,00 43.75 300,00 1549.60 1603.70 653.69 32729 46668 H5 0.50 451 42.95 6053959.45 51097623 1900.00 4425 300,00 1621.53 1675.63 723.06 362.02 527,04 HS 0.50 456 43.44 6053994.09 510916,02 2100.00 44,75 300.00 1692.85 1746.95 793,05 397.07 487.74 HS 0,50 4.61 43,92 6054029,03 510855,27 2100.00 45.25 300.00 1763.57 1817,67 863.67 432.42 -718.97 HS 0.50 466 44.41 6054064.29 510793.99 End Cry 2150.87 45.50 300,00 1799.30 1853.40 899.82 450.52 -78033 HS 0.50 4.66 44.66 6054082.34 51076261 2200.00 45.50 300,00 1833.73 1887.83 934.82 68.05 410.68 HS 0.00 4.70 44.66 6054099,81 51073223 SV-1 225331 4550 300,00 187460 1028.70 078.36 488.84 54670 HS 0.00 4.72 44.66 6054120.55 510600.18 2300.00 45.50 300,00 190312 1957.92 1006.05 503.71 47245 HS 0.00 4.73 44.66 6054135.38 510670.41 2400.00 45.50 300.00 1973,90 2128.00 1077.29 539.38 -934.23 HS 0.00 4.76 44.66 6054170,95 510608.59 2500.00 45.50 300,00 204389 209609 1148.52 575.04 496.00 HS 0.00 479 44.66 6054206.51 610546.77 2600.00 45.50 300,00 2114,07 2168.17 1219.75 610.71 -1057.77 HS 0.00 4.82 44.66 6054242.08 510484.94 Cry 3.5/100 260087 45.50 300.00 2114.69 2168,79 1220.37 611.02 -1058.31 24.53L 0.00 412 44.66 6054242.39 510484.40 2700.00 48,68 298,08 2182.17 2236.27 1292.79 66,23 -112179 23,22L 3.50 4.88 6.06 6054277.49 510420.88 Ugnu Top(U04) 2700.01 4897 20792 2188.10 224220 1200.54 04941 -1127.78 23.12L 150 4.80 4397 8054200.87 51041430 2800.00 51.91 296.33 226.05 2300.15 1369.31 681.37 -119021 22.1L 3.50 4,94 51,49 6054312.52 51035241 2900.00 55.16 294.73 2305.48 2359.58 1449.03 716.00 -1262.78 21.15L 3.50 5.00 54.93 6054347.04 510279.60 3000.00 58.43 293.24 236023 2414.33 1531,66 749.99 -1339.22 20,34L 3.50 5.05 58.38 6054380.90 510203,31 1348.Cap 3018.82 50.05 202.98 2870.00 2424.10 154751 75690 -1354.02 20.2L 250 507 5803 605438720 510188.51 3100.00 61.72 291.86 2410.11 2464.21 161668 783.21 -1419.25 19.65L 3.50 5.11 61.83 6054414.00 510123.23 3200.00 65.03 290.57 2454.92 2509,02 1704.38 815.54 -1502.58 10.07L 3.50 5,16 65,28 60544620 510039.86 3300.00 88,34 28934 2494.50 2548.60 1793.82 86.86 -1588.89 18,58L 3,50 5.21 68.74 6054477.38 509953,51 3400,00 71.66 288,16 2528.70 258280 1884.80 877,05 -1677.88 18,18L 3,50 5,26 7220 6054507.43 509864,50 3500.00 74.99 287.03 2557.39 2611,49 1977.23 906.00 -1769.16 17.85L 3.50 5.31 75.66 6054536.23 509773.17 3600,00 78.32 285.94 2580,47 2634.57 2070.51 933.60 -16626 17.6L 3.50 5.36 79.12 6054563.68 50967915 3700.00 81,88 284.87 2597.84 2651,94 2164.37 959.75 -1957.31 17.42L 3.50 5.41 82.58 605689,68 50958480 End Cry 3707.29 81.00 284.79 2588,89 2652,99 2171.23 961.60 -1961,36 HS 3.50 5.41 82.83 6054591,52 509577.91 3800.00 81.00 284,79 2611.94 2666.04 2258.42 985,03 -2053.10 HS 0.00 5.44 8283 605614.81 509489.14 3900.00 81.00 284,79 2626.02 2680.12 2352.47 1010.31 -2148,82 HS 0.00 5.47 8283 6054639.93 509393.39 4000,00 81,00 284.79 2640.11 2694.21 2446.52 1035.58 -224454 HS 0.00 5.49 8283 6054665.06 509297,64 410000 8180 284.79 2654,19 2708.29 2540.58 1060.86 4340.27 HS 0.00 5.52 8283 605690.18 509201,88 4200.00 51.00 284.79 2668.27 2722.37 2634.63 1088,13 .2435.09 HS 0.00 5.54 8283 6054715,31 509106.13 • U5-2 Cool Bed 4205.34 81.00 284.70 2681.70 273580 2724.30 111023 -2527.25 HS 0.00 5.57 82.83 605473926 50001484 Marker 4300.00 81.90 284.79 2682,36 2736.46 2728.68 1111.41 -2531,71 HS 0.00 5.57 8283 605476,6 509010.38 4400.00 81.90 284.79 2696.44 275054 2822.73 1136.89 -2627.43 HS 0.00 5.59 8283 6054765.56 508914.63 • 600.00 81.00 284.79 2710.52 2764.62 2916.79 1161.96 -2723.16 HS 0.00 5.61 8283 6054790.68 508818.87 4600.00 81.90 284.79 2724.60 2778.70 3010.84 1187.24 4818.88 HS 0.00 5.63 8283 6054815.80 508723.12 4700.00 81.90 284.79 2738.69 2792.79 3104.89 1212,51 4914.60 HS 0.00 5.65 8283 6054840.93 508627.37 4800.00 6180 284.79 2752.77 280617 3198.94 1237.79 -3010.32 HS 0.00 5,67 82.83 6054866.05 508531.62 4900,00 81,90 284.79 2766.85 2820.95 3293.00 1263,07 4106.05 HS 0.00 5.00 82,83 6054891.18 509435.87 50%10 8180 284,70 278083 2835.03 3387.05 1288.34 -3201.77 HS 0,00 5.71 82.83 6054916.30 508340.11 5100.00 81.90 284.79 2795.02 2849.12 361.10 131382 4297.49 HS 0.00 5.73 82.83 6054941.42 508244.36 5200,00 61.90 284.79 2809.10 286320 3575.15 1338,89 439321 HS 0.00 5.75 82.83 6054966.55 508148.61 5300.00 81,90 284.79 2823.18 2877.28 366921 1364.17 -348814 HS 0.00 5.77 82,83 6054991,67 508052.86 5400.00 81,90 284,79 2837.26 2891,36 376326 1389.45 4584.66 HS 0.00 5.78 82,83 6055016.80 507057.11 5500.00 81,90 284,79 2851.35 2905.45 385731 1414.72 4680.38 HS 0.00 580 82.83 6055041.92 507861.35 5600.00 81.90 284.79 2865.6 2919.53 395136 1440,00 -3776.10 HS 0.00 582 82.83 6055067.05 507765.60 5700,00 8180 284,79 2879.51 2933.61 4045.42 1465.27 -3871,83 HS 0,00 5.83 82.83 6055092,17 507669.85 5800.00 8180 284,79 2893,60 2947.70 4139.47 1490,55 4967.55 HS 0.00 5,85 8283 605511729 507574.10 5900,00 81,90 284,79 2907,68 2961.78 4233,52 1515,82 406327 HS 0,00 5,86 82.83 6055142.42 507478,35 6000,00 81,90 284,79 2921,76 2975,56 4327.57 1541.10 -4156.99 HS 0.00 5.88 8283 6055167,54 507382.59 6100,00 81.90 284.79 2935.84 2989,94 4421.63 1566.38 4254,72 HS 0.00 5.89 82.83 6055192,67 507266.54 6200.00 81.90 284,79 2949.93 3004.03 4515.68 1591,65 -4350.44 HS 0.00 5.91 82.83 6055217,79 507191,09 6300,00 81,90 284.79 2964,01 3018,11 4609.73 1616,93 -4446.16 HS 0.00 5.92 82,83 6055242.91 507095.34 6400,00 81,90 284.79 2978,09 3032.19 4703,78 161220 -4541,88 HS 0.00 5,94 82,83 6055268,04 506999,59 6500,00 81,90 284.79 2992.17 3046.27 4797,84 1667.48 -4637,61 HS 0,00 5.95 8283 6055293.16 506903,83 6600,00 81,90 284.79 300626 3060.36 4891,89 1692,76 4733.33 HS 0.00 5,96 82.83 6055318.29 506808.08 670000 81.90 284.79 3020.34 3074.44 4985,94 1718,03 -4829.05 HO 0.00 5,08 82,83 6055343,41 506712,33 6800,00 81,90 284,79 3034.42 3086.52 5079.99 1743,31 4924,77 HS 0,00 5,99 82,83 6055368.54 506616,58 6900.00 81,90 284,79 3048,50 3102,60 5174,05 1768,58 4020,50 HS 0,00 6,00 8283 6055393.66 50652083 7000.00 81,90 284,79 3062,59 3116.69 5268.10 1793,86 5116,22 HS 0,00 6,01 82,83 6055418.78 506425,07 7100.00 81.90 284,79 3076.67 3130.77 5362,15 1819.14 5211,94 HS 0.00 6,03 8283 6055443,91 506329,32 7200,00 81.90 284,79 3090.75 3144,85 5456.20 1844,41 4307,88 HS 0,00 6.04 82.83 00556003 606233.57 7300.00 81.90 284.79 3104,84 9158,94 5550,26 1869,69 5403.35 HS 0,00 6.05 8283 6055494,16 506137.82 Fault 1 7380.22 81.00 284.70 9117.40 3171.50 5034.17 180224 -548370 HS 0.00 6.08 8283 6055518.57 50805238 7400,00 81,00 284.79 311882 3173.02 5644.31 1894,96 4499,11 HS 0.00 608 82,83 8055519.28 506042.06 7500.00 81.00 284.79 3133.00 3187,10 5738.36 1920,24 4594,83 HS 0,00 6.07 82.83 6055544.40 505946.31 Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 2:34 PM Page 1 of 4 Ercluelon Zolw Comments MD 111•) Atlm True TVDSS IVO VS EC NS EW IF DLS Difficulty Index Exclusion Zone Northing Ealing (ft) r) (1 (ft) (ft) (ft) (R) (R) (°) (°110011)DMkWry Indsz NMPl (ftUS) (RUS) 7600.00 81.90 284.79 3147.08 3201.18 5832.41 194552 5690.55 HS 0.00 6.08 82.83 6055569.53 505850.56 7700.00 81.90 284.79 3161.17 321527 5926.47 1970.79 -786428 HS 0.00 6.09 82.83 6055594.85 505754.81 7800.00 81.90 284.79 3175.25 3229.35 6020.52 1996.07 588200 HS 0.00 6.10 82.83 6055619.78 505659.06 7900.00 81.90 284.79 318933 3243.43 6114.57 202134 -5977.72 HS 0.00 6.11 82.83 6055644.90 505563.30 8000.00 81.90 284.79 3203.41 3257.51 6208.62 2046.62 -6073.44 HS 0.00 6.12 82.83 6055670.03 505467.55 8100.00 81.90 284.79 3217.50 3271.60 6302.68 2071.90 5169.17 HS 0.00 6.14 8283 6055695.15 505371.80 8200.00 81.90 284.79 3231.58 3285.68 6396.73 2097.17 5264.89 HS 0.00 6.15 82.83 605572027 505276.05 8300.00 81.90 284.79 3245.66 3299.76 6490.78 2122.45 5360.61 HS 0.00 6.15 82.83 6055745.40 505180.30 8400.00 81.90 284.79 3259.74 3313.84 6584.83 2147.72 -6456.33 HS 0.00 6.16 82.83 6055770.52 505084.54 Lower U05 u 8411.05 81.00 284.78 3201.30 3315.40 8505.22 2150.52 -8488.01 HS 0.00 017 82.83 0055773.30 50507007 8500.00 81.90 284.79 3273.83 3327.93 6678.88 2173.00 -655206 HS 090 6.17 82.83 6055795.65 504988.79 8600.00 81.90 284.79 3287.91 3342.01 6772.94 2198.27 -6647.78 HS 0.00 6.18 82.83 6055820.77 504893.04 8700.00 8190 284.79 3301.99 3356.09 6866.99 2223.55 -6743.50 HS 0.00 &19 82.83 6055845.89 50479729 8800.00 81.90 284.79 3316.07 3370.17 6961.04 2248.83 -6839.23 HS 0.00 6.20 82.83 6055871.02 501701.54 8900.00 81.90 284.79 3330.16 3384.26 7055.09 2274.10 -6934.95 HS 0.00 6.21 82.83 6055896.14 504605.78 900090 81.90 284.79 3344.24 3398.34 7149.15 2299.38 -7030.67 85 0.00 6.22 82.83 6055921.27 504510.03 9100.00 81.90 284.79 3358.32 3412.42 7243.20 2324.65 -7126.39 HS 0.00 6.23 82.83 6055946.39 504414.28 9200.00 81.90 284.79 3372.41 3426.51 733725 2349.93 -7222.12 HS 0.00 8.24 82.83 6055971.52 554318.53 9300.00 81.90 284.79 3386.49 3440.59 7431.30 2375.21 -7317.84 HS 0.00 6.25 82.83 6055996.64 50422278 9400.00 81.90 284.79 3400.57 3454.67 7525.36 2400.48 -7413.56 HS 0.00 6.25 82.83 6056021.78 504127.02 9500.00 81.90 284.79 3414.65 3468.75 7619.41 2425.76 -7509.28 HS 0.00 626 82.83 6058046.89 504031.27 9600.00 81.90 284.79 3428.74 3482.84 7713.46 2451.03 -7605.01 HS 0.00 827 82.83 6056072.01 503935.52 9700.00 81.90 284.79 3442.82 3496.92 7807.51 2476.31 -7700.73 HS 0.00 628 82.83 6056097.14 503839.77 9800.00 81.90 284.79 3456.90 3511.00 7901.57 2501.59 -7796.45 HS 0.00 6.29 82.83 605612226 503744.02 9900.00 81.90 284.79 3470.98 3525.08 7995.62 2526.86 -7892.17 HS 0.00 6.29 82.83 6056147.38 503648.26 Schrader Bluff Top 0915.03 81.90 284.79 3473.10 352720 8009.75 2530.80 -7900.58 HS 0.00 0.30 82.83 0050151.10 503033.88 0000.00 81.90 284.79 3485.07 3539.17 8089.67 2552.14 -7987.90 85 0.00 6.30 82.83 6056172.51 503552.51 N Sequence Top 0081.90 81.00 284.79 340010 355070 810070 257284 -8080.20 HS 0.00 8.31 8283 0050103.08 503474.09 0100.00 81.90 284.79 3499.15 3553.25 8183.72 2577.41 -8083.62 H5 0.00 6.31 82.83 6056197,63 503456.76 0200.00 81.90 284.78 351323 3567.33 8277.78 2602.69 -8179.34 HS 0.00 6,32 82.83 8056222,76 503361.01 0300.00 81.90 284.79 3527.31 3581.41 8371.83 2627.97 -8275.06 HS 0.00 6.32 82.83 6056247.88 50326525 N Top 0300.47 81.00 28479 3540.00 9505.00 848248 2052.35 -8307.41 HS 0.00 833 82.83 0050271.12 50317288 0400.00 81.90 284.79 3541.40 3595.50 8465.88 2653.24 -8370.79 HS 0.00 6.33 82.83 6056273.01 503169.50 0500.00 81.90 284.79 3555.48 3609.58 8559.93 2678.52 -8466.51 HS 0.00 6.34 82.83 6056298.13 503073.75 N Bottom 056618 81.00 284.70 3584.80 3818.90 802218 209525 -8529.88 HS 0.00 004 82.89 0056914.70 50301008 Cry 3.5/100 0580.12 81.90 284.79 3586.76 3820.86 8635.29 2698.77 -8543.20 84.03R 0.00 6.35 82.83 8056318.26 502997.03 0600.00 81.98 285.49 3569.55 3623.65 8654.02 2703.91 -8562.20 63.940 3.50 8.35 82.79 6056323.37 502978.03 0700.00 82.36 289.00 3583.18 3637.28 8749.36 273328 5656.80 83.460 3.50 6.38 82.63 6056352.59 502883.39 0800.00 82.77 292.51 3596.12 3650.22 8846,25 2768.41 -8749.51 83R 3,50 6.40 82.49 6056387.57 502790.64 0900.00 83.21 296.01 3608.32 3662.42 8944.34 2809.18 -8839.98 82.58R 3.50 6.42 82,38 6056428.20 502700.11 1000.00 63.68 299.50 3619.74 3673.84 9043.26 2855.43 5927.89 62.186 3,50 6.45 82.30 6058474.31 502612.14 1100.00 84.17 302.88 3630.33 3584.43 9142.63 2907.00 -9012.89 81.810 3,50 6.47 82.25 6056525.74 502527.07 N Sequence 889e 1163.45 8449 30519 3030.00 3800.70 9205.78 2942.38 -0085.18 81.59R 3.50 0.48 8224 0050501.04 501474.73 1200.00 84.68 306.48 3640.05 3694.15 9242.10 2963.68 -9094.68 61.476 3.50 8.49 82.23 6056582.28 502445.20 1300.00 85.20 309.94 3648.88 3702.98 9341.28 3025.27 -9172,95 81,16R 3.50 6.51 8224 6056643.75 502366.84 1400.00 85.75 313.40 3656.76 3710.86 9439.81 3091.54 -9247.40 80.89R 3.50 8.53 82.28 6056709.89 502292.29 1500.00 86,31 316.87 3663.69 3717.79 9537.32 3162.23 -9317.77 80.65R 3.50 6.55 82.34 6056780.47 502221.83 1600.00 88,89 320.32 3669.62 3723.72 9633.45 3237.10 9383.78 80.44R 3.50 6.57 82.44 6056855.22 502155.71 End Cry 1619.53 87,00 321.00 3670.66 3724.76 9652.03 3252.18 -9396.14 HS 3.50 6.58 82.46 6056870.28 502143.32 1700.00 87.00 321.00 3674.88 3728.98 9728.45 3314.63 -9446.71 HS 0.00 6.58 82.46 6056932.65 502092.66 1800.00 87,00 321.00 3680.11 3734.21 9823.42 3392.24 9509.56 HS 0.00 6.59 82.46 6057010.15 502029.70 1900.00 87.00 321.00 3685.34 3739.44 9918.39 3459.85 9572.40 HS 0.00 6.60 82.46 6057087.65 501966.74 OA Top 1095.47 87.00 321.00 3687.20 3741.30 9952.08 3497.38 -9594.70 HS 0.00 0.00 81,40 0057115,15 501944.40 2000.00 87.00 321.00 3690.58 3744.68 10013.36 3547.45 963525 HS 0.00 6.60 82,46 6057165.18 501903.78 2100.00 87.00 321.00 3695.81 3749.91 10108.33 3625.06 9698.09 HS 0.00 6.61 82.46 6057242.68 501840.82 2200.00 87.00 921.00 3701.04 3755.14 10203.30 3702.67 -9760.94 HS 0.00 6.62 82,46 6057320.16 501777.86 2300.00 87.00 321.00 3706.28 3760.38 10298.27 378028 9823.79 HS 0.00 6.63 82.46 6057397.66 501714.90 0A-2 Top 2311.80 87.00 321.00 3706.00 976180 10300.56 378950 9831.20 HS 0.00 8..05 8240 005740088 501707.41 °Gag 11319.59 8700 31100 370730 3701.40 10316.81 370544 983088 HS 0.00 6.0.9 8240 0057412.80 501702.00 SP22-FN1 Heel Cm 2.5/10D 2389.53 87.00 321.00 3710.96 3765.06 0383.29 3649.76 9880.05 88.876 0.00 6.63 8246 6057467.05 501658.53 2400.00 87.01 321.26 3711.51 3765.61 0393.23 3857.90 -9886.61 88.858 250 6.63 8243 6057475.16 501651.96 2500.00 87.06 323.76 3716.69 3770.79 0487.34 3937.14 -9947.38 88.72R 2.50 6.65 82.15 6057554.31 501591.07 2600.00 87.12 326.27 3721.77 3775.87 0579.92 4018.96 -10004.64 88.6R 2.50 6.67 81.89 6057636.04 501533.69 2700.00 87.18 328.77 3726.75 3780.85 0670.77 410320 -10058.27 88.47R 2.50 6.68 81.84 6057720.19 501479.93 End Cry 274274 8721 329.84 3728.84 3782.94 0709.04 4139.91 -10080.06 HS 2.50 6.69 81.54 6057756.86 501458.08 Cry 2/100 2783.35 8721 329.84 3730.82 3784.92 074522 4174.98 -10100.44 88.621 0.00 6.69 81.54 6057791.89 501437.66 2800.00 87.22 329.51 3731.63 3785.73 0760.08 4189.34 -10108.84 88.61_ 2.00 6.69 81.59 6057806.23 501429.23 SP22-FN1 TGT1 2825.27 87.23 329.00 3732.85 3786.95 0782.71 4211.02 -10121.74 62071_ 2.00 6.70 81.66 6057827.90 501416.30 2900.00 88.30 326.99 3735.77 3789.87 0850.38 4274.34 -10161.32 621 3.05 6.71 8297 6057891.15 501376.63 End Cry 298558 89.52 324.68 3737.39 3791.49 092923 4345.14 -10209.37 HS 3.05 8.72 84.48 6057961.86 501328.47 3000.00 89.52 324.68 3737.51 3791.61 0942.63 4356.90 -10217.70 HS 0.00 6.72 84.48 6057973.61 501320.12 3100.00 89.52 324.68 3738.34 3792.44 1035.54 4438.50 -1027551 HS 0.00 6.73 84.48 6058055.11 501262.19 3200.00 89.52 324.68 3739.17 379327 1128.45 4520.09 -10333.32 HS 0.00 6.74 84.48 6058136.61 501204.27 Cry 2/100 3277.96 89.52 324.68 3739.82 3793.92 1200.89 4583.71 -10378.39 41.381 0.00 6.74 84.48 6058200.14 501159.10 3300.00 89.85 324.39 3739.94 3794.04 1221.39 4601.65 -10391.17 41.381_ 2.00 6.75 84.84 8058218.07 501146.29 0P22FN1 TGT2 3329.67 90.30 324.00 3739.90 3794.00 1249.04 4625.71 -10408.53 33.561_ 2.00 6.75 85.33 6058242.10 501128.90 3400.00 91.47 323.22 3738.81 3792.91 1314.86 4082.32 -1045025 33.57L 2.00 6.76 86.60 6058298.64 501087.10 End Cry 3404.88 91.55 323.17 3738.68 3792.78 1319.44 4686.23 -10453.17 HS 2.00 6.76 86.68 8058302.54 501084.17 3500.00 91.55 32117 3736.10 3790.20 1408.69 4762.34 -10510.17 HS 0.00 6.77 86.68 6058378.55 501027.05 3600.00 91.55 323.17 3733.39 3787.49 1502.51 484235 -10570.09 HS 0.00 6.77 86.68 6058458.46 500967.01 3700.00 91.55 323.17 3730.68 3784.78 1596.34 492236 -10630.02 HS 0.00 6.78 86.68 6058538.37 500806.97 3800.00 91.55 323.17 3727.97 3782.07 1690.17 500237 -10689.94 HS 0.00 6.79 86,69 6058618.28 500846.92 Cry 2/100 3816.44 91.55 323.17 3727.53 3781.63 1705.60 5015.53 -10699.80 174.85R 0.00 6.79 86.69 6058631.42 500837.05 SP22-FN1 TGT3 3834.19 91.20 323.20 3727.10 3781.20 172224 5029.73 -10710.43 178.84R 2.00 6.79 86.33 6058645.60 500826.40 3900.00 89.88 323.23 3726.48 3780.58 1783.99 508243 -10749.84 178.85R 2.00 8.80 85.02 6058698.24 500786.91 End Cry 3924.09 89.40 323.24 3726.63 3780.73 1806.60 5101.73 -10764.26 HS 2.00 6,80 84.54 6058717.51 500772.46 4000.00 89.40 323.24 3727.42 3781.52 1877.81 516254 -10809.69 HS 0.00 6.81 84.54 6058778.24 500726.94 4100.00 89.40 323.24 3728.46 3782.56 1971.63 5242.64 -10869.53 HS 0.00 6.81 84.54 6058858.25 500666.98 4200.00 89.40 323.24 3729.51 3783.61 2065.44 5322.75 -10929.38 HS 0.00 6.82 84.54 6058938.25 500607.01 4300.00 89.40 323.24 3730.55 3784.65 2159.26 5402.86 -10989.23 HS 0.00 6.83 84.54 6059018.26 500547.04 CN2/100 4337.52 89.40 323.24 3730.94 3785.04 2194.45 5432.91 -11011.69 11.93R 0.00 6.83 84.54 6059048.27 500524.54 0722-751 TGT4 4338.43 88.42 323.24 3730.95 3785.05 2195.31 5433.64 -11012.23 3.471 2.00 6.83 84.56 6059049.00 500524.00 End Cry 4339.17 89,43 323.24 3730.96 3785.06 2196.00 543423 -11012.67 HS 2.0D 6.83 84.58 6059049.59 500523.56 4400.00 89.43 323.24 3731.56 3785.66 2253.07 5482.96 -11049.08 HS 0.00 6.83 84.58 6059098.26 500487.08 4500.00 89.43 323.24 3732.54 3786.64 2346.88 5563.07 -11108.92 HS 0.00 6.84 84.58 6059178.27 500427.12 4600.00 89.43 323.24 3733.53 3787.63 2440.70 5643.18 -11168.77 HS 0.00 6.85 84.58 6059258,28 500367.15 4700.00 89.43 323.24 3734.52 3788.62 2534.51 5723.29 -11228.61 HS 0.00 6.85 84.58 6059338.29 500307,19 4800.00 89.43 323.24 3735.50 3789.60 2628.33 5803.40 -11288,46 HS 0.00 6.86 84.58 6059418.30 500247.23 Cry 2/100 4830.62 89.43 323.24 3735.81 3789.91 2657.05 5827.93 -11306,78 165.46R 0.00 6.86 84.58 6059442.79 500228.87 0922-791 TOTS 484274 89.20 323.30 3735.95 3790.05 2668.42 5837.65 -11314.03 179.79R 2.00 6.86 84.33 6059452.50 500221.60 4900.00 88.05 323.30 3737.32 3791.42 2722.10 5883.54 -11348.24 179.79R 2.00 6.87 83.20 6059498.34 500187.33 End Cry 4923.75 87.58 323.31 3738.23 3792.33 2744.36 5902.58 -11362.42 HS 2.00 6.87 82.73 6059517.34 500173.12 5000.00 87.58 323.31 3741.45 3795.55 2815.80 5963.66 -11407.94 95 0.00 6,88 82.73 6059578.35 500127.50 5100.00 87.58 323.31 3745.67 3799.77 2909.49 6043.77 -11467.64 HS 0.00 6.88 82.73 6059658.36 500067.68 5200.00 87.58 323.31 3749.89 3803.99 3003.19 6123.88 -11527.34 HS 0.00 6,89 82.73 6059738.37 500007.86 Cry 2/100 5289.42 87.58 323.31 3753.67 3807.77 3086.97 6195.52 -11580.73 37.49L 0.00 6.89 82.73 6059809.92 499954.37 5300.00 87.75 323.18 3754.10 3808.20 3096.89 6203.99 -11587.05 37.48L 2.00 6.89 62.91 6059818.38 499948.03 8P22FN7 TGT6 5347.39 88.50 322.60 3755.65 3809.75 3141.42 6241.76 -11615.63 21.77L 2.00 6.90 83.73 6059856.10 499919.40 5400.00 89.48 322.21 3756.58 3810.88 3191.03 6283.44 -11647,72 21.761 2.00 6.91 84.75 6059897.72 499887.25 End Cry 5437.41 90.17 321.93 3756.69 3810.79 3226.39 6312.95 -11670.72 HS 2.00 6.91 65.48 6059927.19 499864.21 Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 2:34 PM Page 2 of 4 1 MD Incl Atlm True VDSS TVD VS EC NS EW TF DLS Directional Exclusion fl Zlre Northing Eosins]Commads (n) (r 1 I (11) M) ll IN (ft) HOOK(Difficulty Index ued n°ti IOUs) (flus) 5500.00 90.17 321.93 3756.51 3810.61 3285.59 6362.22 -11709.31 HS 0.00 6.91 85.48 6059976.40 499825.54 5600.00 90.17 321.93 375620 3810.30 3380.17 6440.95 -11770.97 HS 0.00 6.92 85.48 6060055.03 499763.77 Cis 2/100 5649.60 90.17 321.93 3756.06 3810.16 3421.08 6480.00 -11801.55 78.09L 0.00 6.92 85.48 6060094.02 499733.13 5700.00 98.38 320.95 3755.81 3809.91 3474.89 6519.41 -11832.97 7811 2.00 6.93 85.82 6060133.38 499701.66 5800.00 90.79 318.99 3754.79 3808.89 3570.52 6595.97 -11897.28 78.12L 2.00 6.94 86.49 6060209.83 499637.23 SP22-FN1 TGT7 5850.51 91.00 318.00 3754.00 3808.10 3619.19 6633.79 -11930.75 88.551 2.00 6.95 86.83 6060247.60 499603.70 5900.00 91.02 317.01 3753.13 3807.23 3667.09 6670.27 -11964.18 88.571 2,00 6.95 86.99 6060284.03 499570.22 6000.00 91.07 315.01 3751.29 3805.39 3764.49 6742.21 -12033.61 88.611 2,00 6.96 87.32 6080355.84 499500.68 6100.00 91.12 313.01 3749.38 3803.48 3862.63 6811.67 -12105.52 88.651 2.00 6.97 87.65 6060425.18 499428.68 6200.00 91.17 311.01 3747.38 3801.48 3961.36 6878.58 -12179.80 88.691 2.00 6.99 87.98 6060491.97 499354.30 End Cm 6240.75 91.19 310.20 3746.54 3800.64 4001.75 6905.09 -12210.73 HS 2.00 6.99 88,12 6060518.44 499323.33 6300.00 91.19 310.20 3745.31 3799.41 4060.52 6943.33 -12255.98 HS 0.00 6.99 88.12 6060556.59 499278.02 Cm 2/100 6339.19 91.19 310.20 3744.50 3798.60 4099.38 6968.61 -12285.91 69.61R 0.00 7.00 88.12 6060581.83 499248.06 SP22-FN1TGT8 6355.39 9130 310.50 3744.15 3798.25 4115.45 6979.10 -12298.25 50.313 2.00 7.00 88.19 6060592.30 499235.70 6400.00 91.87 311.19 3742.92 3797.02 4159.62 700826 -12331.99 50.32R 2.00 7.00 88.65 6060621.41 499201.92 6500.00 93.15 312.73 3738.54 3792.64 4258.30 7075.05 -12406.28 50.396 2.00 7.01 89.69 6060688.07 499127.54 End Cm 6592.08 94.32 314.15 3732.55 3786.65 4348.66 7138.23 -12472.99 HS 2.00 7.02 89.35 6060751.14 499060.73 6600.00 94.32 314.15 3731.95 3786,05 435641 7143.73 -12478.66 HS 0.00 7.02 89.35 6060756.63 499055.06 6700.00 94.32 314.15 3724.42 3778,52 4454.24 7213.19 .12550.20 HS 0.00 7.03 89.35 6060825.97 498983.41 CM 2/100 6740.27 94.32 314.15 3721.39 3775,49 4493.63 7241.16 -12579.02 164.321 0.00 7.03 89.35 6060853,89 498954.56 6800.00 93.17 313.83 3717.49 3771.59 4552,14 7282.55 -12621.90 164.34L 2.00 7.04 89.56 6060895.22 498911.62 SP22-F61 TGT9 6860.69 92.00 313.50 3714.75 3768.85 4611.71 7324.41 -12665.75 159,71 2.00 7.04 88.45 6060937.00 498867.70 6900.00 91.26 313.23 3713.63 376773 4650.37 7351.39 -12694.32 159.711 200 7.05 87.76 6060963.93 498839.09 End Gm 6905.88 91.15 313.19 3713.51 3767.61 4656.15 7355.41 -12698.60 HS 2.00 7.05 87.65 6060967.95 498834.80 7000.00 9115 313.19 3711.61 3765.71 4748.77 7419.82 -1276722 HS 0.00 7.05 87.65 6061032.24 498766.10 7100.00 91.15 313.19 3709.60 3763.70 4847.17 7488.24 -12840.12 HS 0.00 7.06 87.65 6061100,54 498693.10 7200.00 91.15 313.19 370759 3761.69 4945.57 7556.66 -12913.02 HS 0.00 7.07 87.65 6061168.85 498620.10 7300.00 91.15 313.19 3705.58 3759.68 5043.97 7625.09 -12985.91 HS 0.00 7.07 87.65 6061237.15 498547.10 Cm 2/100 7352.40 91.15 313.19 3704.53 3758.63 5095.53 7660.94 -13024.12 174.66R 0.00 7.07 87.65 6061272.94 498508.85 SP22-FN1 TGT10 7365.08 90.90 31321 3704.30 3758.40 5108.00 7669.62 -13033.35 178.841 2.00 7.07 87.40 6061281.60 498499.60 End Cm 7368.93 90.82 313.21 3704.24 3758.34 5111.79 7672.25 -13036.16 HS 2.00 7.07 87.33 6061284.23 498496.79 7400.00 90.82 313.21 3703.80 3757.90 5142.37 7693.52 .13058.80 HS 000 7.08 87.33 6061305.47 498474.11 7500.00 90.82 313.21 3702.38 3756.46 5240.77 7781.98 -13131.68 HS 0.00 7,08 87.33 6061373.80 498401.14 7600.00 90.82 313.21 3700.92 3755.02 5339.17 7830.44 -13204.56 HS 0.00 7.09 87.33 6061442.14 498328.16 7700.00 90.82 313.21 3699.49 3753.59 6437.58 7898.90 -13277.44 HS 0.00 7.09 87.33 6061510.48 498255.18 7800.00 90.82 313.21 3698.05 3752.15 5535.98 796736 -13350.32 HS 0.00 7.10 87.33 606157882 49818220 Cry MOO 7828.18 90.82 313.21 3697.65 3751.75 5563.71 7986.65 -13370.86 179.89R 0.00 7.10 87.33 6061598.08 498161.63 SP22-FN7 TGT11 7869.33 90.00 313.21 3697.35 3751.45 5604.21 8014.83 -13400.85 LS 2.00 7.10 86.51 6061626.20 498131.60 7900.00 89.39 313.21 3697.51 3751.61 5634.39 8035.82 -1342320 LS 2.00 7.11 85.90 6061647.16 498109.22 End Cm 7964.68 88.09 313.21 3698.94 3753.04 5698.03 8080.10 -13470.34 HS 200 7.11 84.62 6061691.36 498062.02 8000.00 88.09 313.21 3700.11 3754.21 5732.77 810426 -13496.06 HS 0.00 7.11 84.62 6061715.48 498036.26 8100.00 88.09 313.21 3703.44 3757.54 5831.12 8172.69 -13568.91 HS 0.0D 7.12 84.62 6061783.79 497963.32 8200.00 88.09 313.21 3706.77 3760.87 5929.48 8241.12 -13641.75 HS 0.00 7.12 84.62 6061852.10 497890.37 8300.00 88.09 313.21 3710.09 3764.19 6027.84 8309.55 -13714.60 HS 0.00 7.13 84.62 6061920.40 497817.43 Cm 2/100 8368.56 88.09 313.21 3712.38 3766.48 6095.27 8356.46 -13764.54 4.81 0.00 7.13 84.62 6061967.23 497767.42 0722-FN1 TGT12 8373.93 8820 313.20 3712.55 3766.65 6100.55 8360.13 -13768.45 HS 2.00 7.13 84.73 6061970.90 497763.50 8400.00 88.72 313.20 3713.25 3767.35 6126.21 8377.98 -13787.45 HS 2.00 7.14 85.25 6061988.71 497744.47 End Cm 8444.90 89,62 31320 3713.90 3768.00 6170.38 8408.71 -13820.18 HS 2.00 7.14 86.14 6062019.39 497711.71 8500.00 89.62 31320 3714.27 3766.37 6224.61 8446.43 -1386834 HS 0.00 7.14 86.14 6062057.04 497671.48 8600.00 89.62 31320 3714.93 3769.03 6323.03 8514.88 -1393324 HS 0.00 7.15 86.14 6062125.37 497598.49 8700.00 89.62 313.20 3715.60 3769.70 6421.44 8583.34 -14006.13 HS 0.00 7.15 86.14 6062193.71 497525.50 8800.00 8962 313.20 3716.26 3770.36 6519.85 8651.79 -14079.03 HS 0.00 7.16 86.14 6082262.04 497452.50 Gm 2/100 8867.26 89.62 313.20 3716.71 3770.81 6566.05 8697.83 -14128.06 179.791 0.00 7.16 86.14 6062308.00 497403.41 0P22-FN TGT13 887823 89.40 31320 3716.80 3770.90 6596.84 8705.34 -14136.05 179.899 2.00 7.16 85.92 6062315.50 497395.40 End Cry 8898.71 88.99 31320 3717.09 3771.19 6617.00 8719.36 -14150.98 HS 2.00 7.16 85.51 6062329.49 497380.45 8900.00 88.99 31320 3717.11 3771.21 6618.27 8720.24 -14151.92 HS 0.00 7.16 85.51 6062330.37 497379.51 9000.00 88.99 31320 3718.87 3772.97 6716.67 8788.69 -14224.80 HS 0.00 7.17 85.51 6062398.70 497306.53 9100.00 88.99 313.20 3720.63 3774.73 6815.07 8857.13 -14297.69 HS 0.00 7.17 85.51 6062467.02 497233.54 9200.00 88.99 313.20 3722.40 3776.50 6913.47 8925.58 -14370.57 HS 0.00 7.18 85.51 6062535.35 497160.56 9300.06 88.99 313.20 3724.16 3778.26 7011.87 8994.02 -14443.46 HS 0.00 7.18 85.51 6062603.67 497087.58 Cry 2/100 9357.11 88.99 31320 3725.16 3779.26 7068.06 9033.11 -14485.08 0.091 0.00 7.19 85.51 6062642.69 497045.90 9P22-FN1 70114 9382.59 89.50 313.20 3725.50 3779.60 7093.13 9050.55 -14503.65 19.54R 2.00 7.19 86.02 6062660.10 497027.30 9400.00 89.83 313.32 3725.60 3779.70 7110.27 9062.48 -14516.33 19.54R 2.0D 7.19 8633 6062672.01 497014.60 End Gm 9463.01 91.02 319.74 3725.14 3779.24 7172.22 9105.88 -14562.02 05 2.00 720 87.44 6062715.33 496968.85 9500.00 91.02 313.74 3724.48 3778.58 7208.55 9131.45 -14588.74 115 0.00 7.20 87.44 6062740.85 496942.10 9600.00 91.02 313.74 3722.71 3776.81 7306.78 9200.57 -14660.98 HS 0.00 7.20 87.44 6062809.86 496869.76 9700.00 91.02 313,74 3720.94 3775.04 7405.01 9269.70 -14733.22 HS 0.00 7.21 87.44 6062878.87 496797.42 Cm 2/100 9755.58 91.02 313.74 3719.95 3774.05 7459.61 9308.12 -14773.37 108.411 0.00 7.21 87.44 606291722 496757.21 9800.00 90.59 312.47 3719.33 3773.43 7503.33 9338.47 -14805.79 108.431 3.00 7.22 87.20 6062947.52 496724.74 6P22-F61 TGT15 9886.92 89.77 310.00 3719.05 3773.15 7589.34 9395.76 -14871.15 92.91 3.00 7.23 86.75 6063004.70 496659.30 9900.00 89.75 309.61 3719.10 3773.20 7602.33 9404.13 -1488120 92.891 3.00 723 86.78 6063013.06 496649.24 20000.00 89.60 306.61 3719.67 3773.77 7701.91 9465.84 -14959.87 92881 3.00 724 87.08 6063074.64 496570.48 20100.00 89.45 303.62 3720.50 3774.60 7801.83 9523.35 -15041.66 92.851 3.00 725 87.38 6063132.01 496488.61 2020800 89.30 300.62 372159 3775.69 7901.80 9576.51 -15126.34 92.821 3.00 7.26 87.69 6063185.03 496403.85 20300.00 89.15 297.62 3722.94 3777.04 8001.55 9625.16 -15213.68 92.781 3.00 7.27 88,00 6063233.55 496316.45 20400.00 89.01 294.63 3724.55 3778.65 8100.81 9689.18 -15303.45 92731 3.00 7.29 88.32 6063277.42 496226.62 20500.00 88.87 291.63 3726.40 3780.50 8199.31 9703.45 -15395.39 92681 3.00 7.30 88.65 6083316.54 496134.64 20600.00 88.73 288.63 3728.49 3782.59 8296.77 9742.85 .1548925 92.611 3.00 7.31 88.97 6063350.79 496040.73 End Cm 20654.68 88.66 286.99 3729.74 3783.84 8349.52 9759.57 -1554128 HS 3.00 7.31 89.15 6063367.43 495988.67 20700.00 88.66 286.99 3730.80 3784,90 8393.08 9772.81 -15584.62 HS 0.00 7.32 89.15 6063380.60 495945.32 20800.00 88.66 286.99 3733.15 3787.25 8489.18 9802.03 -15680.23 HS 0.00 7.32 89.15 6063409.67 495849.68 20900.00 88.66 266.99 3735.49 3789.59 8585.28 9831.24 -15775.84 HS 0.00 7.32 89.15 6063438.73 495754.03 21000.00 88.66 286.99 3737.84 3791.94 8681.38 9860.46 -15871.44 HS 0.00 7.33 89.15 6063467.79 495658.39 21100.00 88.66 286.99 3740.19 3794.29 8777.48 9869.66 -15967.05 HS 0.00 7.33 89.15 6063496.86 495562.74 21200.00 88.66 286.99 3742.53 3796.63 8873.59 9918.89 -16062.66 HS 0.00 7.34 89.15 6063525.92 495467.10 Cm 2/100 21271.04 88.66 286.99 374420 3798.30 8941.86 9939.65 -16130.58 45.71 0.00 7.34 89.15 6063546.57 495399.15 21300.00 89.26 286.37 3744.72 3798.82 8969.65 9947.96 -16158.32 45.69L 3.00 7.34 89.85 6063554.84 495371.41 SP22-FN1 ALT 21363.82 90.60 285.00 3744.80 3798.90 19030.57 9985.21 -16219.76 35.981 3.00 7.35 88.62 6063571.99 495309.95 TGT16 21400.00 91.48 284.36 3744.14 3793.24 19064.92 9974.38 -16254.75 35.99L 3.00 7.35 87.65 6063581.10 495274.94 End Cm 21433.15 9228 283.78 3743.06 3797.16 1909626 9982.43 -16286.89 HS 3.00 7.36 86.77 6063589.11 495242.80 21500.00 92.28 283.78 3740.39 3794.49 19159.34 9998.34 -16351.76 HS 0.00 7.36 86.77 6063604.91 495177.90 21600.00 92.28 283.78 3736.41 3790.51 19253.69 10022.14 -16448.81 HS 0.00 7.36 86.77 6063628.55 495080.83 0n2/100 2163721 92.28 283.78 3734.93 3789.03 19288.81 10030.99 -16484.92 86.031 0.00 7.37 86.77 6063637.35 495044.71 21700.00 92.41 281.90 3732.36 3786.46 19347.70 10044.93 -16546.09 86.11 3.00 7.37 86.35 6063651.19 494983.53 2180000 9281 278.9D 3727.97 3782.07 19439.93 10062.96 -16644.34 86.231 3.00 7.38 85.69 6063669.07 494885.26 SP22-FN1 ALT 21896.77 9280 276.00 3723.40 3777.50 19527.14 10075.49 -16740.18 82.81 3.00 7.39 85.07 6063681.45 494789.41 TGT17 21900.00 9281 275.90 372324 3777.34 19530.01 10075.83 -16743.38 62.81 3.00 7.39 85.04 6063681.78 494786.20 22000.00 93.18 27292 3718.01 3772.11 19617.70 10083.51 -16842.94 82.961 3.00 7.40 84.23 6063689.31 494686.65 End Cis 22066.26 93.43 270.95 3714.19 376829 19674.36 10085.74 -16909.04 HS 3.00 711 83.69 6063691.44 494620.55 22100.00 93.43 270.95 3712.17 3766.27 19702.92 10086.30 -16942.72 HS 0.00 7.41 83.69 6063691.94 494586.87 22200.00 93.43 271295 3706.20 3760.30 19787.53 1008795 -17042.53 HS 800 712 83.69 6063693.44 494487.07 22300.00 93.43 270.95 3700.22 3754.32 19872.15 10089.60 -17142.34 HS 0,00 7.42 83.69 6063694.93 494387.27 Gm 2/100 22368.93 93.43 270.95 3696.10 3750.20 19930.47 10090.73 -17211.13 138.891 0.00 7.42 83.69 6063695.96 494318.48 SP22-FNI ALT 22396.81 92.80 270.40 3694.60 3746.70 18953.83 10091.06 -17238.77 153.221 3.00 7.43 84.23 6063696.24 494290.84 TGT18 22400.00 92.71 270.35 3694.44 3748.54 19956.68 10091.08 -1724216 153221. 3.00 7.43 84.32 6063696.26 49428716 End en 22420.45 92.16 270.08 3693.57 3747.67 19973.86 10091.18 -17262.59 HS 3.00 7.43 84.82 6063696.30 494267.03 2250000 92.16 270.08 3690.57 3744.67 20040.60 10091.27 -17342.08 HS 0.00 7.43 84.82 6063696.29 494187.54 Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 2:34 PM Page 3 of 4 S Exclr4bn Zone Comments MD Mel Atlm Tr() iVD88 7VD VSEC NS EW TF DLS Direedonal Index Exclusion Zone Northing Eetlrlg (ft) r) (°) (ft) (ft) hl) (ft) (ft) r) (1100ft)Mashy Index Alert Angie 1 (MS) (ftLIS) Cry 2/100 22588.71 92.16 270.08 3687.98 3742.08 20098.24 10091.36 -17410.75 0.076 0.00 7.43 84.82 6063696.27 494118.88 22800.00 93.10 270.08 3688.54 3740.64 20124.48 10091.40 -17442.00 0.07R 3.00 7.44 83.89 6063696.27 494087.63 22700.00 96.10 270.08 3678.52 3732.62 20208.16 10091.54 -17541.67 0.076 3,00 7.45 80.92 6063696.25 493987.98 22800.00 99.10 270.09 3665.30 3719.40 20291.37 10091.69 -17640.78 0.070 3.00 7.46 77.96 6063696.24 493888.88 5P22-FN1 ALT 22896.66 102.00 270.09 3647.60 3701.70 20371.15 10091.83 -17735.79 HS 3.00 7.47 75.09 606369614 493793.87 TGT19 22900.00 102.10 270.09 3646.90 3701.00 20373.89 10091.84 -17739.06 HS 3.00 7.47 74.99 606369624 493790.61 23000.00 105.10 270.09 3623.39 3677.49 20455.49 1009139 -17836.24 HS 3.00 7.48 72.03 6063696.24 493693.43 23100.00 108.10 270.09 3594.83 3648.93 20535.94 10092.14 -17932.06 116 3.00 7.49 69.06 6063696.24 493597.62 23200.00 111.10 270.09 3561.28 3615.38 20615.03 10092.29 -18026,26 HS 3.00 7.49 66.10 6063696.24 493503.43 End Cm 23295.35 113.96 270.09 3524.75 3578.85 20688.97 10092.42 -18114.33 HS 3.00 7.50 63.28 6063696.24 493415.38 23300.00 113.96 270.09 3522.86 3576.96 20692.54 10092.43 .18118.57 HS 0.00 7.50 63.28 6063696.24 493411.13 Cry 2/100 23395.37 113.98 270.09 3484.13 3538.23 20765.72 10092.57 -18205.72 1.64R 0.00 7.51 6328 6063696.24 493323.99 6P22-FN1 ALT Tee 23396.68 . 114.00 270.09 3483.60 . 3537.70 • 20766.72 10092.57 .18206.92 3.00 7.51 63.24 6063696.24 493322.79 Surrey Type: Def Plan Survey Error Model: ISCWSA Rev 0"'3-D 95.000%Confidence 2.7955 afire Survey Program: MD From MD To EOU Freq Hole Size Casing Diameter Description (ft) (m (fl) (in) (lit) Survey Tool Type Borehole I Survey 0.000 41.000 1/100.000 16.000 13.375 SLBGVRO-MWD-Depth Only SP22-FN1/SP22-FN1(P5) Alternate TD 41.000 500.000 11100.000 16000 13.375 SLB GYRO.MWD SP22-FN11SP224'N1(P5) Alternate TD 500.000 2000.000 1/100.000 18.000 13.375 SLB MWDSTD SP22-FN1/SP22-FN1(P5) Alternate TD 500.000 3018.820 1/100.000 16.000 13.375 SLB MWO.GMAG SP22-FN1/SP22-FNI(P5) Alternate TD 3018.820 4500.000 1/100.000 12250 '9.625 SLB MWOSTD SP22-FN1/SP22.PN1(P5) Alternate TD 3018.820 12319.530 1/100.000 12250 9.825 SLB MWD.GMAG SP22-FN1/SP22-EN1(P5) A6emete TD 12319.530 13800.000 1/1 03000 8.750 5.500 SLB MWDSTD SP22-FN1/SP22-FN1(P5) Altemete TD 12319.530 23396.682 1/100.000 8.750 5.600 SLB MWD.GMAG SP22.FN1/SP22-FN1(P5) Alternate TD Legal Description: NoehlnotVI Fenno DO Surface:4451.4 FSL 1366.3 FEL 619 TI 4N ROE UM 6053633.080 511543.560 sp22-Inl 1911:3375 FSL 1126 FEL 14 T14N R8EUM 6057827.900 501416.300 9022-911 tgt2:3790 FSL 1415 FEL 14 714N R8EUM 6058242.100 501128.900 5022-9411913:4193 FSL 1718 FEL 14 T140 R8EUM 6058645.600 500826400 5922-0111814:4597 FSL 2020 FEL 14 714N R8EUM 6059049.000 500524.000 9022-Oil 7815:5000 FSL 2322 FEL 14 T1414 RHEUM 6059452.500 500221.600 6p2241119/6:124 FSL 2623 FEL 11 1146 R8EUM 6059856.100 499919.400 sp22-1n1 47:515 FSL 2939 FEL 11 1141.1 R8EUM 6060247.600 499603.700 sp22-6114$8:860 FSL 3306 FEL 11 T1414 R8EUM 6060592.300 499235.700 50224n119/9:1205 FSL 3674 FEL 11 1141.1 RBEUM 6060937.000 498887.700 9822-6/1 410 0:1550 FSL 4042 FEL 11 T1431 R8EUM 6061281.600 498499.600 sp22-811 7¢71:1894 FSL 4409 FEL 11 114N R8EUM 6061626.200 498131.600 sp22-811 t9112:2239 FSL 4777 FEL 1111414 RBEVM 6061970.900 497763.500 9022-019/13:2583 FSL 5145 FEL 11 T1414 RHEUM 6062315.500 497395.400 5022-10119/14:2928 FSL 233 FEL 101141Y RBEUM 6062660.100 497027.300 902 2-011 1911 5:3272 FSL 600 FEL 10 T140 R8EUM 6063004.700 496659.300 0022 431 6918116:3839 FSL 1949 FEL 1011414 R8EUM 6063571.990 495309550 5022 311 6619117:3948 FSL 2470 FEL 10 T1414 R8EUM 6063681.450 494789.410 9022 411 all 19118:3962 FSL 2968 FEL 10 T1414 R8EUM 6063696.240 494290.840 5022451 aft 78119:3982 FSL 3465 FEL 10 T1414 R8EUM 6063696.240 493793.870 891:3962 FSL 3937 FEL 10 T1414 R8EUM 6063690.240 493322.790 Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 2:34 PM Page 4 of 4 o Oa Oa o 8 8 K CD - 0 c. am z | = ! o 32 o cA & a ■■ ° COD 2'rf 19 ¥.� 4 \ i i * � ° ` . § e 0 ! . . . r! ■ cl as in i C £ @ 4 . o o N! o o § I!! . o o § , § § . 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N •o� . 4 ° •1 i, ' • ° Lta ,- L 0a U) T�`p� •91''d!f trf o�49:i a sf•N •p�s99 N ••4 z•p�r6 P9 cr oN col if6> •O•r ss9� CO d 6' o • QAI969 H 0,4, u 0 co N °o °o °o ° °o °o •c a R ►n T 8 M M 8 li, ,t, T- EP U «< N (4)000£'l =oleos S >>> N N d 0) I Schlumherper SP22-FN1 (P5)Alternate TD Anti-Collision Summary Report 'in 0 Analysis Date-24hr Time: October 15,2012-1705 Analysis Method: 3D Least Distance Client: Eni Petroleum Reference Trajectory: SP22-FN1(P5)Alternate TD(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Spy Inland Rule Set: D&M AntiCollision Standard 5002 85.1/5.2 Slot: SP22 Min Pts: WI local minima indicated. Well: SP22-FNI Borehole: SP22-FN1 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Global within 64407.18 It Selection filters: Definitive Surveys-Definitive Plane-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Del-Survey is set in a borehole-All Non-Del Plans when no Del-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU MI Dee.(ft) Fact. Rule MD(ft) I TVD lft) Alert I Minor I Maier SP23-N3(Del Survey) Waning Mart 8.09 6.70 6.87 1.40 N/A INAS.2.04(m) 0.00 0.00 CICt<=15m•75.00 Eater Alen 1 6.70 5.901 1.141 9.29 MAS•2.04(m) 160.00 160.00 MinPts 8.11 6.701 5. 1.42 5.51 MAS•2,04(m) 230.00 230.00 MINPT-O-EOU 1095 6.70 7.29 4.27 MAS•2,04(m) 320.00 319.98 MinPt-O-SF 47.01 9.91 39.89 37.10 7.90 OSF 1.50 530.00 52 973 CtCt<=15m•15.00 Ea Alert 1088.92 101.60 1020.87 987.331- .41 OSF 1.50 559000 2918.12 MinP1-0-SF WIER 78.57 763.15 737.54 15.90 OSF 1.50 6560.00 3053.32 Mi1Pt-C1Ct 818.63 85.4.=TM 733.21 14.65 OSF 1.50 6640.00 3065.99 MINPT-0-EOU 827.06 94.77 763.<MEM 13.31 OSF 1.50 6740.00 3090.07 MinPt-O-ADP 844•92 120.a ELM 724.59 10.67 OSF 1.50 6970.00 3112.46 MINPT-0-EOU 850,10 126.48 765.1•=ZEE 10.20 OSF 1.50 7040.00 3122.32 MinPt-0-ADP 1053.43 193.48 923.86 859."x- OSF 1.60 7960.00 3251.88 MinPt-0•SF 1093.44 200.67 959.07 892. 08F 1.50 8080.00 3288.78 MinPt-O-SF 1172.15 219.63 1025.15 952. OSF 1.50 8310.00 3301.17 MinPt-0-SF 1251.05 233.92 1094.51 1017.1 �-yl OSF 1.50 8540.00 3333.56 MinPI-0-SF 1578.15 274.46 1394.5- Ia7/ OSF 1.60 9430.00 3458.90 44iriFt. 1924.00 300.34 1723.19 1623.:•�• OSF 1.50 10260.00 3575.78 MinP1-0-SF 2185.78 326.75 1967.36 1859.'•Mg= 08F 1.50 10960.00 3669.37 MinPt-O-SF 12050.03 149.47 11949.85 11900.56 122.24 OSF 1.50 23396.68 3537.70 TD SP23-N3PB1(Del Survey) Weming Alert t� 8.09 6.70 6.87 1.40 WA MAS•2.04(m) 0.00 0.00 CrCt<=15m<15.00 Enter Alert 1 °'1 6.70 5. 1.14 9.29 MAS•2.04(m) 160.00 160.00 MinPts 8,11 6. 5. 1.42 5.51 MAS•2.04(m) 230.00 230.00 MINPT-0-EOU 10.96 6.70 7.29 4.271 MAS•2.04(m) 320.00 319.98 MinPt-O-SF 47.01 9.91 39.99 37.10 7.90t OSF 1.50 530.00 528.73 CtCt<=15m•15.00 Eva Wert 1088.92 101.60 1020.87 987.331 21 OSF 1.50 5580.00 2918.12 68401•0-SF 1. 725.36 689.25 11.04 OSF 1.50 6730.00 3078.66 MnP1-0tCt 800.66 116.8 723.'• 684.80 10.44 OSF 1.50 6790.00 3087.11 MINP1-0-EOU 803.40 119.18 723.w.WZIEn 10.18 OSF 1.50 6820.00 6081.34 I8ri01.0-ADP 892.27 148.60 792.87 743.. 9.': OSF 1.60 7130.00 3134.99 MinPt-O-SF 15778.87 149.70 15678.74 15629.17 159.14 OSF 1,60 23396.68 3537.70 TO 5120-N4PN(Def Survey) Warning Alert 15.93 12.99 14.71 2.94 N/A MAS•3.96(m) 0.00 0.00 CIC1<•15m<15.00 Enter Wert 1 15.551 1299 13.71 MIKE 23.07 MAS.3.96(m) 210.00 210.00 MinPts 15.58 12''MEM 2.59 21.54 MAS•3.96(m) 220.00 220.00 MINPT-0-EOU 24.97 1299 21.50 11.981 59 MAS•3.96(m) 360.00 359.93 MinPr-O•SF 49.05 12.99 44.14 36.06 12.98 MAS•3.96(m) 460.00 459.47 CICts=15m•15.00 Ea Alert 2183.55 20.39 2169.60 2163.1 @ OSF 1.50 3080.00 2454.63 MinPt-0-SF 2727.75 2227 2712.55 2705 OSF 1.60 368.00 2643.97 MinP1-0-SF 2970.70 24.46 2%4.04 2946, MEM, OSF 1.50 3910.00 2681.53 MinPt-O-SF 3374.58 26.79 3356.36 3347.• 1%.71 OSF 1.50 4340.00 2742.09 MinPt-O-SF I 10816.83 31.75 10795.10 10784.:• 528.-• OSF1.50 12080.00 3747.82 MinPt-O-SF 11030.44 32.44 11008.45 10997.'• 527.• OSF 1.50 12310.00 3760.90 MinPl-0•8F 12260.85 82.38 12247.93 12227.• 300. OSF 1.50 13818.44 3781.63 MinPt-O-SF 13176.06 65.84 13131.83 13110.21 304.' OSF 1.50 14830.62 3789.91 44651-0SF 14150.31 70.97 1410273 14079. 303.• OSF 1.50 15920.00 3806.87 MinPt•0•SF 21077.10 79.38 21023.65 20997.72 403.25 OSF 1.60 23396.68 353770 TD 5120-N4(Del Survey) Warring Alen 15.93 12.99 14.71 2.94 N/A MAS•3.96(m) 0.00 0.00 CrCt<•15m015.00 Enter Wert 1 15.551 12.99 13.71 2. 23.07 MAS•3.96(m) 210.00 210.00 MinPts 15.58 12. 13.6 2.59 21.54 MAS•3.96(m) 220.00 220.00 MINPT-0-EOU 24.97 12.99 21.50 11.-:MEIEJ MAS•3.96(m) 360.00' 359,93 MinPt-O-SF 49.05 12.99 44.14 36.06 12.98 MAS•3.96(m) 460.00 459.47 CtCt<•15m•15.00 Ea Alert MILLE 37.31 1271.96 1259.87 53.52 OSF 1.50 38800 2668.86 MerPt-CICI • 1297.83 39."MINK 1258.83 51.18 OSF 1.50 3870.00 2675.90 MINPT-0-EOU 'i 1299.33 40.80 1271.:' . 48.91 OSF 1.50 3920.00 2682.94 MinPI-0-ADP 1308.06 56.'0 MEM 1251.98 35.59 OSF1.50 4190.00 2720.96 MINPT-0-E06 1311.41 60.04 1271..:MEMEL 33.29 08F 1.60 4260.00 2730.82 MinPI-0-ADP 1841.98 164.85 1731.75 1677.1.�-:0, OSF 1.50 6560.00 3054.72 MinPt-O-SF 1977.57 176.19 1859.78 1801.:MOLE. OSF 1.50 6910.00 3104.01 MinPt-0SF 2117.86 190.98 1990.21 1926.:_MEM OSF 1.50 7260.00 3153.30 MinPt-0SP 2255.30 205.76 2117.79 2049. OSF 1.50 7610.00 3202.59 MinPt-0SF 2437.46 226.17 2296.35 2211. MIEM OSF 1.50 8080.00 3268.78 MinPt-0•SF 2570.62 242.14 2408.87 2329•I OSF 1.50 8480.00 3325.11 MinPt-O-SF 2932.71 264.62 2755.97 2668.'•I) OSF 1.50 9440.00 3460.30 MinPt-O-SF 3170.12 278.44 2184.17 2891.:•MIME OSF 1.50 9970.00 3534.94 MinPt-O-SF 3352.93 2%.' '-'r^-Mi1M OSP 1.50 1038.00 3599.86 MinPts 3604.53 353.: <:`: OSF 1.50 10990.8 3672.73 MinPts 3660.06 347.•'MMEE, 3312.36 15.8 OSF 1.50 11620.00 3724.79 MINPT-0-EOU 346.74 3428.24 3312.99 15.87 OSF 1.50 11670.8 3727.41 MinPl-CtCt 12474.62 136.16 12383.52 12338.46 138.42 OSF 1.8 23396.68 3537.70 TD SP24-SE1 1721(Del Nan) Weminp tart 16.04 13.08 14.81 2.96 WA MAS•3.99(m) 0.00 0.00 CICI<=15m<15.8 Eater Alert 1-11 198 14.01 • 18.37 MAS•3.99(m) 28.00 28.00 MinPts 16.44 13.'0 MOM 3.37 7.47 MAS•3.99(m) 370.00 369.90 MINPT-0-EOU i 17.34 13..:MEM 4.26 5.21 MAS•3.99(m) 430.00 429.67 MINPT-0-EOU ' 21.17 13.08 14.66 8.101 MAS•3.99(m) 560.8 558.27 MinPt-O-SF ' 49.12 13.08 41.97 36.05 8.08 MAS•3.99(m) 960.8 929.49 CtCt<•15m>15.8 Ea Alert 212.53 64.8 169.8 147.73 4.97 OSF 1.50 3520.00 2616.56 OSF<5.00 Enter Alert 18.1• 36.42 2.05 OSF 1.50 3710.00 2653.37 MinPts 136.67 10025 69.51 EEZI OSF 1.50 3720.8 2654.78 MinPts 218.82 68.95 172.53 149.87 4.81 OSF 1.50 3900.8 2680.12 OSF>5.00 Ea Alert 9643.80 66.33 9599.25 9577.4 OSF 1.50 13816.44 3781.63 Minh-O-SF 11337.72 76.36 11213948 11261.•MI= OSF 1.8 15680.00 3810.03 Minh-0-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 1 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major 18636.90 82.15 18581.81 18554.75 344.43 OSF 1.50 23396.68 3537.70 TD 13119dN2(02)(De Plan) - Warning Alert 23.97 19.42 2274 4.55 N/A MAS•5.92(m) 0.00 0.00 CtCt<=15m<15.00 Enter Alen r 7I 19.42 21.•'11111ME 28.30 MAS=5.92(m) 200.00 200.00 MinPls 25.27 19.42 M-t 5.85 3.77 MAS•5.92(m) 600.00 597.49 MINPT-0.EOU 3901 26..=® 12.92 228 OSF 1.50 1310.00 1238.89 MINPT-O-EOU 42.39 30.•r 11.40 207 OSF 1.50 1410.00 1317.03 MINPT-O-EOU 66.10 65.02 22.35 MIMEO® OSF 1.50 2000.00 1746.95 Miners 191.36 58.38 152.08 132.98 4.98 OSF 1.50 2980.00 2403.77 OSFe5.00 EAt Alen 516.61 146.31 418.75 370.31 IIIMM OSF 1.50 4500.00 2764.62 MInP1-0-SF 2148.72 352.67 1913.28 1796..•E OSF1.50 10830.00 3653.96 MinPt-O-SF 1476.73 443.72 1180.59 1033.01 5.00 OSF 1.50 14670.00 3788.32 OSF<5.00 Enter Alen IM ME 481.72 902.79 742.54 3.82 OSF1.50 16200.00 3801.48 MinPt-CICt Ipj .-mil 589.80 702.71 506.77 2.79 OSF 1.50 19850.00 3773.11 MinPt-CtCt 109898 590.•=MUIE 50894 2.79 OSF 1.50 19890.00 3773.16 MINPT-O-EOU 1096.49 590.68 702.:MITE. 2.79 OSF 1.50 19910.00 377125 MinPt-O-ADP 1098.68 592.26 703.51 506.4. 2.: OSF 1.50 19960.00 3773.51 MinP1-0-SF 2133.13 641.82 1704.93 1491.32 4.99 OSF 1.50 22380.00 3749.57 OSFe5.00 E>a1 Alert 2950.53 591.87 265.63 2358.67 7.49 OSF 1.50 23396.68 3537.70 TO 5125-N2(Del Survey) '1 Warning Alert 39.151 31.71 N/A MAS.9.67(m) 0.00 0.00 CtCr<=15m<15,00 Enter Alen 39.7 31.71 36..:®. 33.41 MAS=9.67(m) 280.00 279.99 MinPts 39.99 31.71 36..: 8.28 21.25 MAS=9.67 DA) 360.00 359.93 MINPT-0-EOU 48.76 31.71 4235 17.05 10.42 MAS.9.67(m) 490.00 48921 CtCt<•15ma15,00 EA Alert 53.44 31.71 46.43 21. MEE MAS=9.67(m) 520,00 518.87 MinPt-O-SF 2378.49 149.24 2278.41 2229..-MIR OSF 1.50 4440.00 2756.17 MinPt-O-SF 2354.88 144.73 2257.80 2210.1 246• OSF 1.50 4480.00 2761,80 MinPt-O-SF 518.23 156.73 413.15 361.501 5.00 050 1.50 8280.00 3296.94 000<5.00 Enter Ned 447.65 139.6 353.96 308.001 a>, OSF 1.50 8550.00 3334.97 Mino1-0-SF 383.32 116.30 30520 267.02 5.00 OSF 1.50 8830.00 3374.40 OSF>5.00 EMI Alert 339.28 103.39 269.76 235.89 4.98 OSF 1.50 911000 3413.83 OSFeS.00 Enter Alert 1-77 127.78 24230 200.29 3.88 OSF 1.50 9290.00 3439.18 Mint-CICt 361.49 208.L=MalEfi 152.64 2.61 OSF 1.50 9620.00 3485.65 MINPT-0-EOU 369.88 218.48 223.6'Man 26 OSF 1.50 9670.00 3492.69 MinPl-0-ADP 391.74 235.36 234.25 156.:MEE OSF 1.50 9770.00 3506.78 MinP1-0-SF 97090 313.24 763.48 659..: 050 1.50 1132000 3704.63 MinPt-0SF 996.73 300.92 79553 695.82 4.99 OSF 1.50 1141010 3711.60 OSF=5.00 Etd Alit 11776.38 101.46 11708.20 11674.92 176.89 OSF 1.50 23396.68 3537.70 TD SP18-N5(DN Survey) Warning Alert NICE 32.2 MIR I/WM N/A MAS•9.83(m) 0.00 0.00 CIC1<•15m<15.00 Enter Alen MEE 32.24 38.' 48.95 MAS.9.83(m) 21000 21000 Miners 4037 32 M•, 8.14 40.79 MAS•9.83(m) 240.00 240.00 MINPT-0-EOU 4803 32.24 45.14 16.79 17.96 MAS•083(m) 420.00 419.72 CtCI<•15m:15.00 Ei Alert 5838 32.24 53.62 26.1 111.113E MAS.9.83(m) 48000 479.31 Ming-0-SF 91.24 2086.63 2056.6 35.68 OSF 1.50 3370.00 2573.11 MnPt-CIC1 214835 92.. ME= 2055.68 35.13 OSF 1.60 3410.00 2585.92 MINPT-0-EOU 2149.02 93.42 2666.41 34.6 OSF 1.50 3430.80 2591.99 Mn1N-0-ADP 2173.43 16.:-MEEE MERU 31.07 OSF 1.50 3660.00 2645.68 MinPts 2384.67 147.43 2286.06 2237.2 OSF 1.60 4600.00 2778.70 Min%-0.SF 2450.13 150.37 2349.56 2299.7:IM ME; OSF 1.50 4830.00 2811.09 MinPt-O-SF 286765 170.79 275146 26 96.,MEM OSF 1.50 5930.00 2966.00 Min111-0.SF 2923.74 176.49 2905.75 2747.2 MEM OSF 1.50 6070.00 2985.72 Min%-0.SF 3254.01 200.••!M OSF 1.50 6840.00 3094.15 MinPts 3470.17 217.36 3324.93 3252.81 MLU OSF 1.50 7400.00 3173.02 MinPt-O-SF 360.64 240.'=NEM elmmE 2291 OSF 1.50 7880.00 3240.61 MinPts 3705.80 243.61 3543.07 3462•3 OSF 1.50 8030.00 3261.74 Mine1-0.SF 41686 266.23 4009.1'MMIai 23.67 OSF1.50 9240.00 3432.14 Min%-O-ADP 427187 275.23 4089.6 3998. M OSF 1.50 9440.00 3460.30 M1nP1-0.SF 4668.32 2911•MEIMEEMIIE MEM OSF 1.50 10310.00 3582.82 MinP1s 484284 312.26 4634.33 4530. 000 1.50 10710.00 3638.60 Mine0-0.SF 494857 324.08 4733.19 4625.•'MM OSF 1.50 11100.00 3684.43 MInP1-0.SF 497032 320.01 4756..- 23.36 OSF 1.50 11830.00 3735.78 t4nF0-0-ADP 497024 319.••=FOE 4650.32 23.37 000 1.50 11840.00 3736.30 MINPT-O-EOU 319.62 476.71 4650.50 23.99 OSF 1.50 11870.00 3737.87 M6Pt-CICt 1306.13 165.20 12995.67 12840.93 118.79 OSF 1.50 23396.6 3537.70 TD 5P19'N5PB1(De Survey) Wareing Alert MEE 322 MEER N/A MAS•9.83(m) 0.00 0.00 CICl<=15m<15.00 Etter Nett 3224 38..: 48.95 MAS•9.63(m) 210.00 210.00 Mints 40.37 322 38.1• 8.14 40.79 MAS•9.83(m) 240.00 240.00 MINPT-0-EOU 49.03 3224 45.14 16.79 17.96 MAS•9.83(m( 420.00 419.72 CtCl<=1SrrrlS00 Exit Alert 58.38 32.24 53.62 26.151 16.151 MAS•9.83(m) 480.0D 479.31 Mittel-01F MffELE 91.24 2066.63 206.6 35.68 OSF 1.50 3370.00 2573.11 McPI-CICt 2148.35 92- 7.. 2055.68 35.13 OSF 1.50 3410.00 258892 MINPT.0-EOU 2149.02 93.42 2086.41' 34,86 OSF 1.50 3430.00 2591.99 MinPt-O-ADP 2173.43 16.:x'MOE II.Saa 31.07 OSF 1.50 3660.00 2645.68 MinPts 236.18 144.39 2291.60 2243.:•Mfla 050 1.50 4600.00 2778.70 Ming-0SF 2828.30 170.. 1 :r. 24.99 OSF 1.50 5690.00 233220 MinPts 3006.70 189.70 2879.91 2817.•• 050 1.50 6220.00 3006.84 Mitte1-0SF 8170.44 131.79 808225 8038.:=1111111EIE OSF 1.50 13800.00 378207 MinPt-0-9F 16810.98 119.97 16730.67 1661.01 211.92 050 1.50 23396.68 3537.70 TO 5117-5E2 1110(Del Plan) Wiling Met 48.00 32.81 46.78 15.19 WA MA5.10.00(m) 0.00 0.00 CtCt..15m<15.00 Enter Alert M-.r. 32.81 45. 15.151 58.04 MAS•10.00(m) 200.00 200.00 MinPle MOE 3281 34. 11.811 5.10 MAS•10.00(m) 780.00 771.15 MinPrs 45.12 32.811 34.41 1232 4.63 MAS.10.00(m) 860.00 846.46 MINPT-0-EOU 5146 3281 39.26 20.:- MAS•10.00(m) 1080.00 1045.78 MinPt-O-SF 56.26 32.81 41.35 23.:MILE MAS.10.00(m) 1120.00 1080.59 MinPt-0-SF 105.40 3281 8119 72.59 4.97 MAS.1003(m) 1530.00 140548 OSFM.00 Exit Alen _. 245.99 75.6 1%.63 170.94 4.96 OSF 1.50 3060.10 2444.86 OSF6.00 Enter er Ale 1 , 87.51 16.47 139.62 3.92 OSF 1.50 320000 2509.02 Min1-C1C1 227312 6.•: 16.= 139.26 3.90 OSF 1.50 3210.00 2513.22 MINPT-0-EOU 227.77 88.53 168. •MOE 3.89 OSF 1.50 322100 2517.36 MinPl-0-ADP 228.48 88.91 168.6 139. 3.:: OSF 1.50 3230.00 2521.45 Min%-0-SF 27652 84.45 219.89 19207 4.95 OSF 1.50 3390.00 2579.62 5505.00 Eot AIM 1003245 64.32 1003924 10018.1 5. •v 050 1.50 13816.44 3781.63 Min111-0.SF 11751.85 71.36 1170194 11680. OSF 1.50 15700.00 3809.91 MinPt-O-SF 190326 80.48 18978.90 18952.40 35809 OSF 1.50 23396.68 3537.70 TO SP27-N7(Del Survey) Warning NM MEE 32.81 MIEM MOE N/A MAS=10.00(m) 0.00 0.00 MinPts 48.6 32.81 44.15 16.07 13.58 MAS=10.00(m) 470.00 469.39 CtCt<15m<15.00 Enter Alen 1 40.031 32.81 42 15. 9.84 MAS•1500(m) 520.03 518.87 Miners 48.13 32.81 41. 15.32 9.44 MAS•1000(m) 53010 528.73 MINPT-0-EOU 49.14 32.81 42.34 16.33 859 MAS•10.00(m) 560.00 558.27 Ctct<=15ms15.00 Eml Alert 5255 32.81 45.05 19.7417 MMS•1000(m) 600.00 597.49 MinPt-O-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 2 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I 608(ft) Dev.(ft) Fact. Rule MD Ift) I TVD(ft) Alert I Minor I Major 2547.31 32.81 253202 2514.50 178.•• MAS•10.00(m) 3630.00 2640.38 MinPI-0-SF 2575.07 70."Wag 2504.57 55.54 OSF 1.50 3660.00 2645.68 MinPts 3035.78 143.01 2940.11 2892.77 32.. OSF 1.50 4530.00 2768.85 MinP1-0-6F 3026.24 141.80 2931.37 2884.44 32.23 OSF 1.50 4550.00 2771.66 MinP1-0-5F 2331.45 173.10 2215.72 2158.35 20.31 OSF 1.50 6000.00 2975.86 MinPt.0-SF 2053,33 195.11 1922.9• 1856.23 15.., OSF 1.50 6840.00 3094.15 WPM 1047.36 301. /111=E MECI3E, OSF 1.50 10030.00 3543.39 MinPts 868.23 261.24 693.74 606.99 5.00 OSF 1.50 10300.00 3581.41 OSF•.00 Enter Plea =EOM 333.56 169.77 58.91 1.77 OSF 1.50 11160.00 3690.37 MinPt-CtCt 394.48 341.,IIIIIEEE 53.12 1.73 OSF 1.50 11200.00 3694.15 MINPT-0•EOU 395.76 34177 168.:. OSF 1.50 11210.00 369600 MinPts 913.66 274.96 730.02 638.70 5.00 OSF 1.50 11920.00 3740.49 OSFs5.00 Edt Alert 11637.69 138.30 11545.16 11499.39 127.11 OSF 1.50 23396.60 3537.70 TD SP16-FN3(Del Survey) Warning Alert 56.93 32.81 54.01 23.12 N/A MAS•10.00(m) 0.00 0.00 Surleoe r� 32.81 50.1:=En 31.85 MAS•10.00(m) 320.00 31498 MinPts 53.86 32.81 MME 21.05 26.26 MAS•10.00(m) 360.00 359.93 MINPT-0-EOU 54.81 32.81 MEE 22.00 17.69 MAS•10.00(m) 430.00 429.67 MINPT-0-EOU 59.88 32.81 52.31 27.0726 MAO.10.00(m) 600.00 597.49 MinPt-03F 111.94 35.04 87.94 76.90 4.98 OSF 1.50 1458.33 135340 OSF<5.00 Enter Alert 164,62 64.17 121.21 100.451 3.921 OSF 1.50 2000.00 1746.95 MInP1-0-SF 252.23 77.25 200.09 174.98 4.98 OSF 1.50 2800.00 2300.15 OSF•5.00 E4t Alert 579,42 123,64 496.40 455.7:® OSF 1.50 4020.00 2697.02 MinP1-0-SF 707.85 153.09 605.20 554.7, 16Fa OSF 1.50 450400 2764.62 MinPt-0-SF • 1731.51 235.85 1573.69 1495... OSF 1.50 7920.00 3246.25 MinP4O-SF 2056.35 270.04 1875.73 1786.31 111111111nE 06F 1.50 9010.00 3399.75 MinPt-0-SF 2243.00 289.60 2049.21 1953.-' OSF 1.50 960000 3482.84 MinPt-0-SF 2319.91 299.56 2119.62 2020.,MalE, OSF 1.50 9890.00 3519.45 MinPt-0-SF 2433.96 313.08 2224.66 2120.:. i1- OSF 1.50 10250.00 3574.37 MinPt-0-SF 2489.07 319.43 2275.53 2169.• I OSF 1.50 10440.00 3601.13 Min19-0-3F 2530.29 340.90 230268 2189.,11.111E OSF 1.50 12319.53 3761.40 MnP1-0-SF 2408.14 362.13 2166.19 2046.01®'' OSF 1.50 13450.00 3791.56 86,511-0-SF 2406.12 361.62 2164."MK= 10.02 OSF 1.50 13570.00 3788.31 Min%-0-ADP 2406.08 361.. 2 2044.50 10.02 OSF 1.50 13580.00 3788.04 MINPT-0-EOU 0.1 361.49 2164.52 2044.56 10.02 OSF 1.50 13900.00 3787.49 MnPI-CICI 2362.22 384.66 2125.24 1997..fir- OSF 1.50 14290.00 3784.54 Min19-0-SF 2375.72 389.50 2115.51 1986.,MIME OSF 1.50 14760.00 3789.21 Min1,1-0-OF 1 vy 450.86 1971.93 182218 7.58 08F 1.50 16180.00 3901.88 MinPt-CICI 2273•23 451.'IllialilE IIMIEUM 7.57 OSF1.50 18210.00 3801.27 MinPts 1 341 463.68 1967.88 1813.66 7.39 OSF 1.50 16870.00 3768.54 MinPt-C1CI 2278.79 468.•' ` 1810.19 7.31 OSF 1.60 17090.00 3763.90 MINPT-0•E0U 2279.23 48913 1965.••MIME 7.31 OSF 1.50 17130.00 3763.10 MinPt-0-ADP MIME 546.06 1760.11 1578.63 5.85 OSF 1.50 19770.00 3773.81 M6PI-CtCt 2124.92 546.:•ME1 ,11 1578.08 5.84 OSF 1.60 19800.00 3773.43 MINPT-0-EOU 2125.34 547.35 1759.•'M11E, 5.84 OSF 1.50 19820.00 3773.25 MInPt-0-ADP 2129.93 549.22 1763.24 1580.71 3 OSF 1.50 19910.00 3773.25 MinPt-0-SF 2142.99 553.19 1773.66 1589..' OSF 1.50 20030.00 3773.99 MinPt-O•SF 2182.61 558.34 1809.85 1624. IIIIIIEE OSF 1.50 27230.00 3776.07 MinP1-0-SF 2339.13 570.66 1958.1:M1.15D^yam OSF1.50 2650.00 378373 MinPts 2383.62 578.23 1997.,NEM=KM 7 OSF 1.50 21750.00 3786.08 MinPts 2579.33 589.91 2185.52 1989. OSF 1.50 2119100 3796.40 MInPI-0-SF 2926.27 671." 6.54 OSF 1.50 21960.00 3774.28 MinPts 293205 675.76 2481.01 2256.-, LL- OSF 1.50 21970.00 3773.75 MIn1.4-0-SF 3967.63 645.97 336.44 3321.66 9.23 OSF 1.50 23396.68 3537.70 TD 5113-FN4(P5)(Del Plan) WarNng Alert 79.90 32.81 78.66 47.10 N/A MAS•10,00(m) 0,00 0.00 Surface r 90 32.81 77.87 47.101 97.64 MAS•10.00(m) 200.00 200.00 MinPts 80.72 32.81 77.28 47.91 35.89 MA5.10.00(m) 380,00 379.88 MINP1'-O-EOU 82.78 32.81 76.54 49.97 16.26 MAS•10.00(m) 500.00 499,10 MINPT-0-E00 206.79 62,90 164.45 143.89 5.00 OSF 1.50 1760.00 1574.75 OSF<5.00 Enter Alen 243.90 80.45 189.87 163.46 69 OSF 1.50 2000.00 1746.95 MinPt-0-SF 278.39 84.55 221.62 193.84 4.99 06F 1,50 2220.00 1901.85 OSF•5.00 Fit Alert 999.38 146.82 901.18 852. Emilm OSF 1.50 4500.00 2764.62 MinPt-0-OF 3520.99 293.59 3424.93 3327.• 11: • OSF 1.50 11050.00 3679.24 MinPt-0-SF 3613.07 296.16 3415.31 3316,'0,I OSF 1.50 12030.00 3746.25 MinPt-0-OF 361213 295.•.ManE NZ= 18.36 OSF 1.50 12120.00 3750.96 MinPts j] 295.95 3414.45 3316.16 18.36 OSF 1.50 12130.00 3751.48 M4tPt-CtCt • 3602 a 30110 340118 330114 1100 OSF 1.50 12970.00 3791.33 MNPI-CICt 3605.14 310,MEIEZM 3294.46 17.46 OSF 1.60 13390.00 3793.71 MINPT-O-EOU 390825 312.11 3397..- 3 17.38 OSF1.50 13410.00 3792.64 MInP1-O-ADP 361233 317.91 3400.., +®' 17.09 OSF 1.50 13860.00 3785.87 MinPt-0-ADP 3698.05 347.70 3365.92 3250. 15., OSF 1.50 14830.00 3789.90 MinPt•0-SF 5 367.05 3236.53 3114.51 14.26 OSF 1.50 16200.00 380148 MnPI-Ctet 3481.58 367.1• y/5"• 3114.44 14.26 OSF 1.50 16210.00 3801.27 MINPT-0-EOU 3481,65 367.24 3236.'/EEO 14.26 OSF 1.50 16220,00 3801.07 MinPt-0-ADP 425.10 307168 2929.31 11.86 OSF 1.50 19850.00 3773.11 M8Pt-CtCt 3354.63 425,51 WIDE 2929.03 11.85 OSF 1.50 19870.00 3773.11 MINPT.0•E00 3354.86 425,92 3070.•.x'-•n, 11.84 OSF 1.50 19890.00 3773.16 MinPt-0-ADP 338280 43126 3094.30 2950.- 11.7, OSF 1.50 27180.00 3775.46 MinPt-0-SF 5126.40 464,97 4818.09 4663.43 16.58 OSF 1.50 23396.68 3537,70 TD SP3aW 1(P7b)(Def Plan) Pap 79.16 32.81 77.93 46.35 N/A MAS•10.00(m) 0.00 0.00 Surface 3281 61. •MIME 11.44 MAS•10.00(m) 550.00 548.43 MinPts 6896 3281 MEM 36.15 10.62 MAS•10.00(m) 570.00 568.09 MINPT-0-EOU 71.77 3281 63.35 38... MAS•10.00(m) 62100 617.03 MnPt-0-SF 300487 98.,Miliald MEM 46.23 002 1.50 4160.00 2719.56 MinPts 329080 118,64 3211.24 3171..,Man OSF1.50 4580.00 2775.89 86nPt-0-SF 1985.28 255.84 1814.39 1729. 11.,: OSF 1.60 9920.00 3527.90 MinPt-O-SF ® 291.65 1017.55 920.67 6.25 OSF 1.50 12480.00 3769.76 MnPt-CICI 1212.45 2921.INZIEfilE5 920.32 6.24 OSF 1.60 12510.00 3771.30 MINPT-O-EOU 1212.58 292.29 1017.:WX.K, 6.24 OSF 1.50 12520.00 3771.81 MinPt-O-4DP 1214.73 293.39 1018.81 921.. 6. • OSF 150 12590.00 3775.37 MInP1.0-SF 1248.04 305. •MIME 942.71 6.15 OSF 1.50 13150.00 3792.86 MINPT-0-EOU 1249.48 319.6 '�•'ID•' 1MMZU OSF 1.50 13810.00 3787.22 MinPts MiELIM 32128 1033,86 926.86 5.83 OSF 1.50 13650.00 3786.14 M1nPt•CICI 1251.97 331., 1030.:• 920.71 5.68 OSF 1,50 13730.00 3783.97 MINPT-0-EOU 1255.30 335.34 1031,41 MGM 5.63 OSF 1.50 13770.00 3782.89 MinP1.0-ADP 1274.89 344.69 1044.77 930.20 5.. OSF 1.50 13900.00 3780.58 Min%-0-SF 8905.86 170.65 8791.77 8735.21 78.73 OSF 1.50 23396.68 3537.70 TD 5129-S2(Del Survey) IWe 71.18 32.81 69.27 38.38 N/A MAS=10.00(m) 0.00 0.00 Suleee 70.92' 32.81 68.• 38.1• 135.72 MAS•10.00(m) 150.00 150.00 MinPts 71.44 32.81 M,-r'• 38.63 5697 MAS•10.00(m) 280.00 27999 MINPT-0.EOU • 7398 32.81 .,. 41.18 19.95 MAS.10.00 On) 500.00 499.10 MINPT-0-EOU 32.81 66.4- 40... 15.95 MAS•10.00(m) 650.00 646.23 MinPts • Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 3 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I HAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Mina I Major 7283 3281 66.44 40.02 15.87 MAS=10.00(m) 660.00 655.94 MINPT-0-EOU 195.31 47.99 16268 147.• 6.r OSF 1.50 2000.00 1746.95 Ming-OSF 83272 109.77 758.95 722'=MiliU OSF 1.50 4380.00 2747.72 Ming-O-SF 913.57 12285 831.09 790. .MIK OSF 1.50 4600.00 2778.70 Ming-0-SF 961.61 130.79 863.83 820.:•MEE OSF 1.50 4710.00 2794.19 Ming-O-SF 976.46 13676 884.70 839.r MEM OSF 1.50 4800.00 2906.87 Ming-OSF 6435.92 125.96 6385.41 6343. 78.. OSF 1.50 12319.53 3761.40 Ming-0SF 16999.29 129.72 16812.27 16769.57 197.86 05F 1.50 23396.68 3537.70 TD 8114416(P2)(URN Para 71.90 32.81 70.68 39.09 N/A MAS=10.00(m) 0.00 0.00 Surface ( 71.901 32.81 69.8 39. 87.73 MAS=10.00(m) 200.00 200.00 MinPts 71.92 3281 69. 39.11 84.00 MAS=10.00(m) 210.00 210.00 MINPT-O-EOU 9659 32.81 93.08 65.alJ MAS.10.00(0) 530.00 528.73 Ming-O-SF 3601.26 136. -M6MC OSF 1.50 4630.00 278293 MinPts 6124.96 308.70 5918.83 5816.c ME'-'., OSF 1.50 11100.00 3684.43 MinR-O-SF 611264 309.91 5905.70 5802 OSF 1.50 11080.00 3743.63 Ming-0-SF 6109.15 30949 5902..MEM 29.70 OSF 1.50 12170.00 3753.57 Ming-0-ADP 6109.13 309.:M=M 5799.67 29.70 OSF 1.50 12180.00 3754.10 MINPT-O-EOU 309.43 5902.51 5799.70 29.70 OSF 1.50 12190.00 3754.62 MnP8CICt 610223 300.07 5901.:-MEM 30.60 OSF 1.50 12850.00 3788.07 Ming-0-ADP 6102.07 299.91 111LIIIM 5802.16 30.61 OSF 1.50 12860.00 3788.48 MINPT-O-EOU Mt:In'L 299.59 5901,90 5802.36 30.65 OSF 1,50 12880.00 3789.22 Ming-CtCt 13463.27 187.16 13338.17 13276.11 108.46 OSF 1.50 23396.68 3537.70 TD SO202(04b)(Dal Plan) Pass 10310 32.81 101.88 70,29 N/A MAS=10.00(m) 0.00 0.00 Surface MEM 32.81 87. 60.96 16.85 MAS=10.00(m) 550.00 548.43 Minns 93.87 32.81 86. 61.06 15.85 MAS=10.00(m) 570.00 668.09 MINPT-0-E0U 95.18 32.81 87.53 62.3 MEM MAS=10.00(m) 610.00 607.27 Ming-O-SF 2629.91 32.81 2609.13 2597.1.MIEM. MAS=10.00(m) 3780.00 2064.63 M1ng-0-SF 3254.18 38.33 3228.57 3216.1'MOSF 1.60 4470.00 2760.40 Ming-0-SF 3430.34 105.8 l 'mil MUM, OSF 1.50 4660.00 2787.15 MinPts 4417.11 177.59 4298.39 4239. IMEg. OSF 1.50 6270.00 3013.88 MinPI-0-SF 3377.18 254.00 3207.52 3123.1'MEM OSF 1.50 8860.00 3378.62 Ming-0-SF 286641 294. 'I -'r.'•, OSF 1.50 10190.00 3665,92 MinPts 2465.40 305.94 2261.11 2159. OSF 1.50 11110.00 3695.44 Min97-0-SF 2405. 319.48 219201 2085.84 11.32 OSF 1.50 11560.00 3721.47 WIN-CICt 210566 320.4 MOM 2085.19 11.29 OSF 1.50 11590.00 372318 MINPT-O-EOU 2406.19 321.13 2191. 11.27 OSF 1.50 11610.00 372426 MinR-0-ADP 2423.45 337.20 2198. -I 3 10.81 OSF 1.50 12060.00 3747.82 MnPt-0-ADP 249284 359.54 225282 2133.-'I)M OSF 1.50 12770.00 376427 Ming-0SF 2566.60 370.92 2308.99 2185.,,MEDE OSF 1.50 13170.00 3793.02 MinRA-SF 267665 407.54 2406.62 2271.1 r 9..: OSF 1.60 14070.00 378.225 MinR-O-SF 8953.64 242.45 8791.68 8711.19 55.61 OSF 1.50 23356.68 3537.70 TD SD37-DSP1(DM Savoy) Pass 151.86 32.81 150.64 119.05 NIA MAS=10.00(m) 0.00 0.00 Surface MZ[3] 32.81 IMEIM Mad 1255 MAS.10.00(m) 870.00 86.78 Minns 98.86 32.81 89.55 66..-MEM MAS=10.00(m) 940.00 920.36 Ming-O-SF 10377.76 34.75 10354.24 10343.01 OSF 1.50 12260.00 3759.33 MinR-0-SF 10403.83 34.83 10380.26 10369." OSF 1.50 12310.00 3760.90 Ming-0-SF 1169252 65.41 11618.59 11627.11 I1MM. OSF 1.50 13816.44 3781.63 Ming-0-SF 12599.54 69.15 12553,11 12530. OSF 1.50 14830.62 3789.91 MInR-0-SF 13457.30 74.21 13407.50 13383.,: 275.-: OSF1.50 15770.00 3609.27 M1ng-0SF 20698.96 80.27 20645.11 20618.68 391.57 OSF 1.50 23396.68 3537.70 TD 51.124117(P2)(OM PIN Pass 1� 103.05 3261 101.83 70.24 N/A MAS=10.00(m) 0.60 0.00 Surface I 32.81 101.row 126.24 MAS.10.00(m) 203.00 200.00 Minns 103.23 3281 M. 70.42 84.26 MAS=10.00(m) 280.00 279.99 MINPT-0-EOU 104.01 32.81 MEM 71.20 45.10 MAS=10.00(m) 380.00 379.88 MINPT-0-EOU 106.08 3281 Xj 73.27 19.48 MAS=10,00(m) 500.00 499.10 MINPT-O-EOU 337.85 65.30 293.91 272 7.88 OSF 1.50 2000.00 1746.95 Ming 0. - SF 10377.07 67.69 10331.62 10309.38 233. 087 1.50 13816.44 3781.63 MinPt-O-SF 19281.71 82.15 19226.61 19199.56 356.33 OSF 1.50 23396.68 3537.70 TD 3934•N Sand(P2)(Del Plan) .Pass 119.18 32.81 117.96 86.38 N/A MAS=10.0(m) 0.00 0.00 Surface 11-1715q. 32.81 97.1 70. 19,32 MAS=10.00(m) 620.00 617.03 MinPts 103.70 32.81 97.1 70.89 19.07 MAS.10.00(m) 63000 626.78 MINPT-O-EOU 110.60 32.81 103.31 77. llI MAS=10.00(m) 730.00 723.45 Ming-O-SF 1204.96 46.47 1173.65 1158. ME6ii OSF 1.50 3730.00 2656.18 Ming-0-SF I 9 60.10 1015.52 995.82 26.77 OSF 1.50 4820.00 2809.69 MnPt-CICt 1058.27 66.51 mcgm 991.76 24,20 05F 1.50 4960.00 2829.40 MINPT-0-EOU 1061.68 70.60 1014...MI.MIMI 2285 OSF 1.50 5040.00 2840.67 MnR-0-ADP 1121.90 93.98 1058.92 1027.9' 18.r. OSF 1.50 5530.00 2909.67 Min18-0-SF 8191.56 78.78 8138.72 8112.• 157.''• OSF 1.50 13800.00 378207 Ming-0-SF 17201.03 88.12 17141.95 17112.90 296.08 057 1.50 23396.68 3537.70 TD 6P33463(DM Surely) Pass 111.19 32.81 109.27 78.38 N/A MAS=10.00)m) 0.00 0.00 Surface ilinEE 32.81 109. MOE N/A MAS=1000(m) 40.00 40.00 Minns MINIM 32.81 1069 MUM 261.63 MAS.10.00(m) 160.00 160.00 Minns MEE 3281 105.-% 35.54 1A4S=10.00(w) 440.00 439.61 Minns 111.18 32.81 104.,' 78.37 25.05 MAS.10.00(w) 500.00 499.10 MINPT-0-EOU 117.59 3281 109.37 84.:10. MAS=10.00(m) 630.00 626.78 MinR-0.0F 4731.64 123..:iii WILE' 5 OSF1.50 5900.00 2961.78 MinPts 4955.74 127.31 4870.28 4828.• 1111111EM OSF 1.50 6220.00 3006.84 Ming-0-SF 3634.81 325.43 3417.28 3309.t 16..• OSF 1.50 10790.00 3618.96 111mR-0-SF 340.47 3317.28 3204.37 15.69 0571.50 11350.00 3707.04 8nPI-CICI 354522 341.>-maim 3203.56 15.64 OSF 1.50 11380.00 3709.36 MINPT-0-EOU 354583 34244 3316.'= 3203.•t 15.60 OSF 1.50 11400.00 3710.86 MnPt-0-ADP 3558.77 347.20 332672 3211. 15.- OSF 1.50 11930.00 3720.88 MinR-0SF 3560•41 339..1 M=XE 3220.80 15.80 OSF 1.50 11580.00 372262 MINPT-0-EOU 3561.16 340.53 3333.- 3220.•• 15.76 OSF 1.50 11600.00 3723.72 MnR-0-ADP 3699.21 379.43 3445.72 3319.•MEM OSF 1.50 12690.00 3780.36 Ming-0-SF 3788.87 387.54 3529.97 3401.0 l k OSF 1.50 12990.00 3791.53 I6nR-0-SF 3863.19 396.21 359851 3466.•t MEM OSF 150 13300.00 3794.04 MinR-0SF 3943.67 407.30 3671.61 3536.:MOM OSF 1.50 13670.00 3785.60 Ming-0-SF 4030.90 421.28 374051 3609..•MUM OSF 1.50 14120.00 378277 Ming-0SF 9288.81 298.31 9089.40 8990.50 4695 057 1.50 23396.68 3537.70 TD 5108-FN6(73)(Del Plan) Pass 111.08 32.81 109.86 78.27 N/A MAS=10.00(m) 0.00 0.00 Surface 1 IE 32.81 109. 78.27 136.31 MAS=10.00(m) 200.00 200.00 Minns 111.17 32.81 108.9 78.36 11229 MAS=10.00(m) 230.00 230.00 MINPT-0-EOU 131.64 32.81 125.33 98.-.jj111111111M MAS.10.00(m) 600.00 597.49 Ming-0-SF 469.04 55.10 431.90 413.95 IIIIIMM OSF1.50 2000.00 1746.95 Ming-056 =Tam 479.17 571680 5559.40 18.94 OSF 1.50 16200.00 3801.48 Mon-CICI Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 4 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I ND(ft) Alert I Minor I Major 5901. 585.76 5511.06 5316.13 15.14 OSF 1.50 19850.00 3773.11 MinPt-CICt 5902.43 587.s MUM. 5315.12 15.10 0SF 1.50 19900.00 3773.20 MINPT-O•EOU 5903.00 587.93 5510.7-fir 15.08 OSF 1.50 19920.00 3773.30 MinPI-0-4DP 5993.45 604.46 5590.15 5388.•• 14.:• OSF 1.50 20450.00 3779.54 MinPl-0-SF 7660.02 652.17 7224.92 7007.86 17.64 OSF 1.50 23396.68 3537.70 TD SPI O.FN5(Det SVwy) Pass 119.15 32.81 117.24 86.35 WA MAS=10.00(m) 0.00 0.00 Surface MIME 3281 117.1 86.35 2041.39 MAS=10.00(m) 60.00 60.00 MinPts 119.38 32.81 117. 86.58 276.04 MAS=10.00(m) 150.00 150.00 MINPT-0-EOU 140.43 32.81 133.52 107.•.MEW MAS=10.00(m) 600.00 597.49 MinPt-O-SF 431.47 59.50 391.16 371.97 MBE OSF 1.50 2000.00 1746.95 MinPt-0-SF 1184.87 107.66 111251 1077.21 llllllllllllL( OSF 1.50 3940.00 2685.76 MinPt-O-SF 1507.31 137.57 1415.01 1369.7 M111V, OSF 1.50 4500.00 2768.85 MinPt-0-6F 2305.99 169.87 2192.16 2136.1.Mr:; OSF 1.50 6150.00 2996.98 MinP1.0-SF 2489.51 179.37 2369.35 2310.1 1111111111113SD OSF 1.50 6530.00 3050.50 Min%-O-SF 2653.76 187.10 2528.44 2466.-:IIIIIIIIIIIF3! OSF 1.50 6870.00 3098.38 Min%-0•SF 2801.65 194.87 2671.15 2606.7=MOE OSF 1.50 7180.00 3142.04 MinPt-O-SF 2896.69 200.56 2762.39 2696.1'ME= OSF 1.50 7380.00 3170.20 MinP1-0-SF 3006.55 206.11 2868.56 2800. fir-, OSF 1.50 7610.00 3202.59 MinPt-O-SF 3747.44 241.17 3586.08 3506.:MEICE OSF 1.50 9070.00 3408.20 MinPt-O-SF 3866.47 247.19 3701.09 3619.:llllllllllll. OSF 1.50 9300.00 3440.59 MinPI-O-SF 4083.77 259.77 3910.00 3824... El6E OSF 1.50 9720.00 3499.74 MinPt-O-SF 4221.42 269.29 4041.31 3952.1 IIMEM OSF 1.50 9990.00 3537.76 MinPI-0-SF 4392.66 282.04 4204.04 4110.61 llllllllllll• OSF 1.50 0330.00 3585.64 MinPt-0-SF 4572.62 292.00 4377.36 4280.• MODE OSF 1.50 0700.00 3637.28 MinPt-O-SF 4616.88 294.98 4419.64 4321.8•MOM OSF 1.50 0810.00 3651.47 MinPt-O-SF IMMEIEE 321.61 4507.66 4401.04 22.14 OSF 1.50 2200.00 3755.14 MnPI-CICt 4722.67 321..'lM 4400.98 22.13 OSF 1.50 2220.00 3756.19 MINPT-0-EOU 4722.71 321.74 4507.6' 4400.9 22.13 OSF 1.50 2230.00 3756.71 MinPt-O-ADP 472166 321.91 4508.51 4401. IlllllllllllME OSF 1.50 2319.53 3761.40 MinPt-O-SF 1111016E 320.7 1111111^)E MMICEMOilit OSF 1.50 2930.00 3790.64 MinPts 4772.67 346.35 4541.23 4426.3.lllllllllllly OSF 1.50 4010.00 3781.62 MinPt-O-SF 4805.85 351.54=KR MIMI MOE OSF 1.50 4360.00 3785.26 MinPls & 436.44 4365.89 4220.94 16,06 OSF 1.50 6140.00 3802.69 MinPt-CtCt 4657.45 436.71 MOM 4220.74 1605 OSF 1.50 6160.00 3802.29 MINPT-0-EOU 4657.55 436.84 4365.7,M".7 16.05 OSF 1.50 6170.00 3802.09 MinP1-0-ADP 4662.37 440.4.MEM MOO 15.93 OSF 1.50 6310.00 3799.21 MinPts SUM 473.77 4301.43 4144.04 14.67 OSF 1.50 7700.00 375159 MinPt-CtCt 495.63 4274.89 4110.22 13.98 OSF 1.50 8500.00 3768.37 MInPt•CtCt 4605.99 496.041 4274.7 410996 13.97 OSF 1.50 8540.00 3768.63 MINPT-O-EOU 4606.15 496.25 4274.7 4109.91 13.96 OSF 1.50 8560.00 3768.77 MinPI-0-ADP 4616.24 498.74 428121 4117. 13.9 OSF 1.50 8867.26 3770.81 MinPt-O-SF NOM 544.06 4213.72 4032.90 12.65 OSF 1.50 9920.00 3773.30 MnP1-CICt 4577.11 544.51 MEW 4032.60 12.64 OSF 1.50 9940.00 3773.40 MINPT-0-EOU 4577.27 544.73 42115%MEM 12.64 OSF 1.50 9950.00 3773.46 MinPt-8-ADP 4625.02 555.14 4254.39 4069.,,111111111111100 OSF 1.50 20330.00 3777.50 MinP40-SF 4681.52 560.97 4307.01 4120.:MEE, OSF 1.50 20530.00 3781.10 M91PI-0-SF 4720.46 565.87 4342.67 4154.-MEW OSF 1.50 20640.00 3783.50 Min1R-0-SF 5068.58 592.71 4672.•.1111111^MO 111111111111EM OSF 1.50 21520.00 3793.70 MinPts 515623 616.10 4745.46 4540.6 111111111111EE OSF 1.50 21730.00 3785.18 MinPt-O-SF 627953 616.44 5868.03 5663.09 15.32 OSF 1.50 23396.68 3537.70 TD 5135-W4(P2)(Del Plan) Pau 12218 32.81 125.96 94.37 N/A MAS=10.00(m) 0.00 0.00 Surface 3281 118.01 90.99 26.86 MAS=10.00(m) 490.00 489.21 MinPts 124.03 32.81 117. 91.23 23.39 MAS=10.00(m) 520.00 518.87 MINPT-O-EOU 128.68 32.81 121.87 95.87 19.35 MAS=10.00(m) 610.00 607.27 MInP1-0-SF 2631.27 3281 261247 2598.46, 148.32 MAS=10.00(m) 3700130 2651.94 MInP1-0-SF 333587 37.68 3310.39 3298.18 136.61 OSF 1.50 4500.00 276462 MinP1-0-SF 4901.24 112.94 4825.711 4788.44 65.74 OSF 1.50 6170.00 2999.80 MlnPls 332.67 4419.43 4308.87 20.99 OSF 1.50 11310.00 3703.81 McPt.C1Ct 4641.95 334..:M:11130 4307.89 20.90 OSF 1.50 11350.00 3707.04 MINPT-O-EOU 4642.52 334.75 4419.0• 20.86 OSF 1.50 11370.00 3708.60 MInPt-0•ADP 4916.17 378.81 4663.30 4537.= 19.51 OSF 1.50 12783.35 3784.92 MinPt-O-SF 5246.00 419.69 4965.88 4826.31 18.79 OSF 1.50 14170.00 3783.29 MinPt-O-SF 9727.01 359.90 9486.75 9367.11 40.65 OSF 1.50 23396.68 3537.70 TD SP38-W5(P2)(DM Plan) Pas 135.24 32.81 134.01 102.43 N/A MAS=10.00(m) 0.00 0.00 Surface 1 132.831 32.81 127. 100.0. 31.57 MAS=10.00(m) 480.00 479.31 MinPts 133.22 32.81=ii 100.41 25.82 MAO=10.00(m) 520.00 518.87 MINPT-O-EOU 137.81 32.81 130.16 105, 21.27 MAS=10.00(m) 610.00 607.27 MinPl-O-SF 3290.00 42.96 3261.00 3247..' 117. OSF 1.50 4500.00 2764.62 Min1=1-0-SF 4988.81 104.01 1111 '111111= OSF 1.50 6320.00 3020.93 MinPts MMEEE 331.80 5371.16 5260.89 25.35 OSF 1.50 11340.00 3706.24 MnPt-CICI 5593.05 332.,•1111111 -. 526021 25.28 OSF 1.50 11370.00 3708.60 MINPT-8-EOU 559159 33154 5370.••1MEME 25.23 OSF 1.50 11390.00 3710.12 Min%-0-ADP 6175.75 418.99 5896.09 5756.7: 22.1: OSF 150 14240.00 3784.02 MinPt-0-SF 1009179 391.29 9830.60 9700.50 38.78 OSF 1.50 23396.68 3537.70 TD SP11-N7(P4b)(Del Plan) Pau 135.09 32.81 133.86 102.28 N/A MAS=10.00(m) 0.00 0.00 Surface I 135.091 32.81 133.071 102.281 169.78 MAS=10.00(m) 200.00 210.00 MinPts 135.10 32.811 133. 10229 162.56 MAS=10.00(m) 210.00 210.00 MINPT-0-EOU 18219 32.81 176.85 149.:MZE11 MAS=10.00(m) 600.00 597.49 MinPt-O-SF 2984.59 32.81 2971.08 2951.: MAS=10.00(m) 3830.00 2670.27 MinPt-0-SF 3378.31 32.81 3363.14 3345..MOM MAS=10.00(m) 4250.00 2729.41 MinPt-O-SF 5413.74 190.='MErar,MiSU:. 42.76 OSF 1.50 6370.00 3027.97 MinPts 7287.87 307.37 7082.6.MEMEt M32,1 OSF 1.50 12319.53 3761.40 MinPts 7287.86 307.•M 6980.50 35.68 OSF 1.50 12320.00 3761.42 MINPT-0-605 7255.92 300.0.MEM EZZlial 36.39 OSF 1.50 12940.00 3790,85 MinPts 11 299.83 7055.65 6956.03 36.41 OSF 1.50 12960.00 3791.20 MinPt-CtCt 14100.54 211.61 13959.14 13888.93 100.41 OSF 1.50 23396.68 3537.70 TD S107-SE4(P2)(Del Plan) Pas 143.05 32.81 141.82 110.24 N/A MAS=10.00(m) 0.00 0.00 Surface 32.81 141.02 110.241 175.93 MAS=10.00(0) 200.00 200.00 MlnPls 143.14 32.811 140.88 110.33 137.23 MAS=10.00(m) 240.00 240.00 MINPT-0-EOU 158.97 32.81 150.11 126.17 20.66 MAS=10.00(m) 60000 597.49 MinPt-O-SF 191.13 32.81 181.16 158.32 21.72 MAS=10.00(m) 840.00 827.76 MinPt-0-SF 578.13 60.92 537.11 517.21 14.50 OSF 1.50 2000.00 1746.95 Min1=1-0-SF 9789.95 58.25 9750.79 9731.75. 256.39 OSF 1.50 12800.00 3785.73 MinPI-0-SF 10561.81 77.28 10509.96 10484.53 207.63 OSF 1.50 13800.00 3782.07 MInPI-0-SF 19393.02 88.08 19333.97 19304.94 333.99 OSF 1.50 23396.68 3537.70 TD SPO6-FN7(P2)(Del Pen) Pas 167.16 32.81 165.93 134.35 N/A MAS=10.00(m) 0.00 0.00 Surface 1 167.161 32.81 165.131 134.351 205.86 MAS=10.00(m) 200.00 200.00 MinPts 167.27 32.811 165.07 134.46 160.25 MAS=10.00(m) 240.00 240.00 MINPT-O-EOU Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 5 of 11 ir Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)1 EOU(ft) Dev.(ft) Fact. Rule MD(ft) 1 TVD(ft) Alert 1 Minor 1 Major 186.89 32.81 178.43 154.08 25.68 MAS=10.00(m) 600.00 597.49 MinP1-0-SF 220.73 32.81 211.47 187.92 27.33 MAS=10.00(0) 820.00 808.97 MinPt-O-SF 637.82 57.01 599.41 580.81 17.12 OSF 1.50 2000.00 1746.95 MInP1-0SF 2217.62 115.13 2140.54 2102.49 29.13 OSF 1.50 4500.00 2764.62 MinP1-0SF MEMO 475.35 6925.54 6767.42 22.90 OSF 1.50 16200.00 3801.48 M481-CtCt 7109.1. 581.00 6721.44 6528.10 18.38 OSF 1.50 19850.00 3773.11 MinP1-G1G1 7109.46 582.. 6720.•• 6527.24 18.34 05F 1.50 19890.00 3773.16 MINPT-0-EOU 7109.94 582.84 6721..:NUM 18.33 OSF 1.50 19910.00 3773.25 MinPl-0-ADP 7237.82 60288 6835.57 6634.•• 18.•• OSF 1.50 20560.00 3781.73 MinPt-OSF 8893.75 645.13 8463.34 8248.62 20.71 OSF 1.50 23396.68 3537.70 TD SP04-SE5(P2)(DA Plan) Pas 175.05 32.81 173.82 142.24 N/A MA5=10.00(m) 0.00 0.00 Surface ( 175.451 32.81 173.021 142.241 215.63 MAS=10.00(m) 200.00 200.00 MinPts 175.14 32.811 172.931 142.33 177.56 MAO=10.00(m) 230.00 230.00 MINPT-0-EOU 201.38 32.81 194.92 168. m MAS=10.00(m) 600.00 597.49 MinPt-O-SF 738.71 49.82 705.09 608.89®i OSF 1.50 2000.00 1746.95 MinPt-0-SF 10108.36 69.25 17061.86 10039.1. OSF 1.50 12783.35 3784.92 MinPl-0-SF 10867.60 86.51 10809.613 10781.e•MOE OSF 1.50 13800.00 3782.07 MinP1-0-SF 19635.00 95.29 19571.14 19539.71 312.29 OSF 1.50 23396.68 3537.70 TD 5102-SE6(P2)(Def Plan) Pas 191.03 32.81 189.81 158.22 NIA MAS=10.00(m) 0.00 0.00 Surface 1 191.031 32.81 189.001 158.221 235.42 MAS=10.00(0) 200.00 200.00 MinPts 191.08 32.811 188.93 158.27 204.56 MAS=10.00(m) 220.00 220.00 MINPT-0-EOU 229.14 32.81 220.76 196.33 MAS=10.00(m) 610.00 607.27 MinP1-0-SF 953.38 44.23 923.49 909.15® OSF 1.50 2000.00 1746.95 Min%-0-SF 9475.91 111.50 9401.24 9364.4.=ism OSF 1.50 11230.00 3696.90 MInP1-0-SF 11220.84 121.54 11139.48 11099.. •-', OSF 1.50 13800.00 378207 MinP1-0-SF 19797.72 124.12 1971465 19673.60 241.16 OSF 1.50 23396.68 3537.70 TD SP01-8E7(P2)(DA Plan) Pass 199.14 32.81 19792 166.33 N/A MAS=10.00(m) 0.00 0.00 Surface 32.81 197.11 166.331 245.48 MAS=10.00(m) 200.00 2(10.00 MinPls 199.23 32.811 197.0 166.42 202.13 MAS=10.00 On) 230.00 230.00 MINPT-0-EOU 235.86 32.81 229.38 203.06 44.60 MAS=10.00(m) 610.00 607.27 MinP1-0-SF 337.89 32.81 329.99 305.08 50.42 MAS670.00(m) 930.00 911.21 MinF1-0-SF 355.00 32.81 346.77 322.20 50.44 MAO=10.00(m) 970.00 947.68 MinP1-0-SF 1011.55 37.98 985.82 973.57 41.23 OSF 1.50 2609.00 1746.95 MinP1-0SF 10677.91 73.93 10628.30 10603.98 219.56 OSF 1.50 12310.00 3760.90 MInP1-0-SF 13389.09 147.13 13290.67 13241.96 137.41 OSF 1.50 15980.00 3805.77 MInPI-0-SF 20220.75 155.89 20116.49 20064.86 195.80 OSF 1.50 23396.68 3537.7D TD OP09S7(DA Sway) Pas 4915.33 236.25 4756.93 4679.09 31.55 OSF 1.50 0.00 0.00 Surface 2923.23 352.65 2686.07 2570.: 12.6 OSF 1.50 4221.00 2725.19 MnF1-0-SF 286257 337.45 2635...MME3 1297 OSF 1.50 4670.00 2788.56 MnPl-0-ADP 2859.74 334.0. 2634.•• 2525.72 13.09 OSF 1.50 4730.00 2797.01 MINPT-0-EOU '®• 328.03 263665 2529.78 13.34 OSF 1.50 4830.40 2811.09 MinPI-GIGO 18581.22 140.94 18486.93 18440.28 199.14 OSF 1.50 23396.68 3537.70 TD Turaaq ST 1(DA Survey) Pas 502267 32.81 5020.75 4989.86 N/A MAS=10.00(m) 0.00 0.00 Suree 502264 32.81 5020.72 4989.: NI' MAS=10.00(m) 10.00 10.00 MinP1-0-SF 175 5 32.81 5019.9 =ZILE 727272 MAO=10.00(m) 170.00 170.00 MinPts 4013.14 134.42 392288 3878.7• 45.4. OSF 1.50 5170.00 2858.97 MinP1-0-SF 1 3358.471 251.87 3189.96 3106.60 20.13 OSF 1.50 0700.00 3637.28 MnPI-CICI 3358.99 253.21 mamo 3105.78 20.03 OSF 1.50 0750.00 3643.84 MINPT-O-EOU 3359.77 254.68 MIME 3105.09 19.92 OSF 1.50 0800.00 3650.22 MINPT-0-E0U 3359.95 254.90 3189.4 19.90 OSF 1.50 0810.00 3651.47 MinPI-0-ADP 3391.92 261.55 3216.97 3130.37 MEM OSF 1.50 1110.00 3685.44 M1nPI-0-5F 3893.61 278.34 3707.52 3615. mEgiE OSF 1.50 2319.53 3761.40 MinPl-0-SF 5347.28 292.46 5151.77 5054.8. OSF 1.50 4730.00 3788.91 MinPl-0-SF 5412.36 294.89 5215.23 5117.4 M3aM OSF 1.50 4840.00 3790.01 M1nF1-0-5F 5668.30 297.90 5469.16 5370.4.MEM OSF 1.50 5310.00 3808.58 MinP1-0-SF 5863.66 300.66 5662.68 5563...MEM. OSF 1.50 5670.00 3810.08 MinPl-0-SF 5945.45 302.65 5743.14 5642.8,MEM OSF 1.50 5830.00 3808.44 MinPt-0-SF 6681.68 313.93 6471.75 6367.65 MEW, OSF 1.50 7470.00 3756.89 MinP1-0-SF 7325.52 326.16 7107.54 6999.•MME., OSF 1.50 8867.26 3770.81 MinP1-0-5F 7350.72 329.82 7130.30 7020.-.=OW OSF 1.50 8920.00 3771.56 MinPl-0-SF 7364.18 334.95 7140. ' .�' .=ME OSF 1.50 8950.00 3772.09 MinPts 7631.31 342.71 7402.30 7288.•. 3 OSF 1.50 9570.00 3777.34 MinPl-0-SF 7708.16 345.67 7477.17 7362.4•X OSF 1.50 9740.00 377433 MinPI-0-SF 7919.74 349.81 7685.99 7569.9 MEN OSF 1.50 20360.00 3777.97 MinP1-0-SF 7995.25 363.> OSF 1.50 20860.00 3788.66 MinPts 8281.62 334.52 8058.07 7947.10 37.31 OSF 1.50 23396.68 3537.70 TO IOgun 1 P81(Del Survey) Pass 502267 32.81 5020.75 4989.86 N/A MAS=10.00(m) 0.00 0.00 Surface 5022.64 32.81 5020.72 4989. N/ MAO•10.00(m) 10.00 10.00 MinPt-0-SF WEEE 32.81 5019.9 4989.7 7272.72 MAS=10.00(m) 170.00 170.00 MinPts MIMY. 133.90 3882.45 3838.40 45.07 OSF 1.50 5550.00 2912.49 MnPI-C1Ct 3972.32 133.94 T T:- �N 3838.37 45.06 OSF 1.50 5560.00 2913.90 MinPts 3992.56 135.39 3901.72 3857.17 44.:. OSF 1.50 5950.00 2968.82 MinP1-0-SF 8074.64 134.04 7984.74 7940.60 91.-• OSF 1.50 12319.53 3761.40 Minf4-0SF 18369.17 119.65 18288.86 18249.52 233.41 OSF 1.50 23396.68 3537.70 TD $4g.8.1(DA Survey) Pas 502267 32.81 5020.75 4989.86 N/A MAS=10.00(m) 0.00 0.00 Solace 502264 32.81 5020.72 4989.:•' MAS=10.00(m) 10.00 10.00 MInPI-0-SF 50225 32.81 5019.9• 4989. 7272.72 MAS=10.00(m) 170.00 170.00 MinPls 3999. 134.21 3909.29 3865.14 45.27 OSF 1.50 5580.00 2916.71 MnPI-C1C1 3999.38 134. 3909.•MEMIEE 45.26 OSF 1.50 5590.00 2918.12 Minns 4020.48 135.85 3929.33 3884.••M0 OSF 1.50 5990.00 2974.45 MinP1-0-SF 4024.75 135.99 3933.50 3888. e OSF 1.50 6030.00 2980.09 11.1 84601-0-SF 8041.41 137.01 7949.53 7904..M:31 OSF 1.50 12319.53 3761.40 MinPl-0-SF 1838293 120.62 18301.98 18262.31 231.68 05F 1.50 23396.68 3537.70 TO OP14-03(Def Survey) Pass 6623.96 289.27 6430.18 6334.69 34.67 OSF 1.50 0.00 0.00 Surface 5265.02 384.37 5006.94 4860.65 20.8 OSF 1.50 4690.00 2791.38 MinP1-0-SF 5189.26 368.06 4941.7 4821.21 21.49 OSF 1.50 5460.00 2899.81 MinPI-0-ADP 5188.41 367.031 4941.61 4821.39 21.55 OSF 1.50 5500.00 2905.45 MINPT-0-EOU 1 5187.641 364.64 494240 4823.00 21.70 OSF 1.50 5590.00 2918.12 Min%-CICI 8811.46 193.88 8680.55 8617.5 Noram OSF 1.50 12319.53 3761.40 MinP1-0-5F 19008.84 144.17 1891240 18864.67 199.13 OSF 1.50 23396.68 3537.70 TD 011544(Def Sunray) Pass 7580.17 284.51 7389.19 7295.66 40.50 OSF 1.50 0.00 0.00 Surface 6378.77 422.49 6095.36 5956.281 22.911 OSF 1.50 4600.00 2778.70 MinP1-0-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 6 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major 6213.33 395.19 5947.71 5818.14 23.95 OSF 1.50 5890.00 2960.37 MinP1-0-ADP 6212.22 393.861 5947.47 5818.36 24.03 OSF 1.50 5940.00 2967.41 MINPT-O-E8U 1 6211.201 390.88 5948.42 5820.33 24.22 OSF 1.50 6050.00 2982.90 MCPI-CtCI 9218.97 231.77 9062.58 8987.201 61.14 OSF 1.50 12319.53 3761.40 MinPl-0-SF 19175.48 162.44 19066.65 19013.04 178.83 OSF 1.50 23396.68 3537.70 TD OP10A9(Dal Survey) Pm 8587.48 304.07 8383.89 8283.42 42.72 OSF 1.50 0.00 0.00 548589e 7727.90 405.23 7456.44 7322.6 ME.-j OSF 1.50 4690.00 2791.38 Min%-0-SF 7724.40 405.06 7453.04 7319.'MINIM OSF 1.50 4710.00 2794.19 MinP1-0-SF 7529.88 433.12 7239.73 7096.76 MEE OSF 1.50 6040.00 2981.49 MetP1-0-SF 7450.75 417.70 7170.•,N:. 27.06 OSF 1.50 7000.00 3116.69 MinPt-0-ADP 7450.00 416.77 M7411M 7033.23 27.12 OSF 1.50 7050.00 3123.73 MINPT-0.EOU - 415.07 7171.10 7034.42 27.23 OSF 1.50 7140.00 3136.40 MOPI-CtCt 19051.36 200.37 18917.46 18851.00 143.32 OSF 1.50 23396.68 3537.70 TD 0113-03(Del Survey) Pm 995536 30504 975558 9656.32 50.14 OSF 1.50 0.00 000 Surface 7774.26 537.20 7414.77 7237.06 21.80 OSF 1.50 9240.00 343214 MinP1-0-SF 7708.78 527.01 7355.% 22.12 OSF 1.50 10140.00 3558.88 MinPI-0-ADP 7708.30 526.,, 7355.7: 7181.86 22.15 OSF 1.50 10180.00 3564.52 MINPT-0.EOU 1 7707.951 525.40 7356.11 7182.55 22.19 OSF 1.50 10250.00 3574.37 MinPI-CICI 1693237 296.46 16734.40 16035.90 85.95 OSF 1.50 23396.68 3537.70 TD Nkaitch.3(Del Suvey) Pm 7940.05 32.81 7938.14 7907.24 N/A MAO=10.00(m) 0.00 0.00 Surface 7940.03 32.81 7938.11 7907.221 MAS=10.00(m) 10.00 10.00 Mi1P1-0-SF 7940.02 32.81 MIME 7907.21 N/A MAS=10.00(m) 20.00 20.00 MINPT-0-EOU 1 7940.021 32.81 7938..:MEMO 409855.01 MAS=10.00(m) 50.00 50.00 MinPls 7940.23 32.81 MEM 7907.42 9348.85 MAO=10.00(m) 210.00 210.00 MINPT-0-EOU 8639.51 39.13 8612.79 8600.-Nam:1E OSF 1.50 2100.00 1817.67 M0PI-0-SF 9077.33 39.58 9050.30 9037. =On OSF 1.50 2830.00 2318.46 Min1.1-0-SF 9216.01 40.02 9188.74 9175.••MOE OSF 1.50 3020.00 2424.71 60901-0-SF 10666.06 50.45 10631.84 10615.62 MEM OSF 1.50 4600.00 2778.70 MInPI-0-SF 17073.80 54.22 17037.06 17019. =MEE OSF 1.50 11250.00 3698.68 MhP1-0-SF 17862.93 58.90 17823.07 17804... .' OSF 1.50 12310.50 3760.90 MInP1-0-SF 18931.70 83.27 18875.65 18848.4 =ME OSF 1.50 13816.44 3781.63 M'InP1-0-SF 21295.80 84.28 21239.08 21211. •M'. OSF 1.50 16740.27 3775.49 M0PI-0-SF 21348.65 84.49 21291.79 21264.1 �-• OSF 1.50 16800.00 3771.59 MinPt-O-SF 21854.60 86.85 21796.16 21767.7 MEM OSF 1.50 17365.08 3758.40 MinPI-O-SF 22308.73 89.43 22248.58 22219.31 MEM OSF 1.50 17869.33 3751.45 MinP1-0-SF 24252.77 101.68 24184.44 24151..•MigilM OSF 1.50 20000.00 3773.77 MinPt-O-SF 27524.09 99.10 27457,49 27424.99 423.49 OSF 1.50 23396.68 3537.70 TD Nkcfdwq 3982(0.t Survey) Pm 794005 32.81 7938.14 7907.24 N/A MAS=10.00(m) 0.00 0.00 Surface 7940.03 32.81 7938.11 7907.2 8 MAS=10.00(m) 10.00 10.00 MinPt-0-SF 7940.02 32.811 7938.1 7907.21 N/A MAS=10.00(m) 20.00 20.00 MINPT-0.EOU 1 7940.04 32.81 7938. 7907.21 409855.01 MAS=10.00(m) 50.00 5000 MinPI. 7940.23 32.81 7937.4 7907,42 9348.85 MAS=10.00(m) 210.00 210.00 MINPT-8-EOU 8639.51 39.13 8612.79 8600.•=••y OSF 1.50 2100.00 1817.67 MinPt-O-SF 9077.33 39.58 9050.30 9037. =ME OSF 1.50 2830.00 2318.46 MinPI-O-SF 9216.01 40.02 918834 9175.-•MEM OSF 1.50 3020.00 2424.71 Ming-0-SF 10666.06 50.45 10631.84 10615...1.111EKM OSF 1.50 4600.00 2778.70 M01P1-0-SF 17073.80 54.22 17037.06 17019.5 . OSF 1.50 11250.00 3698.68 MinP1-0-SF 1786293 58.90 17823.07 17854.0. •-'- OSF 1.50 12310.00 3760.90 Mi1P1-0-SF 18931.70 83.27 18875.65 18848. =THE OSF 1.50 13816.44 3781.63 Min%-0-SF 21295.80 84.28 21239.08 21211. -NEM OSF 1.50 16740.27 3775.49 MinP1-0-SF 21348.65 84.49 21291.79 21264.1 MEM OSF 1.50 16600.00 3771.59 MinP50•SF 21854.60 86.85 21796.16 21767.- - OSF 1.50 17365.08 3758.40 MinP1-0-SF 22308.73 89.43 22248.58 22219.31 - E OSF 1.50 17869.33 3751.45 MinP1-0-SF 24252.77 101.68 24184.44 24151..•MM1M- OSF 1.50 20000.00 3773.77 MinP1-0-SF 27524.09 99.10 27457.49 27424,99 423.49 OSF 1.50 23396.68 3537.70 TO hriktutchtiq 3P83(0.f Sunray) Pau 7940.05 32.81 7938.14 7907.24 N/A MAS=10.00(m) 0.00 0.00 Surface 7940.03 32.81 7938.11 7907.24 MAS=10.00(m) 10.00 10.00 MinP1.0-SF 7940.02 32.81 7938.1. 7907.21 N/A MAS=10.00(m) 20.00 20.02 MINPT-8-EOU 1 7940.021 3281 7938.,MERED 409655.01 MAS=10.00(m) 50.00 50.00 MinPla 7940.23 32.81 7937.4. 7907.42 9348.85 MAS=10.00(m) 210.00 210.00 MINPT-0-EOU 8639.51 39.13 8612.79 8600.<M',. OSF 1.50 2100.00 1817.67 MinPI.0-SF 9077.33 39.58 9050.30 9037. =OE OSF 1.50 2830.00 2318.46 MinPt-0.SF 9216.01 40.02 9188.74 9175.'•111111E3E OSF 1.50 3020.00 2424.71 MMP1-0-SF 10666.06 50.45 10631.84 10615.:•.=02 OSF 1.50 4600.00 2778.70 MinP1-0-SF 17073.80 54.22 17037.06 17019. =MEE OSF 1.50 11250.00 3698.68 Min%-0-SF 17862.93 58.90 17823.07 17804.. 1.1= OSF 1.50 12310.00 3760.90 MinP1-0-SF 18931.70 83.27 18875.65 18848. =MUC OSF 1.50 13816.44 3781.63 MinPt-0-SF 21295.80 84.28 21239.08 21211. .=ME- OSF 1.50 16740.27 3775.49 MinP1-0.SF 21348.65 84.49 21291.79 21264.1 IMME OSF 1.50 16800.00 3771.59 MinPt-0.SF 21854.60 86.85 21796.16 21767. T'- ]/ OSF 1.50 17369.08 3758.40 MinP1-0-5F 22308.73 89.43 22248.58 22219.31 MEM OSF 1.50 17869.33 3751.45 M1nP1-0-6F 24252.77 101.68 24184.44 24151..-=CR OSF 1.50 20000.00 3773.77 MinP1-0.SF 27524.09 99.10 27457.49 27424.99 423.49 OSF 1.50 23396.68 3537.70 TO Nttolehuq 3981(0.f Sunny) Pm 7940.05 32.81 7938.14 7907.24 N/A MAS=10.00(m) 0.00 0.00 Surface 794003 32.81 7938.11 7907.221 MAS=10.00(m) 10.00 10.00 MInPt-0.SF 7940.02 32.81 moiE 7907.21 11/8 MAS=10.00(m) 20.00 20.00 MINPT-0.EOU 1 794004 32.81 7938.0:®409855.01 MAS.10.00(m) 50.00 5000 MinPts 794023 32.81 MEMO 7907.42 9348.84 MAO=10.00(m) 210.00 210.00 MINPT-0-EOU 8639.51 39.13 8612.79 8600.39 348.20 OSF 1.50 2100.00 1817.67 MinPI-0-SF 9077.33 39.58 9050.30 9037.75 361.43 OSF 1.50 2830.00 2318.46 MinP1-0-SF 9216.01 40.02 9188.74 9175. OSF 1.50 3020.00 2424.71 MinP1-0-6F 10666.06 50.45 10631.84 10615.62 328.56 OSF 1.50 4600.00 2778.70 M0PI-0-SF 17073.80 54.22 17037.06 17019.57 488.13 OSF 1.50 11250.00 3698.68 MinP1-0-6F 17862.93 58.90 17823.07 17804.02 46585 OSF 1.50 12310.00 3760.98 M81P1-0-SF 18931.78 83.27 18875.65 18848.43 347.75 OSF 1.50 13816.44 3781.63 MInP1-0-SF 21295.80 84.28 21239.08 21211.52 386.39 OSF 1.50 16740.27 3775.49 MInP1-0-SF 21348.65 84.49 21291.79 21264.17 386.39 OSF 1.50 16800.00 3771.59 MInPI-O-SF 21854.60 86.85 21796.16 21767.75 384.57 OSF 1.50 17365.08 3758.40 M6P1-0-SF 22308.73 89.43 22248.58 22219.31 381.04 OSF 1.50 17869.33 3751.45 M9PI-O-SF 2425277 101.68 24184.44 24151.09 363.54 OSF 1.50 20000.00 3773.77 MInPI-0-SF 27524.09 99.10 27457.49 27424.99 423.49 OSF 1.50 23396.68 3537.70 TD Mkeilchuq 4(Def Survey) P.M 8188.02 32.81 8186.10 8155.21 N/A MAS=10.00(m) 0.00 0.00 Surface 8188.00 32.81 8186.08 8155.191- MAS=10.00(m) 10.00 1000 MinP1-0-SF 8187.99 32.81 -..f 8155.18 N/A MAS=10.00)0) 20.00 20.00 MINPT-0.EOU MEW 32.81 8186,-11KIMIE 423577.80 MAS=10.00(m) 50.00 50.00 MinPls 8188.02 32.81 8186.01 8155.21 90514.11 MAS 10.00(m) 80.00 80.00 MI6PT-O-EOU Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 7 of 11 4. Offset Trajectory Separation Allow Sep. I Controlling Reference Trajectory Risk Level Alert Status Ct-Cllftll MAS(ft)I EOU(ft) Dev.(ft) Fact. Rub MD(ft) I TVD(ft) Alert I Minor I Major 7974.75 75.34 7923.89 7899.41 162.87 OSF 1.50 1330.00 1254.83 MnPI-CtC1 7974.86 75.. l 7899.22 162.23 057 1.50 1350.00 1270.61 MINPT-0-EOU 7974.98 75.79 7923...-��'y 161.90 OSF 1.50 1360.00 1278.44 MinP1-0-ADP 7975.92 78.11 MEDailmlarii 156.99 OSF 1.50 1400.00 1309.39 MinPts 8032.16 95.1 WZE MIME 129.17 OSF 1.50 2000.00 174695 MinPts 8085.16 103.''NOM MIME, 11685 OSF 1.50 2340.0D 1985.95 MinPls 8164.10 105.16 8093.35 8058.• NEM OSF1.50 2750.00 2268.75 M1nP1-0SF 9273.82 121.94 9191.94 9151.::=ME OSF 1.50 4500.00 2764.62 MinP1-0-SF 16570.07 134.57 16479.82 16435.• 186.'e 057 1.50 13800.00 3782.07 MinPl-0-SF 24751.85 135.05 24661.28 24616.80 278.22 OSF 1.50 23396.68 3537.70 TD NIkehMq 1(Del Slrvay) Pass 807262 32.81 8070.71 8039.82 N/A 1165=10.00(m) 0.00 0.00 Surface 1--80�726�1 32.81 8070.69 8039.:•1)11j1j1j1j1j`,G1 MAS=10.00On) 10.00 10.00 MinPI-0-SF 1 <q 3281 8069.• :• j• 10334.88 MAS=10.00(m) 220.00 220.00 MinPts 8072.32 32.81 8069. • 8039.51 9292.91 MAS•10.00(m) 240.00 240.00 MINPT-0-E0U 8788.52 41.60 8760.15 8746.•.Ijjlj11EBE OSF 1.50 2110.00 1824.70 MinPt-0SF 9375.63 51.13 9340.95 9324. Ijjljlj) 057 1.50 3050.00 2439.89 MinP1-0-SF 10751.29 65.85 10706.81 10685. Mf310. OSF 1.50 4600.00 2778.70 MinPt-0-SF 14186.08 68.10 14140.10 11117.••=Mg, OSF 1.50 8250.00 3292.72 MinPt-0-SF 14614.25 70.00 14566.99 14544.2 1)11)1)1 OSF 1.50 8700.00 3356.09 MinPt-0-SF 17705.52 91.84 17643.71 17613.-: ':y OSF 1.50 12310.00 3760.90 MinPI-0-SF 18198.29 107.52 18126.0 Ifni) 257.72 OSF 1.50 13150.00 3792.86 MinP1-0-ADP 18604.51 12233 18522.42 184821:® OSF1.50 13816.44 3781.63 MinP1-0-6F 20593.33 119.15 20513.36 20474.1:Ijj1jLMO OSF 1.50 16640.00 3782.28 MinP1-0-SF 20843.05 121.67 20761.40 20721.:Ij11111Yi-` --'i OSF 1.50 16960.00 3766.52 MinP1-0-6F 21053.78 126.85 20968.67 20926.,Ijjijjl®l OSF 1.50 17220.00 3761.29 MinP1-0-SF 21109.94 132.09 21021.34 20977..- -'Tt--,' OSF 1.50 17290.00 3759.88 MinPt-0-SF 22372.11 139.16 22279.11 22233..•Ij11111ji OSF 1.50 18867.26 3770.81 MinP1-0-6F 23135.30 144.64 23038.33 229890.-•ice 0571.50 19800.00 3773.43 MinP1-0-SF 23091.86 148.53 23492.30 23443. .=MO, OSF 1.50 20310.00 3777.19 MinPt-0-SF 26617.20 150.11 26516.59 26467.09 268.86 OSF 1.50 23396.68 3537.70 TD Nikafchuq 4P01(Del Survey) Pap 818602 32.81 8186.10 8155.21 N/A MAS•10.00(m) 0.00 0.00 Surface 8188.00 32.81 8186.08 8155.19, ry MAS•10.00(m) 10.00 10.00 68071-0-SF 8187.99 3281 wain 8155.18 N/A MAS•10.00(m) 20.00 20.00 MINPT-0-EOU 1 8187.99 32.81 8186.•- 8155.1: 423577.80 1145.10.00(m) 50.00 50.00 MinPIe 8188.02 32.811 8186.01 8155.21 90514.11 1185.10.00(m) 80.00 80.00 MINPT-0-EOU 823355 32.81 8227.33 8200."MIME MAS:10.00(m) 620.00 617.03 M1nP1-0-SF 8925.37 38.67 8898.95 8886.•=ME OSF 1.50 2100.00 1817.67 MInP1-0-SF 9524.75 39.69 9497.70 9485.•>MOM 0571.50 3020.00 2424.71 MinPt-0-SF 10967.78 49.94 10953.90 10937.: Maar OSF 1.50 469600 2778.70 M1nP1-0-SF 1732249 53.66 17286.12 17268.:..Mii= OSF 1.50 11140.00 3688.42 MinPl-0-5F 1745067 54.06 17414.04 17396.61 OSF1.50 11290.00 3702.13 MinP1-0SF 18207.16 58.84 18167.35 18148. . OSF 1.50 12310.00 3760.90 MInPI-0SF 19274.74 83.36 19218.63 19191.: ) 057 1.50 13816.44 3781.63 MInPt-0SF 2168682 84.66 21629.84 21602.1.=DM) OSF 1.50 16800.03 3771.59 MInFI-OSF 22191.65 87.05 22133.08 22104.,=2 OSF 1.50 17365.08 375640 Mont-OSF 22644.89 89.66 22584.58 22556.<=EX 057 1.50 17869.33 3751.45 MinPt-0SF 24586.17 102.07 24517.58 24484.1.Man OSF 1.50 20000.00 377177 MinP/-0SF 2468256 102.46 24613.72 24580.1• 367.11 OSF 1.50 20100.00 377460 MinPt-0SF 27853.55 99.61 27786.60 27753.94 426.31 OSF 1.50 23396.68 3537.70 TD 0204-07(Def Survey) Pap 9353.08 91.41 9290.65 9261.67 161.32 OSF 1.50 0.00 0.00 Surface MIIMEI 91.•.M=ES 9034.42 157.23 OSF1.50 86000 846.46 MinPts 9532.10 97.55 9465.46 9434.- 154.1• OSF 1.50 2100.00 1817.67 MinPt-OSF 11320.43 116.81 11241.30 11203.61 150.1 OSF 1.50 4600.00 277670 MinPt-OSF 28834.99 142.46 28739.68 28692.52 305.71 OSF 1.50 23396.68 3537.70 TD OP12-01(Del Survey) Pas 9736.59 208.27 9596.54 9528.32 71.34 057 1.50 0.00 0.00 Surface 9471.65 210.37 9330.08 9261. MIME OSF 1.50 980.00 956.73 MinPI.O-SF 1 9451.561 209.4M MZE1,j 69.00 OSF 1.50 131000 1238.89 MinPls 10083.53 200.24 9948.40 9883..•MWE OSF 1.50 4500.00 2764.62 11671-0-SF 14952.42 168.57 14839.40 14783,11j.KU OSF 1.50 12319.53 3761.40 MinPI.O-SF 25022.71 151.61 24921.31 24871.11 249.19 OSF 1.50 23396.68 3537.70 TD OP08-04(Def Survey) Pass 10386.55 71.59 10337.34 10314.96 231.88 OSF 1.50 0.00 0.00 Surface 10372.34 71.55 10323.17 10300.:• 231. OSF 1.50 40.00 40.00 MinFt-O-SF 10187.38 69.26 MEM MaranE 236.57 OSF 1.50 900.00 88160 MinPts 1 10187.381 69.23 10139.66 13118.15 236.70 OSF 1.50 910.00 892.82 M6PI-CtCt 1048259 76.19 10430.18 10405.•Ij11jj1)2 0571.50 2100.00 1817.67 MinPt-O-SF 11791.55 106.45 11719.16 11885.1.1MO( 0671.50 4600.00 2778.70 MinPt-O-SF 1358418 106.63 1351226 13477.'j1ljjljilE•3E- OSF 1.50 7230.00 3149.08 MinPt-O-SF 16218.91 130.17 16131.80 16088.7 •,�:'- OSF 1.50 10600.00 3623.65 MinPI-0-SF 17881.59 133.47 17792.28 17748.1-MI= OSF 1.50 12319.53 3761.40 Min%-0-SF 28238.12 134.70 28148.00 28103.43 316.77 OSF 1.50 23396.68 3537.70 TD 0PO4-07P51(De/Survey) Pap 10518.87 74.46 10467.78 10444.40 224.87 OSF 1.50 0.00 0.00 Surface I 10330.951 74.it I: : 56/3 5 221.75 OSF 1.50 810.00 799.54 MinPts 10753.94 82.01 10697.74 10671., 208 1, OSF 1.50 2100.03 1817.67 Mr49-0SF 11264.30 84.05 11207.84 11181.• 211.71 OSF 1.50 3020.00 242471 68/48-0-SF 12467.77 107.28 12395.06 12360.: 180.1• 0671.50 4600.00 277670 11/nP1-0-SF 19309.16 129.14 1922274 19180.0 225.•• 0671.50 12319.53 3761.40 11671-0SF 2978285 136.66 29691.42 29646.21 329.27 OSF 1.50 23396.68 3637.70 TD 0107-04(Del Survey) Pep • 1055246 82.71 10496.05 10469.75 210.55 OSF 1.50 0.00 0.00 Surface 1 10361551 83 10308.0 10282.21 195.94 OSF 1.50 790.00 780.63 Minns 10821.98 88.81 10761.43 10733.1 �'�• OSF 1.50 2100.00 1817.67 MinPI-0-SF 12657.25 105.97 12:85.63 12551. : OSF 1.50 4600.00 2778.70 MinPI-O-SF 21117.10 127.44 21031.81 20919.0- 250.4 OSF 1.50 13800.00 3782.07 MinPI-0-SF 30193.53 131.09 30105.81 3006244 348.09 067 1.50 23396.68 3537.70 TD OP17-02281(Del Survey) Pas 11448.02 316.84 1123629 11131.18 54.45 OSF 1.50 0.00 0.00 Surface 10487.86 448.10 10188.15 10039. MEM OSF 1.50 6890.00 3101.20 Mint-0-SF 10485.97 448.03 1018630 10037.-•1)1ljijiji OSF 1.50 6910.00 3104.01 MinP1-0-SF 10440.24 443.97 10143.1,E 35.53 OSF 1.50 7830.00 3233.57 10971-0-002 10440.15 443.87 • E 9996.28 35.54 OSF 1.50 7850.03 3236.39 MINPT-0.E0U 10440.0 443.65 10143.16 9996.42 35.56 OSF 1.50 7890.00 324202 MinPl-CtCt 2155753 299.36 20358.03 20258.57 10134 OSF 150 2339668 3537.70 TD 011ktok Pant 1-2(Del Survey) Pass 10783.41 254.79 1061264 10528.62 64.15 OSF 1.50 0.00 0.00 Surface 10511.80 25814 10338.59 10253.56 OSF 1.50 1360.00 1278.44 11671-0-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 8 of 11 Offset Trajectory I Separation Allow Sep. Controlling Reference Trajectory Risk Leval Alert Statue Ct-Ct(ft) MAS(ft) EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major 10511.47 258.24 10338.25 10253.23 61.80 OSF 1.50 1410.00 1317.03 MinPts 10538.48 259.70 10364.21 10278.79 61.66 OSF 1.50 2000.00 1746.95 MI4P1-0-SF 10924.61 25491 10753.29 10669.70 65.32 OSF 1.50 4500.00 2764.62 MinPI-6-SF 15178.49 210.26 15037.65 14968.23 109.30 OSF 1.50 12319.53 3761.40 Mi4P1-0-SF 25015.12 176.79 24896.93 24838.32 213.42 OSF 1.50 23396.68 3537.70 TD 0617-02(Del Survey) Pau 11394.92 314.48 11184.77 11080.44 54.61 OSF 1.50 0.00 0.00 Surface 10522.06 415.14 10244.20 10106.• MM. OSF 1.50 6786.00 3085.71 MInPI-0-SF 10521.55 415.13 10243.69 10106.4. OSF 1.50 6810.00 3089.93 Mint:5-6-6F 10519.95 415.02 10242.1.El= 38.32 OSF 1.50 7000.00 3116.69 MinPI-0-60P 1 10519.951 415... 10104.93 38.32 OSF 1.50 7010.00 3118.10 MinPis 10530.65 416.80 10251.60 10113.85 OSF 1.50 7530.00 3191.33 MinPt-O-SF 21133.61 279.57 20946.90 20854.04 113.79 OSF 1.50 23396.68 3537.70 TD 0111-01(Dal Survey) Pus 10763.31 84.97 10705.26 10678.35 199.89 OSF 1.50 0.00 000 &M ace 10586.91 85.59 10528.38 10501.3.MM OSF 1.50 640.00 636.51 MinP9-0-SF I 10561.62) 85.26 EmE 1®' 196.10 OSF 1.50 970.00 947.68 MinPls 10569.41 85.27 10511.05 10484.1'MOE. OSF 1.50 1150.00 1106.38 MinPt-0-6F 10791.35 93.81 10727.25 10697.54 .' 33 OSF 1.50 2100.00 1817.67 MinPt-0-SF 11876.24 122.62 11793.03 11753.62 MEM OSF 1.50 4600.00 2778.70 68nP1-0-SF 15862.24 143.78 15765.85 15718.461E OSF 1.50 10660.00 3623.65 MinPt-0-SF 17500.32 147.66 17401.55 17352.66 MEM OSF 1.50 12319.53 3761.40 MinPI-0-SF 27736.59 144.23 27640.11 27592.37 290.44 OSF 1.50 23396.68 3537.70 TD 0124-08(Def Survey) Pas 12487.66 326.38 12269.43 12161.28 57.72 OSF 1.50 0.00 0.00 Surface 11095.03 472.24 10779.05 10622.• 35.4• OSF 1.50 7240.00 3150.49 MinPt-6-SF 11060.83 469.27 10746.71 Ma= 35.63 OSF 1.50 8060.00 3265.96 MnP1-6-ADP 11060.76 469.19 10746.6• 10591.57 35.64 OSF 1.50 8080.00 3268.78 MINPT-0-EOU 469.05 10746.72 10591.66 35.65 OSF 1.50 8110.00 3273.00 Mn191-CICt 20866.45 328.21 20647.11 20538.24 95.83 OSF 1.50 23396.68 3537.70 TD OP03-PO5(Del Survey) Pau 11728.89 89.79 11667.98 11639.10 203.00 OSF 1.50 0.00 0.00 Surface 91.191 'MEE 197.40 OSF 1.50 740.00 733.02 MinPls 12012.92 96.08 11947.77 11916.2.M" OSF 1.50 2000.00 1746.95 Min111-0-SF 13950.04 110.55 1387562 13839.4•MGM OSF 1.50 4600.00 2778.70 MinPt-0-SF 22000.70 127.91 21915.10 21872.81 MEIME OSF 1.50 13329.67 3794.00 MinPt-O-SF 22448.16 130.71 22360.69 22317.4 -.° OSF 1.50 13800.00 3782.07 MinPl-0-SF 31526.48 134.45 31436.52 31392.03 354.31 OSF 1.50 23396.68 3537.70 TD OP18.68(Def Survey) Pas 13723.74 312.56 13515.02 13411.19 66.08 OSF 1.50 0.00 0.00 Surface 11694.44 502.89 11358.29 11191.55 35.1• OSF 1.50 9130.00 3416.65 MinPt-O-SF 1 11694.031 502.88M:M/MEE 35.06 OSF 1.50 9230.00 3430.73 MnPI. 20643.00 384.81 20386.14 20258.20 8067 OSF 1.50 23396.68 3537.70 TD 0106.05(Def Survey) Peas 11965.37 95.67 11900.81 11869.69 19224 OSF 150 0.00 0.00 Surface MIME 95.-1 WHILE=ME 189.53 OSF 1.50 720.00 713.85 MnPts 11808.52 95.92 11743.75 11712,M=In OSF 1.50 770.00 761.65 MnPI-6-SF 14218.01 105.33 14147.34 14112.E MIZE. OSF 1.50 4500.00 2764.62 MnFt-0-SF 22044.88 116.41 21966.94 21928.44 OSF 1.50 12810.00 3786.21 MnP1-0-SF 22949.03 123.63 22866.28 22825.'1 MED5 OSF 1.50 13800100 3782.07 MlnPI-6-SF 32019.78 129.07 31933.40 31890.71 374.97 OSF 1.50 23395.68 3537.70 TD OP08-04PB1(Def Survey) Pas 12102.37 41.13 12073.71 12061.24 MOM OSF 150 0.00 0.00 MlnPI-0-SF 12090.22 41.10 12061.57 12049.1.x-. 1 OSF 1.50 40.00 40.00 MInP1-0-SF 11961.14 40.68 11932.73 11920.46 MM. OSF 1.50 600.00 59749 MinP1-0-SF ( 11953.021 40.51 MIME=gm 489.58 OSF 1.50 770.00 761.65 MlnPla 12355.51 56.64 12316.45 12298.8 IIMM OSF 150 2100.00 1817.67 MInPI-0-SF 13862.12 97.67 13795.98 13764. M.4 OSF 1.50 4600.00 2778.70 MInP1-0-SF 18616.16 19.82 18529.29 18486.34 MIM OSF 1.50 10700.00 3637.28 MInP1-0-SF 20199.10 131.97 20110.79 20067.1'MM. OSF 1.50 1231953 3761,40 MinPt-O-SF 30568.49 135.09 30498.10 30453.40 342.13 OSF 1.50 23396.68 3537.70 TD 010645P81(Del Survey) Pas 12243.74 89.06 12183.55 12154.67 211.93 OSF 1.50 0.00 0.00 Surface 12094.00 89.16 12033.72 12004:32 ME:KO OSF 1.50 690.00 684.97 66n%-0-SF EM III I NT.EIM E IIVEMED 99.41 OSF 1.50 710.00 704.24 MinP1s 12093.90 89.16 12033.61 12004.74E OSF 1.50 720.00 713.85 M1nP1-0-SF • 14499.98 99.66 1443308 1440031 Min OSF 1.50 4500.00 2764.62 MinP1-0-SF 23206.41 119.12 23126.67 23087.4 :M OSF 1.50 13800.00 3782.07 MinPl-0-SF 32282.91 124.43 32199.64 32158.49 392.28 OSF 1.50 23396.68 3537.70 TD ONMak Point I-2682(Del Survey) Pus 12552.92 180.49 12431.65 12372.43 105.96 OSF 1.50 0.00 0.00 Surface 1238230 181.87 12260.05 12200.. M1 :s OSF 1.50 870.00 855.78 MinP1-0-SF 12380.50 181.85 12258.27 12199.•2 M1 :'. OSF 1.50 910.00 892.82 MinPt-O-SF MUM 181.79 . J 103.85 OSF 1.50 1010.00 983.73 MinPls 12521.14 184.80 12396.86 12336.. ' 1'�. OSF 1.50 2000.00 1746.95 MinPI-6-SF 13315.66 194.24 13185.05 13121.4.1 6 OSF 1.50 4600.00 2778.70 MinP1-6-SF 18071.15 191.83 17942.94 17879.3.MOUE OSF 1.50 12319.53 3761.40 MnPI-0-SF 2797283 173.67 27856.72 27793.15 242.97 OSF 1.50 23396.68 3537.70 TD OP18-03PB2(Del Sway) Pas 13723.74 312.49 13515.06 13411.26 66.10 OSF 1.50 0.00 0.00 Surface 12394.69 454.91 12090.64 11939.78 41.0 OSF 1.50 7540.00 3192.73 Min%-0-SF 12393.12 454.85 12089.1 11938.27 41.08 OSF 1.50 7730.00 3219.49 MnPI-0-ADP I 12393.14 454.851 12099.1 11938.27 41.08 OSF 1.50 7740.00 3220.90 888646 22126.27 354.29 21899.75 21771.98 93.94 OSF 1.50 23396.68 3537.70 TD 0605-86(Del Survey) Pas 12577.30 86.68 12519.09 12490.62 220.83 OSF 1.50 0,00 0.00 Surface 12438.86 86.28 12390.89 12352.58 219.67 OSF 1.50 560.00 558.27 MinPt-0-SF I 12432.351 86.18 12346.17 219.85 OSF 1.50 700.00 694.61 MinPts 23719.44 109.93 23645.82 23609.51 326.2 OSF 1.50 13816.44 3781.63 MinPI-0-SF 32744.38 117.58 32665.66 32626.80 421.24 OSF 1.50 23396.68 3537,70 TD OP16-03(Def Survey) Pas 14336.54 300.80 14135.67 14035.73 71.72 OSF 1.50 0.00 0.00 Surface MIME 309.06 13920.87 13818.18 68.78 OSF 1.50 1630.00 1480.03 MinPt-C1CI 1412748 309.8 1399. 13817.65 68.61 OSF 1.50 1710.00 1538.44 MINPT-0-EOU 14127.90 310.33 13920. 13817. 68.50 OSF 1.50 1760.00 1574.75 MnPt-6-412P 1 12761.321 479.73 1244080 12281.59 40.07 OSF 1.50 8890.00 338285 MinPt--C1CI 12761.35 479.81 MEEME MIRM 40.06 OSF 1.50 8920.00 3387.07 MnPis Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 9 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(R)_Dev.(R) Fad. Rule MD(ft) 1 TVD(fl) Alert 1 Minor I Major 12773.02 480.92 12451.65 12292.10 40.02 OSF 1.50 9440.00 3460.30 MinPl-0-SF 21691.01 393.51 21428.34 21297.50 82.89 OSF 1.50 23396.68 3537.70 TD 0111-01 PB1(Def Sunray) Pas 13393.14 32.81 13371.75 13360.33 741.20 MAS=10.00(m) 0.00 0.00 Surface 1338224 32.81 13360.84 13349.' 1111l MAS=10.00(m) 40.00 40.00 MinPnO-SF 13267.62 3281 13245.84 13234.81 lllllllf MAS=10.00(m) 600.00 597.49 Min%•O-SF +;1- 2 32.81 E 111= 723.92 MAS=10.00(m) 750.00 742.58 MinPte 1364288 52.86 13606.49 1860..r-=r. OSF 1.50 2100.00 1817.67 MinPI•0-SF 15016.78 99.49 14949.53 14917. jll 11EM OSF 1.50 4600.00 2778.70 MinPt•0-SF 19604.58 137.91 19512.31 19466.671111 RE OSF 1.50 1090000 3662.42 MinPt-O-SF 20999.17 140.35 20905.27 2858.-..WIIE 005 1.50 12319.53 3761.40 MinPt-O-SF 3128213 141.10 31187.94 31141. IIINUO OSF 1.50 23396.68 837.70 MinP1-0-SF 050506P82(Def Survey) Pas 13416.86 80.81 1336247 13336.05 253.92 OSF 1.50 0.00 0.00 Surface 13293.61 80.45 13239.42 13213.1 NEM OSF 1.50 510.00 508.99 MInPt-0-SF I 13284.451 80. 13230. ®' 253.22 057 1.50 670.00 665.63 MlnPts 15751.20 86.96 1569289 15664..r 11/111 OSF 1.50 4500.00 2764.62 MinP1.04F 24504.11 105.87 24433.19 24398.E=Mal OSF 1.50 13816.44 3781.63 MinP1-0-SF 33559.89 11273 33484.41 33447.17 450.49 OSF 1.50 23396.68 3537.70 TD OP03-Po�S2(Del Survey) Pau 13417.50 71.37 13368.99 13346.13 293.40 OSF 1.50 0.00 0.00 Surface N.1 72.26 13240.02 13216.90 287.33 OSF 1.50 680.00 675.31 MnPt-CICI 13289.17 72. NErEEETE 287.29 OSF 1.50 600.00 684.97 Minis 13801.43 79.01 13747.82 13722.4. OSF 1.50 2100.00 1817.67 MinP1-0-SF 15595.56 99.70 15528.52 15495.,• 38.7 OSF 1.50 4600.00 2778.70 MinPt•04F 19400.97 111.25 19326.48 19289. 111 OSF 1.50 9050.00 3405.38 Mi0P1-0-SF 20768.74 119.23 20688.92 20649.51 MK:IM OSF 1.50 10580.12 362086 MinPN-04F 22462.69 119.81 22382.48 22342.8 283. OSF 1.50 12319,53 3761.40 MinP1.0-SF 32933.79 127.26 32848.62 32806.53 391.21 OSF 1.50 23396.68 3537.70 TD OiMak Point 1-1A406(P5)(Def Plan) Pau 13527.91 255.12 13357.19 13272.78 80.13 OSF 1.50 0.00 0.00 Surface 1--q 257.91 13218.41 13133.06 78.45 OSF 1.50 690.00 675.31 Mi1PI-CICt 13391.01 257....NE=KIME12 78.44 OSF 1.50 860.00 684.97 68441s 13417.13 258.97 13243.85 13158.1 78..% OSF 1.50 960.00 93860 MinPI-0-SF 33699.70 275.73 33515.34 33423.96 184.40 OSF 1.50 2388.68 3537.70 TD 0120-07(Def Survey) Pau � 155�66.43 265.05 15389.36 15301.38 88.45 OSF 1.50 0.00 000 Surface 1 5450 a 27274 1526021 15177.66 85.31 OSF 1.50 990.00 96576 M6PI-CICI 15450.41 272:RI.,.9O 15177.63 85.30 OSF 1.50 1000.00 974.76 MINPT-0-EOU 15450.45 272.83 15268..NOME, 85.29 0951.50 1010.00 98373 101nF1-044DP MIME 490.32 1345873 13295.75 42.29 OSF 1.50 9480.00 3465.94 M8PI-C1CI 13786.15 490. 13458.. 13295.58 42.27 OSF 1.50 9530.00 3472.98 MINPT-0-E09 1378623 490.67 13458 . EF r'-53 42.26 OSF 1.50 9550.00 3475.79 M l=t-O-ADP 13831.27 495.31 13500.52 188.=• 42.. OSF 1.50 10800.00 3623.65 MInPI-0-SF 2217257 426.79 21887.72 21745.78 78.10 OSF 1.50 23396.68 3537.70 TD 0P23-W W02(Def Survey) Pm 14330.04 5290 1429381 14277.14 429.65 OSF 1.50 0.00 000 Surface 54.41 13951.06 13934.06 411.37 OSF 1.50 1120.00 1080.59 MinPt 42Ct 1888.49 54.-�'- r'--,.11= 411.07 OSF 1.50 1130.00 1089.22 MnRa 14177.43 64.56 1413315 14112, 11L OSF 1.50 210000 1817.67 lAnPt-0-SF 14534.52 66.52 14488.90 14468,0 OSF 1.50 3100.00 2464.21 MnPI-0SF 15465.72 96.00 15400.59 15369.71 OSF 1.50 4600.00 2778.70 MinP1-0-SF 20069.44 123.01 19987.11 19946. OSF 1.50 10700.00 3637.28 MinP1-0-SF 20156.28 123.54 20073.60 200327 MEM, 055 1.50 10910.00 380.22 MInPt-0SF 21606.26 125.10 2152253 21481.1: 261.11 OSF 1.50 12319.53 3761.40 MinP1-0-SF 31946.49 128.56 31860.46 31817.93 375.60 OSF 1.50 23396.68 3537.70 TD OPZIVAVC3(P1)(Dill PM) Pass 14829.89 69.36 14783.24 14760.54 326.61 OSF 1.50 0.00 0.00 Surface I 14270331 73.77 14220.29 14196.56 300.64 OSF 1.50 1440.00 1339.72 MnPi-CICI 1427034 73-:MEE="E�1R41!9.�6i.4�8 300.31 08F 1.50 1450.00 1347.20 MINPT-0-EOU MIYCi. . 14270.41 73.95 14220.2 299.97 OSF 1.50 1460.00 1354.64 MInPt-0•ADP 1526.04 114.31 15157.55 15120. -L OSF 1.50 4600.00 2778.70 MinP1-0SF 19123.46 152.12 19321.43 19271. =i1LIM 055 1.50 10800.00 3600.22 MInP1-0SF 21821.14 154.37 27717.82 20666. MEM OSF 1.50 12319.53 3761.40 MinPl-0SF 30978.68 159.8 30872.10 30819.30 293.35 OSF 1.50 23396.68 837.70 TD OYktak Pont I-2701(Def Survey) Pau 14777.32 12277 14694.68 14654.55 184.09 065 1.50 0.00 000 Surface 14649.60 12159 14566.37 14526.01 Mialia OSF 1.50 760.00 75212 MnPI-0SF 14648.85 12359 1458.62 14525..•Minn 055 1.50 810.00 799.54 MnPI-0SF I-71 123.<ME=MIME 181.45 OSF 1.50 821.00 80897 MlnPls 14925.41 130.65 14837.51 14794.: IIIIIIIME OSF 1.50 2100.00 1817.67 MInPI-0SF 15944.84 153.99 15841.42 15790.-l 6 OSF 1.50 4600.00 2778.70 MinPl-0SF 19541.91 174.69 19425.12 19367.J.-=ODE OSF 1.50 1070000 3637.28 MinP1-0SF 1961821 175.37 19500.97 19442, ililipil OSF 1.50 10800.00 380.22 MR-0SF 21053.12 179.82 2093291 27873.•MOE OSF 1.50 12319.53 3761.40 MinPl-0SF 31006.91 170.89 3089265 30836.01 273.73 OSF 1.50 2386.68 3637.70 TD OP26DSPO2(Del Survey) Pass 14583.29 3281 14861.26 14850.49 77293 MAS-1000(m) 0.00 000 Surface MEE 33.15 14654.92 14644.88 731.12 065 1.50 920.00 90203 M.PI-CtCI 14678.03 33.1.EIZZE M:. 730.22 OSF 1.50 930.00 911.21 MinPts 1495525 53.82 14918.31 14901. 1111111Mt OSF 1.50 2100.00 1817.67 MinPl-0SF 16219.48 9030 1615237 16120.1.1 OSF 1.50 4600.00 277870 MinPt-OSF 17147.51 99.63 1708036 17047.> OSF1.50 6060.00 2984.31 66nPS0-SF 20677.12 18.13 20584.71 258.•= • OSF 1.50 10900.00 366242 MInPt-0-SF 2205215 140.87 21957.91 21911.:11111111 OSF 1.50 12319.53 3761.40 MinP1-0-SF 32309.38 141.09 32214.99 32168... 345.:• OSF 1.50 23396.68 3537.70 Ming-0-SF 012007P02(Del Survey) Pas 15566.43 285.05 15389.36 1581.8 88.45 OSF 1.50 0.00 000 Surface 54504 272.74 15268.21 15177.66 85.31 OSF 1.50 990.00 965.76 MinPt-CICI 1545041 272.%EL 15177.63 85.30 OSF 1.50 1000.00 974.76 MINPT-0-EOU 15450.45 27283 15268.r NOME, 85.29 OSF 1.50 1010.00 983.73 MnP1-0-ADP 409.95 1443235 14296.12 53.97 OSF 1.50 7270.00 3154.71 MnPt-C1CI 14706.13 410.131 14432281 1426.00 53.95 OSF 1.50 7310.00 316034 MINPT-0-EOU 14706.25 41028 1443231/ 14295.97 53.93 OSF 1.50 7340.00 3164.57 MnP1.0-ADP 14899.55 421.22 14618.16 14478.33 53.271 OSF 1.50 9660.00 3491.29 MinPI-O-8F 16181.06 428.20 150.6.17 15752.86' 56.859 OSF 1.50 12319.53 3761.40 MinPI-0-SF 24238.06 378.10 23985.67 23859.96 96.41 OSF 1.50 23396.68 3537.70 TD Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 10 of 11 Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)1 EOU(ft) Den.(ft) Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major L 0120.07PB1(Def Survey) 15519.90 26270 15344.38 15257.21 89.01 OSF 1.50 0.00 0.00 Surface MIME 26.11 15235.03 15147.08 87.61 OSF 1.50 900.00 883.60 MnPI-CICI 15412.19 26.1 15235.01 iiiiiiEMIE 87.61 OSF 1.50 910.00 892.82 MinPts 15575.19 271.42 1539077 15303... OSF 1.50 2100.00 1817.67 86091-0SF 16149.93 286.55 15958.42 15863. OSF 1.50 4600.00 2778.70 86091-0-SF 20052.06 293.13 19856.32 19758.' 102-- OSF 1.50 12319.53 3761.40 P4891-0SF 29426.47 267.63 29247.73 29158.84 16.53 OSF 1.50 23396.68 3537.70 TD Niksidwq 2(Dot 8taysy) Pass 15979.25 32.81 15977.34 15946.45 N/A MAS=1000(m) 0.00 0.00 Surface 15979.25 32.81 15977.33 15946.'- NI' MAS=10.00 on) 10.00 10.00 58091-0-SF 1 15979.251 32.81 .^ N/A MAS:10.00(m) 20.00 20.00 MinPts 15979.35 32.81 15976.71 15946.54 22084.44 MAS.10.03(m) 220.00 221.00 MINPT.0-E08 16744.90 32.81 16722.73 16712,:=MM MAS=10.00(m) 2100.00 1817.67 MinPt-0-SF 18841.61 58.37 18802.11 18783.2=EDE OSF 1.50 4600.00 2778.70 MinP1-0SF 19462.77 59.13 19422.76 19403.. ME ..n, OSF 1.50 5250.00 2870.24 Miort-O-SF 22870.62 63.98 22827.38 22806.•'M- r-, OSF 1.50 8800.00 3370.17 MinP1-0SF 24198.00 67.55 24152.39 24130.•MUM OSF 1.50 10180.00 3564.52 MinPt-OSF 24735.44 68.82 24688.98 24666.w iiiiiiiiiii E OSF 1.50 10740.00 3642.54 MinPl-0SF 25946.72 77.34 25894.58 25869.•=ME, OSF 1.50 12310.00 3760.90 MinP1-O-SF 26956.63 100.58 26899.04 26856..-=„- OSF 1.50 13816.44 3781.63 MinPtASF 28441.08 109.13 28367.7-NUM 396.77 OSF 1.50 15860.00 3807.93 MinP1-0-ADP 28448.85 109,68 28375.20 28339.1:iiiiiiiiiii EE OSF 1.50 15870.00 3807.76 MinPt-O-OF 28849.96 111.25 28775.25 28738.71 Man OSF 1.50 16355.39 3798.25 MinPt-O-SF 29220.06 113,04 29144.16 29107,,,iiiiiiiiiii= OSF 1.50 16800.00 3771.59 MinP1.0SF 32104.40 134.78 32014.01 31969,621iiiiiiiiiii0$£' OSF 1.50 20200.00 3775.69 MinPt-OSF 3219951 135.17 32108.86 32064. OSF 1.50 2030000 3777.04 MInP1.0SF 35231.84 134.67 35141.52 35097.17 397.17 OSF 1.50 23396.68 3637.70 TD OP03.P05PB1(Def Sunray) Pass 16737.32 57.14 16698.67 16680.19 452.61 OSF 1.50 0.00 0.00 Surface r-= 1 57,:, 445.30 OSF 1.50 620.00 617.03 MinPts 17157.93 67.79 17112.19 17090.1 liiiiiiiiiiiE2IM OSF 1.50 2100.00 1817.67 MnPt-OSF 17682.65 68.96 17636.28 17613..4=E.<: OSF 1.50 3020.00 2424.71 MnPt.O-SF 18805,62 98,6 18739.51 18706.. WitH. OSF 1.50 4600.00 277670 MnPt-O-SF 23842.14 130.59 23754.74 23711.-= OSF 1.50 10903.00 3662.42 MnPt-0SF 25243.18 131.67 2516.07 25111.51 289.7 OSF 1.50 12319.53 3761.40 MOPt-O-SF 35625.21 134.55 35535.22 35490.. 400.,• OSF 1.50 23396.68 3637.70 MnP1-0SF 0921-000001(Del Survey) Pees 17125.75 34.58 17102.37 17091.17 764.55 OSF 1.50 0.00 0.00 Surface Mania 36.66 1661.52 16839.6 710.89 OSF 1.50 970.00 947.68 MinPt-CtCt 1687631 36.,MIME U 710.25 OSF 1.50 98000 956.73 MinPls 1714681 50.6 17112.63 17096.1-IM ME OSF 1.50 2100.00 1817.67 MnPt-OSF 1853370 87.09 18475.31 18446.61 322• OSF 1.50 4600.00 277670 MinPt-0SF 23331.26 122.30 23249.40 23208.•• 288. OSF 1.50 10900.00 3662.42 MnP1-0SF 24700.13 123.76 24617.29 24576. 301.7- OSF 1.50 12319.53 3761.40 S8nPI-0-SF 3503299 126.98 34948.01 34906.,x• 417.0 OSF 1.50 2339660 3537.70 MinP1-0SF 0918-08P81(Def Survey) PINS 1761650 32.81 17604.35 17583.69 1642.94 MAO.10.00(m) 0.00 0.00 Surface iiiiiil} 32.81 17584.4 17561101 1598.13 MAS=10.00(m) 370.00 369.90 MinPls 17596.91 32811 17584. 17564.10 1595.40 MAS=10.00(m) 380.00 379.88 MINPT-0-EOU 18208.20 47.58 18176.03 18160.61= ¢ OSF 1.50 2100.00 1817.67 MinPI-0-SF 19683.03 98.69 19616.84 19584. OSF 1.50 4600.00 2778.70 MinPI.0-SF 24262.15 146.37 24164.18 24115.7:=fZIM OSF 1.50 11100.00 3684.43 MinPt-OSF 25463.91 148.95 25364.26 25114.'•=alai OSF 1.50 12319.53 3761.40 MinP1-0-SF 35531.68 149.98 35431.34 35381.,=MEE OSF 1.50 23396.68 3537,70 55691.0-SF Oliktok Pam I-1(Def Survey) Pan 17634.05 32.81 17832.93 17801.24 WA MAS=10.00(m) 0.00 0.00 Surfece MI -'' 32.81 17830.8 17800.781 11234.70 MAS=10.00(m 00) 220. 220.00 MinPts 17833.76 32.811 17830.7 17800.95 9420.30 MAS=10.00(m) 260.00 260.00 MINPT-O-EOU 18512.19 43.88 18482.57 18468.31=Zra OSF 1.50 2100.00 1817.67 MinPt-0-SF 18523.62 53..:x- ® OSF 1.50 2120.00 1831.73 MinPts 19339.97 58.72 19300.50 19281.c RE OSF 1.50 3470.00 2603.47 MinPt-0-SF 20040.90 95.59 19976.64 19945.31 OSF 1.50 4600.00 2778.70 MinPt-0-SE 24704.48 143.03 24608.80 24561.46®0:: OSF 1.50 11100.00 3684.43 MinPt-0-SF 25907.35 145.58 25809.97 25761. =SIM OSF 1.00 12319.53 3761.40 MinPt-0-SF 35980.60 147.22 35882.13 35833.. 369.,• OSF 1.50 23396.6 3537.70 MinP1-0-SF 0P05A6PBI(De Sunny) Psas I 17840.461 32.81 MEM MEM N/A MAS=10.00(m) 0.00 0.00 MinPts 17840.77 32.81 17838.- 17807.96 13820.56 MAS=10,00(m) 220.00 220.00 MINPT-0-500 18534,60 44.33 18504.64 18490.27 644,99 OSF 1.50 2100.00 1817.67 MinP1-4)-SF 20064.14 96.31 19999.57 19967.83 315.97 OSF 1.60 4800.00 2778.70 MinPt-0SF 2471027 143.76 24614.08 24566.51 259.75 OSF 1.50 11100.00 3684.43 MinP1-0SF 25912.32 146.26 25814.48 2576.06 26764 OSF 1.50 12319.53 3761.40 MinPl-OSF 35976.12 147.74 35877.30 35828.38 367.70 OSF 1.50 23396.6 3537.70 Min%-0-SF Drilling Office 2.6.1120.0 Nikaitchuq\Spy Island\SP22-FN1\SP22-FN1\SP22-FN1(P5)Alternate TD 10/16/2012 11:31 AM Page 11 of 11 Oilfield Services,Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell, Suite 400 Anchorage,AK 99503 Tel (907)273-1766 Fax(907)561-8367 16 October, 2012 Joe Longo, Luca Borri, Spy Island SP22-FN1 (P5) 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: MD From MD To IOU Freq Hob Size Casing Diameter Survey Tool Type Borehole I Survey et) (1U (nJ On) Cm) 0.000 41.000 11100.000 16.000 13.375 SL13_GYRO-MWD-0eplh Or* SP22.FN1 I S11224441(PS) Ahern*TD SP22RJ1ISP22-FN1(P5) 41.000 500.000 1/100.000 16.000 13.375 SLB_GYRO-MWD TO Alternate 500.000 2000.000 11100.000 16.000 13.375 SL.B_MWDSTD SP22-FNI I SP22-FNI(PS) Alternate TD SP22-FN1 I SP22-FN1(PS) 500.000 3018.820 11100.000 16.000 13.375 SL3_MWD+GMAGTD 3018.820 4500.000 1/100.000 12250 9.625 SLB_MWDSTD SP22-FN1 f SP22-FNI(P5) Mn*TD SP22-R11 I SP22.FN1(P5) 3018.820 12319.530 11100.000 12250 9.625 SLB_MWD+GMAG Marna*TO SP22-FN1 I SP22-FN1(P5) 12319.530 13800.000 11100.000 8.750 5.500 SLB_MWDSTDTD SP22-FNI I SP22-FN1(P5) 12319.530 23396.682 11100.000 8.750 5.500 SLB_MWD+GMAGTO Survey Interval Surface hole- 1 per 30 ft using Gyro-While-Drilling, or as directed by the DD until clear of magnetic interference or AC risk, then 1 per 30 ft with MWD, or as directed by the DD until clear of AC risk,then 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 risk. 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: D. Tess Cecil-Cockwell 16 Oct 2012 Schlumberger Traveling Cylinder Plot 0-500'MD NoGo Region EOU's based on: TRAVELING CYLINDER PLOT Oriented EOU Dimension Client: Eni Petroleum N Well: SP22-FN1 NoGo Region Anti-Collision rule Field: Nikaitchuq used:Minor Risk-Separation Factor Structure: Spy Island Date: December 03,2010 North 350 0 10 340 20 1 33�0140 30 320 .* * t, 40 •. 310 •� •.� 120 ♦ 50 300 ����►� , ��.. 60 ♦ i 290 � s� � - ---t 7 280 (( ��/��i�hi►���lj;Ti�R';4- .4444:414 8°,l 4l t,v /..egr, ite:-,;1-Z*. ,6-11N1.II 270 is-+� :. eft ' P • "wg„.i.:-'"'We 'tat' ' I: �./`/;' N. ,1fr��\` t0i.w5aI�i�'' 1 N7(P4b) 4 � , �. ;� .\ 1�� : '-'.--#-..�� I „, a� 100.1,f,,,\I,, ‘Nkm,,,,*:.,;(:,260 �►•i. ��`4 �� �`t ` , ` ��, >a yot 250N \k o`'' _ :�-,•��/: •/ ' 120 4P o� 710 i����a1��I� I iii/ \ 24`��® ■►�* * 120 LI 230 -�. �•♦�� ♦ 130 r� 220 •�� 140 210,# 150 200 160 190 180 170 Well Ticks Type: MD on SP22-FN1(P5)Alternate TD Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schiumberger Traveling Cylinder Plot 500-1000'MD NoGo Region EOU's based on: TRAVELING CYLINDER PLOT Oriented EOU Dimension N Client: Eni Petroleum Well: SP22-FNI NoGo Region Anti-Collision rule • Field: Nikaitchuq used:Minor Risk-Separation Factor Structure: Spy Island 4 • Date: December 03,2010 INorth 350 0 10 340 20 330 30 140 320, 40 . 120 r ■ 50 � 100 /8*11-.-- % Q It 2 �''270 _!`:..�6- ��_I i��•`�_�A-_ i 90 ,,igu Atli���- ��- _", iii 260 '��� i -1' �� r1► i ':6 .4. 100 � / ti h..* ,' .i �,;∎:k 1 .. :. ,,�►A O `,. ` °bet• �, #° ! ` - `>, �� 1 ' � �` 110 x �`t 250 /eir `�`' \ �, �� .� `,.1!,j. kt•• }'•'`ice`` � • `,.. ���` �.. ' I SI14 N6(P2) 24````-" 1�3C 1;,0 4%.'•L ��'1 \ ,titi° T120 "" 10-° t:�'ay 'SP18-N5PB1 6' t- #/• 7 7 1� 230 66. �' rGa— . ` �... 130 6 I ` 016 /� � 220 !i+�i5in•��I/.�1 2 y � ,; r�0 Og_IliPtl1• '71"1 1 c 4_�i* 1, 1is 211 tia�,�►����` `si/•v-`` gi..r� 16, • I 1 .1 200 -".11114 11"41111111M SPP?P7b) 190 .180 . .b)170 Well Ticks Type: MD on SP22-FN1 (P5)Alternate TD Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger Traveling Cylinder Plot 1000-3000'MD NoGo Region EOU's based on: Oriented EOU Dimension N TRAVELING CYLINDER PLOT Client: Eni Petroleum NoGo Region Anti-Collision rule . i. Well: SP22-FN1 used:Minor Risk-Separation Field: Nikaitchuq Factor "c Structure: Spy Island Date: December 03,2010 North 350 0 10 340 /alle. 20 330 .` i;I,, ��1/11ra�`` �,..30 �� �♦ `V �s�t• 6-FN3 32044...„040 ,s` ����, 1'1� rAWIC�ji ITit 40 �C••' ��i i/••,�:F�:>t % �\ 11a:�•- P2 310 'G`C4 '`, /.i!�'. "I j.'VZ; ,.:''''..1%-(9E3( ) '1 �`�,G�y� �!"I jpm1IN� 00,-.a♦ ∎�� ,:k101 b!li: -FN4(P5) ,� Amy. ",7,m V.4q.7 .�%�r%G� I('-11`7; . ; ;/fit► `� �@� '�I�r r1C�'�F� ,AI�I�X1111`i�l � •�` �I. IIiIr... `� mot, �� �f j �•I---v' v i .'� 300 / �, •�y1�1. ..- ,S. 6 1r !' ,a, S •i . 60 litiA: ..•40.2A‘;■4•1011:$1 .1Alifilialri 4 NINeklitti Vitk 4. .:INtVi,s/YallhalAsigAe&Ailt, .wirA V, 4 46.,.;/� . ._ \At. sh, 260 a _ t«'11F.A , --,--N 4'\ r„ /l,'`` r- it I V 1 aV r\�...ie' /j/I 270 \ / 90 „,..., ,„...44,N41 &t.1y•i1te7-mw,,4s 40.f.1 ti 1#711p11.g*1141A71 m,„ 260 ■,' 1 , ,, °9 ” /I/J� ° 100 1► .• ii ►• ♦ *4W *AkitigitsIiv"' 44 wffiliime0110 240,-��—r ttp.4144 ,0 _ �' .j♦j, 120 230 ♦ •i ••...r 1117.0.♦ .•p* °,,,,.4 :•, • 130 ♦ �. . 220 ' 1111111rAtellIN 140 !210 '�._- 1114411451150 200 160D37-DSP1 190 180 170 Well Ticks Type: MD on SP22-FN1 (P5)Alternate TD Calculation Method: Normal Plane Ring Interval: 20.00 ft 1 Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger Traveling Cylinder Plot 3000-12319'MD NoGo Region EOU's based on: TRAVELING CYLINDER PLOT Oriented EOU Dimension Client: Eni Petroleum T/ Well: SP22-FN1 NoGo Region Anti-Collision rule 41 used:Minor Risk- Separation Field: Nikaitchuq Factor . Structure: Spy Island Date: December 03,2010 North 350 0 10 340 '� 33� 30 X140 320 �� 40 LAO 4 11 �� 310 1141111111.12111410 50 300 •• � tr \s, 290 •..." 'n 1 ,i ♦ \CI 280 _ 0 80 270 ®�6isiin01 _ .^"'..,"������� 90 260 INli14.t 41 4 -'` ®0• o..4*i,,i9A./lir.4 4r4j44t.l8b44,,Vi rt%I 4iA b,1l ,4_'eli0 .A,I 7 Mt ltMa 4iaIIIItDS' 141P 11.70`�r 10 l 041.4T I 0.I I 14141AY I 1 1,1W 1M 250 44 ,, �' * 110 240 V , . 120 110 230 N' 4®0 n*p i♦ 130 220 4 e 140 ®. 210 n° ,,150 200 . 160 190 •180 1 (P2)170 Well Ticks Type: MD on SP22-FN1 (P5)Alternate TD Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger Traveling Cylinder Plot 12519-TD NoGo Region EOU's based on: Oriented EOU Dimension TRAVELING CYLINDER PLOT N Client: Eni Petroleum NoGo Region Anti-Collision rule Well: SP22-FN1 used:Minor Risk-Separation A Field: Nikaitchuq Factor Structure: Spy Island Date: December 03,2010 North 350 0 10 340 20 330 � 30 ' 140 ' 320 E •. '* 40 310 i ITIf#1A7#••#4&5°a 300 • ♦ .• .I1 ♦• ♦.•• k 60 290 /*#.• ' , ,*****4 lio 280 ifitth#4... ..... ♦ 80 III �� i Am viIlliiIl 270 90 260 - 0 14i0 0 a uo�*‘8AAa1P*1l 41*141O1111 100 wIL•Vw&, 44 MN v.250 � 3ry , , wt..,• * 110 240 l &s j.■•''' .••••0 120 Wq. 111111_11 0. 230 ♦*** •00 130 220 ��••• Mill •••• 140 �� 2,0 '�,■...••• 150 200 �1. rm/� ,. 190 180 170 Well Ticks Type: MD on SP22-FN1 (P5)Alternate TD Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Drilling Hazards Summary 16" Open Hole/ 13-3/8" Casin2 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" Casin2 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 /b § . Z ' © / '\ { > P C o 0D . A§ ' v, m ` 7* 3 §§' , \ \ ,o; ,o. i,o] =o z} §2| 5 0 \ \ \ ( \ § 2 (o2 to• .02 . 0' - ) 3pgw £ ƒ/ §� ` E � CVr _ if) = w )° ]° P § // 0 2 :,- |o5 |o - | 1 ce s [ ƒ T J - , , 0 °° �§ ■ik leo E }\\ - . -w g Hjoh E � ■ (rz \ _ e (� 9 \\ g§ \ /6 - \( a/ ® 5�� ƒ \/ - - k}� ��. c_> - , t} \1 § ) ¥ K i ! 9K ® 1e \ III I § � § / \� � / E|§ §.2 | q^ © E§w 77G\ j |fZ/ »( ;# 8 I . •` 08 .V.' �2 \k § § /\ h | � | | | a1 tII ij. _ - � �� » i�-- I | | KIM: � �~ « 9 A ■ 1111 III:1 k� I § „ . 1E11% . 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Disclaimer Notice: Schlu Merger submits:his document with the benefits'its judgment.experence,and good oilf!eR practices. This information is provided in accordance wth generally accepted industry prance,relying on fads or informaton provided by others,limitations,computer models,measurements,assumotons and inferences that are nct infallible. Calculations are estimates based on provider information.All proposals,recommendatons,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 Schlumbergeror others is not to be inferred and no intellectual property rights are granted hereby t Mark of Schlumberger Client : Eni Petroleum Well : SP22-FN1 Schlumdcrgcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 3019.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi 0 1 2 Frac Pore SV-4 SV-3 S SV-2 - t B/Permafrost �' SV-1 Ugnu Top (UG4) loom■1 TD Well Lithology Formation Press. Page 2 sp22 4n 1.cfw:10-18-2012:Version ms-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Ychlm ie String : 133/8 Surface Casing District : Prudhoe Bay �j Country : USA Loadcase : Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2939.0 ft Casing/liner Shoe MD : 3019.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 3019.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 134.8 % Mean OH Equivalent Diameter: 18.971 in Total OH Volume : 999.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 2000.0 16.000 190.0 20.063 3019.0 16.000 35.0 16.822 Max. Deviation Angle : 62 deg Max. DLS : 18.424 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 160.0 11.7 8.4 SV-4 Siltstone 782.0 11.5 8.4 SV-4 Siltstone 1168.0 11.5 8.4 SV-3 Sandstone 1489.0 11.5 8.4 SV-2 Siltstone 2000.0 11.5 8.4 B/Permafrost Shale 2258.0 12.0 8.4 SV-1 Sandstone 2709.0 12.5 8.4 Ugnu Top(UG4) Shale 3019.0 12.5 8.4 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1747.0 32 0.7 3019.0 2423.8 50 1.2 Page 3 1 sp22-fnl.ciw;10-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 2: fluid sequence Job Objectives: Cement Surface Casing with Returns Seen at Surface Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty : 0.48 lbf/100ft2 Displacement Volume 440.1 bbl Total Volume 1079.1 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Surface Lead Slurry 476.0 2514.4 10.70 k:2.08E-1 Ibf.s^n/ft2 n:0.187 Ty:16.36 Ibf/100ft2 12.5ppg DeepCRETE 63.0 504.6 2514.4 12.50 k:1.68E-1 Ibf.s^n/ft2 n:0.301 Ty:0.44 Ibf/100ft2 Surface Tail Mud 440.1 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 8 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2012 psi at 2939.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 174 psi ft (x 1000) psi < ) 0 2 — Hydrostatic —Frac —Pore Fluid Sequence Static Well Security Page 4 sp22-tnl.ctw;161 8-2012 Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schap boiler String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase Section 3: pumping schedule - Spacer/Spacer Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/- 0.2ppg Density Range) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 8.5-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Maintain returns during cement job if possible - Attempt to follow highlighted flow rates as close as possible and within ranges specified a Please note variance from highlighted Rates in Job Report Start Job: Circulate BU, Ramp up Rates Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead with Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 2.0 0.0 80 Line up Cement Unit Surface Lead Slurry 5.0 476.0 95.2 476.0 80 Mix/Pump Lead SLurry(3-7 BPM) 12.5ppg DeepCRETE 4.0 63.0 15.8 63.0 80 Mix/Pump Tail Slurry(2-6 BPM) Surface Tail Pause 0.0 0.0 1.0 0.0 80 Shut Down Pumping Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.5 440.1 51.8 440.1 80 Kick Out Plug with Cement Unit Pause 0.0 0.0 5.0 0.0 80 Line Up Rig Pump Shut-In 0.0 0.0 10.0 0.0 80 Bleed Off&Check Floats Total 03:18 1079.1 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 1 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2010 psi at 2939.0 ft Burst 4702 psi at 0.0 ft Page 5 s;I/1 181 Ow 11118 11111:Version wcs coma'?Oh Client : Eni Petroleum Well : SP22-FN1 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Temperature Results BHCT 65 degF Simulated Max HCT 70 degF Simulated BHCT 70 degF Max HCT Depth 3019.0 ft CT at TOC 61 degF Max HCT Time 03:00:01 hr:mn.sc Static temperatures: At Time (hr:mn) 00:10 hr:mn Geo.Temp. Top of Cement (degF) 60 degF 20 degF Bottom Hole (degF) 69 degF 50 degF Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time <30 min c) If issue with mixing system —switch to back-up mixing system d) If issue with tri-plex pump— Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time <10 min c) Note displacement volume pumped by mud pumps: verify with Co. Rep/WSL d) Subtract pumped volume from total volume =volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Page sp22-fn t-cfw;10-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumherger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated ECDs at Surface Shoe during Placement o_ Depth= 3019 ft vi — Frac -1.---11----- I ■ For !._. ,—w 1 I �11 - — — ._ _ �' __° N1111111111111111111011111N11111111111111111110N111111111111111111101111111 M � E� c\i- 11111111111111.11111111111 11 il,- - - ii- ; . : " -- IIINIIIIIIIIIIIIIIIIIIIIIIIII ' �ilili 11111111111111 i mon _ ' 1 __::::::::-.7:-1 7:-j-L,-- - I!'__- 1 1 cr w - �_�� -i 0 111111111111111111111111111111111•11 NMI . (xi- , o .. 1 I.... . p i.__. .. I . .ST- 06 1 1 1 1 1 I 0 30 60 90 120 150 180 210 Time (min) Page 7 sp22-fn1.cfw;10-i&2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated ECDs at Conductor Shoe during Placement 0- Depth= 160 ft cV — Frac ,_ . .. Pore 1 !__..__.1_.___ 1 —-_____J _.__ f_ —__ ,a — Lo - Hydrostatic — Dynamic 11 , i 1 jt I =`r' 1111111111111111111 1111111111111111111111111111111111111111111111111111111111111111111111 �m �� � ��� � =C. I•I• = � �� �� a —I• ������ �w∎�∎�I/��r � ��r�ri�� � � � i c 05 M__111111111111111111111111111 Q � r Ei111111111111111111111111INIIMI , � °. �� �� ���� ��I rn ����I•�� I I �- 1111 II _ _ _ i cp 0 30 60 90 120 150 180 210 Time(min) Page 8 sp22-fn 1.cfw:10-18-2012,Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Surface Pressures during Placement 0 rn Calc.Pump Press. - Calc.CemHP 0 O- O N a a 0 I o- 0 30 60 90 120 150 180 210 Time(min) Page 9 sp22-fnl.cfw;1618-2012:Version wns-cem472_05 Client Eni Petroleum Well : SP22-FN1 Saumburgur String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase Simulated Slurry Temperatures during Placement — l 0 First Sack Ten-p. i _ ■■■■■■■■■■■■■■ . _.. � •�• Last Sick Temp. . �_._-__ ,.. ■■■.i'■■■■■■■■■■■■ I r N i ' VllIl ■■■ ■■■O■■N■■■■■■■►I■■■. ■NN■■■■ '■■■■MMIN■■■■ NN■■■N ■ ■NO�KON ■■■■■■■■■. ■ ■ 1M1 ■ ■■■ NN ■ 1►1■ ■ ■■■ ■ - I ■ ■ ■■►u ■ ■ NO O■O■ ■II OM MOM M ■ ■u■■■►� ■■ NOON ■■N■NI O■■■ ■ ■ O 11111111011 ■ ■ ■■ ■ ■■■O ■ ■N - NI ■■ au ■ O■O■■ ■ ■i�■O■O ■■■ -go ■ ■ ■I ■ ■ ■ ■■ 1`.!■■■N■■N �_ ■■ ■■ ■■■ O ■■■ OO■ ■ ■O ■■■■■ ■ ■ ■■ _o w _`° NON ■■■■■■ OMMOO■■■■■■■■EMOMIN. ■■■■N■■N■■■■ONO■■NNO■■N■■■O■N OMMONN■■■■ ° •CD_ ■■■■■■■■■■■■■1►O■■■O■■I■■■■O■■■■■■■N■■■■■ I rc ■■■■■■■■■■■■■■O'■NO■■■■■■UO■N■ ■■■■■■■■■■ H ■ ■■■■■ ■■■■■■■1I■ ■■■■■■O ■■ N■■■■■■■■N IHIIHII11II1I1iIIIIIII1III1lIIIIIIIII1 k °- ■■■■■■■■■■■■OOO■O■iM21162!UNO■N=ii0 UO _ -o r O ,0 , --m— I I I I I r T r r , 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 10 sp22-tn 1.cfw;10.18-2012;Version wcs-cem412_05 Client : Eni Petroleum Well : SP22-FN1 Humbugs, String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Simulated Slurry Temperatures up to 24 hours after Placement ■� First Sack Temp. as� -m �� �-m f o Last Sack Temp. --::.:- --:::�.-. ��_� o_ . �� .- . -��- - �.. -o ao . „ ��CMM _IME= mum =•-=S�m�� i----s--i MIM-s-. -Mss----- N _ �....�?I EM MOM MIMMIEMMWMM -o _ -� -----. --- OM --.----.-- .l --- .-. .----.-. Imo.----.-.-- a _M —r-- _ 1111•1111111•1141•11111111111111 111111•11 •1111.1.11111111111111=1 _ rn --II111•∎∎�rrr�L. NIMMI .-�- •a- a) - -- - . --.��∎��---�.-. O aNrn- ___ � _____. -- -1� �� o .- --.11II•MNIIIIIHIIIINII III1.11Itl.i•111I•I.�.�I.�II• 111111. ..11 1 ,n__ N �1•. .--.-.H------ 111111111111•1••11111111111111 - �. N �� �.� �.. a ° o cu a)co . �--- ��■�A•rr�r•. .-- o — i01111111111111111111111111------•-•- -- ---- co =C _. ---►� _ * -.----.-M WW- .M.-M 1 i o CL.co ��..� �.■..�.iI :.:::m::- 1 I - -.-.--. _ ...1 .. 1.. 1.1 ... 1 I- 1•111 ----._ -.----.—.-- I -.-.--.-- 7 _. - - ------. -- • _ -.M•--.-. ..-. _ _. 111=111111=111111M c0 IIIIIIIINIIIIUIIIIIIIIIIIIIIIIINIMIIIIIIIIINJNIIIII - O 11111111111•111•11111111111111111111111111111111=m1111111111111111111 ._ Ln I------'---- If - I--•--.- _i -o 111111111.1111111111111111•111111111mmummameamawrommmimm. '_:_-1 0 0 ✓ r r r r r r 0 250 500 750 1000 1250 1500 1750 Time (min) Page 11 sp22-fnl.thy;10-1B-2012:Version wcs-cem472_05 S Client : Eni Petroleum Well : SP22-FN1 String : 133/8 Surface Casing District : Prudhoe Bay �u Country : USA Loadcase : Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.262 Ty :0.48 lbf/100ft2 Gel Strength :6.40 I bf/100ft2 MUD Mud Type :WBM Job volume :440.1 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Surface Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k :2.08E-1 Ibf.s^n/ft2 At temp. :75 degF n :0.187 Ty : 16.36Ibf/100ft2 Gel Strength : 14.25 Ibf/100ft2 DESIGN BLEND SLURRY Name :ASL(0.79) Mix Fluid : 11.075 gal/sk Job volume :476.0 bbl Dry Density : 108.69 lb/ft3 Yield :2.40 ft3/sk Quantity : 1113.31 sk Sack Weight : 100 lb Solid Fraction :38.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 11.075 gal/sk Page 12 sp22-tnl.cfw;1018-2012:Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Sil urger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 12.5ppg DeepCRETE Surface Tail DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.68E-1 Ibf.sAn/ft2 At temp. :74 degF n : 0.301 Ty : 0.44 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid :5.471 gal/sk Job volume :63.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity :226.05 sk Sack Weight : 100 lb Solid Fraction :53.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 5.471 gal/sk Additives Code Conc. Function D046 0.20%BWOB Antifoam D065 0.25%BWOB Dispersant D167 0.25%BWOB Fluid loss D153 0.10%BWOB Antisettling Page 13 sp22-tn1.ctw;10-18-2012;Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlemberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2999.0 ft Casing Shoe :3019.0 ft NB of Cent. Used :29 NB of Floating Cent. :15 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1979.0 16 1/3 NW-ST-13 3/8-8-ST A3B W131 0.0 1899.0 3019.0 13 1/2 NW-ST-13 3/8-8-ST A3B W131 26.2 2959.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) NW-ST-13 3/8-8-ST W131 13 3/8 18.386 14.685 No Hannover 16.000 1225.21 2996.70 A3B it % a— 0 911 L0 60 80 100 — Between Cent. I 1 1 1 4 4-Pt Cent. } -I- . T-tit j N _ , _;.=_,r__ - O O O V Pipe Standoff Page 14 sp224n1.cfw;10.18.2012;version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumkrier String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 6: WELLCLEAN II Simulator ft % % — I 11 n inn —Mad Contamination —Std Betw. Cent —Uncontaminated Slurry —Cement Coverage o 0 o– j . , , ' N { 1 0 O 1 – Fluid SequenceUncontaminated SlurnCement Coveragf FLd[ovdd. R.,.Mid on tlsvd z 3 3 z 0 0 0 0 500 500 500 � _ 500 1000 1000 1000 1000 -c 1500 _ - 1500 -c .c 1500 ' ° 1500 c S. a a — a a> I at at a� 2000 2000 2000 S� 2000 2500 2500 2500 2500 3000 3000 3000 `-' 3000 i m ; a) a, 3 a, 3 5 L O 6 Z .125ryg DeeramE Sul..ta iii MDPJSHIs" •MMn .H. Page 15 sp22-fn1.ciw;10-18-2012;Version wcs-cem472_05 O Client : Eni Petroleum Well : SP22-FN1 ScIimerier String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Section 7: operator summary MIXING PREPARATION MUDPUSH 11 Volume: 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.00 lb/bbl of base fluid D047 20.000 gal 0.20 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer Surface Lead Slurry Volume:569.8 bbl Density : 10.70 lb/gal Yield :2.40 ft3/sk Dry Phase Liquid Phase Blend: 111331 (Ib) Design Mix Water 351.9 bbl 10.0 bbl LAS Design 12.5ppg DeepCRETE Surface Tail Volume:63.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 29.4 bbl 10.0 bbl LAS Design 12.5 22604.963 lb Fresh water 29.445 bbl 10.001 bbl D046 45.210 lb 0.20%BWOB D065 56.512 lb 0.25%BWOB D167 56.512 lb 0.25%BWOB D153 22.605 lb 0.10%BWOB • Page 16 sp22-fn 1.cfw:10-18-2012;Version wcs-cem472_05 Schlumberger CemCADE*well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : SP22-FN1 Country : USA State : Alaska Prepared for : Mr.Luca Borri Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 10-18-2012 Business Phone : (907)659 2434 Prepared by : Stephen Lauper Phone : (907)273-1765 E-Mail Address : slauper@slb.com O(Cic'`G� �c cP FL 4 VATE Disclaimer Notice: Schlumberger submits this document wnh the benefit of ns judgment,experience,and good oilfield practices. This information is provided in accordance wnh generally accepted industry practice,retying on facts or information provided by others,limrlations,computer models,measurements.assumptions and inferences that are not infallible. Calculatons are estimates based on provided information.All proposals.recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING AS CURACY 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 ogles of Schlumherge'or others is net to he inferred and no intellectual property rights are granted hereby Mark of Schlumberger Client : Eni Petroleum Well : SP22-FN1 Schlumbcrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 12320.0 ft BHST : 90 degF Bit Size : 12 1/4 in ft (x 1000) psi < _ — > 0 2.5 -Siltstone— • 1- Frac - N Pore _l 1 hale_ _ —_-- 1 Shale 1 - _ _ ° Shale i , ( i_ r .=. wwwwwwwwwwww■ = ' —..- • • • •Sandstone• • • --�---g - .ter ° ° — -- — u-) Well Lithology Formation Press. Page 2 sp22-1n1.cfw:10-18-2012: LoadCase Intermediate Casing(a):Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Silelmrpr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 3019.0 13 3/8 68.0 12.415 Landing Collar MD : 12240.0 ft Casing/liner Shoe MD : 12320.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 12320.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1615.3 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 3.528 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 782.0 11.5 8.4 SV-4 Siltstone 1168.0 11.5 8.4 SV-3 Sandstone 1489.0 11.5 8.4 SV-2 Siltstone 2000.0 11.5 8.4 B/Permafrost Shale 2258.0 12.0 8.4 SV-1 Sandstone 2709.0 12.5 8.4 Ugnu Top(UG4) Shale 4295.0 12.5 8.4 UG-2 Coal Bed Shale Marke 7389.0 12.5 8.4 Fault 7 Shale 8411.0 12.5 8.4 Lower Ugnu Shale 9915.0 12.5 8.4 Schrader Bluff Top Shale 10082.0 12.5 8.4 N Sequence Top Sandstone 10396.0 12.5 8.4 N Top Sandstone 10566.0 12.5 8.4 N Bottom Sandstone 11163.0 12.5 8.4 N Sequence Base Sandstone 11935.0 12.5 8.4 OA Sand Top Sandstone 12312.0 12.5 8.4 OA-2 Top Sandstone 12320.0 12.5 8.4 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1747.0 32 0.7 3019.0 2424.2 50 1.2 12320.0 3761.9 90 1.9 Page 3 sp22-fnl.cfw;10-18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumbergcr String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 9396'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty : 8.86 Ibf/100ft2 Displacement Volume 928.1 bbl Total Volume 1279.1 bbl TOC 9392.7 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 8197.5 10.50 k:5.23E-2 lbf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 12.5ppg DeepCRETE 251.0 2927.3 9392.7 12.50 k:4.89E-3 lbf.s^n/ft2 n:0.960 Ty:15.95 lbf/100ft2 Mud 928.1 0.0 9.50 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 378 psi at 3019.0 ft Pore 138 psi at 3019.0 ft Collapse 2882 psi at 12240.0 ft Burst 5750 psi at 0.0 ft Csg.Pump out 63 ton Check Valve Diff Press 56 psi (x 1000) psi 0 2.5 1. Hydrostatic --I ---Frac Pore o " o" Irl 0 Mal kr) Fluid Sequence Static Well Security Page 4 sp224n1.clw;10.18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 I Client : Eni Petroleum Well : SP22-FN1 S hlumberger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 3: pumping schedule - Spacer/Spacer Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/- 0.2ppg Density Range) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 7-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Maintain returns during cement job if possible - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from highlighted Rates in Job Report Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Line-up Cement Unit 12.5ppg DeepCRETE 6.0 251.0 41.8 251.0 80 Mix/Pump Cement Slurry(3-7 BPM) Pause 0.0 0.0 2.0 0.0 80 Shut Down Pumping Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Mud 8.0 928.1 116.0 928.1 80 Kick Out Plug w/Cement Unit Pause 0.0 0.0 5.0 0.0 80 Line up Rig Pumps Shut-In 0.0 0.0 15.0 0.0 80 Bleed Off/Check Floats Total 03:13 1279.1 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 183 psi at 12320.0 ft Pore 139 psi at 3019.0 ft Collapse 2724 psi at 136.9 ft Burst 5279 psi at 0.0 ft Page 5 sp22-M1.ctw:10-18-2012; LoadCase Intermediate Casing lal;Versionwcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 S6111911 String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Temperature Results BHCT 85 degF Simulated Max HCT 90 degF Simulated BHCT 76 degF Max HCT Depth 12320.0 ft CT at TOC 76 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time (hr:mn) 00:15 hr:mn Geo.Temp. Top of Cement (degF) 76 degF 81 degF Bottom Hole (degF) 77 degF 90 degF Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl;2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time <30 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time <10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume =volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit: volume verified by Co. Rep/WSL Page 6 sp22-fnl.cfw:10-18-2012: LoadCase Intermediate Casing(al:Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schi berger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated ECDs at Intermediate Shoe o Depth= 12320 ft C) — Frac -{----1----i -i.--j- Pore in — Ftvdrostatic •N Dyna ric I ..._. _ _o —N' _ t __ rni.c) o ., _ cr W IIIIIIIIIIIMMIIIIIII o 111111111•11111111111111- :: M0 - -__ _ _, _ill -=_ - r = ..._ r -I L. ,_. . o t -r -r- t t co l r 1 1 I 1 0 30 60 90 120 150 180 210 Time(min) Page 7 sp22-tnl.ctw.10-18-2012: LoadCase Intermediate Casing(a):Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 SGhlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated ECDs at Surface Shoe co Depth= 3019 ft — Frac - Fbre I I - Hvdrostatic - Dynamic . . I CO CD,— a) `) I . 11) Cl_ o _-- ._ a CO I I I 1 i 0 30 60 90 120 150 180 210 Time(min) Page 8 sp22•tnl.cfw;10-18-2012; LoadCaseInt ermediate Casing(a):Versionwcs-cemd72_05 S Client : Eni Petroleum Well : SP22-FN1 Schlamhargar String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated Surface Pressure Duing Placement ° N — Calc.Rimp Press. r - - Calc.CemHP _ co_ -rr.-®--Ir--- MOMEEMN M MIrrirr-M 11 1 = 1M I cfl_ _ NI .4-._ . � _ ___ ° .. 1'I ° � r���■��!i- - NIIIIIra111111 11111111ll111111l1111111 o r — —■rrNIIIII r - _ .��rrr r - a -----`r- .` T, ,__ 6- fi , .... , „. `° c,..„,„ C a i___`-� mm.°, ,___ _ , .�...�L..... ====�� I- r �iirr ��- IIIIIIIIIIIIIwIIMPM.r..►is cr immirommiremei -1 g-- - _ -- ow.. -- Elm ° I 1 1 I , 1 1 0 30 60 90 120 150 180 210 Time(min) Page 9 sp22-fni.cfw,10-18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Moberg" String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated Slurry Temperatures during Placement 0 W First Sack Terrp. - Last Sack Ternp. _ 1111■■■■ ■■■ ■■■� 1__ 1- ■■■■■■ ■ ■■ ■ min pp ■ �_■■■ ■■1■■■■■us■.a•!.;.. .... N ( ■■ ■■■n■■■■■■.i■■■.. U 1-° ■ ■■ ■ 1111■ ■ ■a■■ �s■■�■■■■ F ■ ■S■ , _■■1■■■S► ■■S.■■...■■ ^N- I ■ . 1111 1111 ll■// ■11 ■ ■■ 111111111111- ■■■■■rl■ ■ ■■■■■u■■ ■ 1 ■■■ 11 ■■■ I 1■■■/,i■■■►ih■■■■ 11 ■ L ■. ■■ ■ ■■ ■■' ■■ /■ 1111■_ ° ■ ■ ■ ■1 ■I/ ■ ■ ■J 1■ ■ 1 III// ■WAIT ■■■■■�_ _ o U a 111111: 111:41111111111111111111111■/■ 1111■_■■ _ QD 1111■■ _ -� , ■■ 4 H 11111 111111111111111111101111111 f� , ■ ■■ ■ ■■ 111■ ::L _ ■■■ ■ 1] .. UM ' ::::::::::___1■■■ 111111 1 _ ± ■■■N■■■■■■■_ MUM. `° , ens . ■ ■__ ■■ 1■■■ ■■ ■ -o 1111 II_ 11■ ■■11 ■■1 ■�■■ 0„ k�■■■■■■ -' � . ■1■■■ iii:: ■■■ I_1'■ O • t t r r t 1 .1_ r r r i I ° 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 10 sp22-fnt.clw;10-18-2012: LoadCase Intermediate Casing lal;Vernon wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 S hlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Simulated Slurry Temperatures up to 24 hours after Placement co -o co First Sack Temp. Last Sack Temp. , ��—' °"I, E._--.,._,',, 11La.=,. ■■■.■ .m■ ■■■ -! _,.c.__,• 0.- ....ii==■i I MI--- ..�■■IL■I■. .. ' I a . ■i■■i■■i■ ■■■■■■■■■■aaaaa■ , 1 ,., pr-- 1 MOM sss�K1� 111+5111111110M1111111111111111111 �! I° o NMI ■ ■IIII■■■■■■■■■■ t L°.s t■ ■■ ■■■■_■ ■■ .■■■__ ) o a ■I0il�l �i1111 111.1 i1�14 i■■■■.■■11i1i■.I�iri■■r■1■■■ i ■■ ■1■�I■■r� ■I■r■.� �■IM■ �MI■��r■ 1 _a� ■■■■■■■■■■■■■■■ a■ ■■ ■... - ■■■■ ■■ aN■■ ° - IMM _:_���$■■■��■�� ��■■1111■■ I r� ■_■ ■■■■■ ■■■■■■■■■■ ■■■■■■■ o ■ ■■■■ ■�■�■ ■■■■■■� ■■� i s=�s: =:�s:== = m=::S :::m- ■ � : _ :�:�::�:::s:::::::::_:�:�::: �_ E■■■■■.■■■■■■■■_■■■■■■■■■■■■■■ _ _0) I•■��■����■�■�■ ■������1��■■■�■ o •1 4 ■I rM■■r■ ■ IR MI ■�MII•O0 ■■■■ 1 0 Lc) r r r lobo 0 250 500 750 1000 1250 1500 1750 Time(min) Page 11 sp22-tn1.ctw;10-18-2012: LoadCase Intermediate Casing(a);Version wcs-censd72_05 Client : Eni Petroleum Well : SP22-FN1 ScImierger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo.Model : HERSCHEL_B. k :5.97E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.616 Ty :8.861bf/100ft2 Gel Strength :32.02 lbf/100ft2 MUD Mud Type :WBM Job volume :928.1 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.23E-2 lbf.s^n/ft2 At temp. :80 degF n :0.324 Ty : 12.921bf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl 12.5ppg DeepCRETE DESIGN Fluid No:3 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :4.89E-3 lbf.s^n/ft2 At temp. :74 degF n :0.960 Ty : 15.951bf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid :5.471 al/s Job volume :251.0 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3 Quantity :900.61 sk Sack Weight : 100 lb Solid Fractio 53.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 5.471 gal/sk Additives Code Conc. Function D046 0.20%BWOB Antifoam D065 0.25%BWOB Dispersant D167 0.25%BWOB Fluid loss D153 0.10%BWOB Antisettling Page 12 sp22-fn1.cfw;10-18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :12300.0 ft Casing Shoe :12320.0 ft NB of Cent. Used :73 NB of Floating Cent. :73 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 9400.0 0 0/0 0.0 9418.2 12320.0 73 1/1 HYDROFORM HFD 50.0 12320.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford(') N.A. N.A. N.A. ft 0 9n 0 60 80 100 — Between Cent. 4- +A Cent. E III II 111 - 4 ... 0 o —_._ _' __ _. _ __. o— o M ll' — 11111111111111•. 0 o _ 0 krs Pipe Standoff Page 13 sp22-tnl.clw;10-18-2012; LoadCase Intermediate Casing(a);Version wes-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Schlulbergcr String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 6: WELLCLEAN II Simulator ft o_ 0 25 50 75 100 0 50 100 I O —Std Betw.Cent. -Mud Contamination co —Cement Coverage -Uncontaminated Slurry ,._1-'. 8 O- N Fluid Sequence Cement Coverage Uncontaminated Slurry c.a ro�.os. P Mw s the wa z 3 3 z 9000 9000 9000 X9000 9500- 9500 9500 $ 9500 10000- i 10000 10000 10000 w w � w 10500 10500 " " 10500 10500 " _c s _c r S. a s_ a p 11000- 11000 o p 11000 11000 0 11500- 11500 11500 11500 12000- 12000 12000 12000 - I o -o o -°'o L.L. 3 3 t 0 0 z z MW .:,-.1.„ N 1l5ppq Dep[RFIE ■ •Noe MUDPJSN ii Page 14 sp22-fnl.ctw 10.182012: LoadCase Intermediate Casing(al-Version wcs-cem472_05 Client : Eni Petroleum Well : SP22-FN1 Scbmierger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing(a) Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume: 100.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.20 gal/bbl of spacer D182 543.750 lb 6.00 lb/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer 12.5ppg DeepCRETE Volume :206.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (lb) Design Mix Water 96.3 bbl 10.0 bbl LAS Design 12.5 73899.539 lb Fresh water 96.259 bbl 10.001 bbl D046 147.799 lb 0.20%BWOB D065 184.749 lb 0.25%BWOB D167 184.749 lb 0.25%BWOB D153 73.900 lb 0.10%BWOB Page 15 sp22-tn1.cfw;10-18-2012; LoadCase Intermediate Casing(a);Version wcs-cem472_05 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. En' E&P Division REVISION STAP-P-1-M-6140 0 1 1 1 1 1 1 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x ND where: P = Pumping Pressure (psi) ND = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW - Px10 + MW ND where: P = Pumping Pressure (kg/cm2) ND = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). S P E O IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. Erd E&P Division REVISION STAP-P-1-M-6140 0 1 1 I I I I LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT)or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. S P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 1 1 1 1 1 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. S P E O IDENTIFICATION CODE PAG 209 OF 338 • Enl E&P Division REVISION STAP-P-1-M-6140 0 1 I J 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 0ameter(in): 12"1/4 Weight(KgA): 1.3 R.K.B.ele vat on(m): 26 Last Csg.Shoe(m): 797 Marsh 1Ascosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter On): 13'7/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.(lb/100le): 5 Users(in): 6.5" Weight Obit): 61 Gels/b/100 t': 2/8 Flow Rate(bpi): 0.25 Mao.Burst pres(psi): 3103 W.L.(cc.30 min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2/1 0 m Time Vol Lrne 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 9 5 2 480 3 0.75 200 10 2 470 4 100 300 10.5 2 463 5 126 400 11 2 465 6 150 500 11.5 2 460 7 1.75 570 12 2 446 8 2.00 600 13 2 440 8 200 550 14 2 437 8.5 200 505 _ 15 2 435 Nde: Pumped with a constant low rate of(bbl): lblume pumped(bbl): Volume returned(bbl): (pst) 1000 900 800 stop pump r 700 ` • e 600 / shut in curve S 500 / - r U 400 . • - . r 8 minutes e 300 200 100 t) . - . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 i 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbD 41 IP Time mins RESULTS:(Press.,, +Press.LO,)x101)epth=[(1.3x797/10)+(430x0.07)]x10/797=1.68(Kg/cmz/10m) Note: Company Representative Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY OK APP 1 DESCRIPTION 0 10/0710 DI-IS CC CC '-'■*•,„ .: ;''',-;w,-Ig . , VICINITY MAII SCALE: 1" .,--. 2 Mlles 1 ---1, 30 2;1 ',.-T SURVEY 25 30 29 2B 21 26 25 * ,,_ ._ ,.---.. ..--,- —4— — .,... :—.........,—,—.--. —,...—— — - 1 W' w ig ! 1'14N I 114N 1 T13N 11N1 . 2 •:Ka* PCto.04D1',. OLIKTOK 5 ;, 1 ... 7-- r _ 1 - 1 N,5 1! 3, i':■,,,.....,,,s_.3R i P' IA DS-3Q P D 0 -- „01 1 (3 Alt up„o i, .,,„.. ' ..,-.14, D 3D ”, JAY _ . MI'. s °AkAi " 314 2a 27 AV l Q lki oo• ""''\' „r-N,L - ,I i f U 1\-. Ni 1 ‘..m1 j.T F-A1 II , -.o I..,I °6 • _ , e, , G P •• 4 . , so ., Oa Ilkili' l' DRAWING NOTES: 1. GRID COORDINATES SHOWN ARE ALAK A STATE PLANE, ZONE 4, N AD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NOR111.. RANGE 9 EAST, UMIAT MERIDIAN. S. ELEVA11ONS 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 OR COORDINATE VALUES IN NA027. ii.logoommill_ 4,41P,1)......... . ......... tin or6:311, oi V. No` .,. SURVEYOR'S CERTIFICATE 0 41 .... 1.1,. A 49 t h 1 t- 70 I HEREBY CERTIFY THAT! AM PROPERLY REGISTERED AND 0 7----% . .1 1 , LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF t...11-=fi'-' in:.4 .64esup ....; ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY n -a . P. r` ■ FRANCIS J CORNING ,,: fir DONE BY Mt OR UNDER MY DIRECT SUPERVISION AND 0 -.. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT . -:I' .• Ls-toses ..." 4w It ,k tip. AS OF OCTOBER 01, 2010 •.%'6...10/4,..A41.9". 4: 4.6,,,,_'•............. aitii"Vii, q-SS ONte-.4■046'. -‘11111‘1111106.1'— 40* 14&Aro SPY ISLAND DRILL SITE WELL CONDUCTORS AS—BUILT LOCATIONS 11*.1 ". CAD FILE:ENI35431).9 fill us Opera rwlifg DATE DRAWING NO: PAR : REV: 1 o/0'. Eni-3543—d9 _ OF 3 0 REV DATE BY CK': APP , DESCRIPTION :REV' DATE BY CK APP DESCRIPTION o 'c /10 DNS CC jCC Ini.ic; Draw;.g N r S iiroii,r �Gc, � C , Sec TU ,A\ St.i[.. v Sec 17 SDP. np A.S-P. NAUb . 74. -, ` `n o00 .71 zJ N ° W Ni CST 000000 "' N — SA, LA P A oLY C-,4 ? 0 C?f t4 0 W .P co DETAIL A. SCALE: 1"•=80' SANDBAG 1°E" ..tL , i46it.1 -i'e'le I4 .,- _ , AViL SNEER t 1 4\rya cia ;lit' O# .lilt a. " gill ua ca C,4QG ` ° •" Y* It DETAIL A \ S N.p• SPY ISLAND DRILL SITE (SID) { t n -5µptytDE' 1t lIE $AG LEGENC SCALE 20 �'DO�200 0 - WELL CONDUCTOR AS—BURT THIS SURVEY 1" — 200' V*/ V.1 dqe SPY ISLAND DRILL SITE WELL CONDUCTORS • AS—BUILT LOCATIONS 2n n .t,,, {PM2Tor CAD FIL :E 4 c9 s optiratang Dc/D'+/2D10 DRAWING NO: ELI-3543—d9 3 ,REV. REV DATE BY CK APP AESCRIPTICN REV DATE Ely CK APP ' DESCRIPTION 00 cc Protracted Section i9, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. - -• 'Y' ` 'V _atitude (N) Longitude (W) F,N.L F.E.L Elev. r (USft.) (USft.) 1 6053423.20 1651769.82 70°33'27.209" 149'54'2.4.765" 797 1171 12,4 2 6053421.65 1651761.87 70°33'27.194" 149'54'25.000" 798 1179 12,4 3 6053420.07 1651754.10 70'33'27,179" 149°54'25.229" 800 1186 12.4 4 6053418.56 1651746.17 70'33'27.164" 149°54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70°33'27.149" 149'54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149°54'25.925" 804 1210 12.4 7 6053412.44 1651714.77 70°33'27.104" 149'54'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70'33'27.089" 149°54'26,622" 809 1234 12.4 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" 14754'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149°54'27,318" 813 1257 12.4 12 6053404.80 1651675.51 70°33'27.029" 149°54'27.551" 815 1265 12,4 13 6053400,38 1651652.80 70°33'26.986" 149°54'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70°33'26.971" 149°54'28.453" 821 1296 12.4 15 6053397,31 1651637.12 70°33'26.956" 149°54'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149°54'28.917" 824 1311 12.4 17 6053394,32 1651621.47 70°33'26.927" 149°54'29.147" 825 1319 12.4 18 6053392.78 1651613.58 70°33'26.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 7(733'26.881" 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°33126.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70°33'26.838" 149°5.4'30.538" 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 1651.528.13 70°33'26.750" 14754'31,904" 843 1413 12.4 27 6053374.53 1651520.23 70°33'26.734" 14754'32,137" 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" 147'54'33.527" 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 r 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 *pm* 40.!,fisci,9e, SPY ISLAND DRILL SITE WELL CONDUCTORS • f AS-BUILT LOCATIONS 2n• 1' rP4.a�'1 CAD PILE-Eh13543C9 CIS operating DATE, DRAWING ND: Ent-3543-d9 IPART: 3 I REV... 1 a 0. o 10 s m o > o ' \V W v > a aa s a, a a a a a a a a a a a a aa, v a a a, v v a a a•..0• Y M N e .� N IV N N N N N N N N N N N N N N N N N N N N Q Z C D_ 7, ., . . . ., ., ., .1 ., ., ., ., ei N N . .i .i . .i eti .-1 0 'c a- w . 3 .Q _ e 4-, w �.1 ., 01 10 Cr NOW a N 01 ^ 1f1 00 LID .-I 01 n M .-1 00 %D a N 1A M ,1 CO C N N 00 01 O N N M a a IA tD Oo 01 0 .-1 .i N a IA 1!1 tD N 00 O .-1 N N v1 N ey N N ei N., N e, N eti N., N eti N e N N N N M M o M M M M M M n a J LL ei ti ., y N N N N N N N N N H N N O .i ey .r .-I a) C • C o pp u Z O^1 001 0 0 0 0 0 0 M .-I .-I .1 N N N N N N M M M M M M MOW ' 'N N 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 co 00 000 0000 0000 to LL D c s o _ _ _ _ _p _ _ _ _ _ _ 00 N q CO 0 .7 0 M N O M ttO M N O M M 0^1 t0 M N 111 M N 01 N t11 00 M tD 00 O M v1 O N a N- Ol .-I 0o O M Ill N 01 a t0 Ol ., M t0 N v1 N. 01 . . . . . . . . . . . . . . . . a1 M M M a a a V1 Vf IA IA IA tD tD n n n n n 00 00 00 O1 01 O1 O O O O eti N N e-1 ., ey N N . . . . . . e-1 eti N e-1 .1 N N N N N 7 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 v1 In In In . . . 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O O '^V_ OMl .a m m .m-1 N pp ra N N t^O to to to to Ou11 ton tan 0 @ } m M M M M M M M M M JO Y M M M M M M M M M M Q _� 0 0 0 0 0 0 0 0 0 0 O Q t0 l0 to l0 l0 t0 to to tO t0 (.) In 7 o _ 'O 1-101-1 C 0 . M O m O O l> ID -- 'O O Z m 0 ei N m a N to N 00 0^0 =• r-1 0) .--i N N M M M M M M M M M O E• _, v u V• 0 V O - -- 0 String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial • Surface Casing 13 3/8",68.000 ppf,L-80 BTC,L-80 32.0-3019.0 12.259 1.97 1.91 3.17 Burst Design(13 3/8"Surface Casing) Collapse Design(13 3/8"Surface Casing) Axial Design(13 3/8"Surface Casing) 700 I 700 700 t = L a 1400 a 1400 a 1400 0 0 0 112 m y 2100 al 2100 N 2100 m a> a> 2800 2800 2800 Design Load Line T Design Load Lin- - Design Load Line Pi.e Ratin• Pi.e Rakin• - Pie Ratin• II L 2600 3250 3900 4550 0 700 1400 2100 400000 800000 1200000 160000C Burst Rating(psi) Collapse Rating(psi) Axial Force(lbf) Minimum Safety Factors(13 3/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(13 3/8"Surface Casing) 32 13 3/8",68.000 ppf,L-80 BTC,L-80 1.97 B5 +100.00 Cl 4.81 B5 2.55 B5 41 1.97 05 +100.00 Cl 4.82 B5 2.55 B5 Drilling Load: Pressure Test 160 1.97 B5 28.76 Cl 4.94 B5 2.55 05 Test Pressure: 2500.0 psi 160 1.97 B5 28.75 01 4.94 B5 2.55 B5 Mud Weight: 9.40 ppg 200 1.97 B5 23.01 Cl 4.99 05 2.55 05 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 200 1.97 05 23.01 Cl 3.91 B5 2.52 B5 500 1.97 B5 9.24 01 3.17 B5 2.42 B5 Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 700 1.97 B5 6.65 01 3.26 05 2.41 B5 Surface Pressure(1/3'BHP): 549.1 psi 900 1.97 05 5.23 Cl 3.34 B5 2.39 B5 Shoe Depth,MD: 3019.0 ft 1000 1.97 B5 4.74 01 3.39 B5 2.39135 Fracture Pressure at Shoe: 1578.2 psi 1100 1.97 B5 4.35 01 3.43 85 2.38 B5 Fracture Margin of Error: 0.00 ppg 1200 1.97 05 4.03 01 3.48 B5 2.37 B5 1300 1.97 B5 3.76 01 3.52 05 2.36 B5 External Pressure: Fluid Gradients(w/Pore Pressure) 1400 1.97 B5 3.53 01 3.56 B5 2.36 B5 TOC,MD: 3019.0 ft 1460 1.97 05 3.42 01 3.90 B5 2.38 B5 Prior Shoe,MD: 160.0 ft 1671 1.97 B5 3.06 01 5.80 Al 2.49 B5 Mud Weight Above TOC: 9.40 ppg 1671 1.97 05 3.06 Cl 5.81 Al 2.49 B5 Fluid Gradient Below TOC: 8.40 ppg 1700 1.97 05 3.02 01 5.83 Al 2.50 B5 Pore Pressure In Open Hole: No 2000 1.97 B5 2.65 01 6.13 Al 2.49 135 2601 1.97135 2.13 01 6.93 Al 2.49 B5 2601 1.97 05 2.13 01 4.10 B5 2.28 B5 Collapse Load Data(13 3/8"Surface Casing) 2700 1.97 B5 2.07 01 4.15 05 2.27 B5 2800 1.97 B5 2.01 Cl 4.20 85 2.26 B5 Drilling Load: Full/Partial Evacuation 2900 1.97 05 1.96 01 4.25 65 2.26 B5 Mud Weight: 9.40 ppg 2900 1.97 B5 1.96 01 4.24 B5 2.26 B5 Mud Level,MD: 3019.0 ft 3000 1.97 B5 1.92 01 4.29 65 2.25 B5 Assigned External Pressure:Fluid Gradients(w/Pore Pressure) 3017 1.97 B5 1.91 Cl 4.29 B5 2.25 B5 3018 1.97135 1.91 01 4.29 B5 2.25 B5 External Pressure:Fluid Gradients(w/Pore Pressure) 3019 1.97 B5 1.91 01 4.29 B5 2.25 B5 TOO,MD: 3019.0 ft Prior Shoe,MD: 160.0 ft Fluid Gradient Above TOC: 9.40 ppg Fluid Gradient Below TOC: 8.40 ppg 05 Pressure Test Pore Pressure In Open Hole Below TOC: No Cl Full/Partial Evacuation Al Running in Hole-Avg.Speed Axial Load Data(13 3/8"Surface Casing) Running in Hole-Avg.Speed: 0.1 ft/s Green Cement Pressure Test: 500.0 psi String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Production Casing 9 5/8",40.000 ppf,L-80 Series 500 Type 563(TC) 32.0-12320.0 8.750 A 3.75 1.67 2.98 A Alternate Drift Burst Design(9 5/8"Production Casing) Collapse Design(9 5/8"Production Casing) Axial Design(9 5/8"Production Casing) 2500-- - 2500 2500 - g g a 5000- - a 5000 a 5000 0 - 0 0 a)d [ i 2 N 7500- y 7500 - y 7500 10000- ---- 10000 10000 - - Design Load Line - Design Load Line - Design Load Line 12500- i - Pipe Rating L 12500 Pi.e Ratin. 12500 Pi.e Ratin. 1I I I 1 1 1 1 1 1 1 .. 1500 3000 4500 6000 0 950 1900 2850 400000 600000 800000 Burst Rating(psi) Collapse Rating(psi) Axial Force(Ibf) Minimum Safety Factors(9 5/8"Production Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(9 5/8"Production Casing) 32 9 5/8",40.000 ppi,L-80 Series 500 Type 563(TC) 4.05 B6 +100.00 Cl 3.80 A5 3.48 AS Production Load: Tubing Leak 41 4.05 B6 +100.00 Cl 3.81 A5 3.48 A5 Packer Fluid Density: 9.00 ppg 200 4.06 B6 30.47 Cl 3.91 AS 3.51 AS 22000.0 ft 200 4.06 B6 30.47 Cl 3.38 AS 3.29 AS 500 4.08 B6 12.26 Cl 2.98 AS 3.06 A4 Perforation Depth,MD: 23396.7 ft 700 4.09 B6 8.83 01 3.06 AS 3.05 A4 Gas Gravity: 0.70 780 4.09 B6 7.97 Cl 3.09 A4 3.05 A4 Reservoir Pressure: 1549.5 psi 900 4.10 B6 6.96 Cl 3.09 A4 3.04 A4 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 1000 4.11 B6 6.32 Cl 3.09 A4 3.04 A4 1100 4.11 66 5.80 Cl 3.10 A4 3.03 A4 External Pressure: Fluid Gradients(w/Pore Pressure)1200 4.12 B6 5.37 01 3.10 A4 3.03 A4 TOC,MD: 12320.0 ft 1300 4.12 B6 5.02 Cl 3.10 A4 3.03 A4 Prior Shoe,MD: 3019.0 ft 1400 4.13136 4.72 01 3.10 A4 3.03 A4 Mud Weight Above TOC: 9.40 ppg 1700 4.14 B6 4.05 C1 3.11 A4 3.02 A4 Fluid Gradient Below TOC: 8.40 ppg 2000 4.15136 3.56 C1 3.12 A4 3.02 A4 Pore Pressure In Open Hole: Yes 2601 4.18 B6 2.88 C1 3.15 A4 3.03 A4 2700 4.19 B6 2.80 Cl 3.16 A4 3.03 A4 Collapse Load Data(9 5/8"Production Casing) 2800 4.19 B6 2.72 C1 3.16 A4 3.03 A4 2900 4.19 B6 2.65 C1 3.17 A4 3.03 A4 Drilling Load: Full/Partial Evacuation 3000 4.20 B6 2.60 CI 3.18 A4 3.03 A4 Mud Weight: 9.40 ppg 3019 4.20 B6 2.58 Cl 3.18 A4 3.03 A4 Mud Level,MD: 12320.0 ft 3100 4.20 B6 2.54 C1 3.18 A4 3.03 A4 Assigned External Pressure:Fluid Gradients(w/Pore Pressure) 3161 4.20 B6 2.52 01 3.18 A4 3.03 A4 3200 4.20 66 2.50 C1 3.19 A4 3.04 A4 External Pressure:Fluid Gradients(w/Pore Pressure) 3300 4.21 B6 2.46 C1 3.19 A4 3.04 A4 TOC,MD: 12320.0 ft 3400 4.21 B6 2.43 C1 3.20 A4 3.04 A4 Prior Shoe,MD: 3019.0 ft 3500 4.21 B6 2.40 C1 3.20 A4 3.04 A4 Fluid Gradient Above TOC: 9.40 ppg 3600 4.21 B6 2.38 C1 3.21 A4 3.05 A4 Fluid Gradient Below TOC: 8.40 ppg 3707 4.21 B6 2.37 C1 3.21 A4 3.05 A4 Pore Pressure In Open Hole Below TOC: No 10700 4.28 B6 1.73 C1 3.98 A4 3.21 Cl 10700 4.28 B6 1.73 01 3.98 A4 3.20 01 11000 4.28 B6 1.71 C1 4.11 A4 3.19 01 11300 4.28 B6 1.70 C1 4.26 A4 3.17 C1 Axial Load Data(9 5/8"Production Casing) 11600 4.28 B6 1.69 C1 4.43 A4 3.16 C1 11700 4.28 B6 1.69 01 4.49 A4 3.65 01 Running in Hole-Avg.Speed: 0.7 ft/s 12318 4.29 B6 1.67 01 4.99 A4 3.62 01 12319 3.93 B6 1.67 01 4.99 A4 3.57 01 Overpull Force: 100000 Ibf 12320 3.75 136 1.67 01 4.99 A4 3.54 01 Green Cement Pressure Test: 1800.0 psi B6 Tubing Leak C1 Full/Partial Evacuation A4 Overpull Force AS Green Cement Pressure Test(Axial) Page 1 o 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, November 29,2012 9:57 AM To: 'Born Luca' Cc: Davies, Stephen F (DOA) Subject: RE: SP22-FN1 (PTD 212-162) Thanks. An updated schematic would be good to have. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From: Borri Luca [mailto:Luca.Borri @enipetroleum.com] Sent:Thursday, November 29, 2012 9:39 AM To: Schwartz,Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: SP22-FN1 (PTD 212-162) Guy We can install an oil swellable pck 1 joint after the shoe,our liner always include this type of packer. Do you need the update schematic? Regards Luca From: Schwartz,Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, November 28, 2012 4:58 PM To: Borri Luca Cc: Davies, Stephen F(DOA) Subject: SP22-FN1 (PTD 212-162) Luca, Are you planning on setting some kind of swellable packer at the toe of the well(attached to slotted liner) to keep the N sand isolated from the OA sand? Was just thinking that it might be better to keep the sands isolated even if they are in same pool. The reservoir pressure may change differentially over time and start crossflowing. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) 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. 11/29/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 28, 2012 4:58 PM To: 'Borri Luca' Cc: Davies, Stephen F(DOA) Subject: SP22-FN1 (PTD 212-162) Luca, Are you planning on setting some kind of swellable packer at the toe of the well (attached to slotted liner) to keep the N sand isolated from the OA sand ? Was just thinking that it might be better to keep the sands isolated even if they are in same pool. The reservoir pressure may change differentially over time and start crossflowing. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11/28/2012 TRANSMITTAL LETTER CHECKLIST WELL NAME Ni l�G� %1 cc� C PTD# Z Development Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: (.`t_Qi kick-cei POOL: /l/4a_/IC CL c�<� c --4 -C el<2z - Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 m To =_ a) n , co o te o Q a>c co To o.>_' ? m 0 `° .0 o E m U) O O u, N E E w a T -a co O E a) n o_ (p n 0 0 a) > °c o c ° as (n w (n as 3 6) ° O O coo w O 0) E ^ @ z c CO a a) n ao 2 m E 0 a) L co c 0) 0) '>, (9 Q x a) D 0 a) C C a) N o5 cn U. a) `O O cy)d CO co U a) n CD co 0 L .0 o- N C a) co a7 C O n = E M 3 L j. N -o co co o U V) T n 'O 3 C N (/) C 3 n 0 a E > a) -co 2 — 0 a Q E n = (n C) ° c a) ° 3 CO c Cl) N (a w N OO) a) Uo CO W. 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E V aU) n o a) a) - 0 a) ' a) -o N E 0) 00 N C o = 0 co .a w (n o a) E@ o 0 0) a) n u) w 0 w 1- '� rn n m m `'3 a - o `o) T .- 3 2 N ° - o n•• a a) a, o c .S 0. a_ aaai N >, (° a) a) a) .3 c ` m o 0 o co Y a - 5 ,_ m o o 0 a) > " m al .-L O N L - `o -o -a 0 ' C co L L L 0 L a) N 'y a) a) > o) 0 L a) N y U ° 0 . C a) E E _.'(n C E Q) ° w Ct `° O L C c " a) 0 co `O a O 'N _ 3 "a 0 u) C O 0 -co C a) C o co 0 > 0 3 m m m c : a a 0 (° 3 a o 0 a) a) 0 °o Q) = a) o 0 2 m c 0 a) (n (a 0 C C C U 0 0 o O 0 V) 0 a) 0 O a7 O a3 (A L]. E a) C 0 U -o to 0 0 0 0 .° (a a) _o o 0 0 > > 3 rn > > o) 0 3 V) m = n ' a) U•J w 2 E a Q - - = m a`) o E E c = 3 °' °c '(0t 1- i- F- .n a°i - a°i > d a o 3 E ca N m c Tz° aJD5. 5CO � ooa° a° v � ¢ a 0cn000c) < = < , omm0 n2 aa0 (0 (00 ° ✓ @ W n• Er co DD O r N M V in (O N O N M g N (N r N ON O r co;' M M (M (M M CM M • O O N N N .. �/ N O a) N a) O C ..h4 O C (6 N CO a) CO N 0 o U C 0 a) 0 ((NI 0 IQ ° o ! Q. R C O ` T 0 E .J N Z. 0 CM O W DIE C) 0 0 u r v Q to C Q co 0 Q (/) LO Q w c9 j Well History File APPENDIX I nfoi illation 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. 1p` 1 6z. HALLIBURTON Sperry Drilling Surface Data Logging End of Well Report SP22-FN1 SP22-FN1 PB1 SP22-FN1 PB2 SP22-FN1 PB3 SP22-FN1 PB4 Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: March 6, 2013 .- HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Show Reports 7. Formation Tops 8. Survey Report 9. Days vs. Depth 10. After Action Review Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP22-FN1, SP22-FN1 PB1, SP22-FN1 PB2, SP22-FN1 PB3, & SP22-FN1 PB4 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23478-00-00 (SP22-FN 1) 50-629-23478-70-00 (SP22-FN1 PB1) 50-629-23478-71-00 (SP22-FN1 PB2) 50-629-23478-72-00 (SP22-FN1 PB3) 50-629-23478-73-00 (SP22-FN1 PB4) Sperry Job Number: AK-AM-0900169420 Job Start Date: 24 Jan 2013 Spud Date: 27 Jan 2013 Total Depth: 22,923' MD, 3,408' TVD (SP22-FN1) 14,550' MD, 3,729' TVD (SP22-FN1 PB1) 16,360' MD, 3,723' TVD (SP22-FN1 PB2) 19,306' MD, 3,735' TVD (SP22-FN1 PB3) 21,800' MD, 3,742' TVD (SP22-FN1 PB4) North Reference: True Declination: 20.113° Dip Angle: 81.071° Total Field Strength: 57615.676 nT ■ Date Of Magnetic Data: 25 Jan 2013 Wellhead Coordinates N: North 70° 33' 27.875" Wellhead Coordinates W: West 149° 54' 19.155" Drill Floor Elevation: 53.82' Ground Elevation: 13.1' Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Kori Jo Plowman, Leigh Ann Rasher Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 Eni Petroleum HALLI B U RTO N I Sperry Drilling DAILY SUMMARY 01/24/2013 Mudloggers on standby. 01/25/2013 Mudloggers on standby. 01/26/2013 Rig up mudlogging unit. Pick up 5"drill pipe. Slip and cut drill line and service top drive. Make up clean out BHA. 01/27/2013 Wash and ream out conductor with BHA#1 to 160' MD. Lay down BHA#1 and pick up BHA#2. Drill ahead to 961' MD. Max gas observed was 28 units at 939' MD. 01/28/2013 Drill ahead from 961' MD to 2720' MD. Max gas observed was 416 units at 2039' MD. 01/29/2013 Drill ahead from 2720' MD to surface hole TD of 3097' MD/2441'TVD. Circulate bottoms up twice and back ream out of hole per K&M rep. Max gas while drilling was 120 units at 2820' MD and max trip gas was 683 units. 01/30/2013 Continue to back ream out of hole per K&M rep. Lay down BHA#2. Rig up casing equipment and run in hole with 13 3/8"casing. Land casing at 3082' MD. Circulate and condition mud for cement job. Perform cement job. 01/31/2013 Continue to cement per detail. Rig down cement equipment, rig up and clean diverter system. Remove bell system and nipple down diverter system. Install Vetco Gray multibowl assembly. Nipple up BOP stack. Pick up and lay down heavy weight drill pipe. Load 5"drill pipe in pipe shed. Pick up 5" drill pipe. 02/01/2013 Continue to pick up 5"drill pipe. Test BOP. Pick up BHA#3. 02/02/2013 Run in hole with BHA#3. Circulate and condition hole. Test casing and strip in drill. Drill shoe track and 20' of new formation. Displace mud. Perform leak off test to 13.0 ppg EMW. Slip and cut drill line. Drill ahead to 3796' MD as of midnight. Max gas observed was 174 units at 3269' MD. 02/03/2013 Drill ahead from 3796' MD to 6750' MD. Max gas observed was 76 units at 3872' MD. 02/04/2013 Drill ahead from 6750' MD to 9030' MD. Max gas observed was 93 units at 8652' MD. 02/05/2013 Drill ahead from 9030' MD to 9863' MD. Back ream out of hole due to tool failure. Max gas observed was 183 units at 9771' MD. 02/06/2013 Continue to back ream out of hole to 1100' MD. Pull out of hole on elevators. Lay down BHA#3 and pick up BHA#4. Eni Petroleum HALLIBURTON I Sperry Drilling 02/07/2013 Continue to pick up BHA#4. Run in hole to 293' MD and shallow hole test tools. Continue to run in hole. Run in hole to 8100' MD and begin to wash and rotate to 9863' MD. Drill ahead from 9863' MD to 10636' MD. Max gas observed was 216 units at 10571' MD. 02/08/2013 Drill ahead from 10636' MD to intermediate TD of 12140' MD. Circulate bottoms up and begin to back ream out of hole. Max gas observed was 166 units at 10797' MD. 02/09/2013 Continue to back ream out of hole. Blow down top drive and pull out on elevators to BHA. Lay down BHA #4. 02/10/2013 Change out rams to 9 5/8" casing. Remove wear bushings and install test plug. Rig up and test rams. Remove test plug and install modified wear bushings. Pick up and make up Tesco casing drive system. Pick up and make up shoe track and test. Begin to float 9 5/8"casing. 02/11/29013 Continue to float 9 5/8"casing to 12122' MD. Rig up cement head and lines. Fill casing and condition mud for cement job. Pump cement. Rig down cement equipment and prepare to nipple down BOPE. 02/12/2013 Rig down cement equipment and nipple down BOPE stack. Set 9 5/8"emergency slips. Nipple up BOPE and freeze protect. Change out rams to variables. Service top drive, drawworks, and travelling equipment. Change out saver sub and begin to pick up 4.5"drill pipe. 02/13/2013 Finish picking up 4.5" drill pipe. Test BOPs. Clean and service rig. Make up and pick up BHA#5. Run in hole with BHA#5. Flow and calibrate gas gear—gas detector and gas chromatograph. 02/14/2013 Continue to run in hole with BHA#5. Shallow test MWD tools. Wash to bottom from 10,139' MD. Circulate one bottoms up at 11,941' MD. Casing test for 30 minutes at 3,000 psi. Displace to FazePro OBM. Drill cement and 20' of new hole to 12,160' MD. Circulate bottoms up and pull back to 12,122' MD. Prepare to conduct Formation Integrity Test. 02/15/2013 Perform Formation Integrity Test to 13.0 ppg equivalent mud weight. Drill ahead. Cuttings consist primarily of unconsolidated sand, becoming variably silty in certain intervals. Max gas of 1143 units, with average gas of 485 units. 02/16/2013 Continue drilling ahead to SP22-FN1 PB1 TD at 14,550' MD. Backream out of hole per K&M rep. Open hole sidetrack initiated at 13,280' MD. Once sidetracked, continue to drill ahead. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone, becoming variably silty. Max gas of 1443 units, with average gas of 1005 units. 02/17/2013 Continue drilling ahead to SP22-FN1 PB2 TD at 16,360' MD. Backream out of hole per K&M rep. Open hole sidetrack initiated at 14,880' MD. Once sidetracked, continue to drill ahead. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone, becoming variably silty. Max gas of 1613 units in PB2, with average gas of 897 units. Eni Petroleum HALLIBURTON j Sperry Drilling 02/18/2013 Continue to drill ahead. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone. Max gas of 1654 units,with average gas of 922 units. 02/19/2013 Continue to drill ahead to SP22-FN1 PB3 TD of 19,306' MD. Begin to backream out of hole per K&M rep. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone with varying amounts of siltstone, and some shaly intervals. Max gas of 1894 units, with an average gas of 762 units. 02/20/2013 Continue to backream out of hole per K&M rep. Initiate open hole sidetrack at 17,950' MD. Once sidetracked, drill ahead. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone, with varying amounts of siltstone. Max gas of 1714 units,with average gas of 917 units. 02/21/2013 Continue to drill ahead. Problems with pumps near the end of the day, resulting in extended periods of low pumping rates while repairs were being conducted to the pumps. During intervals of low pump rates, we are unable to monitor gas. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone, with varying amounts of siltstone. Max gas of 1934 units,with average gas of 1051 units. 02/22/2013 Continue to drill ahead to SP22-FN1 PB4 TD of 21,800' MD. Backream out of hole per K&M rep. Initiate open hole sidetrack at 20,200' MD. Once sidetracked, drill ahead in primary borehole. Problems with pumps continued through the morning, resulting in continued low pump/flow rates, and the inability to monitor gas during these intervals. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone with varying amounts of siltstone. Max gas of 1973 units, with an average gas of 829 units. 02/23/2013 Continue to drill ahead. Cuttings consist primarily of unconsolidated sand and calcareously cemented sandstone with varying amounts of siltstone. Once crossing planned fault at 21,831' MD, samples become shaly. Max gas of 2074 units, with an average gas of 915 units. 02/24/2013 Continue to drill ahead to SP22-FN1 TD of 22,923' MD. Backream out of hole per K&M rep. Cuttings consist primarily of varying amounts of shale and siltstone, with lesser amounts of unconsolidated sand and calcareously cemented sandstone through the OA and N sands. Max gas of 572 with an average gas of 186 units. Max trip gas encountered of 192 units. 02/25/2013 Continue to backream out of hole per K&M rep. Max trip gas of 54 units. 02/26/2013 Continue to backream out of hole per K&M rep to 11,941' MD. Circulate bottoms up per K&M. Slip and cut drill line. Service drawworks, top drive, and crown. Pull out of hole on elevators. Lay down BHA#5. Max trip gas of 17 units. 02/27/2013 Continue to lay down BHA#5. Remove wear ring and install test plug. Test BOPs. Rig up and run 5.5" slotted liner. 02/28/2013 Continue to run in hole with 5.5" slotted liner. "After-run"calibration check was done on gas chromatograph, yielding 1.7%error. A calibration check on the gas detector yielded a 0.4% error. Eni Petroleum HALLIBURTON Customer: ENI Report#: 1 Well: SP22-FN1 Date: 26-Jan-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 160' Rig: Doyon 15 Current Depth: 160' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $2,810.00 Rig Activity: M/U Clean out BHA Total Charges: $6,610.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: RossSmo�so��mmerB��ha�a� ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) 0.0 0.0 0.0 0' Flow In •.m) SPP ssi) ': Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary De,tn Tools ECD === to v o Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids De.th Mud T .e in out (sec/6t ••b E. cP (Ib/100ft2) ml/30min m./I % PITS Spud Mud 8.70 129 23.0 38 39 6.8 9.00 350 2.0 Y � .: Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary == :_r::::::--7-.7_7..1T„ fit Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 K Background Trip Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: P/U 5”DP.Slip&cut drill line,service top drive.M/U clean out BHA. ■ Logging Engineers: Emil!Opitz,Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone 907-685-0453 1 HALLIBURTON Customer: ENI Report#: 2 Well: SP22-FN1 Date: 27-Jan-2013 Area: Spy Island Time: 0:00:00 . Sperry Drilling Location: North Slope Yesterdays Depth: 160' Rig: Doyon 15 Current Depth: 961' Job No.: AK-AM-0900169420 24 Hour Progress: 801' Daily Charges: $2,810.00 Rig Activity: Drill ahead Total Charges: $9,420.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr 0.0 245.2 1446.6 233' Flow In •.m 639 SPP • 873 Flow In(spm) 151 Gallons/stroke 4.23 @ 96% ,.. mom- r MWD Summary Depth Tools ECD Avg Min Max 160' to 961' GyroPulse Collar,TeleScope 825,ARC 825 9.67 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids De.th Mud T pe in out (sec/.t ..b E. cP Ib/100ft2) ml/30min m./I % :± 774' Spud Mud 9.10 - 98 24.0 29 33 5.2 9.90 2,300 _2.7 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 16" 1.117 - 160' ---- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 28 939' 2945 0 0 0 0 0 0 Minimum 3 449' 124 0 0 0 0 0 0 Average 8 660 0 0 0 0 0 0 Background 7 Trip - Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Wash&ream out conductor w/BHA#1 to 160'.L/D BHA#1 &P/U BHA#2.Drill ahead to 961'MD.Max gas observed was 28 units @ 939'MD. Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 A 'r Ii ''� y,.,7 _. :...�� •. , 7TTT n,.::..._'�" ... ._ o,:..'..�: HALLIBURTON Customer: ENI Report#: ....3 Well: SP22-FN1 Date: 28-Jan-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 961' Rig: Doyon 15 Current Depth: 2720' Job No.: AK-AM-0900169420 24 Hour Progress: 1759' Daily Charges: $2,810.00 Rig Activity: Drill ahead li:: Total Charges: $12,230.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ros�smo��o�n�mme��he�e� rn m ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) 30.0 166.4 516.8 1052' Flow In ••m) 664 SPP(psi) 1307 Flow In (spm) 157 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD . Min Max 961' to 2720' GyroPulse Collar,TeleScope 825,ARC 825 ... 10.43 9.94 11.21 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud T pe in out sec/•t ••b Es cP (Ib/100ft2) ml/30min mill % 2546' Spud Mud 9.50 88 22.5 31 32 5.4 9.50 1,400 4.3 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 16" 1.117 - 160' ---- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) -------_--_- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n 'i Maximum 416 2039' 52713 0 0 0 0 0 0 Minimum 2 1568' 28 0 0 0 0 0 0 Average 106 12553 0 0 0 0 0 0 Background 53 Trip - Connection - * 10,000 Units = 100%Gas In Air ,Y; (current) (max) (max) 24 hr Recap: Drill ahead f/961'MD to 2720'MD.Max gas observed was 416 units at 2039'MD. 1. is Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 Customer: ENI Report#: 4 HALLIBURTON Well: SP22-FN1 Date: 29-Jan-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 2720' Rig: Doyon 15 Current Depth: 3097' Job No.: AK-AM-0900169420 24 Hour Progress: 377' Daily Charges: $2,810.00 Rig Activity: Drill ahead Total Charges: $15,040.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE ..ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ^ ROP(ft/hr) 167.1 398.2 3012' Flow In(••m) 799 SPP 'Si 1051 ,, Flow In(spm) 189 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD Avg Min Max 2720' to 3097' GyroPulse Collar,TeleScope 825,ARC 825 10.21 10.05 10.58 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T se in out sec/.t ••b Es cP (Ib/100ft2) ml/30min me/1 3097' Spud Mud 9.60 68 23.5 25 30 5.4 9.60 1,000 5.2 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Vt 1 Hughes VM-1 16" 1.117 - 160' 3097' --- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary -*' Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 120 2820' 14784 0 0 0 0 0 0 Minimum 3 2975' 18 0 0 0 0 0 0 Average 74 8822 0 0 0 0 0 0 ( Background - Trip 683 Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead f/2720'MD to TD of 3097'MD/2441'TVD.CBU x2&BROOH per K&M.Max gas while drilling was 120 units `¢@ 2820'MD.Max trip gas was 683 units. 1 11 i. i.• Logging Engineers: Emil Opitz/Leigh Ann Rasher _ Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 t HALLIBURTON Customer: ENI Report#: 5 Well: SP22-FN1 Date: 30-Jan-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 3097' Rig: Doyon 15 Current Depth: 3097' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $2,810.00 Rig Activity: Cement Total Charges: $17,850.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/simonsonmmer/euchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) Flow In (gpm) SPP(psi) Flow In (spm) , Gallons/stroke 4.23 @ `!F% • MWD Summary Depth Tools I ECD Avg Min Max to (PP9) • Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % _ 3097' Spud Mud 9.50 47 17 15 7.60 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 Lithology (%) Cht Silt Silt-it CI, Clyst Sh Lst Coal Gvl Tuft Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 68 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Cont.BROOH per K&M.L/D BHA#2.R/U csg equip&RIH w/13 3/8"csg.Land csg @ 3082'MD.Circ&cond mud for cmt job.Perform cmt job. Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 t FiALLIBURTON Customer: ENI Report#: 6 Well: SP22-FN1 Date: 31-Jan-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 3097' Rig: Doyon 15 Current Depth: 3097' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $2,810.00 Rig Activity: P/U 5"DP Total Charges: $20,660.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Kee a 5mo so gimme a ha a a. __ . _.. .. t -7-_. a , T. -a ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In (•pm) SPP 'Si . -. Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD Avg Min Max Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud T pe in out (sec/at) ••b Es cP (Ib/100ft2) ml/30min ms/I % 3097' Gel Mud 9.40 45 16 16 7.60 v.. ,-A Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 } Summary 13 3/8" 3082' BTC 68.0 L-80 il ' Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff _ (current) ------_----- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 59 Connection - * 10,000 Units = 100%Gas In Air (current) (max) lmaxl 24 hr Recap:Cont.cmt per detail.R/D cmt equip.R/U&clean diverter system.Remove bell system&N/D diverter system.Install Vetco Gray multibowl assy.N/U BOP stack.R/U&L/D HWDP.Load 5"DP in pipe shed.P/U 5"DP. i Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 _ HALLIBURTON Customer: ENI _ Report#: 7 Well: SP22-FN1 Date: 1-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 3097' Rig: Doyon 15 Current Depth: 3097' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $3,410.00 Rig Activity: RIH BHA#3 Total Charges: $24,070.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keene 5mo"o"gimme a"ha"a" ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr ---- Flow In •.m) SPP(psi) Flow In (spm) Gallons/stroke 4.23 @ 96% -L77 ,sue, MWD Summary Depth Tools ECD Av. Min Max Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids De.th Mud T .e in out (sec/qt) ..b E. cP (Ib/100ft2) m1/30min ms/I % 3097' Gel Mud/LSND 9.30 45 16 16 7.40 -- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 - 3097' ---- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) tmax) 24 hr Recap:Cont.P/U 5"DP.Test BOPE.P/U BHA#3. Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 �A, HALLIBURTON Customer: ENI Report#: 8 Well: SP22-FN1 Date: 2-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 3097' Rig: Doyon 15 Current Depth: 3796' Job No.: AK-AM-0900169420 24 Hour Progress: 699' Daily Charges: $4,410.00 Rig Activity: Drill 12.25"Hole Total Charges: $28,480.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Kee"e smo"o"�mme a"�ha"a" ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr 45.2 271.4 859.9 3512' Flow In(••m 846 SPP •si) 1194 ..: Flow In (spm) 200 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD Av. Min Max ri 3097' to 3796' Xceed 900,TeleScope 825,ARC 825 9.38 9.13 9.58 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out sec/•t ••b Es cP Ib/100ft2) ml/30min mill 3373' Gel Mud/LSND 9.25 48 1.8 9 22 6.2 10.10 700 4.0 on# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition pl 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 3097' _--- x Size Set At Type Weight Grade r. Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 flfl Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff _ (current) 100 ----------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 174 3269' 21465 0 0 0 0 0 0 Minimum 3 3353' 35 0 0 0 0 0 0 Average 40 4566 0 0 0 0 0 0 ;F Background 22 Trip - Connection - * 10,000 Units = 100%Gas In Air e (current) (max) (max) 24 hr Recap:Cont.RIH w/BHA#3.Circ&cond hole.Test casing and strip in drill.Drill shoe track and 20'of new formation.Displace mud.Perform LOT to 13.0 ppg EMW.Slip&cut drill line.Drill ahead to 3796'MD as of midnight.Max gas observed was 174 units at 3269'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 b ii HALLIBURTON Customer: ENI Report#: 9 Well: SP22-FN1 Date: 3-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 3796' Rig: Doyon 15 Current Depth: 6750' Job No.: AK-AM-0900169420 24 Hour Progress: 2954' Daily Charges: $3,410.00 Rig Activity: Drill 12.25"Hole Total Charges: $31,890.00 [ . Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For K e s m .B h ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) 23.9 326.5 632.1 5197' Flow In (••m) 900 SPP(•si) 1941 Flow In (spm) 213 Gallons/stroke 4.23 @ 96% ,_..r D Depth Tools ECD WPM Min Max ` MWD Summary 3796' to 6750' Xceed 900,TeleScope 825,ARC 825 ... 9.73 9.21 10.12 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids De.th Mud T se in out (sec/.t) ••b Es cP Ib/100ft2) m1/30min m•/I 6316' LSND 9.20 54 15.0 12 27 4.8 9.80 1,300 4.8 i. Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 — 3097' ---- �;a» ,.. �....,..� Size Set At Type Weight Grade ' Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 ' -,'L-z-,',.; '27:,, - .:7- ,' I —7---'F...:1 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff ' (current) 100 ----------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 76 3872' 9137 0 0 0 0 0 0 Minimum 2 6283' 14 0 0 0 0 0 0 Average 14 1416 0 0 0 0 0 0 Background 2 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead f/3796'MD to 6750'MD.Max gas observed past 24 hours was 76 units at 3872'MD. i ■ Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 I HALLIBURTON Customer: ENI Report#: 10 Well: SP22-FN1 Date: 4-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 6750' Rig: Doyon 15 Current Depth: 9030' Job No.: AK-AM-0900169420 24 Hour Progress: 2280' Daily Charges: $3,410.00 Rig Activity: Drill 12.25" Hole Total Charges: $35,300.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Kee"e 5m" ""�mme a ha"a 71 � .:1 s gy . _ . . 7.-= r __._ :.7.7 I. ,.. �-_ ROP Current Avg 24 hr Max Max at ft Current Pump& Flow Data: ROP(ft/hr) 29.7 327.2 792.5 6785' Flow In (gpm) 898 SPP(psi) 2065 Flow In (spm) 212 Gallons/stroke 4.23 @ 96% I MWD Summary Depth Tools ECD Avg Min Max 6750' to 9030' Xceed 900, TeleScope 825,ARC 825 9.82 8.10 10.22 ili :-. . Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 8632' LSND 9.20 46 16.5 10 22 5.0 9.80 1,500 5.5 §" Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16' 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 3097' ---- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 -_P x Lithology(%o) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 95 -- 5 _------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 93 8652' 11352 0 0 0 0 0 0 Minimum 2 8330' 29 0 0 0 0 0 0 Average 13 1250 0 0 0 0 0 0 Background 5 Trip - Connection - * 10,000 Units = 100%Gas In Air '' (current) (max) max) 24 hr Recap: Drill ahead f/6750'MD to 9030'MD.Max gas observed the past 24 hours was 93 units at 8652'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By Leigh Ann Rasher Unit Phone: 907-685-0772 .. --77-7:— �� HALLIBURTON customer:�ENI LL..._� u_.. __ � _�. Report#: � 11 Well: SP22-FN1 Date: 5-Feb-2013 Area: Spy Island Time: 0:00:00 4 Sperry Drilling Location: North Slope Yesterday's Depth: 9030' ( Rig: Doyon 15 Current Depth: 9863' Job No.: AK-AM-0900169420 24 Hour Progress: 833' Daily Charges: $3,410.00 Rig Activity: BROOH Total Charges: $38,710.00 Reason for Trip: NO FAILURES IA HSE Incidents: NO HSE Report For: KeenedSlmonsoNAmend/9uohanao tri.4 ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) 251.3 459.6 9054' Flow In •pm) 901 SPP .si) 1644 Flow In(spm) 213 Gallons/stroke 4.23 @ 96% 2s 9030' to 9863' Depth Xceed 900,TeleScope o _Tools ... MWD Summary ' th ECD Avg Min Max p e 825,ARC 825 ... 9.97 7.86 10.11 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out sec/st) a•b Es cP (Ib/100ft2 ml/30min ms/I % 9863' LSND 9.35 48 17.5 13 25 4.8 9.80 1,500 6.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition , 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 3097 ---- Size Set At Type Weight rade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 90 -- 10 _------- ri Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 183 9771' 14860 40 0 0 0 0 0 Minimum 2 9692' 22 0 0 0 0 0 0 Average 25 2555 0 0 0 0 0 0 Background 15 Trip 20 Connection - * 10,000 Units = 100%Gas In Air (current) (max) max r Recap: Drill ahead f/9030'MD to 9863'MD.BROOH due to tool failure.Max gas observed the past 24 hours was 183 units at 9771'MD. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 l ., ; -.'�' '' i:. ,.'* rte, = 1#"C. . iALLIBURTON Customer: ENI Report#: 12 Well: SP22-FN1 Date: 6-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 9863' [-9 Rig: Doyon 15 Current Depth: 9863' Job No.: AK-AM-0900169420 24 Hour Progress: 0' rl Daily Charges: $3,410.00 Rig Activity: P/U BHA#4 Total Charges: $42,120.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Perry/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) Flow In (gpm) SPP(psi) Flow In (spm) Gallons/stroke 4.23 @ 96%i"_ Depth Tools Avg Min ( Max (MWD Summary 9863' to 9863' Xceed 900,TeleScope 825. ARC 825 IECD (ppg) —I ( ' Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 9863' LSND 9.30 50 17.0 15 24 5.0 9.90 1,400 6.0 »was Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT-A-X-1-WT-DTF 2RR Hycalog SKHI716D-E4C PDC 12.25" 0.969 9863' Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 17 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Cont.BROOH to 1100'MD.POOH on elevators.L/D BHA#3.P/U BHA#4. I Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 AN HALLIBURTON Customer: ENI Report#: 13 i. Well: SP22-FN1 Date: 7-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 9863' Rig: Doyon 15 Current Depth: 10636' Job No.: AK-AM-0900169420 24 Hour Progress: 773' Daily Charges: $3,410.00 Rig Activity: Drill 12.25"Hole Total Charges: $45,530.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Perry/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) 53.1 262.6 450.6 9864' Flow In •.m 213 SPP(psi) 2560 Flow In(spm) 903 Gallons/stroke 4.23 @ 96% --; MWD Summary Depth Tools ECD (ppg) Avg Min Max 9863' to 10636' Xceed 900,TeleScope 825,ARC 825,SADN 825 10.42 9.97 10.57 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (..b Eq) cP (Ib/100ft2) m1/30min mg/I % 10466' LSND 9.40 49 17.5 15 22 4.8 9.90 1.400 6.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12 25" 0.969 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT A-X-1 WT-DTF 2RR Hycalog SKHI716D-E4C PDC 12.25' 0.969 - 9863' ---- Size Set At Type Weight Grade u Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 i Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 90 10 Gas Summary Chromatograph(ppm) Units" Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 216 10571' 24464 412 262 84 89 25 0 IMinimum 3 9869' 8 0 0 0 0 0 0 Average 54 6041 84 44 12 11 0 0 Background 11 Trip 5 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) rte, 24 hr Recap:Cont.P/U BHA#4.RIH to 293'MD.Shallow hole test.Cont.RIH.Slip and cut drill line.Cont.RIH.Wash and rotate from 8100'MD to 9863'MD.Drill ahead from 9863'MD to 10636'MD as of midnight.Max gas observed was 216 units at 10571'MD. 1 1'; Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 4 �ALLIBURTON Customer: ENI Report#: 14 Well: SP22-FN1 Date: 8-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 10636' Rig: Doyon 15 Current Depth: 12140' Job No.: AK-AM-0900169420 24 Hour Progress: 1504' I( Daily Charges: $3,410.00 Rig Activity: Drill 12.25"Hole Total Charges: $48,940.00 _ Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Perry/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump& Flow Data: ROP(ft/hr) 274.1 474.8 11120' Flow In(.pm) 901 SPP asi 2418 Flow In (spm) 213 Gallons/stroke 4.23 © 96% Depth Tools Avg Min Max ',ii: MWD Summary 10636' to 12140' Xceed 900,TeleScope 825,ARC 825,SADN 825 ECD (ppg) 10.65 10.23 10.82 Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (p.b Eq) cP (Ib/100ft2) ml/30min mg/I % 12140' LSND 9.50 48 20.0 13 22 5.0 9.80 1,400 6.5 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT-A-X-1-WT-DTF 2RR Hycalog SKHI716D E4C PDC 12.25" 0.969 - 9863' ---- 7a 7.7.w,,;,,,.,_ _. ya,. 2""': dui _:_.,„.... :, ,`7, ^u =: ', ,.'',,17.77.7. Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal GVI Tuff (current) 60 40 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 166 10797' 13825 264 335 235 301 192 111 .i Minimum 2 11995' 11 0 0 0 0 0 0 Average 48 3288 57 78 62 86 63 39 Background 11 Trip 99 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Drill ahead from 10636'MD to 12140'MD.CBU.BROOH.Max gas observed was 166 units at 10797'MD. 1. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 • I L HALLIBUR1 td Customer: ENI Report#: 15 Well: SP22-FN1 Date: 9-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 12140' a Rig: Doyon 15 Current Depth: 12140' li Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $3,410.00 Rig Activity: L/D BHA#4 Total Charges: $52,350.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Perry/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump& Flow Data: ROP(ft/hr) ---- Flow In(..m SPP .si) Flow In(spm) _ Gallons/stroke 4.23 @ 96% Depth Tools Avg Min Max . MWD Summary to ECD (ppg)--- , Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) ..b E. cP (Ib/100ft2) ml/30min mg/I 12140' LSND 9.40 48 20.0 13 20 5.0 9.80 1,400 6.5 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ � • Condition 1 Hu.hesVM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT-A-X-1-WT-DTF 2RR Hycalog SKHI716D-E4C PDC 12.25" 0.969 9863' ---- Size Set At Type Weight rade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 l. * Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff $ (current) -_--_--- - - Gas Summary Chromatograph(ppm) .:'s Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 1 i. Background Trip 20 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) I j i 24 hr Recap:Cont.BROOH.Blow down top drive,pull on pull on elev to BHA.L/D BHA#4. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 16 Well: SP22-FN1 Date: 10-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 12140' Rig: Doyon 15 Current Depth: 12140' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $3,410.00 Rig Activity: Float 9 5/8"casing Total Charges: $55,760.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Pe ry/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) Flow In(gpm) SPP(psi) Flow In(spm) Gallons/stroke 4.23 @ 96% MWD Summary D pth Tools ECD (ppg) Avg Min Max to Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 12140' LSND 9.50 60 17.5 17 22 5.0 9.70 1,400 6.5 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969. 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT-A-X-1-Wr-DTF 2RR Hycalog SKHI716D-E4C PDC 12.25" 0.969 10.80 9863' 12140' 2277' [14.0 160 2-2-CT-A-X-1-ER-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" Hydril 40.0 L-80 I Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 5 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:CIO rams to 9 5/8"casing.Remove wear bushing&install test plug.R/U&test rams.Remove test plug&install modified wear bushing.P/U&M/U Tesco csg drive system.P/U&M/U shoe track&test.RIH w/9 5/8"csg. Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 17 t Well: SP22-FN1 Date: 11-Feb-2013 i. :_ Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 12140' Rig: Doyon 15 Current Depth: 12140' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $3,410.00 Rig Activity: R/D Cmt Equip Total Charges: $59,170.00 Reason for Trip: NO FAILURES I.,z HSE Incidents: NO HSE Report For: Keener/Perry/Amend/Buchanan ., mm x gym . ROP Current Avg 24 hr Max Max at ft Current Pump& Flow Data: ROP(ft/hr ---- Flow In •.m) _ SPP esi Flow In(spm) Gallons/stroke 4.23 @ 96% Depth Tools W ' Min Max MWD Summary ' to ECD Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) ••b E•) cP (Ib/100ft2) ml/30min mg/I % . I' 12140' LSND 9.35 60 18 18 9.50 -- _ Olt# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hu.hes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 35.50 3097 9863 6766' 10.0 190.0 2 2-CT A X 1 WT DTF 2RR Hycalog SKHI716D-E4C PDC 12.25" 0.969 10.80 9863' 12140' 2277' [14.0 160 2 2 CT A X-1 ER TD Size Set At Type Weight rade ` Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 i Background Trip 35 Connection * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Cont.float 9 5/8"casing to 12122'MD.R/U cmt head&lines.Fill casing.Condition mud for cmt job.Pump cmt.R/D cmt equip.Prep to N/D BOPE. n , Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 .. -:: HALLIBURTON Customer: ENI Report#: 18 Well: SP22-FN1 Date: 12-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 12140' Rig: Doyon 15 Current Depth: 12140' ,.. Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $3,410.00 Rig Activity: P/U 4.5"DP i. Total Charges: $62,580.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: KeenerIPerryIAnerdIButhann ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: .,; '-'J-- ROP(ft/hr) Flow In(gpm) SPP(psi) Flow In(spm) Gallons/stroke 4.23 @ 96% Depth Tools pn I MWD Summary De JECD (ppg) Avg Mi Max tO Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids A ., Depth Mud Type in out (sec/qt) (ppb Eq) cP (lb/100ft2) ml/30min mg/I 12140' LSND 9.35 51 14 15 9.60 Bit# Bit Type Size TEA Hours Depth in/out Footage WOB RPM Condition :A- 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD .,, 2 Hycalog SKH1716D-E4C PDC 12.25" 0.969 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT-A-X-1-WT-DTF 2RR Hycalog SKH1716D-E4C PDC 12.25" 0.969 10.80 9863' 12140' 2277' [14.0 160 2-2-CT-A-X-1-ER-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 400 L-80 ...,. . -. _ ,...., . ... .,,,, ■ I Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) , — Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n '-' Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 . ..,.. Average 0 0 0 0 0 0 0 ,,. Background - Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:RID cmt equip.N/D BOPE stack.Set 9 5/8"emergency slips.N/U BOPE and freeze protect.C/O rams to variables. 1 Service top drive,drawworks,and travelling equip.C/O saver sub.P/U 4.5 DP. Logging Engineers- Leigh Ann Rasher/Kori Jo Plowman Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#:` _ .. 19 Well: SP22-FN1 Date: 13-Feb-2013 Area: Spy Island Time: 0:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 12140' k k s ; Rig: Doyon 15 Current Depth: 12140' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $4,410.00 Rig Activity: RIH w/BHA#5 Total Charges: $66,990.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Perry/Amentl/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(fUhr) ---- Flow In ••m SPP *Si) Flow In(spm) Gallons/stroke 4.23 @ 96% '# Depth Tools �M Min Max Summary to ECD (ppm Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids w Depth Mud Type in out (sec/qt) sib Eq) cP (Ib/100ft2) ml/30min mg/I 12140' LSND 9.35 51 14 15 ---- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Hughes VM-1 Milltooth 16" 1.117 22.20 170' 3097' 2927' 25.0 40.0 1-1-WT-A-E-2-NO-TD 2 Hycalog SKHI716D-E4C PDC 12.25" 0.969 35.50 3097' 9863' 6766' 10.0 190.0 2-2-CT-A-X-1-WT-DTF „E 2RR Hycalog SKHI716D-E4C PDC 12.25" 0.969 10.80 9863' 12140' 2277' [14.0 160 2-2-CT-A-X-1-ER-TD Size Set At Type Weight rade i Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 �:. Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff _ (current) ------------ . Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 l'Average 0 0 0 0 0 0 0 Background - Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) f. � a ' 24 hr Recap:Finish picking up 4.5"DP. Test BOPs. Clean and service rig. M/U&P/U BHA#5. RIH w/BHA#5. Flow and calibrate all gas gear. r ; 1 1 Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report# 20 Well: SP22-FN1 Date: 14-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 12140' Rig: Doyon 15 Current Depth: 12160' Job No.: AK-AM-0900169420 24 Hour Progress: 0' 1. Daily Charges: $3,410.00 Rig Activity: Prep for LOT Total Charges: $70,400.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Amend/Buchanan it ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: if ROP(ft/hr) - 219.9 239.0 12141' Flow In(..m 499 SPP(psi) 2922 Flow In(spm) 118 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD Avg Min Max 12786' to 12786' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope ... 10.70 10.69 10.71 _ _ _ _ ' -' aiz Vic...n.. ._...»,-dam. .,."k as-.:?,a.....•_ 'S �auu..e�'�k'-`.i..,..:. ., ,: s' Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids I. Death Mud T .e in out sec/.t) Ratio cP Ib/100ft2) m1/30min lb/bbl) 12140' FazePro 9.40 50 65/35 18 11 4.4 1.70 2 4.9 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 _ 12140' ---- 1. Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 ' t. Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff _ (current) ------ ----- ����� Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 42 12159' 4495 19 10 3 3 0 0 Minimum 22 12142' 1906 0 4 0 0 0 0 Average 32 2992 46 25 20 19 7 7 Background 4 Trip 0 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) ' m 24 hr Recap:Continue to RIH w/BHA#5. Shallow test MWD. Wash to bottom from 10139'MD. CBU lx at 11941'MD. Casing test for 30 min @ 3000 psi. Displace to FazePro OBM. Drill cement and 20'of new hole to 12160'MD. CBU and pull back to 12122'MD. Prep for LOT. it I Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 i. _ HALLIBURTON Customer: ENI Report#: 21 Well: SP22-FN1 Date: 15-Feb-2013 Area: Spy Island Time: 24:00:00 ! Sperry Drilling Location: North Slope Yesterdays Depth: 12160' Rig: Doyon 15 Current Depth: 14052' Job No.: AK-AM-0900169420 24 Hour Progress: 1892' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $73,810.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) 55.1 248.0 427.5 12596' Flow In •.m 546 SPP 'Si) 3458 r Flow In(spm) 129 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools n.. ._, ECD Avg Mine Max 12160' to 14052' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope 11.21 10.59 12.37 t Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T .e in out (sec/qt) Ratio cP Ib/100ft2) ml/30min (Ib/bbl) 13765' FazePro 9.40 9.40 51 67/33 20 11 4.6 2.30 2.99 5.35 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ---- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 0,,' Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 90 -- 10 ---_---- . r---., Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1143 13284' 128377 1101 661 334 365 169 85 Minimum 22 12214' 1925 4 0 0 0 0 0 Average 485 42944 392 251 132 149 74 38 Background 68 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Perform FIT to 13.0 ppg EMW. Drill ahead. Cuttings consist primarily of unconsolidated sand,becoming variably silty in certain intervals. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 22 Well: SP22-FN1 _ Date: 16-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope _ Yesterdays Depth: 14052' Rig: Doyon 15 Current Depth: 14738' Job No.: AK-AM-0900169420 24 Hour Progress: 686' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $77,220.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) 313.0 299.5 398.6 14650' Flow In ••m) 540 SPP •si) 3481 Flow In(spm) 128 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD Avg Min Max 14052' to 14738' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope ...) 11.25 10.95 11.54 • Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids De•th Mud T se in out (sec/qt) Ratio cP Ib/100ft2 ml/30min lb/bbl) % 14325' FazePro 9.40 9.40 48 66/34 19 10 5.0 2.10 2.73 6.12 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ---- ra Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 100 ----------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1443 14715' 160957 1267 764 422 493 248 132 Minimum 38 13318' 2146 20 21 22 36 37 24 Average 1005 102247 892 552 309 364 185 98 Background 104 Trip 53 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead to SP22-FN1 PB1 TD at 14550'MD. BROOH per K&M. Open hole sidetrack at 13280'MD,and continue to drill ahead. Cuttings consist primarily of unconsolidated sand,becoming variably silty in certain intervals. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 23 Well: SP22-FN1 Date: 17-Feb-2013 Area: Spy Island Time: 24:00:00 1 Sperry Drilling Location: North Slope Yesterdays Depth: 14738' Rig: Doyon 15 Current Depth: 15050' Job No.: AK-AM-0900169420 24 Hour Progress: 312' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $80,630.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) 318.0 303.9 450.7 14927' Flow In ••m 548 SPP(psi 3609 Flow In (spm) 129 Gallons/stroke 4.23 @ 96% IMWD Summary Depth Tools I ECD Avg _ Min Max 14738' to 15050' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope (ppg) 11.42 11.06 11.68 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) m1/30min (Ib/bbl) % 16360' FazePro 9.40 9.40 49 67/33 19 10 5.0 2.00 2.60 6.06 '"i Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ---- .. Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 100 ------_---- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1613 14985' PB2 177799 1403 821 451 531 269 143 Minimum 30 14889' 3056 29 34 37 54 60 38 Average 897 85726 750 471 277 343 191 106 Background 41 Trip 98 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead to SP22-FN1 PB2 TD at 16360'MD. BROOH per K&M. Open hole sidetrack at 14880'MD,and continue to drill ahead. Cuttings consist primarily of unconsolidated sand,becoming variably silty in certain intervals. 1 Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 24 Well: SP22-FN1 Date: 18-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 15050' Rig: Doyon 15 Current Depth: 17819' Job No.: AK-AM-0900169420 24 Hour Progress: 2769' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $84,040.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Amend/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) 214.0 309.7 511.7 15193' Flow In ••m 505 SPP •si 3648 Flow In (spm) 122 Gallons/stroke 4.23 @ 96% Depth Tools ECD Avg Min Max MWD Summary 15050' to 17819' Xceed 675,PeriScope 675,TeleScope 675, Ecoscope (... 11.54 11 09 11.96 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Death Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) m1/30min (lb/bbl) % 17474' FazePro 9.40 9.45 51 69/31 17 14 5.0 2.40 3.12 5.96 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ------;i; Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 100 -------_--- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1654 15663' 179142 1397 785 413 479 233 126 Minimum 207 17728' 13362 232 217 168 232 157 93 Average 922 90199 783 480 275 336 182 101 Background 112 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue to drill ahead in primary borehole. Cuttings consist primarily of unconsolidated sand. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 Customer: ENI Report# 25 HALLIBURTON Well: SP22-FN1 Date: 19-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 17819' Rig: Doyon 15 Current Depth: 19306' .. Job No.: AK-AM-0900169420 24 Hour Progress: 1487' Daily Charges: $3,410.00 Rig Activity: BROOH Total Charges: $87,450.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Wimmer/Buchanan x ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr 268.9 463.0 18290' Flow In (ism 492 SPP •si 3598 Flow In (spm) 118 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD Avg Minh Max 17819' to 19306' Xceed 675,PeriScope 675,TeleScope 675.Ecoscope (..g) 12.18 11.63 12.61 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids De•th Mud T pe in out sec/it) Ratio cP Ib/100ft2) ml/30min (lb/bbl) ' 19263' FazePro 9.40 9.45 55 66/34 18 18 4.4 2.40 3.12 7.11 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' --_- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 60 -- 15 -- 25 _---- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1894 18544' 201731 1410 751 382 473 241 136 Minimum 85 19154' 4978 86 93 78 119 93 58 Average 762 63104 535 330 193 254 152 90 Background 82 Trip 190 Connection - * 10,000 Units = 100%Gas In Air j (current) (max) (max) 24 hr Recap: Drill ahead to SP22-FN1 PB3 TD of 19306 MD reached at 2130hrs. Begin to BROOH per K&M.. Cuttings consist primarily of unconsolidated sand with varying amounts of siltstone,and some shaly intervals.. x., t'':( Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 n HALLIBURTON Customer: ENI Report#: 26 Well: SP22-FN1 Date: 20-Feb-2013 ' Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 19306' Rig: Doyon 15 Current Depth: 19850' Job No.: AK-AM-0900169420 24 Hour Progress: 544' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $90,860.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/VVimmer/Buchanan y^^^N d ! ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) 234.5 275.3 495.9 18195' Flow In ••m 493 SPP(•si 3671 Flow In (spm) 119 Gallons/stroke 4.14 @ 94% MWD Summary Death Tools ECD Avg Min Max 19306' to 19850' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope 12.15 11.53 12.34 v 7.----:::::III-- ' ' „ , Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Death Mud T se in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min lb/bbl) % 19175' FazePro 9.40 9.45 54 67/33 18 16 4.4 2.10 2.73 7.97 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ---- a„,A 7.x.a ..._.._,,..11 u .S: xx::7W.r..,...w...,_s2zx, .,s .:.,..o...._.yw».�.,+ka�Cm'`z-*�...._ �.:E+. ,;..f. i Size Set At Type Weight Grade ,,;} Casing 20" 160' EVAMAR 178.9 X-65 i 13 3/8" 3082' BTC 68.0 L-80 Summary i 9 5/8" 12122' HYDRIL 40.0 L-80 E t °n'c'. K Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff [:...-;;{ I (current) 95 -- 5 -------_ 7 Gas Summary 1 Chromatograph(ppm) ° Units" Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1714 19191' 184920 1623 911 469 582 277 155 Minimum 44 17957' 2299 32 34 33 56 52 35 Average 917 78702 747 442 237 301 155 89 Background 119 Trip 80 Connection - * 10,000 Units = 100% Gas In Air 1. ' (current) (max) max .. . 24 hr Recap:Continue to BROOH per K&M. Initiate open hole sidetrack at 17950'MD. Drill ahead. Cuttings consist primarily of unconsolidated sand with varying amounts of siltstone. t. 1. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 27 Well: SP22-FN1 Date: 21-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 19850' Rig: Doyon 15 Current Depth: 21555' Job No.: AK-AM-0900169420 24 Hour Progress: 1705' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $94,270.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Wimmer/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) 341.6 251.1 399.5 21493' Flow In .pm) 503 SPP(psi 3862 Flow In(spm) 119 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD . Min Max 19850' to 21555' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope 12.32 11.91 12.62 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Death Mud T pe in out sec/qt) Ratio cP (Ib/100ft2 ml/30min (Ib/bbl) % 21454' FazePro 9.45 9.55 53 67/33 19 14 4.6 2.20 2.86 7.53 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ---- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 100 ----_----_- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1934 20034' 206146 1500 789 404 501 243 137 Minimum 175 20534' 18979 209 166 116 164 105 61 Average 1051 95588 760 423 235 305 166 96 Background 119 Trip - Connection - * 10,000 Units = 100% Gas In Air (current) (max) (max) . .. 24 hr Recap:Continue to drill ahead. Problems with pumps near end of day,resulting in low pump/flow rates. These low flow rates aren't able to be monitored for gas. Cuttings consist primarily of unconsolidated sand with varying amounts of siltstone. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 28 Well: SP22-FN1 Date: 22-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 20240' Rig: Doyon 15 Current Depth: 20715' Job No.: AK-AM-0900169420 24 Hour Progress: 475' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $97,680.00 _ Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Wimmer/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump& Flow Data: F ROP(ft/hr) 318.5 233.9 428.3 20623' Flow In (gpm) 489 SPP(psi) 3689 Flow In (spm) 118 Gallons/stroke 4.14 @ 94% MWD Summary Depth Tools ECD Avg Min Max 20240' to 20715' Xceed 675,PeriScope 675,TeleScope 675,Ecoscope 12.07 11.60 12.20 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 20512' FazePro 9.40 9.40 53 66/34 19 12 4.6 2.05 2.67 6.76 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 12140' Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 ILithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1973 20568' 211932 1386 667 316 378 172 93 Minimum 200 20648' 16617 142 84 50 69 46 28 Average 829 60821 433 219 110 139 73 43 Background 76 Trip 219 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) y 24 hr Recap:Continue to drill ahead to SP22-FN1 PB4 TD of 21800'MD. BROOH per K&M to open hole sidetrack point. Initiate open hole =side track per DD. Drill ahead in primary well bore. Problems with pumps continued early in the morning,resulting in low pump/flow rates. These low flow rates aren't able to be monitored for gas. Cuttings consist primarily of unconsolidated sand with varying amounts of siltstone. Logging Engineers: Emil Opitz/Kori Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 J iALLIBURTON Customer: ENI Report#: 29 Well: SP22-FN1 Date: 23-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 20715' Rig: Doyon 15 Current Depth: 22020' Job No.: AK-AM-0900169420 24 Hour Progress: 1305' Daily Charges: $3,410.00 Rig Activity: Drilling Ahead Total Charges: $101,090.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: RossNVimmer/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump& Flow Data: ' ROP(ft/hr) 98.4 231.1 481.5 21374' Flow In(gpm) 491 SPP(psi) 3902 x, Flow In (spm) 119 Gallons/stroke 4.14 @ 94% -' I MWD Summary Depth Tools I ECD Avg Min Max 20715' to 22020' Xceed 675,PeriScope 675,Telescope 675,Ecoscope (ppg) 12.24 11.91 12.47 Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) _ % 21833' FazePro 9.50 53 66/34 18 17 4.6 2.30 2.99 6.58 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 12140' Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst _ Coal Gvl Tuff (current) 30 20 50 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 2074 21060' 220112 1455 674 318 381 172 96 Minimum 48 21910' 4833 27 28 28 49 43 29 Average 915 68786 510 259 137 179 95 56 Background 47 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) r 24 hr Recap: Drill ahead in primary well bore. Cuttings consist primarily of unconsolidated sand with varying amounts of siltstone prior to planned Fault. Shale becomes prevelant after fault. i ) Logging Engineers: Emil Opitz/Koh Jo Plowman Report By: Emil Opitz Unit Phone: 907-685-0772 IF ;:: --LL)-u111.L..,..„.Lf.i 7i;:.:, ' HALLIBURTON Customer: ENI Report#: 30 Well: SP22-FN1 Date: 24-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 22020' Rig: Doyon 15 Current Depth: 22923' Job No.: AK-AM-0900169420 24 Hour Progress: 903' Daily Charges: $4,410.00 Rig Activity: BROOH Total Charges: $105,500.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Wimmer/Buchanan ' ' ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) 188.2 336.9 22597' Flow In(gpm) 439 SPP(psi) 3138 Flow In (spm) 106 Gallons/stroke 4.14 @ 94% IMWD Summary 22020' Depth 22923' Xceed 675,PeriScope 6T7o57TiseleScope 675,Ecoscope E(pCpgD) 1A275 1M2ir112 1M3a2x5 Ip Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (1b/100ft2) ml/30min (lb/bbl) % 22923' FazePro 9.50 55 66/34 18 16 N/A 2.00 2.60 6.79 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 12140' 7"777f1—..1.1.- 11 ' 11 1:7 .7...771 II .7_771: IIITTIII_I:TTIII .7-. 117 _ 7,7.1.7If '-,.-- Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 400 L-80 . ,--,/ Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) 70 30 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-51 C-5n Maximum 572 22717' 69355 282 74 39 46 32 19 Minimum 3 22822' 29 0 0 0 0 0 0 Average 186 21056 93 43 29 40 33 22 Background 112 Trip 192 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead in primary well bore to TD of 22,923'MD.BROOH per K&M. 1 Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 31 Well: SP22-FN1 Date: 25-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterdays Depth: 22923' Rig: Doyon 15 Current Depth: 22923' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $3,410.00 Rig Activity: BROOH Total Charges: $108,910.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Wimmer/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr ---- Flow In(..m 439 SPP •si 3138 Flow In(spm) 106 Gallons/stroke 4.14 @ 94% .. MWD Summary Depth Tools ECD Avg Min Max 22923' to 22923' Xceed 675,PeriScope 675,TeleScope 675.Ecoscope ...) --- Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T se in out sec/.t Ratio cP (Ib/100ft2 ml/30min (Ib/bbl 22923' FazePro 9.40 56 66/34 17 13 N/A 1.90 2.47 6.50 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM ;Condition 3 Hycalog SKH616M PDC 8.75" 0.969 - 12140' ---- Size Set At Type Weight Grade ': , Casing 20" 160' EVAMAR 178.9 X-65 _' Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 w=. Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) '; 777 717217:771: - w. .gym �,uow.._. : . _ :77 ::::17.7.7_17_721: __::: .- 711 Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 54 Connection - * 10,000 Units = 100%Gas In Air ; (current) (max) (max) . 24 hr Recap:Cont.to BROOH per K&M. 1 Iv I. h Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 t '„ HALLIBURTON Customer: ENI Report#: 32 Well: SP22-FN1 Date: 26-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 22923' Rig: Doyon 15 Current Depth: 22923' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $8,064.00 Rig Activity: LID BHA Total Charges: $116,974.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Ross/Wimmer/Buchanan E ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) Flow In(gpm) SPP(psi) Flow In(spm) Gallons/stroke 4.14 @ 94% I MWD Summary Depth Tools ECD Avg Min Max to (ppg) Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (Ib/bbl) % 22923' FazePro 9.40 54 66/34 18 12 N/A 1.80 2.34 6.45 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 105.00 12140' 22923' 16489' 10.0 140.0 2-1-WT-A-X-IN-No-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 I Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip 17 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Cont.to BROOH per K&M to 11,941'MD.CBU per detail.Slip&cut drill line and service drawworks,top drive,traveling equip. and crown.POOH on elevators.L/D BHA.***Please note extra$5,254 charge for consumables used*** li Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 Y ,: uw. HALLIBURTON Customer: #: 33 Well: SP22-FN1 Date: 27-Feb-2013 «:::.. Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 22923' Rig: Doyon 15 Current Depth: 22923' Job No.: AK-AM-0900169420 24 Hour Progress: 0' i Daily Charges: $2,810.00 Rig Activity: Run 5.5"liner Total Charges: $119,784.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: KeenerAMmmer/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr ---- Flow In ••m SPP •si ° Flow In(spm) Gallons/stroke 4.14 @ 94% MWD Summary Depth Tools ECD Avg Min Max to , Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (lb/bbl) % 22923' FazePro 9.40 54 66/34 18 12 N/A 1.80 2.34 6.50 4 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM ,,Condition 3 Hycalog SKH616M PDC 8.75" 0.969 105.00 12140' 22923' 16489' 10.0 140.0 2-1-WT-A-X-IN-No-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) -------_---- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Cont.L/D BHA#5.Remove wear ring&install test plug.Test BOPE.Remove test plug&install wear ring.CIO saver sub,service upper and lower IBOP.Transfer 5"DP for liner run.M/U shoe and run 5.5"liner. M' Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 I HALLIBURTON Customer: ENI Report# 34 Well: SP22-FN1 Date: 28-Feb-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 22923' _ Rig: Doyon 15 Current Depth: 22923' Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $2,810.00 Rig Activity: Run 5.5"liner Total Charges: $122,594.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Wimmer/Buchanan > r- *4, .. ,, .. a ?, ';;.. '.s ,`" :- :. - -r a .; K, ,. x ,, ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) Flow In (gpm) SPP(psi) Flow In (spm) Gallons/stroke 4.14 @ 94% M MWD Summary Depth Tools ECD Avg Min Max to (...) Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (Ib/bbl) % 22923' FazePro 9.40 56 66/34 18 13 N/A 1.70 2.21 6.71 Bit# I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 105.00 12140' 22923' 16489' 10.0 140.0 2-1-WT-A-X-IN-No-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology (%) Ss Cht Silt _ Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n I Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) ,. .. 44 ,' 41 y 24 hr Recap:RIH w/5.5"liner.P/U&M/U HRDE running tool,mix&pour pal mix.Cont.RIH w/5.5"liner.Cont to trip in hole filling pipe every 20 stands.At 19,346'MD break circ.Rotate liner in hole to 21,305'MD. Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report# 35 Well: SP22-FN1 Date: 1-Mar-2013 Area: Spy Island Time: 24:00:00 Sperry Drilling Location: North Slope Yesterday's Depth: 22923' Rig: _Doyon 15 Current Depth: 22923' Job No.: AK-AM-0900169420 24 Hour Progress: 0' ); Daily Charges: $2,810.00 Rig Activity: L/D 4.5"DP Total Charges: $125,404.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Mmmer/Buchanan r IL. ..; mow.:ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP ft/hr) Flow In (gpm) SPP(psi) Flow In (spm) Gallons/stroke 4.14 @ 94% MWD Summary Depth Tools I ECD Avg Mir, Max to (ppg) Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (Ib/bbl) % 22923' Brine 9.05 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 105.00 12140' 22923' 16489' 10.0 140.0 2-1-WT-A-X-IN-No-TD 'r Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl _ Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap:Cont.rotate 5.5"liner in hole on 5"DP to 21929'MD.Break circ&drop setting ball&pump down. Pressure test annulus&P/U drill string to verify HRDE running tool released.Displace OBM to brine.POOH&L/D 5"DP.Service break&L/D liner running tool.L/D 4.5"DP. Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 HALLIBURTON Customer: ENI Report#: 36 Well: SP22-FN1 Date: 2-Mar-2013 Area: Spy Island Time: 24:00:00 4 Sperry Drilling Location: North Slope Yesterday's Depth: 22923' Rig: Doyon 15 Current Depth: 22923' o; Job No.: AK-AM-0900169420 24 Hour Progress: 0' Daily Charges: $2,810.00 Rig Activity: Run 4.5"Tubing Total Charges: $128,214.00 Reason for Trip: NO FAILURES HSE Incidents: NO HSE Report For: Keener/Wimmer/Buchanan ROP Current Avg 24 hr Max Max at ft Current Pump & Flow Data: ROP(ft/hr) ---- Flow In(•em) SPP(.si Flow In (spm) Gallons/stroke 4.14 @ 94% MWD Summary Depth Tools ECD Avg Min Max to Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal Lime Cor Solids Death Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min (Ib/bbl) % 22923' Brine 9.05 28 ------- Bit# 1 Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 Hycalog SKH616M PDC 8.75" 0.969 105.00 12140' 22923' 16489' 10.0 140.0 2-1-WT-A-X-IN-No-TD Size Set At Type Weight Grade Casing 20" 160' EVAMAR 178.9 X-65 Summary 13 3/8" 3082' BTC 68.0 L-80 9 5/8" 12122' HYDRIL 40.0 L-80 Lithology (%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n a Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 _ 0 0 0 0 0 0 Background Trip Connection - 10,000 Units = 100%Gas In Air (current) (max) max 24 hr Recap:Cont.L/D 4.5"DP.Clean stack w/Johnny Wacker.Remove wear ring.Install pump w/slick line,P/U tool string and "r install pack off and test tool.R/D wireline.Pull tbg and pump out of hole.M/U motor shroud,service motor and seal assembly& POOH.Install motor centralizer.Install TEC line,cap tube&MLE.Splice MLE cable and tube&test.Run 4.5"tubing. f. i Logging Engineers: Emil Opitz/Leigh Ann Rasher Report By: Leigh Ann Rasher Unit Phone: 907-685-0772 o N H 0 0 0 0 0 0 o p ;a - N v v 0 o m m m m E v 0 m a a a a o N o E 4 LL LL w a • C F N N N N lL 0 Oo CD N O) (n N a a c O c-, v m m c a N y L co m d LL co Z a N N Z Q W a p 0 ti p p O W F- D I- ttp ~tv 17 `0 w X O O Q G Q Q J m U U IL , N N 2 a LL• m C7 Ti. 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U) M M M M V / ✓ + a0 0 0 0 0 o O N O O UM) O o O O V O O O O O O O O oV V V V , UE ommmmmmmmmmmmmmmmmm 5 mmmmmmmmm O G) 0 L D r r M D N M M o O O O O O O 2 a� m p O UUo V M U N m. `L L0. ❑ m Z Q O �' m m m m r UUUV v V V N ^ U) O O O O M ,c'' 09 m UO m a-O N N N N N N Q. v U N U) r CO r U d N M V Ur N) m .4O 13 _ J V/ 2 o = , m u.. 0 (NN Q a 0 03 CO CO " ? m m a m o o m a) o a a a a a a U u. a a a U. a lC LL LL L_ LL L_ LL V_ LL LL l6 N • U) I- 00 Q) O O N M 0 Q V 6 (O 1� aO O N N N N N M M N M tT U) m r a0 m N N N (0 N c c E J J 0 0 0 0,o0m= + � c K K () U Ce m m m > l7 J CC OL > N N N N N N N o 0 0 0 0 0 0 O o 0 0 0 O W y E ) O) ON) ON) O) CO O U) O O O O O O J O O O O O O V E (o V U) V O O O O O O — co U0 M N 10 0 co U() U) l() U) V CO CO CO CO CO CO CD C : O) 0 r V V O) CO V co CO N JC N N N N N N M O 0)) W W • N N .- .-- s- = O> O) O) O) O) O) O) o Nn U) N() U) Nn N() m V V zW V V CO M CO M CO CO CO CO CO CO (O (O (O CO O (O U) (O (O (O CO : O W O) O U) O o ' > U) r L() V U) r o O co m (o (0 (0 (0 CO It • " " aaaa U (.) zzzzzz 0 0 LO (n Nn N Nn N (O CO CO U) U) In N co CO (O (O (O CO (h O) • LY E (O Nn M M M '7 0 (D 2 N N N N N N C lY _E N V 0 0 0 • K co co co co M M O M N r OO a0 O) U) U) V V V V co re E LL E v v v v N co � co (D V7 V7 V7 U7 d O U) N Nn Nn N Nn ✓ U) U) U) U) U) U) } ° (O CO N N CO Q N iN Q.• m co r co co co V 2 CI is, N co O G V N N co U) to V V U) LL n „ N Nn u) N u) u) u) tta)To C N O w m 0 0 0 0 0 0 C O V Nn U) v v v E D. W O) O O) O) O) U) U c C • c▪ M) N N N N c," U E. d OD O) CO CO 0) O) M N N N N N N N Cal a- 01 w N N N N N N O LL LL LL LL LL LL • M V N (O r a0 N N N N N N HALLIBURTON Well Name: SP22-FN1 Depth(MD) 10500 to 13000 ft - Sperry Drilling Location: Spy Island (TVD) 3605 to 3748 ft Operator: ENI Petroleum Show Report No. 1 Show Report Report Prepared By: Emil Opitz Formation: N&OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 7 Feb to 15 Feb 2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 10544 ft Gas Units 215 Mud Chlorides(mg/L)= 1400 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 24500 1670 = 22830 C1/C2 = 59 ∎∎ �• C2 407 21 ■ 386 C1/C3 = 96 ---- C3 247 - 9 = 238 C1/C4 = 145 li=i/ i1ON/A C4 159 - 2 = 157 C1/C5 = 951 NPH M ri C5 24 - 0 = 24 Production 100 i Analysis •Gas 1 Oil 1 Water ©Non-Producible Hydrocarbons -=l■i■ L Depth 10571 ft Gas Units 216 Mud Chlorides(mg/L)= 1400 Gas liii _ Flowline Background Show - -- _- - ppm ppm ppm - _ Hydrocarbon Ratios 10 C1 24464 - 862 = 23602 C1/C2 = 59 �� C2 412 - 15 = 397 C1/C3 = 93 ∎∎ C3 262 - 9 = 253 C1/C4 = 299 Oil = C4 84 - 5 = 79 C1/C5 = 265 -- - IIIIIIIIIIII C5 89 - 0 = 89 NPH Production 1 Analysis 1 Gas 1 Oil •Water ©Non-Producible Hydrocarbons `; Hydrocarbon Ratios Depth 12720 ft Gas Units 1092 Mud Chlorides(mg/L)= 107500 C1 C1 C1 C1 fi+' Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 124276 - 1988 = 122288 C1/C2 = 123 C2 1039 - 48 = 991 C1/C3 = 212 C3 630 53 = 577 C1/C4 = 548 NPH C4 293 - 70 = 223 C1/C5 = 446 C5 301 - 27 = 274 _ Production 100 _ --- Analysis II Gas I Oil I Water E Non-Producible Hydrocarbons _— -- Depth 12998 ft Gas Units 861 Mud Chlorides(mg/L)= 115000 Gas Flowline Background Show ----_-- --- ----- PPm PPm PPm Hydrocarbon Ratios 10 C1 99088 - 4013 = 95075 C1/C2 = 110 C2 936 - 75 = 861 C1/C3 = 185 Oil — C3 589 - 74 = 515 C1/C4 = 511 C4 293 - 107 = 186 C1/C5 = 360 ---- C5 314 - 50 = 264 NPH Production 1 Analysis •Gas II Oil •Water ©Non-Producible Hydrocarbons HALLIBURTON Well Name: SP22-FN1 Depth(MD) 13500 to 14800 ft Sperry Drilling Location: Spy Island (TVD) 3750 to 3745 ft Operator: ENI Petroleum Show Report No. 2 Show Report Report Prepared By: Emil Opitz Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 16-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 13694 ft Gas Units 1163 Mud Chlorides(mg/L)= 120000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 Cl 133330 - 5228 = 128102 C1/C2 = 129 C2 1080 - 89 = 991 C1/C3 = 241 C3 611 - 79 = 532 C1/C4 = 241 C4 653 - 121 = 532 C1/C5 = 749 NPH C5 250 - 79 = 171 __ Production 100 _ Analysis •Gas •Oil 1 Water E Non-Producible Hydrocarbons Depth 14145 ft Gas Units 1292 Mud Chlorides(mg/L)= 120000 Gas Flowline Background Show ----- PPm PPm PPm 1 -- _- ------ Hydrocarbon Ratios 10 C1 142457 - 8674 = 133783 C1/C2 = 133 C2 1178 - 174 = 1004 C1/C3 = 253 C3 690 - 161 = 529 C1/C4 = 1088 Oil C4 364 - 241 = 123 C1/C5 = 460 —— ——— —C5 419 - 128 = 291 NPH Production 1 Analysis •Gas •Oil 1 Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios p; Depth 14350 ft Gas Units 1162 Mud Chlorides(mg/L)= 115000 C1 C1 C1 C1 r}-', Flowline Background Show C2 C3 C4 C5 x PPm PPm PPm . Hydrocarbon Ratios Cl 131221 9801 = 121420 C1/C2 = 134 1000 C2 1107 - 200 = 907 C1/C3 = 253 C3 670 191 = 479 C1/C4 = 2130 NPH C4 365 - 308 = 57 C1/C5 = 474 _ C5 422 - 166 = 256 --Production 100 — Analysis •Gas I Oil •Water ©Non-Producible Hydrocarbons —- Depth 14715 ft Gas Units 1443 Mud Chlorides(mg/L)= 115000 Gas Flowline Background Show ———— ——— ———- — PPm PPm PPm ———— Hydrocarbon Ratios 10 C1 160957 - 9444 = 151513 C1/C2 = 143 C2 1267 - 204 = 1063 C1/C3 = 270 Oil C3 764 - 203 = 561 C1/C4 = 2104 C4 422 - 350 = 72 C1/C5 = 512 ————• C5 493 - 197 = 296 NPH Production 1 Analysis •Gas 1 Oil 1 Water ©Non-Producible Hydrocarbons HALLIBURTON Well Name: SP22-FN1 Depth(MD) 15100 to 17500 ft Sperry Drilling Location: Spy Island (TVD) 3751 to 3735 ft Operator: ENI Petroleum Show Report No. 3 Show Report Report Prepared By: Emil Opitz Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 18-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. 6s Hydrocarbon Ratios Depth 15279 ft Gas Units 1453 Mud Chlorides(mg/L)= 110000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 160401 - 7432 = 152969 C1/C2 = 142 C2 1200 - 119 = 1081 C1/C3 = 277 C3 650 - 98 = 552 C1/C4 = 275 "e7< C4 721 - 165 = 556 C1/C5 = 827 NPH C5 300 - 115 = 185 __ Production 100 — _ ----• Analysis •Gas •Oil I Water ©Non-Producible Hydrocarbons — —— Depth 15829 ft Gas Units 1514 Mud Chlorides(mg/L)= 110000 Gas Flowline Background Show ___ PPm PPm PPm -------------- -——— _— Hydrocarbon Ratios 10 - C1 164676 - 8936 = 155740 C1/C2 = 136 C2 1313 - 171 = 1142 C1/C3 = 262 C3 742 - 148 = 594 C1/C4 = 1059 Oil k C4 391 - 244 = 147 C1/C5 = 502 !" C5 456 - 146 = 310 NPH Production 1 Analysis •Gas I Oil I Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios Depth 16601 ft Gas Units 1383 Mud Chlorides(mg/L)= 100000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 PPm PPm PPm Hydrocarbon Ratios 1000 Cl 151877 9497 = 142380 C1/C2 = 146 ���� C2 1162 - 190 = 972 C1/C3 = 285 C3 685 186 = 499 C1/C4 = 2906 NPH C4 377 328 = 49 C1/C5 = 554 /' C5 450 - 193 = 257 —_— Production 100 _— ——— Analysis •Gas I Oil I Water ©Non-Producible Hydrocarbons ——--- Depth 17119 ft Gas Units 1503 Mud Chlorides(mg/L)= 98000 Gas - . Flowline Background Show ——__——— ———- PPm PPm PPm ————— Hydrocarbon Ratios 10 - C1 161439 - 10306 = 151133 C1/C2 = 130 - C2 1364 - 197 = 1167 C1/C3 = 251 Oil C3 796 - 195 = 601 C1/C4 = 1757 C4 434 - 348 = 86 C1/C5 = 486 ————• C5 521 - 210 = 311 NPH Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons j HALLIBURTON Well Name: SP22-FN1 Depth(MD) 18000 to 19800 ft Sperry Drilling Location: Spy Island (TVD) 3726 to 3740 ft Operator: ENI Petroleum Show Report No. 4 Show Report Report Prepared By: Emil Opitz Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 20-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 18158 ft Gas Units 1644 Mud Chlorides(mg/L)= 100000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 180881 - 6347 = 174534 C1/C2 = 148 C2 1251 - 71 = 1180 C1/C3 = 295 C3 643 - 52 = 591 C1/C4 = 303 C4 672 - 96 = 576 C1/C5 = 933 NPH C5 274 - 87 = 187 _ Production 100 _ " _ Analysis 1 Gas 1 Oil 1 Water ©Non-Producible Hydrocarbons - Depth 18517 ft Gas Units 1684 Mud Chlorides(mg/L)= 100000 Gas Flowline Background Show --- PPm PPm PPm ___--- Hydrocarbon Ratios 10 t C1 177127 - 30599 = 146528 C1/C2 = 115 C2 1611 333 = 1278 C1/C3 = 218 C3 895 - 222 = 673 C1/C4 = 997 Oil C4 444 - 297 = 147 C1/C5 = 387 - - ---- 05 537 - 158 = 379 NPH Production 1 Analysis 1 Gas 1 Oil 1 Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios Depth 19195 ft Gas Units 1714 Mud Chlorides(mg/L)= 89000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 Cl 184920 27766 = 157154 C1/C2 = 123 _��■ C2 1623 - 345 = 1278 C1/C3 = 243 C3 911 263 = 648 C1/C4 = 2311 NPH C4 469 - 401 = 68 C1/C5 = 428 C5 582 - 215 = 367 __ Production 100 __ ---- Analysis 1 Gas 1 Oil •Water ©Non-Producible Hydrocarbons -- -- G Depth 19641 ft Gas Units 1353 Mud Chlorides(mg/L)= 89000 Gas Flowline Background Show _---- - ---- PPm PPm PPm --- Hydrocarbon Ratios 10 C1 143841 - 10590 = 133251 C1/C2 = 115 C2 1326 - 169 = 1157 C1/C3 = 222 Oil C3 753 - 154 = 599 C1/C4 = 1058 C4 397 - 271 = 126 C1/C5 = 405 --- - C5 498 - 169 = 329 NPH Production 1 Analysis •Gas 1 Oil 1 Water ©Non-Producible Hydrocarbons 1 t HALLIBURTON Well Name: SP22-FN1 Depth(MD) 20000 to 21700 ft Sperry Drilling Location: Spy Island (TVD) 3739 to 3777 ft Operator: ENI Petroleum Show Report No. 5 Show Report Report Prepared By: Emil Opitz Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 21 Feb-23 Feb 2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 20034 ft Gas Units 1934 Mud Chlorides(mg/L)= 89000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 (,; C1 203821 - 11506 = 192315 C1/C2 = 155 C2 1441 - 199 = 1242 C1/C3 = 327 C3 762 - 173 = 589 C1/C4 = 333 C4 882 304 = 578 C1/C5 = 1012 NPH C5 374 - 184 = 190 ---- Production 100 _ --- Analysis •Gas II Oil •Water ©Non-Producible Hydrocarbons ,-- - Depth 20568 ft Gas Units 1973 Mud Chlorides(mg/L)= 103000 Gas Flowline Background Show ___-- PPm PPm PPm --_-- Hydrocarbon Ratios 10 C1 213862 - 1925 = 211937 C1/C2 = 152 C2 1416 - 23 = 1393 C1/C3 = 323 C3 679 - 22 = 657 C1/C4 = 779 OII C4 324 - 52 = 272 C1/C5 = 629 - - - -- 05 391 - 54 = 337 NPH Production 1 Analysis •Gas 1 Oil •Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios Depth 21055 ft Gas Units 2074 Mud Chlorides(mg/L)= 93000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ■ PPm PPm PPm Hydrocarbon Ratios 1000 Cl 219430 - 7777 = 211653 C1/C2 = 155 C2 1454 - 85 = 1369 C1/C3 = 344 C3 679 64 = 615 C1/C4 = 1003 NPH C4 318 - 107 = 211 C1/C5 = 678 C5 386 - 74 = 312 _ l Production 100 __ -- Analysis U Gas •Oil •Water ©Non-Producible Hydrocarbons -- - Depth 21587 ft Gas Units 1755 Mud Chlorides(mg/L)= 114000 Gas Flowline Background Show ------ - --- PPm PPm PPm --'- Hydrocarbon Ratios 10 C1 194313 - 6189 = 188124 C1/C2 = 147 C2 1352 - 76 = 1276 C1/C3 = 356 Oil C3 597 - 68 = 529 C1/C4 = 1297 C4 282 - 137 = 145 C1/C5 = 726 ----• C5 353 - 94 = 259 NPH Production 1 Analysis I Gas I Oil I Water /Non-Producible H drocarbons HALLIBURTON Well Name: SP22-FN1 Depth(MD) 22600 to 22800 ft Sperry Drilling Location: Spy Island (TVD) 3571 to 3470 ft Operator: ENI Petroleum Show Report No. 6 Show Report Report Prepared By: Emil Opitz Formation: N Sands Report Delivered To: Andrew Buchanan Date Drilled: 24-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 22650 ft Gas Units 438 Mud Chlorides(mg/L)= 112000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 49496 - 2837 = 46659 C1/C2 = 206 C2 246 - 19 = 227 C1/C3 = 598 C3 92 - 14 = 78 C1/C4 = 536 C4 124 - 37 = 87 C1/C5 = 1372 NPH C5 76 - 42 = 34 _ Production 100 —<<-— Analysis II Gas I Oil I Water ©Non-Producible Hydrocarbons �— Depth 22670 ft Gas Units 480 Mud Chlorides(mg/L)= 112000 Gas Flowline Background Show ——— PPm PPm PPm --------'— Hydrocarbon Ratios 10 C1 59750 - 2837 = 56913 C1/C2 = 221 i C2 277 - 19 = 258 C1/C3 = 662 C3 100 14 = 86 C1/C4 = 2277 Oil , C4 62 - 37 = 25 C1/C5 = 2033 — - - 05 70 - 42 = 28 NPH Production 1 Analysis 1 Gas •Oil I Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios Depth 22712 ft Gas Units 570 Mud Chlorides(mg/L)= 112000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 68158 - 12214 = 55944 C1/C2 = 264 C2 286 - 74 = 212 C1/C3 = 1929 C3 74 45 = 29 C1/C4 = #DIV/0! NPH • :/ C4 39 - 39 = 0 C1/C5 = #DIV/0! _ C5 46 - 46 = 0 Production 100 ___ ——— Analysis I Gas I Oil II Water ©Non-Producible Hydrocarbons ..——— Depth 22769 ft Gas Units 517 Mud Chlorides(mg/L)= 112000 Gas - Flowline Background Show __— — --—- PPm PPm PPm ————— Hydrocarbon Ratios 10 - C1 62493 - 12214 = 50279 C1/C2 = 378 C2 207 - 74 = 133 C1/C3 = #DIV/01 Oil C3 45 - 45 = 0 C1/C4 = #DIV/0! C4 26 - 26 = 0 C1/C5 = _#DIV/01 • C5 30 - 30 = 0 NPH Production 1 - Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons 1 HALLIBURTON Well Name: SP22-FN1 PB1 Depth(MD) 12550 to 13510 ft Sperry Drilling Location: Spy Island (TVD) 3726 to 3739 ft Operator: ENI Petroleum Show Report No. 1 Show Report Report Prepared By: Leigh Ann Rasher Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 15-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 12556 ft Gas Units 854 Mud Chlorides(mg/L)= 107500 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 [ PPm PPm PPm Hydrocarbon Ratios 1000 C1 101189 - 5116 = 96073 C1/C2 = 124 C2 811 - 39 = 772 C1/C3 = 213 ° C3 476 - 24 = 452 C1/C4 = 243 x, C4 417 - 21 = 396 C1/C5 = 775 NPH C5 124 - 0 = 124 Production 100 _ f'-= Analysis •Gas 1 Oil I Water ©Non-Producible Hydrocarbons —..- rh Depth 12719 ft Gas Units 1092 Mud Chlorides(mg/L)= 115000 Gas 1.,- Flowline Background Show _ _ ____ PPm PPm PPm Hydrocarbon Ratios 10 t- C1 124276 - 1285 = 122991 C1/C2 = 123 I. C2 1039 - 39 = 1000 C1/C3 = 210 C3 630 - 45 = 585 C1/C4 = 547 Oil V C4 293 - 68 = 225 C1/C5 = 454 - --- g C5 301 - 30 = 271 NPH Production 1 I Analysis I Gas I Oil 1 Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios Depth 13284 ft Gas Units 1143 Mud Chlorides(mg/L)= 115000 Cl Cl Cl Cl Flowline Background Show C2 C3 C4 C5 PPm PPm PPm l Hydrocarbon Ratios 1000 C1 128377 - 7749 = 120628 C1/C2 = 126 — C2 1101 - 143 = 958 C1/C3 = 232 C3 661 141 = 520 C1/C4 = 935 NPH C4 334 - 205 = 129 C1/C5 = 452 C5 365 - 98 = 267 _ __ --_li_.i = ` Production 100 -- __———,, f Analysis 1 Gas •Oil 1 Water ©Non-Producible Hydrocarbons .— - 1 Depth 13503 ft Gas Units 914 Mud Chlorides(mg/L)= 115000 Gas • Flowline Background Show _ ____ — — ppm PPm PPm ———— Hydrocarbon Ratios 10 Cl 105077 - 1620 = 103457 C1/C2 = 120 C2 912 - 53 = 859 C1/C3 = 217 Oil C3 543 - 67 = 476 C1/C4 = 704 e C4 281 - 134 = 147 C1/C5 = 431 NPH ` C5 321 - 81 = 240 E Production 1 Analysis •Gas 1 Oil II Water ©Non-Producible Hydrocarbons I HALLIBURTON Well Name: SP22-FN1 PB2 Depth(MD) 14700 to 16025 ft r Sperry Drilling Location: Spy Island (ND) 3745 to 3723 ft Operator: ENI Petroleum Show Report No. 1 Show Report Report Prepared By: Leigh Ann Rasher Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 17-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. • Hydrocarbon Ratios Depth 14714 ft Gas Units 1443 Mud Chlorides(mg/L)= 122000 C1 C1 C1 C1 F Flowline Background Show C2 C3 C4 C5 ppm ppm ppm .i Hydrocarbon Ratios 1000 C1 160957 - 8371 = 152586 C1/C2 = 143 C2 1267 - 200 = 1067 C1/C3 = 272 ii C3 764 - 204 = 560 C1/C4 = 274 t' C4 915 - 358 = 557 C1/C5 = 838 NPH C5 380 - 198 = 182 —- Production 100 —— t Analysis •Gas 1 Oil I Water E Non-Producible Hydrocarbons —--- 7' Depth 14965 ft Gas Units 1613 Mud Chlorides(mg/L)= 122000 Gas Flowline Background Show —---- PPm PPm PPm — Hydrocarbon Ratios 10 -- C1 178271 - 6397 = 171874 C1/C2 = 138 C2 1379 - 131 = 1248 C1/C3 = 264 C3 800 - 149 = 651 C1/C4 = 1116 Oil C4 442 - 288 = 154 C1/C5 = 498 - - - - - - - 05 521 - 176 = 345 NPH Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios • Depth 15825 ft Gas Units 1201 Mud Chlorides(mg/L)= 120000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 C1 133035 - 7655 = 125380 C1/C2 = 131 C2 1108 - 152 = 956 C1/C3 = 248 -- C3 661 156 = 505 C1/C4 = 1929 NPH C4 371 - 306 = 65 C1/C5 = 498 C5 452 - 200 = 252 ....... Production 100 __ ---- Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons —- ---- Depth 16021 ft Gas Units 1473 Mud Chlorides(mg/L)= 120000 Gas Flowline Background Show ——— — —— PPm ppm PPm ————- -— Hydrocarbon Ratios 10 C1 162638 - 7622 = 155016 C1/C2 = 138 C2 1293 - 173 = 1120 C1/C3 = 272 Oil C3 744 - 175 = 569 C1/C4 = 2584 C4 401 - 341 = 60 C1/C5 = 599 ————' C5 479 - 220 = 259 NPH Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons HALLIBURTON Well Name: SP22-FN1 PB3 Depth(MD) 15430 to 18550 ft Sperry Drilling Location: Spy Island (TVD) 3749 to 3714 ft Operator: ENI Petroleum Show Report No. 1 Show Report Report Prepared By: Leigh Ann Rasher Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 2/18/2013-2/19/2013 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 15438 ft Gas Units 1513 Mud Chlorides(mg/L)= 110000 C1 C1 C1 Cl Flowline Background Show C2 C3 C4 C5 , PPm PPm PPm Hydrocarbon Ratios 1000 .- C1 168995 - 3817 = 165178 C1/C2 = 135 C2 1284 - 62 = 1222 C1/C3 = 258 C3 704 - 63 = 641 C1/C4 = 252 C4 779 - 124 = 655 C1/C5 = 758 NPH C5 316 - 98 = 218 �/ Production 100 _ ——— Analysis I Gas I Oil 1 Water ©Non-Producible Hydrocarbons _��-- Depth 15662 ft Gas Units 1654 Mud Chlorides(mg/L)= 110000 Gas Flowline Background Show ___ PPm PPm PPm ---_-------- E Hydrocarbon Ratios 10 C1 179535 - 8280 = 171255 C1/C2 = 140 - C2 1374 - 148 = 1226 C1/C3 = 262 C3 780 - 126 = 654 C1/C4 = 865 Oil C4 409 - 211 = 198 C1/C5 = 502 - - - - C5 472 - 131 = 341 NPH 1 Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios Depth 18035 ft Gas Units 1402 Mud Chlorides(mg/L)= 112000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 Cl 152829 - 7787 = 145042 C1/C2 = 127 C2 1305 160 = 1145 C1/C3 = 245 C3 756 164 = 592 C1/C4 = 1769 NPH C4 403 - 321 = 82 C1/C5 = 537 C5 496 - 226 = 270 __ Production 100 __ —— Analysis II Gas I Oil I Water ©Non-Producible Hydrocarbons - --— 1 Depth 18542 ft Gas Units 1894 Mud Chlorides(mg/L)= 100000 Gas - Flowline Background Show ___---— ——— PPm PPm PPm ————— Hydrocarbon Ratios 10 C1 201731 - 9287 = 192444 C1/C2 = 149 C2 1410 - 117 = 1293 C1/C3 = 297 Oil C3 751 - 103 = 648 C1/C4 = 1069 C4 382 - 202 = 180 C1/C5 = 609 ————• C5 473 - 157 = 316 NPH Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons HALLIBURTON1 Well Name: SP22-FN1 PB4 Depth(MD) 19640 to 20875 ft Sperry,Drilling Location: Spy Island (TVD) 3741 to 3733 ft Operator: ENI Petroleum Show Report No. 1 Show Report Report Prepared By: Leigh Ann Rasher Formation: OA Sands Report Delivered To: Andrew Buchanan Date Drilled: 21-Feb-13 Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth 19641 ft Gas Units 1353 Mud Chlorides(mg/L)= 83000 C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 1- C1 148109 - 9938 = 138171 C1/C2 = 119 E-' C2 1346 - 181 = 1165 C1/C3 = 232 ......eie/ ;, C3 764 - 168 = 596 C1/C4 = 226 vo,•?. C4 908 - 296 = 612 C1/C5 = 646 NPH C5 393 - 179 = 214 — Production 100 - — _ Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons — ——— Depth 20034 ft Gas Units 1934 Mud Chlorides(mg/L)= 83000 Gas • Flowline Background Show _—___ ppm ppm PPm ----- ---------- ____ __— Hydrocarbon Ratios 10 C1 206146 - 11077 = 195069 C1/C2 = 150 C2 1500 - 197 = 1303 C1/C3 = 317 Q= C3 789 - 173 = 616 C1/C4 = 1912 Oil C4 404 - 302 = 102 C1/C5 = 613 — - - - C5 501 - 183 = 318 NPH Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons Hydrocarbon Ratios c Depth 20706 ft Gas Units 1684 Mud Chlorides(mg/L)= 94000 Cl Cl Cl Cl Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 180031 - 12766 = 167265 C1/C2 = 150 1000 C2 1307 - 191 = 1116 C1/C3 = 323 _ C3 685 167 = 518 C1/C4 = 2934 NPH C4 364 - 307 = 57 C1/C5 = 636 ' ,. C5 460 - 197 = 263 _ _ Production 100 —_--_——— Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons ——— f Depth 20874 ft Gas Units 1845 Mud Chlorides(mg/L)= 94000 Gas i-. Flowline Background Show ---_— — — —— PPm PPm PPm ——— —— Hydrocarbon Ratios 10 s ? C1 199886 - 7372 = 192514 C1/C2 = 152 C2 1383 - 117 = 1266 C1/C3 = 335 Oil C3 687 - 112 = 575 C1/C4 = 1447 C4 358 - 225 = 133 C1/C5 = 653 — ———. C5 448 - 153 = 295 NPH Production 1 Analysis I Gas I Oil I Water ©Non-Producible Hydrocarbons i HALLIBURTON VA Sperry Drilling .nii Eni Pc tirc.Ileiuim SP22-FN1 Interpolated Tops Marker MD INC AZ TVD TVDSS 16"Surface Borehole 20"Conductor Shoe 160.0 0.2 5.1 160.0 -106.2 - SV-4 768.5 18.9 297.7 760.9 _ -707.1 SV-3 1,161.0 34.1 301.3 1,110.5 1 -1,056.7 SV-2 1,478.5 41.5 300.3 1,361.8 -1,308.0 Permafrost Base 2,006.0 45.4 301.3 1,750.5 -1,696.7 SV-1 2,253.0 46.0 302.5 1,923.4 -1,869.6 Ugnu Top(UG4) 2,730.0 53.5 _ 301.7 2,248.4 -2,194.6 13 3/8"Surface Casing Shoe 3,082.0 60.0 293.7 2,433.9 -2,380.1 TD 16" Borehole 3,097.0 60.1 293.5 2,441.4 -2,387.6 12 1/4"Intermediate Borehole UG-2 Coal Bed Marker 3,882.0 76.8 282.2 2,735.3 -2,681.5 _ Lower Ugnu 8,057.0 81.8 284.6 3,274.1 -3,220.3 Schrader Bluff Top 9,776.0 82.3 283.4 3,509.2 -3,455.4 N Sequence Top 9,954.0 82.2 283.3 3,533.1 -3,479.3 N Top 10,533.0 82.3 287.1 3,610.3 -3,556.5 N Bottom 10,597.0 82.3 287.1 3,618.9 -3,565.1 N Sequence Base 10,910.0 82.6 294.9 3,662.7 -3,608.9 9 5/8"Intermediate Casing 12,122.0 87.0 322.8 3,700.9 -3,647.1 TD 12 1/4"Borehole 12,140.0 86.7 323.8 3,701.9 -3,648.1 8 3/4"Lateral Borehole OA Top 12,413.0 86.4 322.2 3,719.7 -3,665.9 OA-2 Top 12,513.0 86.4 322.7 3,726.0 -3,672.2 OA-3 Top 12,635.0 86.6 322.9 3,733.6 -3,679.8 OA-4 Top 13,030.0 86.6 322.3 3,751.4 -3,697.6 OA-4 Top 13,195.0 91.4 320.8 3,755.6 -3,701.8 Fault A 15,025.0 87.5 325.7 3,748.8 -3,695.0 OA-3 Top 17,578.0 90.8 310.8 3,734.3 -3,680.5 Fault B 17,823.0 92.2 311.5 3,728.5 -3,674.7 Fault C 18,955.0 87.9 315.3 3,733.4 -3,679.6 OA-3 Top 19,052.0 87.7 313.5 3,737.2 -3,683.4 Fault D 21,831.0 88.7 275.4 3,782.9 -3,729.1 5 112"Liner 21,929.0 93.6 275.5 3,781.7 -3,727.9 OA Bottom 22,315.0 110.9 273.8 3,695.0 -3,641.2 OA-4 Top 22,335.0 111.6 273.6 3,687.7 -3,633.9 OA-3 Top 22,367.0 112.6 273.2 3,675.7 -3,621.9 OA-2 Top 22,382.0 113.1 273.1 3,669.8 -3,616.0 OA Top 22,400.0 113.7 272.9 3,662.7 -3,608.9 N Bottm 22,731.0 120.3 270.9 3,505.4 -3,451.6 N Top 22,772.0 120.3 270.5 3,484.7 -3,430.9 TD 8 3/4"Borehole 22,923.0 120.4 271.2 3,408.4 -3,354.6 HALLIBU RTON ,..01 Sperry Drilling en'' E n0 Petroleum SP22-FN1 PB1, SP22-FN1 PB2, SP22-FN1 PB3, & SP22-FN1 PB4 Interpolated Tops Marker MD INC AZ TVD TVDSS SP22-FN1 PB1 Lateral Borehole Sidetrack Point 13,280.0 92.7 321.2 3,752.3 -3,698.5 OA-3 Top 13,396.0 92.9 319.6 3,746.3 -3,692.5 OA-2 Top 13,550.0 92.3 319.3 3,739.2 -3,685.4 TD SP22-FN1 PB1 14,550.0 91.6 321.3 3,728.4 -3,674.6 SP22-FN1 PB2 Lateral Borehole Sidetrack Point 14,880.0 90.0 325.5 3,744.8 -3,691.0 Fault A 15,015.0 90.3 324.9 3,744.5 -3,690.7 OA-2 Top _ 16,140.0 92.2 312.9 3,725.8 -3,672.0 TD SP22-FN1 PB2 16,360.0 90.3 314.3 3,722.7 -3,668.9 SP22-FN1 PB3 Lateral Borehole Sidetrack Point 17,950.0 89.6 310.7 _ 3,726.1 -3,672.3 OA-3 Top 18,057.0 92.5 310.0 _ 3,723.2 -3,669.4 OA-2 Top 18,220.0 93.1 308.0 3,715.9 -3,662.1_ Fault C _ 18,960.0 89.9 313.2 3,717.1 -3,663.3 OA-1 Top 19,142.0 84.7 312.2 3,724.8 -3,671.0 OA-2 Top 19,213.0 86.6 312.2 3,730.7 -3,676.9 TD SP22-FN1 PB3 19,306.0 87.6 312.3 3,734.8 -3,681.0 SP22-FN1 PB4 Lateral Borehole Sidetrack Point 20,240.0 88.4 295.7 3,741.8 -3,683.9 OA-3 Top 20,410.0 92.0 293.7 3,737.5 -3,683.9 OA-2 Top 20,590.0 91.2 291.0 3,731.2 -3,677.7 TD SP22-FN1 PB4 21,800.0 88.6 309.2 3,760.8 -3,677.7 HALLIBURTON DIRECTIONAL SURVEY REPORT Eni Petroleum SP22-FN1 Nikaitchuq USA AK-XX-0900169420 All depths reference the driller'spipe tally. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 Tl E-I N 40.72 0.00 0.00 40.72 0.00 N 0.00 E 0.00 0.00 121.11 0.10 26.85 121.11 0.06 N 0.03 E 0.06 0.12 169.53 0.17 2.04 169.53 0.17 N 0.05 E 0.17 0.19 201.76 0.47 350.08 201.76 0.35 N 0.03 E 0.35 0.95 233.88 0.78 345.12 233.88 0.69 N 0.05 W 0.69 0.98 262.89 0.76 331.42 262.88 1.05 N 0.19 W 1.05 0.64 297.41 1.18 307.81 297.40 1.47 N 0.58 W 1.47 1.66 327.80 2.17 300.54 327.78 1.95 N 1.32 W 1.95 3.33 356.18 3.25 300.24 356.12 2.63 N 2.48 W 2.63 3.81 387.05 4.70 298.78 386.92 3.68 N 4.34 W 3.68 4.71 418.15 5.95 301.28 417.88 5.13 N 6.84 W 5.13 4.09 449.02 7.18 299.08 448.55 6.90 N 9.89 W 6.90 4.07 479.82 8.05 300.30 479.08 8.92 N 13.44 W 8.92 2.87 510.89 8.50 300.16 509.83 11.18 N 17.30 W 11.18 1.45 541.60 8.90 299.86 540.18 13.50 N 21.32 W 13.50 1.31 572.59 9.07 297.76 570.79 15.83 N 25.56 W 15.83 1.19 603.94 9.94 297.25 601.71 18.22 N 30.16 W 18.22 2.79 634.35 11.46 295.62 631.59 20.73 N 35.21 W 20.73 5.10 665.42 13.56 294.52 661.92 23.57 N 41.31 W 23.57 6.80 691.88 14.88 293.47 687.57 26.22 N 47.25 W 26.22 5.08 723.07 16.19 295.25 717.62 29.67 N 54.86 W 29.67 4.47 785.29 19.86 298.41 776.78 38.40 N 72.00 W 38.40 6.10 847.59 22.75 300.07 834.82 49.47 N 91.74 W 49.47 4.74 910.77 25.98 301.49 892.36 62.82 N 114.12 W 62.82 5.20 971.77 27 67 X302.55 946.80 77.42 N 137.45 W 77.42 2.88 1034.54 28.43 302.07 1002.19 93.20 N 162.40 W 93.20 1.26 1096.73 30.76 300.91 1056.27 109.23 N 188.59 W 109.23 3.86 5.30 1158.97 34.05 301.31 1108.81 126.47 N 217.14 W 126.47 1251.87 34.43 301.18 1185.61 153.58 N 261.83 W 153.58 0.42 1345.71 38.48 299.66 1261.07 181.77 N 309.92 W 181.77 4.42 1439.04 42.00 300.33 1332.30 211.92 N 362.12 W 211.92 3.80 1532.41 40.71 300.35 1402.39 243.08 N 415.36 W 243.08 1.38 1625.72 39.92 300.07 1473.53 273.46 N 467.53 W 273.46 0.87 1719.17 43.19 299.34 1543.46 304.16 N 521.38 W 304.16 3.54 1812.51 43.40 300.21 1611.39 335.95 N 576.93 W 335.95 0.68 1905.75 43.56 300.26 1679.05 368.25 N 632.36 W 368.25 0.18 1999.04 45.45 301.31 1745.58 401.73 N 688.53 W 401.73 2.17 2092.41 44.70 301.66 1811.52 436.26 N 744.91 W 436.26 0.85 2185.74 46.40 302.14 1876.87 471.46 N 801.47 W 471.46 1.86 2279.21 45.80 302.64 1941.68 507.54 N 858.34 W 507.54 0.75 2372.60 45.49 302.91 2006.97 543.69 N 914.48 W 543.69 0.39 2465.99 45.00 303.48 2072.73 580.00 N 969.98 W 580.00 0.68 2559.34 45.11 304.24 2138.67 616.81 N 1024.85 W 616.81 0.59 2652.43 50.97 303.16 2200.89 655.17 N 1082.43 W 655.17 6.35 2746.24 54.02 301.43 2258.00 694.91 N 1145.33 W 694.91 3.57 2839.58 57.94 298.85 2310.22 733.71 N 1212.24 W 733.71 4.78 2932.96 59.38 297.28 2358.78 771.22 N 1282.61 W 771.22 2.11 3014.86 59.79 294.43 2400.25 802.01 N 1346.16 W 802.01 3.04 3190.41 62.47 289.45 2485.05 859.34 N 1488.72 W 859.34 2.92 3283.78 63.97 288.36 2527.12 886.34 N 1567.57 W 886.34 1.91 3377.17 65.14 286.31 2567.24 911.46 N 1648.07 W 911.46 2.34 3470.55 67.14 285.11 2605.01 934.57 N 1730.27 W 934.57 2.44 3563.95 69.08 284.89 2639.84 957.00 N 1813.98 W 957.00 2.09 3657.35 71.49 282.81 2671.34 978.03 N 1899.34 W 978.03 3.32 37 :: 8 � , 282.35 2699.64 '7.40 ' `' 988. .;.40 1.89 2.36 3844.03 75.40 282.18 2724.91 1016.49 N 2073.95 W 1016.49 3937.31 78.93 282.29 2745.63 1035.76 N 2162.82 W 1035.76 3.79 4030.00 0400 LOU.00 L(0U.04 1004.L4 IN LL03.U0 VV 1U04.L4 4.10 4124.04 85.65 281.36 2770.24 1072.14 N 2344.19 W 1072.14 3.36 4217.43 85.30 282.17 2777.61 1091.12 N 2435.34 W 1091.12 0.94 4310.76 84.91 282.87 2785.57 1111.28 N 2526.11 W 1111.28 0.86 4404.12 84.08 283.63 2794.53 1132.57 N 2616.57 W 1132.57 1.20 4497.39 83.37 282.98 2804.73 1153.91 N 2706.79 W 1153.91 1.03 4590.71 83.67 282.73 2815.26 1174.54 N 2797.19 W 1174.54 0.42 4684.04 83.64 282.27 2825.57 1194.62 N 2887.75 W 1194.62 0.49 `` 4777.43 83.48 283.65 2836.05 1215.43 N 2978.18 W 1215.43 1.48 4871.10 83.54 283.75 2846.63 1237.47 N 3068.61 W 1237.47 0.12 4964.22 83.61 283.15 2857.05 1258.99 N 3158.60 W 1258.99 0.64 , 1 5057.58 83.45 283.19 2867.58 1280.13 N 3248.93 W 1280.13 0.18 5150.99 83.61 283.44 2878.10 1301.51 N 3339.25 W 1301.51 0.32 5244.34 83.44 285.09 2888.63 1324.36 N 3429.14 W 1324.36 1.77 5337.80 82.93 285.50 2899.72 1348.84 N 3518.65 W 1348.84 0.70 5431.20 82.60 285.73 2911.48 1373.78 N 3607.89 W 1373.78 0.43 5524.57 82.21 285.71 2923.82 1398.85 N 3696.98 W 1398.85 0.42 5617.97 81.97 285.29 2936.68 1423.58 N 3786.12 W 1423.58 0.51 5711.34 82.17 284.77 2949.56 1447.56 N 3875.44 W 1447.56 0.59 5804.68 82.22 285.59 2962.23 1471.77 N 3964.68 W 1471.77 0.87 5898.06 82.16 286.42 2974.92 1497.28 N 4053.61 W 1497.28 0.88 L. 5991.47 82.04 287.16 2987.76 1524.01 N 4142.19 W 1524.01 0.80 6084.89 82.29 287.62 3000.50 1551.67 N 4230.51 W 1551.67 0.56 6178.33 82.35 287.84 3012.98 1579.87 N 4318.71 W 1579.87 0.24 6271.72 81.95 287.66 3025.74 1608.07 N 4406.82 W 1608.07 0.47 6365.09 82.06 287.59 3038.73 1636.07 N 4494.94 W 1636.07 0.14 6458.44 81.86 288.16 3051.78 1664.44 N 4582.91 W 1664.44 0.64 ¥ 6551.78 82.28 287.86 3064.66 1693.02 N 4670.83 W 1693.02 0.55 6645.15 81.78 288.47 3077.61 1721.85 N 4758.69 W 1721.85 0.84 6734.90 81.59 287.09 3090.59 1748.97 N 4843.25 W 1748.97 1.54 6831.75 82.34 286.34 3104.12 1776.55 N 4935.10 W 1776.55 1.09 Eib 6925.19 81.97 285.72 3116.88 1802.11 N 5024.06 W 1802.11 0.77.4d g 7018.43 82.21 285.16 3129.71 1826.69 N 5113.08 W 1826.69 0.65 7112.75 81.89 284.15 3142.76 1850.33 N 5203.46 W 1850.33 1.11 7205.36 82.08 282.46 3155.67 1871.43 N 5292.70 W 1871.43 1.82 7298.76 82.07 282.71 3168.55 1891.59 N 5382.98 W 1891.59 0.27 7392.10 81.33 282.54 3182.02 1911.78 N 5473.11 W 1911.78 0.81 7485.57 82.23 282.81 3195.38 1932.07 N 5563.37 W 1932.07 1.00 L. 7579.01 82.19 283.04 3208.05 1952.78 N 5653.60 W 1952.78 0.25 7672.49 82.19 282.96 3220.75 1973.61 N 5743.84 W 1973.61 0.08 7765.81 82.25 283.94 3233.39 1995.12 N 5833.76 W 1995.12 1.04 7859.19 82.15 284.06 3246.06 2017.50 N 5923.53 W 2017.50 0.17 7952.59 82.57 283.84 3258.48 2039.82 N 6013.37 W 2039.82 0.51 8046.00 81.78 284.59 3271.19 2062.54 N 6103.07 W 2062.54 1.16 8139.29 82.17 284.98 3284.22 2086.12 N 6192.39 W 2086.12 0.59 8232.75 82.25 285.16 3296.89 2110.19 N 6281.80 W 2110.19 0.21 8326.12 82.19 284.78 3309.53 2134.09 N 6371.18 W 2134.09 0.41 8419.41 81.40 284.94 3322.84 2157.77 N 6460.42 W 2157.77 0.86 8512.74 81.88 285.45 3336.41 2181.97 N 6549.53 W 2181.97 0.75 8606.11 82.39 285.82 3349.19 2206.90 N 6638.60 W 2206.90 0.67 8699.41 82.18 285.74 3361.71 2232.04 N 6727.57 W 2232.04 0.24 8792.86 82.37 286.59 3374.27 2257.82 N 6816.51 W 2257.82 0.92 8886.21 82.56 287.27 3386.51 2284.77 N 6905.04 W 2284.77 0.75 8979.52 82.11 287.04 3398.96 2312.05 N 6993.41 W 2312.05 0.54 9072.92 82.32 285.65 3411.61 2338.09 N 7082.20 W 2338.09 1.49 9166.26 82.28 285.01 3424.12 2362.54 N 7171.41 W 2362.54 0.68 9259.74 82.10 283.96 3436.82 2385.71 N 7261.08 W 2385.71 1.13 -.ALL 9352.29 82.03 284.33 3449.60 2408.11 N 7349.96 W 2408.11 0.40 9445.60 81.71 284.10 3462.79 2430.79 N 7439.50 W 2430.79 0.42 r„ 9539.01 82.18 283.77 3475.88 2453.06 N 7529.27 W 2453.06 0.61 9632.44 82.16 284.32 3488.61 2475.52 N 7619.06 W 2475.52 0.58 9726.16 82.35 284.01 3501.24 2498.25 N 7709.10 W 2498.25 0.39 9819.66 82.30 282.78 3513.73 2519.72 N 7799.24 W 2519.72 1.30 9860.34 82.29 282.39 3519.18 2528.50 N 7838.59 W 2528.50 0.95 9953.71 82.18 283.25 3531.80 2549.03 N 7928.79 W 2549.03 0.92 10047.08 82.12 283.70 3544.55 2570.58 N 8018.74 W 2570.58 0.48 10140.41 82.36 284.78 3557.15 2593.33 N 8108.38 W 2593.33 1.18 pip 10233.78 82.60 284.86 3569.37 2617.00 N 8197.86 W 2617.00 0.27 10327.09 82.35 285.60 3581.59 2641.30 N 8287.12 W 2641.30 0.83 10420.54 82.36 285.85 3594.02 2666.41 N 8376.27 W 2666.41 0.27 = i 10513.88 82.29 287.04 3606.49 2692.59 N 8464.99 W 2692.59 1.27 10607.12 82.35_ 287.10 3618.95 2719.72 N 8553.32 W 2719.72 0.09 10700.41 81.67 288.27 3631.92 2747.78 N 8641.34 W 2747.78 1.44 10793.78 81.77 290.76 3645.37 2778.64 N 8728.42 W 2778.64 2.64 10887.11 82.24 293.95 3658.35 2813.79 N 8813.89 W 2813.79 3.42 if19Rf1 5A R3 5R 9A7 71 4f,R9 RA 9854 90 N RR97 3R W 9A54 9f1 4 94 11073.97 86.66 302.66 3677.84 2900.97 N 8977.75 W 2900.97 6.23 11167.36 87.46 306.17 3682.63 2953.68 N 9054.68 W 2953.68 3.85 11260.71 88.60 310.07 3685.84 3011.26 N 9128.06 W 3011.26 4.35 11354.20 89.17 312.85 3687.66 3073.14 N 9198.10 W 3073.14 3.03 60 11447.61 89.19 315.98 3689.00 3138.50 N 9264.81 W 3138.50 3.35 11540.95 89.72 319.75 3689.89 3207.70 N 9327.41 W 3207.70 4.08 11634.33 89.57 321.18 3690.47 3279.72 N 9386.85 W 3279.72 1.54 11727.62 88.92 321.11 3691.70 3352.36 N 9445.37 W 3352.36 0.70 11820.98 89.40 321.61 3693.06 3425.27 N 9503.66 W 3425.27 0.74 11914.41 89.30 321.13 3694.12 3498.25 N 9561.99 W 3498.25 0.52 12007.77 89.05 321.15 3695.47 3570.94 N 9620.56 W 3570.94 0.27 12095.31 87.32 321.38 3698.24 3639.19 N 9675.30 W 3639.19 '--'51 1.99 12152.30 86.54 324.49 3701.29 3684.60 N 9709.60 W 3684.60 5.62 12245.70 86.05 321.72 3707.33 3759.13 N 9765.55 W 3759.13 3.01 12338.98 86.14 322.48 3713.68 3832.56 N 9822.71 W 3832.56 0.82 12432.33 86.47 322.31 3719.70 3906.36 N 9879.56 W 3906.36 0.40 12525.61 86.35 322.90 3725.54 3980.33 N 9936.10 W 3980.33 0.64 12618.91 86.41 322.85 3731.43 4054.57 N 9992.30 W 4054.57 0.08 12712.22 87.53 323.30 3736.36 4129.06 N 10048.28 W 4129.06 1.29 12804.79 88.39 322.92 3739.66 4203.04 N 10103.81 W 4203.04 1.02 12898.85 87.72 323.17 3742.85 4278.17 N 10160.32 W 4278.17 0.76 12992.50 86.21 322.69 3747.81 4352.78 N 10216.69 W 4352.78 1.69 13085.66 87.17 321.85 3753.19 4426.34 N 10273.61 W 4426.34 1.37 13178.98 91.02 320.88 3754.66 4499.21 N 10331.85 W 4499.21 4.25 13300.00 92.10 321.22 3751.37 4593.29 N 10407.90 W 4593.29 0.94 13365.70 90.03 321.09 3750.15 4644.45 N 10449.10 W 4644.45 3.16 13459.24 90.23 320.65 3749.93 4717.01 N 10508.13 W 4717.01 0.52 13552.91 89.45 322.21 3750.20 4790.24 N 10566.53 W 4790.24 1.86 13645.78 89.65 323.72 3750.93 4864.37 N 10622.46 W 4864.37 1.64 13739.12 89.58 325.01 3751.55 4940.23 N 10676.84 W 4940.23 1.38 13832.54 89.63 325.55 3752.20 5017.01 N 10730.05 W 5017.01 0.58 13925.86 90.33 323.73 3752.23 5093.11 N 10784.05 W 5093.11 2.09 14019.13 90.68 323.17 3751.41 5168.04 N 10839.59 W 5168.04 0.71 14112.41 90.49 323.71 3750.45 5242.96 N 10895.15 W 5242.96 0.61 14205.78 90.73 324.30 3749.46 5318.50 N 10950.03 W 5318.50 0.68 14299.23 90.65 324.58 3748.34 5394.51 N 11004.37 W 5394.51 0.31 .`e 14392.54 90.23 324.74 3747.62 5470.63 N 11058.34 W 5470.63 0.48 14485.87 90.32 324.78 3747.17 5546.85 N 11112.19 W 5546.85 0.11 14579.17 90.51 324.32 3746.50 5622.86 N 11166.30 W 5622.86 0.53 14672.55 90.27 324.98 3745.86 5699.02 N 11220.33 W 5699.02 0.75 14765.92 90.23 324.78 3745.45 5775.39 N 11274.04 W 5775.39 0.22 r 14859.31 90.55 325.14 3744.82 5851.85 N 11327.66 W 5851.85 0.52 14925.00 88.78 326.18 3745.20 5906.09 N 11364.71 W 5906.09 3.13 14952.69 88.04 326.62 3745.97 5929.14 N 11380.03 W 5929.14 3.11 15046.14 87.37 325.43 3749.71 6006.57 N 11432.21 W 6006.57 1.46 . ku 15139.54 89.94 325.19 3751.90 6083.34 N 11485.35 W 6083.34 2.76 15232.80 90.66 325.29 3751.42 6159.96 N 11538.52 W 6159.96 0.78 15326.17 90.95 325.94 3750.10 6237.01 N 11591.24 W 6237.01 0.76 15419.45 90.50 326.30 3748.92 6314.44 N 11643.24 W 6314.44 0.62 15512.80 91.27 326.32 3747.48 6392.10 N 11695.01 W 6392.10 0.83 15606.18 91.02 326.31 3745.62 6469.79 N 11746.79 W 6469.79 0.27 As 15699.57 91.93 325.25 3743.21 6546.98 N 11799.30 W 6546.98 1.50 15792.90 91.70 321.94 3740.25 6622.05 N 11854.65 W 6622.05 3.55 15886.26 90.54 315.61 3738.43 6692.22 N 11916.13 W 6692.22 6.89 15979.53 90.21 312.86 3737.82 6757.28 N 11982.95 W 6757.28 2.97 16072.85 90.34 312.69 3737.37 6820.65 N 12051.45 W 6820.65 0.23 16166.18 90.22 313.61 3736.91 6884.48 N 12119.54 W 6884.48 0.99 16259.57 89.95 312.90 3736.77 6948.47 N 12187.56 W 6948.47 0.81 16352.94 90.18 313.25 3736.67 7012.24 N 12255.76 W 7012.24 0.45 16446.36 90.82 312.59 3735.85 7075.85 N 12324.17 W 7075.85 0.98 16539.72 91.19 312.86 3734.22 7139.19 N 12392.74 W 7139.19 0.49 16633.13 91.33 312.316 3732.16 7202.38 N 12461.50 W 7202.38 0.61 16726.48 90.22 311.48 3730.90 7264.71 N 12530.98 W 7264.71 1.48 16819.94 90.57 309.67 3730.26 7325.50 N 12601.96 W 7325.50 1.97 16913.34 89.13 309.14 3730.50 7384.78 N 12674.13 W 7384.78 1.64 17006.71 89.02 309.09 3732.01 7443.68 N 12746.56 W 7443.68 0.13 17100.11 88.88 309.85 3733.72 7503.04 N 12818.65 W 7503.04 0.83 17193.48 89.86 311.09 3734.75 7563.64 N 12889.67 W 7563.64 1.69 17286.82 90.27 311.56 3734.64 7625.27 N 12959.77 W 7625.27 0.67 17380.20 89.68 311.37 3734.68 7687.11 N 13029.75 W 7687.11 0.66 17473.61 89.95 310.51 3734.98 7748.31 N 13100.31 W 7748.31 0.96 17567.03 90.82 310.68 3734.35 7809.10 N 13171.24 W 7809.10 0.95' 17660.47 90.27 311.29 3733.47 7870.38 N 13241.77 W 7870.38 0.88 17753.86 92.41 311.43 3731.28 7932.07 N 13311.85 W 7932.07 2.30 17847.23 92.18 311.54 3727.54 7993.87 N 13381.74 W 7993.87 0.27,..x" g 17990.00 89.10 310.84 3725.95 8087.88 N 13489.15 W 8087.88 2.21 18033.92 88.51 310.96 3726.86 8116.63 N 13522.34 W 8116.63 1.37 18127.29 88.83 311.25 3729.03 8178.00 N 13592.68 W 8178.00 0.46 18220.56 90.09 312.23 3729.91 8240.09 N 13662.27 W 8240.08 1.71 18313.89 89.88 313.18 3729.94 8303.38 N 13730.85 W 8303.38 1.04 18407.33 90.10 313.49 3729.95 8367.51 N 13798.82 W 8367.51 0.41 18500.69 89.76 314.24 3730.07 8432.20 N 13866.13 W 8432.20 0.88 18594.08 89.95 314.70 3730.30 8497.62 N 13932.77 W 8497.62 0.53 18687.50 89.78 317.30 3730.52 8564.82 N 13997.66 W 8564.82 2.79 18780.90 90.69 317.08 3730.14 8633.34 N 14061.13 W 8633.34 1.00 18874.24 88.85 318.63 3730.51 8702.54 N 14123.76 W 8702.54 2.58 18967.71 87.72 314.82 3733.31 8770.55 N 14187.79 W 8770.55 4.25 19061.15 87.68 313.36 3737.06 8835.51 N 14254.85 W 8835.51 1.56 19154.63 87.83 311.65 3740.72 8898.62 N 14323.71 W 8898.62 1.83 19247.95 87.74 310.72 3744.33 8960.02 N 14393.88 W 8960.02 1.00 19341.33 90.27 309.51 3745.95 9020.17 N 14465.28 W 9020.17 3.00 19434.73 91.83 310.41 3744.24 9080.15 N 14536.86 W 9080.15 1.93 19528.14 90.99 307.38 3741.94 9138.77 N 14609.53 W 9138.77 3.37 19621.43 90.69 306.73 3740.57 9194.98 N 14683.97 W 9194.98 0.77 19714.89 90.01 304.61 3740.00 9249.47 N 14759.89 W 9249.47 2.38 19808.26 89.96 302.56 3740.03 9301.12 N 14837.67 W 9301.12 2.20 19901.55 90.41 300.52 3739.73 9349.92 N 14917.17 W 9349.92 2.24 19994.88 90.39 298.65 3739.08 9395.99 N 14998.33 W 9395.99 2.00 20088.25 89.41 297.57 3739.24 9439.98 N 15080.68 W 9439.98 1.56 20181.55 89.46 295.50 3740.16 9481.66 N 15164.14 W 9481.66 2.22 20275.00 87.79 295.73 3742.40 9522.05 N 15248.38 W 9522.05 1.80 20368.35 89.84 298.09 3744.33 9564.28 N 15331.60 W 9564.28 3.35 20461.66 90.96 298.99 3743.68 9608.86 N 15413.56 W 9608.86 1.54 20555.06 89.96 297.92 3742.93 9653.36 N 15495.68 W 9653.36 1.57 20648.40 88.50 293.70 3744.19 9693.99 N 15579.68 W 9693.99 4.78 20741.88 89.61 293.21 3745.73 9731.19 N 15665.42 W 9731.19 1.30 20835.43 90.10 291.16 3745.96 9766.51 N 15752.04 W 9766.51 2.25 20928.74 89.99 292.53 3745.89 9801.23 N 15838.64 W 9801.23 1.47 21022.15 88.64 292.15 3747.01 9836.73 N 15925.04 W 9836.73 1.50 21115.58 88.02 292.49 3749.73 9872.20 N 16011.43 W 9872.20 0.76 21209.04 87.36 292.00 3753.50 9907.55 N 16097.86 W 9907.55 0.88 P 21302.78 86.78 289.50 3758.29 9940.72 N 16185.40 W 9940.72 2.73 21395.79 84.90 283.05 3765.04 9966.70 N 16274.39 W 9966.70 7.21 21489.16 88.04 282.98 3770.79 9987.69 N 16365.18 W 9987.69 3.36 21582.49 88.70 281.57 3773.45 10007.52 N 16456.34 W 10007.52 1.67 21675.86 87.87 279.04 3776.24 10024.22 N 16548.15 W 10024.22 2.85 21769.17 87.24 274.23 3780.22 10034.99 N 16640.72 W 10034.99 5.19 21862.62 89.56 275.71 3782.83 10043.08 N 16733.78 W 10043.08 2.94 21955.96 95.25 275.44 3778.92 10052.14 N 16826.56 W 10052.14 6.10 22049.20 100.35 275.76 3766.27 10061.15 N 16918.46 W 10061.15 5.48 22142.49 104.18 275.12 3746.45 10069.79 N 17009.19 W 10069.79 4.16 22235.86 107.90 274.27 3720.66 10077.14 N 17098.61 W 10077.14 4.08 22329.19 111.39 273.21 3689.29 10082.88 N 17186.31 W 10082.88 3.89 22422.66 114.40 272.53 3652.93 10087.20 N 17272.29 W 10087.20 3.29 22516.16 118.19 270.95 3611.51 10089.76 N 17356.06 W 10089.76 4.33 Ilk 22609.44 120.06 271.25 3566.11 10091.32 N 17437.53 W 10091.32 2.02 22702.79 120.22 271.18 3519.24 10093.03 N 17518.24 W 10093.03 0.18 22796.28 120.33 270.15 3472.11 10093.97 N 17598.97 W 10093.97 0.96 22858.11 120.36 271.34 3440.87 10094.67 N 17652.32 W 10094.67 1.66 22923.00 120.38 271.15 3408.06 10095.88 N 17708.30 W 10095.88 0.25 CALCULATION BASED ON MINI MUM C. VATURE METHOD SURVEY COORDINATES RELATIVE TO NELL SYSTEM REFERENCE POINT TVD VAL LES GIVEN RELATI VE TO DRILLING MEASUREMENTPOINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES(TRUE) A TOTAL CORRECTION OF 20.11 DEG FROM MAGNETIC NORTH 10 TRUE NORTH HAS PFFN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE 10 11-E HELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE)AT22923.00 FEET IS 20384.08 FEETALONG 299.69 DEGREES(TRUE) Date Printed:15 March 2013 f HALLIBURTON DIRECTIONAL SURVEY REPORT Eni Petroleum SP22-FN1 PB1 Nikaitchuq USA AK-XX-0900169420 All depths reference the driller's pipe tally. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100f) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 11 E-I N 40.72 0.00 0.00 40.72 0.00 N 0.00 E 0.00 0.00 121.11 0.10 26.85 121.11 0.06 N 0.03 E 0.06 0.12 169.53 0.17 2.04 169.53 0.17 N 0.05 E 0.17 0.19 201.76 0.47 350.08 201.76 0.35 N 0.03 E 0.35 0.95 233.88 0.78 345.12 233.88 0.69 N 0.05 W 0.69 0.98 262.89 0.76 331.42 262.88 1.05 N 0.19 W 1.05 0.64 297.41 1.18 307.81 297.40 1.47 N 0.58 W 1.47 1.66 327.80 2.17 300.54 327.78 1.95 N 1.32 W 1.95 3.33 356.18 3.25 300.24 356.12 2.63 N 2.48 W 2.63 3.81 387.05 4.70 298.78 386.92 3.68 N 4.34 W 3.68 4.71 418.15 5.95 301.28 417.88 5.13 N 6.84 W 5.13 4.09 449.02 7.18 299.08 448.55 6.90 N 9.89 W 6.90 4.07 479.82 8.05 300.30 479.08 8.92 N 13.44 W 8.92 2.87 510.89 8.50 300.16 509.83 11.18 N 17.30 W 11.18 1.45 Mil, 541.60 8.90 299.86 540.18 13.50 N 21.32 W 13.50 1.31 572.59 9.07 297.76 570.79 15.83 N 25.56 W 15.83 1.19 i 603.94 9.94 297.25 601.71 18.22 N 30.16 W 18.22 2.79 Ow634.35 11.46 295.62 631.59 20.73 N 35.21 W 20.73 5.10 665.42 13.56 294.52 661.92 23.57 N 41.31 W 23.57 6.80 691.88 14.88 293.47 687.57 26.22 N 47.25 W 26.22 5.08 723.07 16.19 295.25 717.62 29.67 N 54.86 W 29.67 4.47 785.29 19.86 298.41 776.78 38.40 N 72.00 W 38.40 6.10 847.59 22.75 300.07 834.82 49.47 N 91.74 W 49.47 4.74 910.77 25.98 301.49 892.36 62.82 N 114.12 W 62.82 5.20 971.77 27.67 302.55 946.80 77.42 N 137.45 W 77.42 2.88 1034.54 28.43 302.07 1002.19 93.20 N 162.40 W 93.20 1.26 1096.73 30.76 300.91 1056.27 109.23 N 188.59 W 109.23 3.86 1158.97 34.05 301.31 1108.81 126.47 N 217.14 W 126.47 5.30 1251.87 34.43 301.18 1185.61 153.58 N 261.83 W 153.58 0.42 1345.71 38.48 299.66 1261.07 181.77 N 309.92 W 181.77 4.42 1439.04 42.00 300.33 1332.30 211.92 N 362.12 W 211.92 3.80 1532.41 40.71 300.35 1402.39 243.08 N 415.36 W 243.08 1.38 1625.72 39.92 300.07 1473.53 273.46 N 467.53 W 273.46 0.87 1719.17 43.19 299.34 1543.46 304.16 N 521.38 W 304.16 3.54 1812.51 43.40 300.21 1611.39 335.95 N 576.93 W 335.95 0.68 1905.75 43.56 300.26 1679.05 368.25 N 632.36 W 368.25 0.18 1999,04 45.45 301.31 1745.58 401.73 N 688.53 W 401.73 2.17 2092.41 44.70 301.66 1811.52 436.26 N 744.91 W 436.26 0.85 2185.74 46.40 302.14 1876.87 471.46 N 801.47 W 471.46 1.86 2279.21 45.80 302.64 1941.68 507.54 N 858.34 W 507.54 0.75 • 2372.60 45.49 302.91 2006.97 543.69 N 914.48 W 543.69 0.39 2465.99 45.00 303.48 2072.73 580.00 N 969.98 W 580.00 0.68 2559.34 45.11 304.24 2138.67 616.81 N 1024.85 W 616.81 0.59 2652.43 50.97 303.16 2200.89 655.17 N 1082.43 W 655.17 6.35 2746.24 54.02 301.43 2258.00 694.91 N 1145,33 W 694.91 3.57 2839.58 57.94 298.85 2310.22 733.71 N 1212.24 W 733.71 4.78 2932.96 59.38 297.28 2358.78 771.22 N 1282.61 W 771.22 2.11 3014.86 59.79 294.43 2400.25 802.01 N 1346.16 W 802.01 3.04 3190.41 62.47 289.45 2485.05 859.34 N 1488.72 W 859.34 2.92 3283.78 63.97 288.36 2527.12 886.34 N 1567.57 W 886.34 1.91 3377.17 65.14 286.31 2567.24 911.46 N 1648.07 W 911.46 2.34 3470.55 67.14 285.11 2605.01 934.57 N 1730.27 W 934.57 2.44 3563.95 69.08 284.89 2639.84 957.00 N 1813.98 W 957.00 2.09 3657.35 71.49 282.81 2671.34 978.03 N 1899.34 W 978.03 3.32 3750.66 73.20 282.35 2699.64 997.40 N 1986.12 W 997.40 1.89 ZRdd RZ 75 An 9R9 1R 7794 01 1MR 40 Pi 907Z OR W 1MR 40 9 ZR 4UOU.00 OZ. O LOU.00 L/OU.04 1U04.L4 IN LL03.U0 VV ILI3I.L4 4.10 4124.04 85.65 281.36 2770.24 1072.14 N 2344.19 W 1072.14 _`.., 3.36 4217.43 85.30 282.17 2777.61 1091.12 N 2435.34 W 1091.12 0.94 4310.76 84.91 282.87 2785.57 1111.28 N 2526.11 W 1111.28 0.86 4404.12 84.08 283.63 2794.53 1132.57 N 2616.57 W 1132.57 1.20 4497.39 83.37 282.98 2804.73 1153.91 N 2706.79 W 1153.91 1.03 4590.71 83.67 282.73 2815.26 1174.54 N 2797.19 W 1174.54 0.42 pp 4684.04 83.64 282.27 2825.57 1194.62 N 2887.75 W 1194.62 0.49 4777.43 83.48 283.65 2836.05 1215.43 N 2978.18 W 1215.43 1.48 4871.10 83.54 283.75 2846.63 1237.47 N 3068.61 W 1237.47 0.12 4964.22 83.61 283.15 2857.05 1258.99 N 3158.60 W 1258.99 0.64 5057.58 83.45 283.19 2867.58 1280.13 N 3248.93 W 1280.13 0.18 5150.99 83.61 283.44 2878.10 1301.51 N 3339.25 W 1301.51 0.32 5244.34 83.44 285.09 2888.63 1324.36 N 3429.14 W 1324.36 1.77 5337.80 82.93 285.50 2899.72 1348.84 N 3518.65 W 1348.84 0.70 5431.20 82.60 285.73 2911.48 1373.78 N 3607.89 W 1373.78 0.43 5524.57 82.21 285.71 2923.82 1398.85 N 3696.98 W 1398.85 0.42 5617.97 81.97 285.29 2936.68 1423.58 N 3786.12 W 1423.58 0.51 5711.34 82.17 284.77 2949.56 1447.56 N 3875.44 W 1447.56 0.59 5804.68 82.22 285.59 2962.23 1471.77 N 3964.68 W 1471.77 0.87 5898.06 82.16 286.42 2974.92 1497.28 N 4053.61 W 1497.28 0.88 lak 5991.47 82.04 287.16 2987.76 1524.01 N 4142.19 W 1524.01 0.80 -_. 6084.89 82.29 287.62 3000.50 1551.67 N 4230.51 W 1551.67 0.56 6178.33 82.35 287.84 3012.98 1579.87 N 4318.71 W 1579.87 0.24 6271.72 81.95 287.66 3025.74 1608.07 N 4406.82 W 1608.07 0.47 6365.09 82.06 287.59 3038.73 1636.07 N 4494.94 W 1636.07 0.14 6458.44 81.86 288.16 3051.78 1664.44 N 4582.91 W 1664.44 0.64 6551.78 82.28 287.86 3064.66 1693.02 N 4670.83 W 1693.02 0.55 °:. 6645.15 81.78 288.47 3077.61 1721.85 N 4758.69 W 1721.85 0.84 6734.90 81.59 287.09 3090.59 1748.97 N 4843.25 W 1748.97 1.54 6831.75 82.34 286.34 3104.12 1776.55 N 4935.10 W 1776.55 1.09 1 6925.19 81.97 285.72 3116.88 1802.11 N 5024.06 W 1802.11 0.77 7018.43 82.21 285.16 3129.71 1826.69 N 5113.08 W 1826.69 0.65 7112.75 81.89 284.15 3142.76 1850.33 N 5203.46 W 1850.33 1.11 7205.36 82.08 282.46 3155.67 1871.43 N 5292.70 W 1871.43 1.82 7298.76 82.07 282.71 3168.55 1891.59 N 5382.98 W 1891.59 0.27 7392.10 81.33 282.54 3182.02 1911.78 N 5473.11 W 1911.78 0.81 r 7485.57 82.23 282.81 3195.38 1932.07 N 5563.37 W 1932.07 1.00 7579.01 82.19 283.04 3208.05 1952.78 N 5653.60 W 1952.78 0.25 7672.49 82.19 282.96 3220.75 1973.61 N 5743.84 W 1973.61 0.08 7765.81 82.25 283.94 3233.39 1995.12 N 5833.76 W 1995.12 1.04 7859.19 82.15 284.06 3246.06 2017.50 N 5923.53 W 2017.50 0.17 7952.59 82.57 283.84 3258.48 2039.82 N 6013.37 W 2039.82 0.51 8046.00 81.78 284.59 3271.19 2062.54 N 6103.07 W 2062.54 1.16 8139.29 82.17 284.98 3284.22 2086.12 N 6192.39 W 2086.12 0.59 8232.75 82.25 285.16 3296.89 2110.19 N 6281.80 W 2110.19 0.21 8326.12 82.19 284.78 3309.53 2134.09 N 6371.18 W 2134.09 0.41 8419.41 81.40 284.94 3322.84 2157.77 N 6460.42 W 2157.77 0.86 8512.74 81.88 285.45 3336.41 2181.97 N 6549.53 W 2181.97 0.75 8606.11 82.39 285.82 3349.19 2206.90 N 6638.60 W 2206.90 0.67 8699.41 82.18 285.74 3361.71 2232.04 N 6727.57 W 2232.04 0.24 8792.86 82.37 286.59 3374.27 2257.82 N 6816.51 W 2257.82 0.92 - " 8886.21 82.56 287.27 3386.51 2284.77 N 6905.04 W 2284.77 0.75 8979.52 82.11 287.04 3398.96 2312.05 N 6993.41 W 2312.05 0.54 9072.92 82.32 285.65 3411.61 2338.09 N 7082.20 W 2338.09 1.49 9166.26 82.28 285.01 3424.12 2362.54 N 7171.41 W 2362.54 0.68 9259.74 82.10 283.96 3436.82 2385.71 N 7261.08 W 2385.71 1.13 9352.29 82.03 284.33 3449.60 2408.11 N 7349.96 W 2408.11 0.40 '=--s 9445.60 81.71 284.10 3462.79 2430.79 N 7439.50 W 2430.79 0.42 9539.01 82.18 283.77 3475.88 2453.06 N 7529.27 W 2453.06 0.61 9632.44 82.16 284.32 3488.61 2475.52 N 7619.06 W 2475.52 0.58 9726.16 82.35 284.01 3501.24 2498.25 N 7709.10 W 2498.25 0.39 9819.66 82.30 282.78 3513.73 2519.72 N 7799.24 W 2519.72 1.30 9860.34 82.29 282.39 3519.18 2528.50 N 7838.59 W 2528.50 0.95 9953.71 82.18 283.25 3531.80 2549.03 N 7928.79 W 2549.03 0.92 10047.08 82.12 283.70 3544.55 2570.58 N 8018.74 W 2570.58 0.48 10140.41 82.36 284.78 3557.15 2593.33 N 8108.38 W 2593.33 1.18 10233.78 82.60 284.86 3569.37 2617.00 N 8197.86 W 2617.00 0.27 10327.09 82.35 285.60 3581.59 2641.30 N 8287.12 W 2641.30 0.83 10420.54 82.36 285.85 3594.02 2666.41 N 8376.27 W 2666.41 0.27 10513.88 82.29 287.04 3606.49 2692.59 N 8464.99 W 2692.59 1.27 10607.12 82.35 287.10 3618.95 2719.72 N 8553.32 W 2719.72 0.09 10700.41 81.67 288.27 3631.92 2747.78 N 8641.34 W 2747.78 1.44 10793.78 81.77 290.76 3645.37 2778.64 N 8728.42 W 2778.64 2.64 11073.97 86.66 302.66 3677.84 2900.97 N 8977.75 W 2900.97 6.23 11167.36 87.46 306.17 3682.63 2953.68 N 9054.68 W 2953.68 3.85 11260.71 88.60 310.07 3685.84 3011.26 N 9128.06 W 3011.26 4.35 11354.20 89.17 312.85 3687.66 3073.14 N 9198.10 W 3073.14 3.03 11447.61 89.19 315.98 3689.00 3138.50 N 9264.81 W 3138.50 3.35 11540.95 89.72 319.75 3689.89 3207.70 N 9327.41 W 3207.70 4.08 11634.33 89.57 321.18 3690.47 3279.72 N 9386.85 W 3279.72 1.54 11727.62 88.92 321.11 3691.70 3352.36 N 9445.37 W 3352.36 0.70 11820.98 89.40 321.61 3693.06 3425.27 N 9503.66 W 3425.27 0.74 11914.41 89.30 321.13 3694.12 3498.25 N 9561.99 W 3498.25 0.52 12007.77 89.05 321.15 3695.47 3570.94 N 9620.56 W 3570.94 0.27 L 12095.31 87.32 321.38 3698.24 3639.19 N 9675.30 W 3639.19 1.99 12152.30 86.54 324.49 3701.29 3684.60 N 9709.60 W 3684.60 5.62 12245.70 86.05 321.72 3707.33 3759.13 N 9765.55 W 3759,13 3.01 12338 98 86.14 322.48 3713.68 3832.56 N 9822.71 W 3832.56 0.82 12432 33„_ 86.47 322.31 3719.70 3906.36 N 9879.56 W 3906.36 0.40 12525.61 86.35 322.90 3725.54 3980.33 N 9936.10 W 3980.33 0.64 12618.91 86.41 322.85 3731.43 4054.57 N 9992.30 W 4054.57 0.08 12712.22 87.53 323.30 3736.36 4129.06 N 10048.28 W 4129.06 1.29 12804.79 88.39 322.92 3739.66 4203.04 N 10103.81 W 4203.04 1.02 12898.85 87.72 323.17 3742.85 4278.17 N 10160.32 W 4278.17 0.76 12992.50 " 86.21 322.69 3747.81 4352.78 N 10216.69 W 4352.78 . • 13085.66 87.17 321.85 3753.19 4426.34 N 10273.61 W 4426.34 1.37 13178.98 91.02 320.88 3754.66 4499.21 N 10331.85 W 4499.21 4.25 13272.40 92.97 321.27 3751.41 4571.84 N 10390.51 W 4571.84 2.13 13366.29 92.93 320.16 3746.58 4644.41 N 10449.88 W 4644.41 1.18 13459.06 92.76 318.64 3741.97 4714.76 N 10510.18 W 4714.76 1.65 13552.42 92.27 319.38 3737.88 4785.16 N 10571.35 W 4785.16 0.95 13645.78 91.75 320.62 3734.60 4856.64 N 10631.33 W 4856.64 1.44 13739.12 90.23 322.18 3732.99 4929.57 N 10689.55 W 4929.57 2.33 13832.54 90.39 325.69 3732.48 5005.07 N 10744.53 W 5005.07 3.76 13925.86 88.68 326.24 3733.24 5082.40 N 10796.76 W 5082.40 1.92 14019.13 90.15 326.41 3734.19 5160.01 N 10848.47 W 5160.01 1.59 14112.41 91.42 328.33 3732.92 5238.56 N 10898.76 W 5238.56 2.47 14205.78 91.03 327.08 3730.92 5317.46 N 10948.64 W 5317.46 1.40 14299.23 89.71 325.77 3730.32 5395.32 N 11000.31 W 5395.32 1.99 14392.54 90.13 323.43 3730.45 5471.37 N 11054.36 W 5471.37 2.55 14484.26 91.58 321.39 3729.08 5544.04 N 11110.30 W 5544.04 2.73 14550.00 91.58 321.39 3727.26 5595.39 N 11151.31 W 5595.39 0.00 CALCULAII ON BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINA1ES RELATIVE 10 WELL SYS1EM REFERENCE POINT 1VD VALUES GIVEN RELATIVE TO DRI W NG MEASUREMENT POINT VERTICAL SECTION RELATIVE 10 WELL 1-EAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES(TRUE) A TOTAL CORREC I ON OF 20.11 DEG FROM MAGNETIC NORTH 10 1R.E NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE 10 11-E WELL I-EAD. HORIZONTAL DISPLACEMENT(CLOSURE)AT 14550.00 FEET IS 12476.38 FEETALONG 296.65 DEGREES(1RUE) Date Printed:15 March 2013 P ) HALLIBURTON DIRECTIONAL SURVEY REPORT Eni Petroleum SP22-FN1 PB2 Nikaitchuq USA AK-XX-0900169420 All depths reference the driller's pipe tally. , , ., , ` Vertical Vertical e .,!„ ,,.k clination Direction Depth Latitude Departure Section Dogleg •grees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 Tl E-I N 40.72 0.00 0.00 40.72 0.00 N 0.00 E 0.00 0.00 121.11 0.10 26.85 121.11 0.06 N 0.03E 0.06 0.12 169.53 0.17 2.04 169.53 0.17 N 0.05E 0.17 0.19 201.76 0.47 350.08 201.76 0.35 N 0.03 E 0.35 0.95 233.88 0.78 345.12 233.88 0.69 N 0.05 W 0.69 0.98',,-%M 262.89 0.76 331.42 262.88 1.05 N 0.19 W 1.05 0.64 297.41 1.18 307.81 297.40 1.47 N 0.58 W 1.47 1.66 327.80 2.17 300.54 327.78 1.95 N 1.32 W 1.95 3.33 356.18 3.25 300.24 356.12 2.63 N 2.48 W 2.63 3.81 387.05 4.70 298.78 386.92 3.68 N 4.34 W 3.68 4.71 418.15 5.95 301.28 417.88 5.13 N 6.84 W 5.13 4.09 449.02 7.18 299.08 448.55 6.90 N 9.89 W 6.90 4.07 479.82 8.05 300.30 479.08 8.92 N 13.44 W 8.92 2.87 510.89 8.50 300.16 509.83 11.18 N 17.30 W 11.18 1.45 541.60 8.90 299.86 540.18 13.50 N 21.32 W 13.50 1.31 572.59 9.07 297.76 570.79 15.83 N 25.56 W 15.83 1.19 603.94 9.94 297.25 601.71 18.22 N 30.16 W 18.22 2.79 634.35 11.46 295.62 631.59 20.73 N 35.21 W 20.73 5.10 665.42 13.56 294.52 661.92 23.57 N 41.31 W 23.57 6.80 691.88 14.88 293.47 687.57 26.22 N 47.25 W 26.22 5.08 723.07 16.19 295.25 717.62 29.67 N 54.86 W 29.67 4.47 785.29 19.86 298.41 776.78 38.40 N 72.00 W 38.40 6.10 847.59 22.75 300.07 834.82 49.47 N 91.74 W 49.47 4.74 910.77 25.98 301.49 892.36 62.82 N 114.12 W 62.82 5.20 971.77 27.67 302.55 946.80 77.42 N 137.45 W 77.42 2.88 1034.54 28.43 302.07 1002.19 93.20 N 162.40 W 93.20 1.26 1096.73 30.76 300.91 1056.27 109.23 N 188.59 W 109.23 3.86 1158.97 34.05 301.31 1108.81 126.47 N 217.14 W 126.47 5.30 1251.87 34.43 301.18 1185.61 153.58 N 261.83 W 153.58 0.42 1345.71 38.48 299.66 1261.07 181.77 N 309.92 W 181.77 4.42 1439.04 42.00 300.33 1332.30 211.92 N 362.12 W 211.92 3.80 1532.41 40.71 300.35 1402.39 243.08 N 415.36 W 243.08 1.38 1625.72 39.92 300.07 1473.53 273.46 N 467.53 W 273.46 0.87 1719.17 43.19 299.34 1543.46 304.16 N 521.38 W 304.16 3.54 1812.51 43.40 300.21 1611.39 335.95 N 576.93 W 335.95 0.68 1905.75 43.56 300.26 1679.05 368.25 N 632.36 W 368.25 0.18 1999.04 45.45 301.31 1745.58 401.73 N 688.53 W 401.73 2.17 2092.41 44.70 301.66 1811.52 436.26 N 744.91 W 436.26 0.85 2185.74 46.40 302.14 1876.87 471.46 N 801.47 W 471.46 1.86 2279.21 45.80 302.64 1941.68 507.54 N 858.34 W 507.54 0.75 2372.60 45.49 302.91 2006.97 543.69 N 914.48 W 543.69 0.39 2465.99 45.00 303.48 2072.73 580.00 N 969.98 W 580.00 0.68 2559.34 45.11 304.24 2138.67 616.81 N 1024.85 W 616.81 0.59 2652.43 50.97 303.16 2200.89 655.17 N 1082.43 W 655.17 6.35 2746.24 54.02 301.43 2258.00 694.91 N 1145.33 W 694.91 3.57 2839.58 57.94 298.85 2310.22 733.71 N 1212.24 W 733.71 4.78 2932.96 59.38 297.28 2358.78 771.22 N 1282.61 W 771.22 2.11 3014.86 59.79 294.43 2400.25 802.01 N 1346.16 W 802.01 3.04 3190.41 62.47 289.45 2485.05 859.34 N 1488.72 W 859.34 2.92 3283.78 63.97 288.36 2527.12 886.34 N 1567.57 W 886.34 1.91 3377.17 65.14 286.31 2567.24 911.46 N 1648.07 W 911.46 2.34 3470.55 67.14 285.11 2605.01 934.57 N 1730.27 W 934.57 2.44 3563.95 69.08 284.89 2639.84 957.00 N 1813.98 W 957.00 2.09 3657.35 71.49 282.81 2671.34 978.03 N 1899.34 W 978.03 3.32 3750.66 73.20 282.35 2699.64 997.40 N 1986.12 W 997.40 1.89 'ARAM m 7R An 9119 10 977d 01 1010 AO Al 1071 OR W 1MR AO 9 00 4U3U.00 t *L/0U.04 IU04.L4 1 .``'°''-�-LL03.U0 VV I U04.L'+ 4.10 4124.04 .-`; kM ,, c .; .., 2770.24 1072.14 N " '2344.19 W 1072.14 .36 4217.43 85.30 282.17 2777.61 1091.12 N 2435.34 W 1091.12 0.94 4310.76 84.91 282.87 2785.57 1111.28 N 2526.11 W 1111.28 0.86 4404.12 84.08 283.63 2794.53 1132.57 N 2616.57 W 1132.57 1.20 4497.39 83.37 282.98 2804.73 1153.91 N 2706.79 W 1153.91 1.03 4590.71 83.67 282.73 2815.26 1174.54 N 2797.19 W 1174.54 0.42 'W„' 4684.04 83.64 282.27 2825.57 1194.62 N 2887.75 W r 1194.62 , ;0.49 ?i 4777.43 83.48 283.65 2836.05 1215.43 N 2978.18 W 1215.43- • x.48 4871.10 83.54 283.75-f 2846.63 1237.47 N 3068.61 W 1237.47 0'12 4964.22 83.61 283 15 2857.05 1258.99 N 3158.60 W 1258.99 ' ' . 0.64 5057.58 83.45 283.19 -2867.58 1280.13 N 3248.93 W %-- 1280.13, 0.18 5150.99 83.61 283.44 2878.10 1301.51 N 3339.25 W 1301.51 0.32 5244.34 83.44 285.09 2888.63 1324.36 N 3429.14 W 1324.36 1.77 5337.80 82.93 285.50 2899.72 1348.84 N 3518.65 W 1348.84 0.70 5431.20 82.60 285.73 2911.48 1373.78 N 3607.89 W 1373.78 0.43 5524.57 82.21 285.71 2923.82 1398.85 N 3696.98 W 1398.85 0.42 5617.97 81.97 285.29 ` "' '2936.68 1423.58 N 3786.12 W 1423.58 0.51 5711.34 82.17 284.77 2949.56 1447.56 N 3875.44 W 1447.56 0.59 5804.68 82.22 285.59 2962.23 1471.77 N 3964.68 W 1471.77 0.87 5898.06 82.16 286.42 2974.92 1497.28 N 4053.61 W 1497.28 0.88 ',• 5991.47 82.04 287.16 2987.76 1524.01 N 4142.19 W 1524.01 0.80 6084.89 82.29 287.62 3000.50 1551.67 N 4230.51 W 1551.67 0.56 6178.33 82.35 287.84 3012.98 1579.87 N 4318.71 W 1579.87 0.24 : 6271.72 81.95 287.66 3025.74 1608.07 N 4406.82 W 1608.07 0.47 ; 6365.09 82.06 287.59 3038.73 1636.07 N 4494.94 W 1636.07 0.14 6458.44 81.86 288.16 3051.78 1664.44 N 4582.91 W 1664.44 0.64 6551.78 82.28 287.86 3064.66 1693.02 N 4670.83 W 1693.02 --° '•0.55 6645.15 81.78 288.47 r ` .=3077.61 1721.85 N 4758.69 W 1721.85 ,: 0.84 6734.90 81.59 287.09 3090.59 1748.97 N 4843.25 W 1748.97 1.54 6831.75 82.34 286 34 .=y 3104.12 1776.55 N 4935.10 W 1776.55 1# 09 „ 6925.19 81.97 285.72 3116.88 1802.11 N 5024.06 W 1802.11 ■77; 7018.43 82.21 285.16 3129.71 1826.69 N 5113.08 W 1826.69 0.65 7112.75 81.89 284.15 3142.76 1850.33 N 5203.46 W 1850.33 1.11 7205.36 82.08 282.46 3155.67 1871.43 N 5292.70 W 1871.43 1.82 7298.76 82.07 282.71 3168.55 1891.59 N 5382.98 W 1891.59 0.27 7392.10 81.33 282.54 3182.02 1911.78 N 5473.11 W 1911.78 0.81 7485.57 ,-.'82.23 282.81 3195.38 1932.07 N 5563.37 W 1932.07 1.00 7579.01 ''82.19 283.04 3208.05 1952.78 N 5653.60 W 1952.78 0.25 7672.49 :. _. 82.19 282.96 3220.75 1973.61 N 5743.84 W 1973.61 0.08 7765.81 ''" r'82.25 283.94 3233.39 1995.12 N 5833.76 W 1995.12 1.04 , 7859.19 `=',82.15 284.06 3246.06 2017.50 N 5923.53 W 2017.5Q 0.17 7952.59 82.57 283.84 3258.48 2039.82 N 6013.37 W 2039.82 0.51 8046.00 81.78 284.59 3271.19 2062.54 N 6103.07 W 2062.54 1.16 8139.29 82.17 284.98 3284.22 2086.12 N 6192.39 W 2086.12 0.59 8232.75 82.25 285.16 3296.89 2110.19 N 6281.80 W 2110.19 0.21 8326.12 82.19 284.78 3309.53 2134.09 N 6371.18 W 2134.09 0.41 li ' 8419.41 81.40 284.94 3322.84 2157.77 N 6460.42 W 2157.77 0.86 8512.74 81.88 285.45 3336.41 2181.97 N 6549.53 W 2181.97 0.75 8606.11 82.39 285.82 3349.19 2206.90 N 6638.60 W 2206.90 0.67.; 1; 8699.41 82.18 285.74 3361.71 2232.04 N 6727.57 W 2232.04 0.24'-, m.,i y ,82.37 286.59 3374.27 2257.82 N 6816.51 W 2257.82 0.92.E 8886.21 82.56 287.27 3386.51 2284.77 N 6905.04 W 2284.77 0.75 8979.52 82.11 287.04 3398.96 2312.05 N 6993.41 W 2312.05 0.54 9072.92 82.32 285.65 3411.61 2338.09 N 7082.20 W 2338.09 1.49 9166.26 82.28 285.01 3424.12 2362.54 N 7171.41 W 2362.54 0.68 • 9259.74 82.10 283.96 3436.82 2385.71 N 7261.08 W 2385.71 1.13 352.29 "'° '82.03 284.33 3449.60 2408.11 N 7349.96 W 2408.11 0.40 81.71 284.10 3462.79 2430.79 N 7439.50 W 2430.79 0.42 '.01 82.18 283.77 3475.88 2453.06 N 7529.27 W 2453.06 -°0.61 *; , 963244 82.16 284.32 8 61 2475.52 N 7619.06 W 2475.52 0.58:' 97A„,16 ! , 82.35 284.01 124 ,e 498.25 N 7709.10 W 2498.25 0,39' 9819.66 82.30 282.78 3513.73 2519.72 N 7799.24 W 2519.72 1.30 9860.34 82.29 282.39 3519.18 2528.50 N 7838.59 W 2528.50 0.95 9953.71 82.18 283.25 3531.80 2549.03 N 7928.79 W 2549.03 0.92 10047.08 82.12 283.70 3544.55 2570.58 N 8018.74 W 2570.58 0.48 10140.41 82.36 284.78 3557.15 2593.33 N 8108.38 W 2593.33 1.18 • 10233.78 82.60 284.86 3569,37 2617.00 N 8197.86 W 2617.00 0.27' : 10327.09 82.35 285.60 3581.59 2641.30 N 8287.12 W 2641.30 0.83:' i' 10420.54 82.36 285.85 3594.02 2666.41 N 8376.27 W 2666.41 0.27 .; 10513.88 82.29 287.04 3606.49 2692.59 N 8464.99 W 2692.59 1.27:„" 10607.12 82.35 287.10 3618.95 2719.72 N 8553.32 W 2719.72 0.09=', 10700.41 81.67 288.27 3631.92 2747.78 N 8641.34 W 2747.78 1.44 10793.78 81.77 290.76 3645.37 2778.64 N 8728.42 W 2778.64 2.64 11(373.97 86.66 302.66 3677.84 2900.97 N 8977.75 W 2900.97 6.23 11167.36 87.46 306.17 3682.63 2953.68 N 9054.68 W 2953.68 3.85 11260.71 88.60 310.07 3685.84 3011.26 N 9128.06 W 3011.26 4.35 11354.20 89.17 312.85 3687.66 3073.14 N 9198.10 W 3073.14 3.03 11447.61 89.19 315.98 3689.00 3138.50 N 9264.81 W 3138.50 3.35 11540.95 89.72 319.75 3689.89 3207.70 N 9327.41 W 3207.70 4.08 11634.33 89.57 321.18 3690.47 3279.72 N 9386.85 W 3279.72 1.54 11727.62 88.92 321.11 3691.70 3352.36 N 9445.37 W 3352.36 0.70 11820.98 89.40 321.61 3693.06 3425.27 N 9503.66 W 3425.27 0.74 11914.41 89.30 321.13 3694.12 3498.25 N 9561.99 W 3498.25 0.52 12007.77 89.05 321.15 3695.47 3570.94 N 9620.56 W 3570.94 0.27 12095.31 87.32 321.38 3698.24 3639.19 N 9675.30 W 3639.19 1.99 12152.30 86.54 324.49 3701.29 3684.60 N 9709.60 W 3684.60 5.62 12245.70 86.05 321.72 3707.33 3759.13 N 9765.55 W 3759.13 3.01 12338.98 86.14 322.48 3713.68 3832.56 N 9822.71 W 3832.56 0.82 12432.33 86.47 322.31 3719.70 3906.36 N 9879.56 W 3906.36 0.40 12525.61 86.35 322.90 3725.54 3980.33 N 9936.10 W 3980.33 0.64 12618.91 86.41 322.85 3731.43 4054.57 N 9992.30 W 4054.57 0.08 12712.22 87.53 323.30 3736.36 4129.06 N 10048.28 W 4129.06 1.29 12804.79 88.39 322.92 3739.66 4203.04 N 10103.81 W 4203.04 1.02 12898.85 87.72 323.17 3742.85 4278.17 N 10160.32 W 4278.17 0.76 12992.50 86.21 322.69 3747.81 4352.78 N 10216.69 W 4352.78 1.69 13085.66 87.17 321.85 3753.19 4426.34 N 10273.61 W 4426.34 1.37 13178.98 91.02 320.88 3754.66 4499.21 N 10331.85 W 4499.21 4.25 13365.70 90.03 321.09 3752.95 4644.28 N 10449.39 W 4644.28 0.54 13459.24 90.23 320.65 3752.74 4716.84 N 10508.42 W 4716.84 0.52 13552.91 89.45 322.21 3753.00 4790.07 N 10566.82 W 4790.07 1.86 13645.78 89.65 323.72 3753.73 4864.20 N 10622.75 W 4864.20 1.64 13739.12 89.58 325.01 3754.36 4940.06 N 10677.13 W 4940.06 1.38 13832.54 89.63 325.55 3755.00 5016.84 N 10730.34 W 5016.84 0.58 13925.86 90.33 323.73 3755.03 5092.95 N 10784.34 W 5092.95 2.09 14019.13 90.68 323.17 3754.21 5167.87 N 10839.88 W 5167.87 0.71 14112.41 90.49 323.71 3753.26 5242.79 N 10895.44 W 5242.79 0.61 14205.78 90.73 324.30 3752.27 5318.33 N 10950.32 W 5318.33 0.68 14299.23 90.65 324.58 3751.14 5394.35 N 11004.66 W 5394.35 0.31 14392.54 90.23 324.74 3750.42 5470.46 N 11058.63 W 5470.46 0.48 14485.87 90.32 324.78 3749.98 5546.69 N 11112.48 W 5546.69 0.11 14579.17 90.51 324.32 3749.30 5622.69 N 11166.59 W 5622.69 0.53 14672.55 90.27 324.98 3748.66 5698.85 N 11220.62 W 5698.85 0.75 14765.92 90.23 324.78 3748.26 5775.22 N 11274.33 W 5775.22 0.22 14859.31 90.55 325,14 3747.62 5851.68 N 11327.95 W 5851.68 0.52 14952.69 89.84 324.84 3747.30 5928.16 N 11381.52 W 5928.16 0.83 15046.09 90.52 324.93 3747.01 6004.56 N 11435.25 W 6004.56 0.73 15139.49 91.36 324.99 3745.48 6081.02 N 11488.87 W 6081.02 0.90 15232.80 91.77 322.78 3742.93 6156.37 N 11543.84 W 6156.37 2.41 15326.17 91.42 321.05 3740.33 6229.83 N 11601.41 W 6229.83 1.89 15419.45 89.41 319.20 3739.65 6301.41 N 11661.21 W 6301.41 2.93 15512.80 89.08 316.65 3740.88 6370.69 N 11723.75 W 6370.69 2.75 15606.81 91.94 318.14 3740.05 6439.87 N 11787.38 W 6439.87 3.43 15699.57 90.23 317.13 3738.29 6508.39 N 11849.87 W 6508.39 2.14 15792.91 90.66 317.39 3737.57 6576.94 N 11913.21 W 6576.94 0.54 15886.26 91.48 316.63 3735.82 6645.21 N 11976.86 W 6645.21 1.20 15979.53 91.83 316.30 3733.13 6712.80 N 12041.07 W 6712.80 0.52 16072.85 91.29 312.62 3730.59 6778.13 N 12107.64 W 6778.13 3.98 16166.20 92.50 313.05 3727.50 6841.56 N 12176.06 W 6841.56 1.38 16259.57 89.69 313.46 3725.72 6905.52 N 12244.04 W 6905.52 3.04 16293.11 90.27 314.28 3725.73 6928.76 N 12268.22 W 6928.76 2.99 CALCUA110N BASED ON MIN MUM CURVATURE METHOD SURVEY COORDINATES RELATIVE 10 WELL SYS1EM REFERENCE POINT P 1VD VALUES GIVEN RELATIVE TO DRI W NG MEASUREMENT POINT VERTICAL SECTION RELA11VE 10 WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES(TRUE) ',., . m �"i Vii" i i ��:3"�a`� '`"" •'�"" ",. HORIZONTAL DISPLACEMENTZCLOSUFE)AT 16293.11 FEET IS 14089.61 FEETALONG 299.46 DEGREES(TRUE) Date Printed:15 March 2013 HALLIBURTON DIRECTIONAL SURVEY REPORT Eni Petroleum SP22-FN1 PB3 Ni kaitch uq USA AK-XX-0900169420 All depths reference the driller's pipe tally. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (fed) (feet) (feet) (feet) (deg/900ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 11E-IN 40.72 0.00 0.00 40.72 0.00 N 0.00 E 0.00 0.00 121.11 0.10 26.85 121.11 0.06 N 0.03E 0.06 0.12 169.53 0.17 2.04 169.53 0.17 N 0.05 E 0.17 0.19 201.76 0.47 350.08 201.76 0.35 N 0.03 E 0.35 0.95 233.88 0.78 345.12 233.88 0.69 N 0.05 W 0.69 0.98 262.89 0.76 331.42 262.88 1.05 N 0.19 W 1.05 0.64 297.41 1.18 307.81 297.40 1.47 N 0.58 W 1.47 1.66 327.80 2.17 300.54 327.78 1.95 N 1.32 W 1.95 3.33 356.18 3.25 300.24 356.12 2.63 N 2.48 W 2.63 3.81 387.05 4.70 298.78 386.92 3.68 N 4.34 W 3.68 4.71 418.15 5.95 301.28 417.88 5.13 N 6.84 W 5.13 4.09 449.02 7.18 299.08 448.55 6.90 N 9.89 W 6.90 4.07 479.82 8.05 300.30 479.08 8.92 N 13.44 W 8.92 2.87 510.89 8.50 300.16 509.83 11.18 N 17.30 W 11.18 1.45 541.60 8.90 299.86 540.18 13.50 N 21.32 W 13.50 1.31 572.59 9.07 297.76 570.79 15.83 N 25.56 W 15.83 1.19 603.94 9.94 297.25 601.71 18.22 N 30.16 W 18.22 2.79 634.35 11.46 295.62 631.59 20.73 N 35.21 W 20.73 5.10 665.42 13.56 294.52 661.92 23.57 N 41.31 W 23.57 6.80 691.88 14.88 293.47 687.57 26.22 N 47.25 W 26.22 5.08 723.07 16.19 295.25 717.62 29.67 N 54.86 W 29.67 4.47 785.29 19.86 298.41 776.78 38.40 N 72.00 W 38.40 6.10 847.59 22.75 300.07 834.82 49.47 N 91.74 W 49.47 4.74 910.77 25.98 301.49 892.36 62.82 N 114.12 W 62.82 5.20 971.77 27.67 302.55 946.80 77.42 N 137.45 W 77.42 2.88 1034.54 28.43 302.07 1002.19 93.20 N 162.40 W 93.20 1.26 1096.73 30.76 300.91 1056.27 109.23 N 188.59 W 109.23 3.86 1158.97 34.05 301.31 1108.81 126.47 N 217.14 W 126.47 5.30 `; 1251.87 34.43 301.18 1185.61 153.58 N 261.83 W 153.58 0.42 1345.71 38.48 299.66 1261.07 181.77 N 309.92 W 181.77 4.42 1439.04 42.00 300.33 1332.30 211.92 N 362.12 W 211.92 3.80 1532.41 40.71 300.35 1402.39 243.08 N 415.36 W 243.08 1.38 1625.72 39.92 300.07 1473.53 273.46 N 467.53 W 273.46 0.87 1719.17 43.19 299.34 1543.46 304.16 N 521.38 W 304.16 3.54 n 1812.51 43.40 300.21 1611.39 335.95 N 576.93 W 335.95 0.68 1905.75 43.56 300.26 1679.05 368.25 N 632.36 W 368.25 0.18 1999.04 45.45 301.31 1745.58 401.73 N 688.53 W 401.73 2.17 2092.41 44.70 301.66 1811.52 436.26 N 744.91 W 436.26 0.85 2185.74 46.40 302.14 1876.87 471.46 N 801.47 W 471.46 1.86 2279.21 45.80 302.64 1941.68 507.54 N 858.34 W 507.54 0.75 2372.60 45.49 302.91 2006.97 543.69 N 914.48 W 543.69 0.39 2465.99 45.00 303.48 2072.73 580.00 N 969.98 W 580.00 0.68 2559.34 45.11 304.24 2138.67 616.81 N 1024.85 W 616.81 0.59 2652.43 50.97 303.16 2200.89 655.17 N 1082.43 W 655.17 6.35 2746.24 54.02 301.43 2258.00 694.91 N 1145.33 W 694.91 3.57 2839.58 57.94 298.85 2310.22 733.71 N 1212.24 W 733.71 4.78 2932.96 59.38 297.28 2358.78 771.22 N 1282.61 W 771.22 2.11 3014.86 59.79 294.43 2400.25 802.01 N 1346.16 W 802.01 3.04 3190.41 62.47 289.45 2485.05 859.34 N 1488.72 W 859.34 2.92 3283.78 63.97 288.36 2527.12 886.34 N 1567.57 W 886.34 1.91 3377.17 65.14 286.31 2567.24 911.46 N 1648.07 W 911.46 2.34 3470.55 67.14 285.11 2605.01 934.57 N 1730.27 W 934.57 2.44 3563.95 69.08 284.89 2639.84 957.00 N 1813.98 W 957.00 2.09 3657.35 71.49 282.81 2671.34 978.03 N 1899.34 W 978.03 3.32 ="x;;3750.66 73.20 282.35 2699.64 997.40 N 1986.12 W 997.40 1.89 3844.03 75.40 282.18 2724.91 1016.49 N 2073.95 W 1016.49 2.36 .31 78.93 282.29 2745.63 1035.76 N 2162.82 W 1035.76 3.79 4UJU.00 OL.OD LOU.00 L(OU.04 -IU04.L■ IN LLOJ.UO VV I U04.L4 4.I O Ets 4124.04 85.65 281.36 2770.24 1072.14 N 2344.19 W 1072.14 3.36 4217.43 85.30 282.17 2777.61 1091.12 N 2435.34 W 1091.12 0.94 4310.76 84.91 282.87 2785.57 1111.28 N 2526.11 W 1111.28 0.86 4404.12 84.08 283.63 2794.53 1132.57 N 2616.57 W 1132.57 1.20 4497.39 83.37 282.98 2804.73 1153.91 N 2706.79 W 1153.91 1.03 4590.71 83.67 282.73 2815.26 1174.54 N 2797.19 W 1174.54 0.42 4684.04 83.64 282.27 2825.57 1194.62 N 2887.75 W 1194.62 0,49 4777.43 83.48 283.65 2836.05 1215.43 N 2978.18 W 1215.43 1.48 4871.10 83.54 283.75 2846.63 1237.47 N 3068.61 W 1237.47 0.12 4964.22 83.61 283.15 2857.05 1258.99 N 3158.60 W 1258.99 0.64 5057.58 83,45 283.19 2867.58 1280.13 N 3248.93 W 1280.13 c 0.18 5150.99 83.61 283.44 2878.10 1301.51 N 3339.25 W 1301.51 0.32 5244.34 83.44 285.09 2888.63 1324.36 N 3429.14 W 1324.36 1.77 5337.80 82.93 285.50 2899.72 1348.84 N 3518.65 W 1348.84 0.70 5431.20 82.60 285.73 2911.48 1373.78 N 3607.89 W 1373.78 0.43 5524.57 82.21 285.71 2923.82 1398.85 N 3696.98 W 1398.85 0.42 5617.97 81,97 285.29 2936.68 1423.58 N 3786.12 W 1423.58 0.51 5711.34 82.17 284.77 2949.56 1447.56 N 3875.44 W 1447.56 0.59 5804.68 82.22 285.59 2962.23 1471.77 N 3964.68 W 1471.77 0.87 5898.06 82.16 286.42 2974.92 1497.28 N 4053.61 W 1497.28 0.88 5991.47 82.04 287.16 2987.76 1524.01 N 4142.19 W 1524.01 0.80 6084.89 82.29 287.62 3000.50 1551.67 N 4230.51 W 1551.67 0.56 6178.33 82.35 287.84 3012.98 1579.87 N 4318.71 W 1579.87 0.24 6271.72 81.95 287.66 3025.74 1608.07 N 4406.82 W 1608.07 0.47 6365.09 82.06 287.59 3038.73 1636.07 N 4494.94 W 1636.07 0.14 6458.44 81.86 288.16 3051.78 1664.44 N 4582.91 W 1664.44 0.64 6551.78 82.28 287.86 3064.66 1693.02 N 4670.83 W 1693.02 0.55 6645.15 81.78 288.47 3077.61 1721.85 N 4758.69 W 1721.85 0.84 6734,90 81.59 287.09 3090.59 1748.97 N 4843.25 W 1748.97 1.54 6831.75 82.34 286.34 3104.12 1776.55 N 4935.10 W 1776.55 1.09 , <<6925.19 81.97 285.72 3116.88 1802.11 N 5024.06 W 1802.11 0.77 7018.43 82.21 285.16 3129.71 1826.69 N 5113.08 W 1826.69 0.65 7112.75 81.89 284.15 3142.76 1850.33 N 5203.46 W 1850.33 1.11 7205.36 82.08 282.46 3155.67 1871.43 N 5292.70 W 1871.43 1.82 7298.76 82.07 282.71 3168.55 1891.59 N 5382.98 W 1891.59 0.27 7392.10 81.33 282.54 3182.02 1911.78 N 5473.11 W 1911.78 0.81 7485.57 82.23 282.81 3195.38 1932.07 N 5563.37 W 1932.07 1.00 7579.01 82.19 283.04 3208.05 1952.78 N 5653.60 W 1952.78 0.25 7672.49 82.19 282.96 3220.75 1973.61 N 5743.84 W 1973.61 0.08 7765.81 82.25 283.94 3233.39 1995.12 N 5833.76 W 1995.12 1.04 7859.19 82.15 284.06 3246.06 2017.50 N 5923.53 W 2017.50 0.17 7952.59 82.57 283.84 3258.48 2039.82 N 6013.37 W 2039.82 0.51 8046.00 81.78 284.59 3271.19 2062.54 N 6103.07 W 2062.54 1.16 8139.29 82.17 284.98 3284.22 2086.12 N 6192.39 W 2086.12 0.59 8232.75 82.25 285.16 3296.89 2110.19 N 6281.80 W 2110.19 0.21 8326.12 82.19 284.78 3309.53 2134.09 N 6371.18 W 2134.09 0.41 8419.41 81.40 284.94 3322.84 2157.77 N 6460.42 W 2157.77 0.86 8512.74 81.88 285.45 3336.41 2181.97 N 6549.53 W 2181.97 0.75 8606.11 82.39 285.82 3349.19 2206.90 N 6638.60 W 2206.90 0.67 8699.41 82.18 285.74 3361.71 2232.04 N 6727.57 W 2232.04 0.24 8792.86 82.37 286.59 3374.27 2257.82 N 6816.51 W 2257.82 0.92 8886.21 82.56 287.27 3386.51 2284.77 N 6905.04 W 2284.77 0.75 8979.52 82.11 287.04 3398.96 2312.05 N 6993.41 W 2312.05 0.54 9072.92 82.32 285.65 3411.61 2338.09 N 7082.20 W 2338.09 1.49 9166.26 82.28 285.01 3424.12 2362.54 N 7171.41 W 2362.54 0.68 9259.74 82.10 283.96 3436.82 2385.71 N 7261.08 W 2385.71 1.13 9352.29 82.03 284.33 3449.60 2408.11 N 7349.96 W 2408.11 0.40 9445.60 81.71 284.10 3462.79 2430.79 N 7439.50 W 2430.79 0.42 9539.01 82.18 283.77 3475.88 2453.06 N 7529.27 W 2453.06 0.61 9632.44 82.16 284.32 3488.61 2475.52 N 7619.06 W 2475.52 0.58 9726.16 82.35 284.01 3501.24 2498.25 N 7709.10 W 2498.25 0.39 9819.66 82.30 282.78 3513.73 2519.72 N 7799.24 W 2519.72 1.30 9860.34 82.29 282.39 3519.18 2528.50 N 7838.59 W 2528.50 0.95 9953.71 82.18 283.25 3531.80 2549.03 N 7928.79 W 2549.03 0.92 10047.08 82.12 283.70 3544.55 2570.58 N 8018.74 W 2570.58 0.48 10140.41 82.36 284.78 3557.15 2593.33 N 8108.38 W 2593.33 1.18 10233.78 82.60 284.86 3569.37 2617.00 N 8197.86 W 2617.00 0.27 10327.09 82.35 285.60 3581.59 2641.30 N 8287.12 W 2641.30 0.83 10420.54 82.36 285.85 3594.02 2666.41 N 8376.27 W 2666.41 0.27 10513.88 82.29 287.04 3606.49 2692.59 N 8464.99 W 2692.59 1.27 10607.12 82.35 287.10 3618.95 2719.72 N 8553.32 W 2719.72 0.09 10700.41 81.67 288.27 3631.92 2747.78 N 8641.34 W 2747.78 1.44 10793.78 81.77 290.76 3645.37 2778.64 N 8728.42 W 2778.64 2.64 11073.97 86.66 302.66 3677.84 2900.97 N 8977.75 W 2900.97 6.23 11167.36 , 87.46 306.17 3682.63 2953.68 N 9054.68 W 2953.68 r 3.85-" 11260.71 ,' 88.60 310.07 3685.84 3011.26 N 9128.06 W 3011.26 4.35 11354.20 89.17 312.85 3687.66 3073.14 N 9198.10 W 3073.14 3.03 11447.61 89 19 315.98 3689.00 3138.50 N 9264.81 W 3138.50 . %F .- _ `" 3689.89 3207.70 N 9327.41 W 3207.70 4.08'" :. X1975 . 11634.33 89.57 321.18 3690.47 3279.72 N 9386.85 W 3279.72 1.54 11727.62 88.92 321.11 3691.70 3352.36 N 9445.37 W 3352.36 0.70 11820.98 89.40 321.61 3693.06 3425.27 N 9503.66 W 3425.27 0.74 11914.41 89.30 321.13 3694.12 3498.25 N 9561.99 W 3498.25 0.52 12007.77 89.05 321.15 3695.47 3570.94 N 9620.56 W 3570.94 0.27 III 87 32 3698.24 3639.19 N 9675.30 W 3639.19 1.99 86 3701.29 3684.60 N 9709.60 W 3684.60 5.62 86 0 3707.33 3759.13 N 9765.55 W 3.01 .wf: ~86.14 322.48» ._ ,.' 3713.68 3832.56 N 9822.71 W 3832.56 0.82r 86.47 322.31 3719.70 3906.36 N 9879.56 W 3906.36 0.401- 12525.61 86.35 322.90 3725.54 3980.33 N 9936.10 W 3980.33 0.64 12618.91 86.41 322.85 3731.43 4054.57 N 9992.30 W 4054.57 0.08 12712.22 87.53 323.30 3736.36 4129.06 N 10048.28 W 4129.06 1.29 12804.79 88.39 322.92 3739.66 4203.04 N 10103.81 W 4203.04 1.02 4278.17 N 10160.32 W 4278.17 12898.85 87.72 323.17 3742.85 0.76 12992.50 °°_° 86.21 322.69 3747.81 4352.78 N 10216.69 W 4352.78 1.69 13085.66 87.17 321.85 3753.19 4426.34 N 10273.61 W 4426.34 1.37 13178.98 91.02 320.88 3754.66 4499.21 N 10331.85 W 4499.21 4.25 13300.00 92.10 321.22 3751.37 4593.29 N 10407.90 W 4593.29 ,; 0.94 13365.70 90.03 321.09 3750.15 4644.45 N 10449.10 W 4644.45 3.16 13459.24 90.23 320.65 3749.93 4717.01 N 10508.13 W 4717.01 0.52 13552.91 89.45 322.21 3750.20 4790.24 N 10566.53 W 4790.24 1.86 13645.78 89.65 323.72 3750.93 4864.37 N 10622.46 W 4864.37 1.64 13739.12 89.58 325.01 3751.55 4940.23 N 10676.84 W 4940.23 1.38 13832.54 89.63 325.55 3752.20 5017.01 N 10730.05 W 5017.01 0.58 13925.86 - 90.33 323.73 `3752.23 5093.11 N 10784.05 W 5093.11 _ .2 09 w, 14019.13 90.68 323.17 3751.41 5168.04 N 10839.59 W 5168.04 '0.71 14112.41 90.49 323.71 3750.45 5242.96 N 10895.15 W 5242.96 0.61 14205.78 90.73 324.30 3749.46 5318.50 N 10950.03 W 5318.50 `,0.68 14299.23 90.65 324.58 3748.34 5394.51 N 11004.37 W 5394.51 ,1.31 14392.54 90.23 324.74 3747.62 5470.63 N 11058.34 W 5470.63 0.48 14485.87 90.32 324.78 3747.17 5546.85 N 11112.19 W 5546.85 0.11 14579.17 90.51 324.32 3746.50 5622.86 N 11166.30 W 5622.86 0.53 14672.55 90.27 324.98 3745.86 5699.02 N 11220.33 W 5699.02 0.75 14765.92 90.23 324.78 3745.45 5775.39 N 11274.04 W 5775.39 0.22 14859.31 90.55 325.14 3744.82 5851.85 N 11327.66 W 5851.85 0.52 14952.69 88.04 326.62 3745.97 5929.14 N 11380.03 W 5929.14 3.12 15046.14 87.37 325.43 3749.71 6006.57 N 11432.21 W 6006.57 1.46 15139.54 89.94 325.19 3751.90 6083.34 N 11485.35 W 6083.34 2.76 15232.80 90.66 325.29 3751.41 6159.96 N 11538 HIV 52 6159.96 0.78 15326.17 90.95 325.94 3750.10 6237.01 N 11591.24 W 6237.01 0.76 15419.45 90.50 326.30 3748.92 6314.44 N 11643.24 W 6314.44 0.62 15512.80 91.27 326.32 3747.48 6392.10 N 11695.01 W 6392.10 0.83 15606.18 91.02 326.31 3745.61 6469.79 N 11746.79 W 6469.79 0.27 15699.57 91.93 325.25 3743.21 6546.98 N 11799.30 W 6546.98 1.50 15792.90 91.70 321.94 3740.25 6622.05 N 11854.65 W 6622.05 3.55 15886.26 90.54 315.61 3738.42 6692.22 N 11916.13 W 6692.22 6.89 15979.53 90.21 312.86 3737.81 6757.28 N 11982.95 W 6757.28 2.97 16072.85 90.34 312.69 3737.37 6820.65 N 12051.45 W 6820.65 0.23 16166.18 90.22 313.61 3736.91 6884.48 N 12119.54 W 6884.48 0.99 16259.57 89.95 312.90 3736.77 6948.47 N 12187.56 W 6948.47 0.81 16352.94 90.18 313.25 3736.67 7012.24 N 12255.76 W 7012.24 0.45 16446.36 90.82 312.59 3735.85 7075.86 N 12324.17 W 7075.85 0.98 16539.72 91.19 312.86 3734.21 7139.19 N 12392.74 W 7139.19 0.49 16633.13 91.33 312.31 3732.16 7202.38 N 12461.50 W 7202.38 0.61 16726.48 ° 90.22 311.48 3730.90 7264.71 N 12530.98 W 7264.71 1.48 16819.94 90.57 309.67 3730.25 7325.50 N 12601.96 W 7325.50 1.97 16913.34 89.13 309.14 3730.50 7384.78 N 12674.13 W 7384.78 1.64 17006.71 89.02 309.09 3732.00 7443.68 N 12746.56 W 7443.68 0.13 -- i,17100.11 -- 88.88 .., .309.85,. 1. 3733 72 as x .04 N 12818.65 W 7503.04 a 0.83 17193.48 89.86 311.09 3734.74 7563.64 N 12889.67 W 7563.64 1.69 17286.82 90.27 311.56 3734.64 7625.27 N 12959.77 W 7625.27 0.67 17380.20 89.68 311.37 3734.68 7687.11 N 13029.74 W 7687.11 0.66 17473.61 89.95 310.51 3734.98 7748.31 N 13100.31 W 7748.31 0.96 17567.03 90.82 310.68 3734.35 7809.10 N 13171.24 W 7809.10 0.95 17660.47 90.27 311.29 3733 46 '' , a,;; 7 `! 7870.38 0.88 7753.86 92.41 311.43 3731 28 4,, ,-; 0 832.+7 2.30 .... .. .,. <e.9 nn An 40 nat ZA ‘,3,7„3.1.2.8,4,,,,„:' 'fn7 GA-`'°5ue' _. 56' �'�°`. _ x .' .4 . :* n. 18033.92 92.51 310.71 3724.11 8116.10 N 13522.78 W 8116.10 2.95 18127.29 92.28 307.91 3720.21 8175.20 N 13594.95 W 8175.20 3.01 18220.56 93.12 307.98 3715.81 8232.49 N 13668.42 W 8232.49 0.90 18313.89 90.68 308.27 3712.72 8290.07 N 13741.80 W 8290.07 2.63 18407.33 89.38 308.26 3712.67 8347.94 N 13815.16 W 8347.94 1.39 18500.69 88.58 308.64 3714.33 8405.98 N 13888.26 W 8405.98 0.95 18594.08 88.24 309.98 3716.92 8465.12 N 13960.49 W 8465.12 1.48 18687.50 90.83 310.86 3717.68 8525.68 N 14031.61 W 8525.68 2.93 18780.90 90.19 311.68 3716.85 8587.29 N 14101.80 W 8587.29 1.11 18874.24 89.81 313.32 3716.85 8650.35 N 14170.62 W 8650.35 1.80 18967.71 89.91 313.16 3717.08 8714.38 N 14238.71 W 8714.38 0.20 19061.15 87.47 313.23 3719.22 8778.31 N 14306.81 W 8778.31 2.61 19154.63 84.26 312.02 3725.96 8841.45 N 14375.40 W 8841.45 3.67 19239.94 87.64 312.34 3731.98 8898.58 N 14438.45 W 8898.58 3.98 & TION BASED ON MIN MUM CURVATURE METHOD SURVEY COORDINATES RELATIVE 10 WELL SYSTEM REFERENCE POINT 1VD VAII ES GIVEN RELATIVE TO DRI W NG MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL 1-EAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES(TRUE) A TOTAL CORRECTION OF 20.11 LEG FROM MAGNETIC NORTH 10 TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE 10 11-E WELL HEAD. I-IORIZONTAL DISPLACEMENT{CLOSURE)AT 19239.94 FEET „,,,,;.,, ; a -.; , IS 16960.35 FEETALONG 301.65 DEGREES(TRUE) Date Printed:15 March 2013 HALLIBURTON DIRECTIONAL SURVEY REPORT Eni Petroleum SP22-FN1 PB4 Nikaitchuq USA AK-XX-0900169420 All depths reference the driller'spipe tally. W' 111,111r Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 11E-IN 40.72 0.00 0.00 40.72 0.00 N 0.00 E 0.00 0.00 121.11 0.10 26.85 121.11 0.06 N 0.03 E 0.06 0.12 169.53 0.17 2.04 169.53 0.17 N 0.05 E 0.17 0.19 201.76 0.47 350.08 201.76 0.35 N 0.03 E 0.35 0.95 233.88 0.78 345.12 233.88 0.69 N 0.05 W 0.69 0.98 262.89 0.76 331.42 262.88 1.05 N 0.19 W 1.05 0.64 297.41 1.18 307.81 297.40 1.47 N 0.58 W 1.47 1.66 327.80 2.17 300.54 327.78 1.95 N 1.32 W 1.95 3.33 356.18 3.25 300.24 356.12 2.63 N 2.48 W 2.63 3.81 387.05 4.70 298.78 386.92 3.68 N 4.34 W 3.68 4.71 418.15 5.95 301.28 417.88 5.13 N 6.84 W 5.13 4.09 449.02 7.18 299.08 448.55 6.90 N 9.89 W 6.90 4.07 479.82 8.05 300.30 479.08 8.92 N 13.44 W 8.92 2.87 510.89 8.50 300.16 509.83 11.18 N 17.30 W 11.18 1.45 541.60 8.90 299.86 540.18 13.50 N 21.32 W 13.50 1.31 572.59 9.07 297.76 570.79 15.83 N 25.56 W 15.83 1.19 603.94 9.94 297.25 601.71 18.22 N 30.16 W 18.22 2.79 634.35 11.46 295.62 631.59 20.73 N 35.21 W 20.73 5.10 665.42 13.56 294.52 661.92 23.57 N 41.31 W 23.57 6.80 691.88 14.88 293.47 687.57 26.22 N 47.25 W 26.22 5.08 723.07 16.19 295.25 717.62 29.67 N 54.86 W 29.67 4.47 785.29 19.86 298.41 776.78 38.40 N 72.00 W 38.40 6.10 847.59 22.75 300.07 834.82 49.47 N 91.74 W 49.47 4.74 910.77 25.98 301.49 892.36 62.82 N 114.12 W 62.82 5.20 971.77 27.67 302.55 946.80 77.42 N 137.45 W 77.42 2.88 1034.54 28.43 302.07 1002.19 93.20 N 162.40 W 93.20 1.26 1096.73 30.76 300.91 1056.27 109.23 N 188.59 W 109.23 3.86 1158.97 34.05 301.31 1108.81 126.47 N 217.14 W 126.47 5.30 1251.87 34.43 301.18 1185.61 153.58 N 261.83 W 153.58 0.42 1345.71 38.48 299.66 1261.07 181.77 N 309.92 W 181.77 4.42 1439.04 42.00 300.33 1332.30 211.92 N 362.12 W 211.92 3.80 1532.41 40.71 300.35 1402.39 243.08 N 415.36 W 243.08 1.38 1625.72 39.92 300.07 1473.53 273.46 N 467.53 W 273.46 0.87 1719.17 43.19 299.34 1543.46 304.16 N 521.38 W 304.16 3.54 1812.51 43.40 300.21 1611.39 335.95 N 576.93 W 335.95 0.68 1905.75 43.56 300.26 1679.05 368.25 N 632.36 W 368.25 0.18 1999.04 45.45 301.31 1745.58 401.73 N 688.53 W 401.73 2.17 2092.41 44.70 301.66 1811.52 436.26 N 744.91 W 436.26 0.85 2185.74 46.40 302.14 1876.87 471.46 N 801.47 W 471.46 1.86 2279.21 45.80 302.64 1941.68 507.54 N 858.34 W 507.54 0.75 2372.60 45.49 302.91 2006.97 543.69 N 914.48 W 543.69 0.39 2465.99 45.00 303.48 2072.73 580.00 N 969.98 W 580.00 0.68 2559.34 45.11 304.24 2138.67 616.81 N 1024.85 W 616.81 0.59 2652.43 50.97 303.16 2200.89 655.17 N 1082.43 W 655.17 6.35 2746.24 54.02 301.43 2258.00 694.91 N 1145.33 W 694.91 3.57 2839.58 57.94 298.85 2310.22 733.71 N 1212.24 W 733.71 4.78 2932.96 59.38 297.28 2358.78 771.22 N 1282.61 W 771.22 2.11 3014.86 59.79 294.43 2400.25 802.01 N 1346.16 W 802.01 3.04 3190.41 62.47 289.45 2485.05 859.34 N 1488.72 W 859.34 2.92 3283.78 63.97 288.36 2527.12 886.34 N 1567.57 W 886.34 1.91 3377.17 65.14 286.31 2567.24 911.46 N 1648.07 W 911.46 2.34 3470.55 67.14 285.11 2605.01 934.57 N 1730.27 W 934.57 2.44 3563.95 69.08 284.89 2639.84 957.00 N 1813.98 W 957.00 2.09 3657.35 71.49 282.81 2671.34 978.03 N 1899.34 W 978.03 3.32 3750.66 73.20 282.35 2699.64 997.40 N 1986.12 W 997.40 1.89 ARdd NI 7R df1 WO 1R 7794 01 iniA 40 Al 9f17!OR W 1f11R 40 9*1R 411.1U.00 OZ.DO LOU.00 L/OU.O4 IU74.L4 N LLOO.UO VV I U34.L4 4.10 4124.04 85.65 281.36 2770.24 1072.14 N 2344.19 W 1072.14 3.36 4217.43 85.30 282.17 2777.61 1091.12 N 2435.34 W 1091.12 0.94 4310.76 84.91 282.87 2785.57 1111.28 N 2526.11 W 1111.28 0.86 4404.12 84.08 283.63 2794.53 1132.57 N 2616.57 W 1132.57 1.20 4497.39 83.37 282.98 2804.73 1153.91 N 2706.79 W 1153.91 1.03 4590.71 83.67 282.73 2815.26 1174.54 N 2797.19 W 1174.54 0.42 4684.04 83.64 282.27 2825.57 1194.62 N 2887.75 W 1194.62 0.49 4777.43 83.48 283.65 2836.05 1215.43 N 2978.18 W 1215.43 1.48 4871.10 83.54 283.75 2846.63 1237.47 N 3068.61 W 1237.47 0.12 4964.22 83.61 283.15 2857.05 1258.99 N 3158.60 W 1258.99 0.64 5057.58 83.45 283.19 2867.58 1280.13 N 3248.93 W 1280.13 0.18 5150.99 83.61 283.44 2878.10 1301.51 N 3339.25 W 1301.51 0.32 5244.34 83.44 285.09 2888.63 1324.36 N 3429.14 W 1324.36 1.77 5337.80 82.93 285.50 2899.72 1348.84 N 3518.65 W 1348.84 0.70 5431.20 82.60 285.73 2911.48 1373.78 N 3607.89 W 1373.78 0.43 5524.57 82.21 285.71 2923.82 1398.85 N 3696.98 W 1398.85 0.42 5617.97 81.97 285.29 2936.68 1423.58 N 3786.12 W 1423.58 0.51 5711.34 82.17 284.77 2949.56 1447.56 N 3875.44 W 1447.56 0.59 5804.68 82.22 285.59 2962.23 1471.77 N 3964.68 W 1471.77 0.87 5898.06 82.16 286.42 2974.92 1497.28 N 4053.61 W 1497.28 0.88 5991.47 82.04 287.16 2987.76 1524.01 N 4142.19 W 1524.01 0.80 6084.89 82.29 287.62 3000.50 1551.67 N 4230.51 W 1551.67 0.56 6178.33 82.35 287.84 3012.98 1579.87 N 4318.71 W 1579.87 0.24 6271.72 81.95 287.66 3025.74 1608.07 N 4406.82 W 1608.07 0.47 6365.09 82.06 287.59 3038.73 1636.07 N 4494.94 W 1636.07 0.14 6458.44 81.86 288.16 3051.78 1664.44 N 4582.91 W 1664.44 0.64 6551.78 82.28 287.86 3064.66 1693.02 N 4670.83 W 1693.02 0.55 6645.15 81.78 288.47 3077.61 1721.85 N 4758.69 W 1721.85 0.84 6734.90 81.59 287.09 3090.59 1748.97 N 4843.25 W 1748.97 1.54 6831.75 82.34 286.34 3104.12 1776.55 N 4935.10 W 1776.55 1.09 6925.19 81.97 285.72 3116.88 1802.11 N 5024.06 W 1802.11 0.77 7018.43 82.21 285.16 3129.71 1826.69 N 5113.08 W 1826.69 0.65 7112.75 81.89 284.15 3142.76 1850.33 N 5203.46 W 1850.33 1.11 7205.36 82.08 282.46 3155.67 1871.43 N 5292.70 W 1871.43 1.82 7298.76 82.07 282.71 3168.55 1891.59 N 5382.98 W 1891.59 0.27 7392.10 81.33 282.54 3182.02 1911.78 N 5473.11 W 1911.78 0.81 illek 7485.57 82.23 282.81 3195.38 1932.07 N 5563.37 W 1932.07 1.00 7579.01 82.19 283.04 3208.05 1952.78 N 5653.60 W 1952.78 0.25 7672.49 82.19 282.96 3220.75 1973.61 N 5743.84 W 1973.61 0.08 7765.81 82.25 283.94 3233.39 1995.12 N 5833.76 W 1995.12 1.04 7859.19 82.15 284.06 3246.06 2017.50 N 5923.53 W 2017.50 0.17 7952.59 82.57 283.84 3258.48 2039.82 N 6013.37 W 2039.82 0.51 8046.00 81.78 284.59 3271.19 2062.54 N 6103.07 W 2062.54 1.16 8139.29 82.17 284.98 3284.22 2086.12 N 6192.39 W 2086.12 0.59 8232.75 82.25 285.16 3296.89 2110.19 N 6281.80 W 2110.19 0.21 8326.12 82.19 284.78 3309.53 2134.09 N 6371.18 W 2134.09 0.41 8419.41 81.40 284.94 3322.84 2157.77 N 6460.42 W 2157.77 0.86 8512.74 81.88 285.45 3336.41 2181.97 N 6549.53 W 2181.97 0.75 8606.11 82.39 285.82 3349.19 2206.90 N 6638.60 W 2206.90 0.67 l! 8699.41 82.18 285.74 3361.71 2232.04 N 6727.57 W 2232.04 0.24 ifili, 8792.86 82.37 286.59 3374.27 2257.82 N 6816.51 W 2257.82 0.92 8886.21 82.56 287.27 3386.51 2284.77 N 6905.04 W 2284.77 0.75 8979.52 82.11 287.04 3398.96 2312.05 N 6993.41 W 2312.05 0.54 9072.92 82.32 285.65 3411.61 2338.09 N 7082.20 W 2338.09 1.49 9166.26 82.28 285.01 3424.12 2362.54 N 7171.41 W 2362.54 0.68 9259.74 82.10 283.96 3436.82 2385.71 N 7261.08 W 2385.71 1.13 9352.29 82.03 284.33 3449.60 2408.11 N 7349.96 W 2408.11 0.40 9445.60 81.71 284.10 3462.79 2430.79 N 7439.50 W 2430.79 0.42 9539.01 82.18 283.77 3475.88 2453.06 N 7529.27 W 2453.06 0.61 9632.44 82.16 284.32 3488.61 2475.52 N 7619.06 W 2475.52 0.58 9726.16 82.35 284.01 3501.24 2498.25 N 7709.10 W 2498.25 0.39 9819.66 82.30 282.78 3513.73 2519.72 N 7799.24 W 2519.72 1.30 9860.34 82.29 282.39 3519.18 2528.50 N 7838.59 W 2528.50 0.95 9953.71 82.18 283.25 3531.80 2549.03 N 7928.79 W 2549.03 0.92 10047.08 82.12 283.70 3544.55 2570.58 N 8018.74 W 2570.58 0.48 10140.41 82.36 284.78 3557.15 2593.33 N 8108.38 W 2593.33 1.18 10233.78 82.60 284.86 3569.37 2617.00 N 8197.86 W 2617.00 0.27 10327.09 82.35 285.60 3581.59 2641.30 N 8287.12 W 2641.30 0.83 10420.54 82.36 285.85 3594.02 2666.41 N 8376.27 W 2666.41 0.27 10513.88 82.29 287.04 3606.49 2692.59 N 8464.99 W 2692.59 1.27 10607.12 82.35 287.10 3618.95 2719.72 N 8553.32 W 2719.72 0.09 10700.41 81.67 288.27 3631.92 2747.78 N 8641.34 W 2747.78 1.44 10793.78 81.77 290.76 3645.37 2778.64 N 8728.42 W 2778.64 2.64 11073.97 86.66 302.66 3677.84 2900.97 N 8977.75 W 2900.97 6.23 11167.36 87.46 306.17 3682.63 2953.68 N 9054.68 W 2953.68 3.85 11260.71 88.60 310.07 3685.84 3011.26 N 9128.06 W 3011.26 4.35 11354.20 89.17 312.85 3687.66 3073.14 N 9198.10 W 3073.14 3.03 11447.61 89.19 315.98 3689.00 3138.50 N 9264.81 W 3138.50 3.35 11540.95 89.72 319.75 3689.89 3207.70 N 9327.41 W 3207.70 4.08 11634.33 89.57 321.18 3690.47 3279.72 N 9386.85 W 3279.72 1.54 11727.62 88.92 321.11 3691.70 3352.36 N 9445.37 W 3352.36 0.70 11820.98 89.40 321.61 3693.06 3425.27 N 9503.66 W 3425.27 0.74 11914.41 89.30 321.13 3694.12 3498.25 N 9561.99 W 3498.25 0.52 12007.77 89.05 321.15 3695.47 3570.94 N 9620.56 W 3570.94 0.27 12095.31 87.32 321.38 3698.24 3639.19 N 9675.30 W 3639.19 1.99 12152.30 86.54 324.49 3701.29 3684.60 N 9709.60 W 3684.60 5.62 12245.70 86.05 321.72 3707.33 3759.13 N 9765.55 W 3759.13 3.01 12338.98 86.14 322.48 3713.68 3832.56 N 9822.71 W 3832.56 0.82 12432.33 86.47 322.31 3719.70 3906.36 N 9879.56 W 3906.36 0.40 12525.61 86.35 322.90 3725.54 3980.33 N 9936.10 W 3980.33 0.64 12618.91 86.41 322.85 3731.43 4054.57 N 9992.30 W 4054.57 0.08 12712.22 87.53 323.30 3736.36 4129.06 N 10048.28 W 4129.06 1.29 12804.79 88.39 322.92 3739.66 4203.04 N 10103.81 W 4203.04 1.02 12898.85 87.72 323.17 3742.85 4278.17 N 10160.32 W 4278.17 0.76 12992.50 86.21 322.69 3747.81 4352.78 N 10216.69 W 4352.78 1.69 13085.66 87.17 321.85 3753.19 4426.34 N 10273.61 W 4426.34 1.37 13178.98 91.02 320.88 3754.66 4499.21 N 10331.85 W 4499.21 4.25 13300.00 92.10 321.22 3751.37 4593.29 N 10407.90 W 4593.29 0.94 r 13365.70 90.03 321.09 3750.15 4644.45 N 10449.10 W 4644.45 3.16 13459.24 90.23 320.65 3749.93 4717.01 N 10508.13 W 4717.01 0.52 13552.91 89.45 322.21 3750.20 4790.24 N 10566.53 W 4790.24 1.86 13645.78 89.65 323.72 3750.93 4864.37 N 10622.46 W 4864.37 1.64 13739.12 89.58 325.01 3751.55 4940.23 N 10676.84 W 4940.23 1.38 13832.54 89.63 325.55 3752.20 5017.01 N 10730.05 W 5017.01 0.58 13925.86 90.33 323.73 3752.23 5093.11 N 10784.05 W 5093.11 2.09 14019.13 90.68 323.17 3751.41 5168.04 N 10839.59 W 5168.04 0.71 14112.41 90.49 323.71 3750.45 5242.96 N 10895.15 W 5242.96 0.61 14205.78 90.73 324.30 3749.46 5318.50 N 10950.03 W 5318.50 0.68 14299.23 90.65 324.58 3748.34 5394.51 N 11004.37 W 5394.51 0.31 14392.54 90.23 324.74 3747.62 5470.63 N 11058.34 W 5470.63 0.48 14485.87 90.32 324.78 3747.17 5546.85 N 11112.19 W 5546.85 0.11 14579.17 90.51 324.32 3746.50 5622.86 N 11166.30 W 5622.86 0.53 14672.55 90.27 324.98 3745.86 5699.02 N 11220.33 W 5699.02 0.75 14765.92 90.23 324.78 3745.45 5775.39 N 11274.04 W 5775.39 0.22 14859.31 90.55 325.14 3744.82 5851.85 N 11327.66 W 5851.85 0.52 14925.00 88.78 326.18 3745.20 5906.09 N 11364.71 W 5906.09 3.13 14952.69 88.04 326.62 3745.97 5929.14 N 11380.03 W 5929.14 3.11 15046.14 87.37 325.43 3749.71 6006.57 N 11432.21 W 6006.57 1.46 15139.54 89.94 325.19 3751.90 6083.34 N 11485.35 W 6083.34 2.76 15232.80 90.66 325.29 3751.42 6159.96 N 11538.52 W 6159.96 0.78 15326.17 90.95 325.94 3750.10 6237.01 N 11591.24 W 6237.01 0.76 15419.45 90.50 326.30 3748.92 6314.44 N 11643.24 W 6314.44 0.62 15512.80 91.27 326.32 3747.48 6392.10 N 11695.01 W 6392.10 0.83 15606.18 91.02 326.31 3745.62 6469.79 N 11746.79 W 6469.79 0.27 15699.57 91.93 325.25 3743.21 6546.98 N 11799.30 W 6546.98 1.50 15792.90 91.70 321.94 3740.25 6622.05 N 11854.65 W 6622.05 3.55 15886.26 90.54 315.61 3738.43 6692.22 N 11916.13 W 6692.22 6.89 15979.53 90.21 312.86 3737.82 6757.28 N 11982.95 W 6757.28 2.97 16072.85 90.34 312.69 3737.37 6820.65 N 12051.45 W 6820.65 0.23 16166.18 90.22 313.61 3736.91 6884.48 N 12119.54 W 6884.48 0.99 16259.57 89.95 312.90 3736.77 6948.47 N 12187.56 W 6948.47 0.81 16352.94 90.18 313.25 3736.67 7012.24 N 12255.76 W 7012.24 0.45 16446.36 90.82 312.59 3735.85 7075.85 N 12324.17 W 7075.85 0.98 16539.72 91.19 312.86 3734.22 7139.19 N 12392.74 W 7139.19 0.49 16633.13 91.33 312.31 3732.16 7202.38 N 12461.50 W 7202.38 0.61 16726.48 90.22 311.48 3730.90 7264.71 N 12530.98 W 7264.71 1.48 16819.94 90.57 309.67 3730.26 7325.50 N 12601.96 W 7325.50 1.97 16913.34 89.13 309.14 3730.50 7384.78 N 12674.13 W 7384.78 1.64 17006.71 89.02 309.09 3732.01 7443.68 N 12746.56 W 7443.68 0.13 17100.11 88.88 309.85 3733.72 7503.04 N 12818.65 W 7503.04 0.83 17193.48 89.86 311.09 3734.75 7563.64 N 12889.67 W 7563.64 1.69 17286.82 90.27 311.56 3734.64 7625.27 N 12959.77 W 7625.27 0.67 17380.20 89.68 311.37 3734.68 7687.11 N 13029.75 W 7687.11 0.66 17473.61 89.95 310.51 3734.98 7748.31 N 13100.31 W 7748.31 0.96 i 17567.03 90.82 310.68 3734.35 7809.10 N 13171.24 W 7809.10 0.95 17660.47 90.27 311.29 3733.47 7870.38 N 13241.77 W 7870.38 0.88 17940.58 310.70 , $725 96 „ ,_;t,_;=8055.25 N 13452.04 W ; ,, 8055.25 2.74 18033.92 88.51 310.96 3727.37 8116.27 N 13522.66 W 8116.27 1.37 18127.29 88.83 311.25 3729.54 8177.64 N 13593.00 W 8177.64 0.46 18220.56 90.09 312.23 3730.42 8239.73 N 13662.59 W 8239.73 1.71 18313.89 89.88 313.18 3730.44 8303.02 N 13731.17 W 8303.02 1.04 18407.33 90.10 313.49 3730.46 8367.15 N 13799.13 W 8367.15 0.41 18500.69 89.76 314.24 3730.57 8431.84 N 13866.44 W 8431.84 0.88 18594.08 89.95 314.70 3730.81 8497.27 N 13933.09 W 8497.27 0.53 18687.50 89.78 317.30 3731.03 8564.46 N 13997.98 W 8564.46 2.79 18780.90 90.69 317.08 3730.65 8632.98 N 14061.45 W 8632.98 1.00 18874.24 88.85 318.63 3731.02 8702.18 N 14124.07 W 8702.18 2.58 18967.71 87.72 314.82 3733.82 8770.19 N 14188.11 W 8770.19 4.25 19061.15 87.68 313.36 3737.57 8835.15 N 14255.16 W 8835.15 1.56 19154.63 87.83 311.65 3741.23 8898.26 N 14324.02 W 8898.26 1.83 19247.95 87.74 310.72 3744.84 8959.66 N 14394.20 W 8959.66 1.00 19341.33 90.27 309.51 3746.46 9019.81 N 14465.60 W 9019.81 3.00 19434.73 91.83 310.41 3744.75 9079.79 N 14537.17 W 9079.79 1.93 19528.14 90.99 307.38 3742.45 9138.41 N 14609.84 W 9138.41 3.37 19621.43 90.69 306.73 3741.08 9194.62 N 14684.28 W 9194.62 0.77 19714.89 90.01 304.61 3740.51 9249.11 N 14760.20 W 9249.11 2.38 aiik 19808.26 89.96 302.56 3740.54 9300.76 N 14837.98 W 9300.76 2.20 19901.55 90.41 300.52 3740.23 9349.56 N 14917.49 W 9349.56 2.24 19994.88 90.39 298.65 3739.58 9395.63 N 14998.64 W 9395.63 2.00 20088.25 89.41 297.57 3739.75 9439.62 N 15081.00 W 9439.63 1.56 20181.55 89.46 295.50 3740.67 9481.30 N 15164.46 W 9481.30 2.22 20275.00 90.35 294.84 3740.82 9521.05 N 15249.04 W 9521.05 1.19 20368.35 91.97 294.53 3738.93 9560.02 N 15333.84 W 9560.02 1.77 20461.66 92.12 292.76 3735.60 9597.42 N 15419.25 W 9597.42 1.90 20555.06 92.08 291.17 3732.18 9632.33 N 15505.81 W 9632.33 1.70 20648.40 89.62 290.59 3730.79 9665.59 N 15593.01 W 9665.59 2.71 20741.88 89.05 _, , 290.89 3731.88 9698.69 N 15680.42 W 9698.69 0.69 20834.43 88.51 289.90 3733.85 9730.94 N 15767.15 W 9730.94 1.22 20927.74 89.40 290.37 3735.55 9763.05 N 15854.74 W 9763.05 1.08 21021.15 90.27 291.84 3735.82 9796.69 N 15941.88 W 9796.69 1.83 21114.58 87.78 292.16 3737.41 9831.68 N 16028.49 W 9831.68 2.69 21208.04 88.87 295.56 3740.14 9869.46 N 16113.91 W 9869.46 3.82 21302.42 87.91 298.46 3742.79 9912.30 N 16197.95 W __ 9912.30 3.24 21395.79 85.98 302.14 3747.77 9959.33 N 16278.44 W 9959.33 4.45 21489.16 87.53 304.64 3753.06 10010.63 N 16356.26 W 10010.63 3.15 21582.49 89.35 306.95 3755.60 10065.19 N 16431.93 W 10065.19 3.15 21675.86 88.28 309.19 3757.53 10122.75 N 16505.41 W 10122.75 2.66 21734.35 88.58 309.19 3759.13 10159.69 N 16550.73 W 10159.69 0.51 1 CALCUAlION BASED ON MINMUN CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT. 1VD VALUES GIVEN RELATIVE TO DRILLING MEASUF:EMENTPOINT VERTICAL SECTION RELATIVE TO WELL FEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES(IRE) A TOTAL C)RRECTION OF 20.11 DEG FROM MAGNETIC NORTH TO 1R E NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE 10 THE WELL FEAD. HORIZONTAL DISPLACEMENT(CLOSURE)AT 21734.35 FEET IS 19420.25 FEETALONG 301.54 DEGREES(TRUE) Date Printed:15 March 2013 1 HALLIBURTON SP22-FN1 Sperry Drilling Days vs. Depth 0 r , , t 26 Jan 2013 Pre-spud meeting 1000 --- -- 27 Jan 2013 Spud the well @ 0500 hrs �— _ ------ 160'MD, 160'TVD _ I (�nn•p 2000 --- ' --- 30 Jan 2013 ----------- "�u 'I II Run&Land 13 3/8" '��^''''�■ .!L casing to 3082'MD --- —_ L�II IIII �l[ oNe�III II IL 3000 ---- I 26 Jan 2013 — 4000 -----f------ -- --- -- ----'— SDL rig up unit and — 29 Jan 2013 — II gas equipment 5000 — Reached surface TD — --- --- ---- I , , , , , , — @ 0800 hrs ' Prognosed 3097'MD/2441'TVD 6000 -- .___ - Actual 7000 11 02 Feb 2013 -- --- --- --- — RIH,FIT 13.0 ppg EMW, 06 Feb 2013 8000 Drill ahead to 3796'MD RIH w/new MWD tools,resume drilling -- --- --- --- — 9000 ! t --- --- — �' 05 Feb 2013 ��� POOH @ 9863'MD .. , m. 10000 -- for MWD tool failure toll_ _t —_ 11 Feb 2013 Run&Land 9 5/8" — --- — --- -- ++ casing to 12122'MD Q 11000 ---- --- --- --- ----u----- --- --- — d) 14Feb2013 0 _ 08 Feb 2013 —_ — RIH, FIT 13.0 ppg EMW �- 12000 — --- -- .117 TS Reached intermediate TD .- i @1345 hrs 16 Feb 2013 13000 -- 12140'MD/3702'TVD .------- SP22-FN1 PB1 TD --- N @ 0500 hrs CV 14000 ____ ___ 16 Feb 2013 � 14550'MD/3729'TVD t Open Hole Sidetrack -- ^�!^� -- s @ 1100 hrs ` 17 Feb 2013 SP22-FN1 PB2 TD 15000 ---- --- . 13280'MD/3752'TVD ---- --_ @ 1515 hrs --- — t I I I I _ 1 16360'MD/3723'TVD 17 Feb 2013 i - 16000 ------------ Open Hole Sidetrack — ' --- I --- — @ 2100 hrs 17000 ---- -- 14880'MD/3745'TVD — ----------- — I 22 Feb 2013 18000 ---- 20 Feb 2013 _ Open Hole Sidetrack ___ Open Hole Sidetrack @ 1500 hrs -- @ 0300 hrs 20240'MD/3742'TVD --_. 19000 ---- --- --- 17950'MD/3726'TVD -- -- i 22 Feb 2013 20 Feb 2013 �— 20000 --------------I SP22-FN1 PB3TD — — SP22-FN1 PB4TD .— @2130hrs @0715hrs 19306'MD/3735'TVD 21800'MD/3761'TVD 21000 --- --- ---- ' 22000 ----------------+-- — 23000 -------------- 24 Feb 2012 •-- - - Reached production TD -- 24000 -- at 1240 hrs i�� --- --- — 22923'MD/3408'TVD : --- --- 25000 I I , , , . _ , , , , . , , , , , . ._ 1_ 0 5 10 15 20 25 30 35 40 Rig Days HALLIBURTON Sperry Drilling Surface Data Logging After Action Review Employee Name: Emil Opitz Date: 29-Jan-13 Well: SP22-FN1 Hole Section: Surface What went as, or better than, planned: Rig down and rig up went smoothly. All data transfers (WITS, Dx, Petro link) worked as 9 9 p Y Ny ) expected. Gas Detection equipment functioned properly. Re-routed the gas gear exhaust lines to avoid future freeze-ups. Difficulties experienced: With the new version of Insite, several things still need to be adjusted; namely Pump Configurations and Start Depths in various descriptors and bit information. Recommendations: N/A Innovations and/or cost savings: N/A HALLIBURTON Sperry Drilling Surface Data Logging After Action Review Employee Name: Leigh Ann Rasher Date: 12-Feb-2013 Well: SP22-FN1 Hole Section: Intermediate What went as, or better than, planned: No major issues were encountered with the gas equipment and INSITE ran well. Difficulties experienced: During intermediate section lag was slighty off due to the'lag controls' under lag monitor. They were somehow deleted or set as default. We had to go in and add our lag time from the gas trap to the gas equipment into the'delay suction to gas output' box and select baseline chrom 1 as the chromatograph used. Recommendations: Make sure to double check all configurations before drilling. Innovations and/or cost savings: N/A HALLIBURTON Sperry Drilling Surface Data Logging After Action Review Employee Name: Emil Opitz Date: 28-Feb-2013 Well: SP22-FN1 Hole Section: Production What went as, or better than, planned: After re-routing the exhaust lines for the gas equipment, we no longer had any issues with them freezing up. Changing runs 5 times during the production section for all of the plugbacks was successful. Difficulties experienced: The Vortex Cooler was not functioning properly. We were unable to thoroughly diagnose the cause of the problem on site, but the symptoms included reduced gas detection, and increased "gas trap to gas detector"time. Lag was also difficult to keep calibrated throughout the entire well. Recommendations: Have the Vortex Cooler thoroughly checked and looked over. Add 2-3% annulus correction for each plugback to account for the troughing prior to kicking off the open hole sidetrack. Innovations and/or cost savings: N/A
