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50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ OP04-07 JBR 03/25/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 H2S sensor Failed in the cellar needed replaced.pass re-test after I left location. Bag-11seconds Rams-6 seconds HCR- .5seconds Test Results TEST DATA Rig Rep:Holmes/HilerOperator:Eni US Operating Company Inc.Operator Rep:Ashley/Wimmer Contractor/Rig No.:Nordic 4 PTD#:2081990 DATE:3/4/2022 Type Operation:WRKOV Annular: 250/3500Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE220307185810 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 1116 Sundry No: 321-638 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 Blind/shear P #2 Rams 1 2 7/8X 5 1/2 P #3 Rams 1 2 7/8X 5 1/2 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 1 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P2000 200 PSI Attained P24 Full Pressure Attained P90 Blind Switch Covers:PAll stations Nitgn. Bottles (avg):P4@2975 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector F FH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA 9 99 9 9 9 re-test after I left location.Bag-11seconds Rams-6 seconds HCR- .5seconds F F STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:4 DATE: 2/28/22 Rig Rep.: Rig Phone: 907-685-1470 Operator: Op. Phone: 907-685-0710 Rep.: E-Mail Well Name: PTD #22081990 Sundry #321-638 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1116 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1NATrip Tank PP Annular Preventer 1 13 5/8"P Pit Level Indicators PP #1 Rams 1 13 5/8" BSR P Flow Indicator PP #2 Rams 1 2 7/8" x5.5" vbr P Meth Gas Detector PP #3 Rams 1 2 7/8" x5.5" vbr P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)2990 P CHOKE MANIFOLD:Pressure After Closure (psi)1975 P Quantity Test Result 200 psi Attained (sec)11 P No. Valves 14 P Full Pressure Attained (sec)81 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 @ 2850 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:10.5 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/23/22 1:16pm Waived By Test Start Date/Time:2/24/2022 13:00 (date) (time)Witness Test Finish Date/Time:2/24/2022 23:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Nordic Test was conducted with 4.5 and 4" test joints. Gas and PVT alarms tested. This is an updated form to amend the inaccurate recording of MASP and closure/opening times earlier sent in. Attachment “13-5M Shaffer/Hydril” dated 2/28/2022 shows close and open times. Ron Holmes / Nate Sipes ENI Tim Ashley / Russ Wimmer Nikaitchuq OP04-07 Test Pressure (psi): OPPdrilling@eni.com Form 10-424 (Revised 02/2022) 2022-0224_BOP_Nordic4_Nikaitchuq_OP04-07_revised 5(9,6('5(32575HF G 9 9 99 999 9 9 -5HJJ 5(9,6('5(32575HF G This is an updated form to amend the inaccurate recording of MASP and closure/opening times earlier sent in. 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Operations Abandon LJ Plug Perforations LJ Fracture Stimulate L Pull Tubing U Operations ant �f03un LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved`Pfogram ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: _ESP Change -out_ ❑Z 2. Operator Ent US Operating Co. Inc. 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑D Exploratory ❑ Stratigraphic ❑ Service❑ 208-199 3. Address: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 6. API Number: 99503 50-029-23409-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0373301, 0355024, 0390616, OPO4-07 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Nikaitchug Schrader Bluff Oil Pool 11. Present Well Condition Summary: Total Depth measured 12144 feet Plugs measured N/A feet true vertical 3936 feet Junk measured N/A feel Effective Depth measured 12142 feet Packer measured N/A feet true vertical 3936 feet true vertical N/A feet .Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2,455 13.375' 2,455 2,097 5,210 2,480 Intermediate 8,750 9.625' 8,750 3,838 6,890 4,790 Production Liner 3,625 5.5' 12,142 3,936 Slotted Slotted Perforation depth Measured depth 8750-12142 feet True Vertical depth 3838-3936 feet 4.5 L80 7,407 3,558 Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A Production or Injection Data Prior to well operation: Subsequent to operation: 1165 25116341!205 Amjad Chaudhry 220 670 106 2366 20 210 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) Daily Report of Well Operations Q Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 15. Well Class after work: Exploratory ❑ Development Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil L GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ Gas LJ WDSPL ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Name: Stefano Piedelici Contact Name: Amjad Chaudhry Title: WellOperations Proect M ana er Contact Email: amiad.chaudhnraeni.mm Signature: \ Date: Contact Phone: '4 Form 10404 Revised 4/2017 RBDMS-W-4✓JUN 13 2019 Submit Original Only Sur. Casing 13-3/8", 68 # 2,455 MD, 2,097 TVD 60° Inc. 7" 26 ppf, L-80 scab liner with seal stem Nikaitchuq Field — Oliktok Point Pad Swivel joint 5' MD/TVD 4-'/2° 12.6 ppf L80 HW563 Production Tubing 4-'/z" 12.6 ppf Production Tubing 4-'/2' cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line 7,407' MD, 3,558' TVD - Discharge Gauge Sub E n li � a LIrOO Ileulh`nl OPO4-07 Oil Producer with ESP Lift As Completed 05/01/2019 7,477" MD, 3,577' TVD, 75 deg Inc — Bottom of Motor Centralizer Centrilift ESP, 66 -stage 380P18 SXD + 20 -stage GINPSS SXD pump, 513 GST3 seal, 250 HP 562XP motor 7,710" MD, Baker SLZXP Scab Liner Hanger Packer 8,517' MD, Baker SLXP Liner Hanger Packer Interm. Casing 9-5/8", 47 # 8,750' MD, 3,838' TVD 84° Inc. Confidential HAL Zonal Isolation /Swell Packers i 5-/2" Silver Bullet Ecc. Nose Guide Shoe Slotted Liner, 5-'/2' 17 ppf 12,142' MD, 3,936' TVD Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 aa Job: WORKOVER 2n II WCER Level: Daily Report Date: 4/312019 Report #: 1 Page: 1 of 2 Well Header PermlVConcessionN OPerater Subsidiary Initial La as Code ENIPETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Euvation(ft) Ground Level in) Fire, Flange lm Run - Base F..go in) RKB-Tbbinq goods(it) 5320 1220 Rigs Rig TYPe R19 Num Rip Sre4 Dare Rig Release Date Rig Name 1C.= RIG4 NORDIOGLISTA LAND RIG 0981 4r42019 Daily Information We Temperature(°F) Wind Days LTI(days) Days Rl(days) POB Clear 15 NE@]MPH 33.0 Safety Incidents - Near Miss Data Category Type Subtype Severity Cause Lost time? Comment Safety Drills Type -Occur Last Dale Next Date Days Until Next Check (day:) Rig Inspection Satety Mewling 1 4/3/2019 1 4/32019 4/42019 4/4/2019 1 1 Casings seat Cas. Type OD (I.) ID (in) Grade Top (ftKB) Rome. PVKB) TVD Bet,(ftKB) Run Date CASING CASING LINER t33I0 95/8 512 1242 8.8:3 489 L -a0 L80 L40 -2.420.8 A.9 4,900.0 2-20.9 0,]2].0 12,142.0 2.08-.1 3.0350 3.935.6 5212010 8/12010 6/13/2010 Last Cementing Cementing SUq Date: 6/312010 Sbingi CASING, S,nl,MKB Comment: Seg- Top lhKel I Top Was Mein Ban (NKB) Co. 1 1 6.339.0,Volume Calculations ,n7.0 I Planned 500' Move lop of N Sand Job Information Job Phase Plannetl SMrt Date Start Date EM Data P56 Duration (days) WORKOVER 4131201900:00 413/X11900:00 0.00 Daily Summary Operations 24h Forecast Rig up hoses to OPO4, prep for builhead Stage in Tiger Tank. Conduct Bullhead Well Kill. ND Tree. NU BOP. Uh Summary Prep for ng move. Move dg eR of Opts, stage sena selling As mob and placing f Wculite for wnmemand. Move over Cook Prep for operations. Operation at 07.00 Prepping to kill well. Time Log sun End Cum Dur Time Time Dur (hr) thn Phase Dip, Act. Plan Opec Descr. 00:00 0330 3.50 350 Prep for rig move replace creclod MRGfiImilers an walker system, replace well house M1tich cover, raise SOP enclosure, and ,found hoses in walker be, 0330 0SW 2.00 5.50 MOB A 2 P PJSM, walk ng away from well house approximately 10'. 0530 09:30 4.00 9.50 MOB A 5 P PJSM, obtain unit work permit lay Hour and mats to walk dg clean outer BOP enclosure wall utilizing man lift. 0930 14.00 4.50 1400 MOB A 5 Weld on Ww W pleca of hemulite to liner, and continue to lay transition mats. 14:00 1730 3.50 11.50 MOB 1 A 1, P BeginwaWJngdq Easttmvarde OPO4-07. Move oversell, set dg down. 17:30 00:00 85(1 24.00 O A —mune wl0 peaparing III As opetatbtu. Complete bean for Curings Brat. Gas Readings Avg Backgfound Gas (%) Mai Background Gas (X) Avg Connectlun Gas 1%) Max Connection Gas (%) Avg Drift Gas (%) I Avg no Gas (%1 Max Trip use list Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Atltll ons (bar) Cum Additions (bbl) Losses (b60 Co. Losses )bbi) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative E. representable Ent repre5entativa Em representative Tool Push Tool Push Tod Push I. Lawrence Robert ONeal Mitch Billington Good Ackerman Richard Tanury Bron Pederson Jason Morse Is EM end Eni Nardi, Nortl¢ Nordic Drilling Supv. Drilling Su, Rig Clerk HSE Tool Pusher Tool Pusher HSE akryclerksdoyont 5®empeboleurnoo m geog.ackamen®empebalaum.co dgmanagerAgltinordic-aninta.com W7AS541722 907A 0721 907-670.8604 Personnel Log (POB) Company Serv. Type Work H (M1n Stand-by H (lar) Count Note BHGE (Vetco) W Swam ASRC BHGE (Centn(A) Peak Jacobs needle Wellhead Mud engineer Chad,, Man ESP Equipment Operators Equipment Operators Nordic Peunomal 12.50 12.50 12.50 12.50 12.0 1250 12.50 1 1 2 2 2 3 22 12.5 Hours 125 Hours 25 Hours 25 Hours 25 Hours 37.5 Hours 275 hours BOP Stack &Components Description sren Dare Last Certification Data Pressure Rating (psi) Type Make Model ID No. (in) Is Range (psi) I Last Cert Data Slow Circulation Rates Pump Number: Make: Mad ' Shirt Data End Date Liner Size(in) Volume Per Stroke Override(bbllstp I Maa PressufeRod) Well Name: OPO4-1307 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/312019 Report #: 1 Page: 2 of 2 Date pep<M1 (M(al Slow Sad Strokes (spm) P (Pel) Ee hl D Flow (g,m) Daily B./W- --Supply Item Denetlpgon: Ectapment Fuel Unit Label: gal us Unit Sin: Note: bate Consumetl 4/32018 J]]0 Re,, 3R0 Remrnetl IW.....d Cum Recelvetl 3]).0 3]].0 Cum Re[umetl 0.0 Cum On Loc 0.0 Note Supply Item DeseNpilan: Rig FU91 Unit Label: gal us UOn el.: Nole: Date Consumetl calved 0",010 8380 68]2.0 Returnetl Cum Consumed Cum Recelvetl 8380 8,0]2.0 Cum Retumetl 00 Cum On Lee 6,034.0 Note supply Intel riptlon: Rg Waler UnRLIdel: ON Unit Size: NOW: Date Consumetl Recelvetl U32019 ) 0 143.D RMurnetl Lam Consumetl Lum Recelvetl ].0 149.0 Cum Rammetl 0.11 Cum On Loc 136 0 Note Last Authority Visit Dam To Ins, Nbr TOteI I.N.L. number Comment TOP Cards Submitted Lomparry N Rpm C. NORDIPCAUSTA SERVICES 2 PJSM General Notes Lpmmepb Well Name:P0 Wellbore Name: e: OPO4-0707 Well Code: 23893 �d1 ��n11nI Job: WORKOVER �CIIIIII WCER Level: Daily Report Date: 414/2019 Report Y: 2 Page: 1 of 2 Well Header PermlNConresslon N° Operator Su I lary Mwal Lahee Cade ADL -388583 ENI PETROLEUM ENI Pefropum Ga, Inc. DEVELOPMEm WELL Rotary Table Elevation Do Ground Level A-) Faat Flange(ft) RKB - Base "..as (it) BKB- Tubing Spool(N) 53.20 1220 I Rigs we Name Comramerwe Type cog Num Rig Short Data Rig Release Data MIND RIG 4 NORDIC CALISTA RIG 0981 6132019 Daily Information We Temperaturet°F) Wind Days LTl (days) Days Rl (days) Poe Clear�9MPH 35.0 Safety Incidents - Near Miss Data Category Type Subtype severlry Cause Lost time? Comment Safety Drills Days UntilNext Check Type NOccur Last Date Next Date (days) Rig inspection 2 4/42018 41512019 1 Solely Meeting 2 4/4/2019 415/2019 1 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bosom (hKBI TVD Bot (ftKel Run Data G ING 133/8 12.42 L90 -2,420.0 20209 2,080.1 5212010 CASING 9518 8.68 LBD 3,835.0 6112010 LINER 512 4.89 L-80 4,908.0 12,142.0 3,9356 8/132010 Last Cementing Cementing Sart Data: 6rJ2010 Strin:CASING, 8,72E KB Comment: Staff ToptftKB) Top Meas Meth Ban Role) Co. 1 8,339.0 I Volume Calculatxins 11.1".0 1 Planned 500' Above top of N Sand Job Information Job Phase Plamled Skirt Data Skirt Date end Data P50 Duration (days) WORKOVER 01320180:0 4/320190000 000 Daily Summary Operations 24h Forecast RounaGGp homing to lad on 9.9 ppg NaCl. Conduct Bullhead Kilt, pep he ND tree and NU BOP. 24h Summary Stage in Cuttings Box and Tiger Tank, bake on 9.3 ppg NaCl Into pip. Conduct Bullhwd Well Sol, Attempted to bleed off residual, cannot bleed tubing down from 150 psi, lA down from 50 An Operation at 07.00 Prepping fluids for well kill. Time Log Stare eta Cam our Time Time Dur @r) fir) Phase Our. Act. Plan Gper. Descr. 000 0300 S.00 3.00 W.O. A 1 P PJSM, connect panic line to choke, clean up pit area, and pro are to take on brave. 0300 1200'. 900 12.00 W 0 A 5 P Spot tunings lank and balm up same, move tiger took old of cpntoinment and pick up remaining rig more. Remove and clean up old liner used for spring pulled tubing, begin att loading 8.3 PPG Nal brine or pits. make up gnas to robing and A annulus for well 011 common. and begin mixing high vocos8y, 0111. 12:00 1300 1.00 13.00 .O. M 8 P PJSM, Complete hadrg high viscosity pill and test lines gcin, to tubing and A annuals to 3000 PSI. 130 14:00 1.00 14.00 W O. M 9 P Perform well kill comment, ant, bothered 125 BBL NaCl bona down tubing with Initial s 07 P51. A annulus 384 PSI, B annulus 230 PSI, final Pressures TBG 850 PSI, A annulus 487 PSI, B annulus 320 PSI, at 2,5-3 BPM rale. Shot down and monitomd pressure while Irving up to pump down S annulus with pressures falling to TBG 22 P61, A annulus 450 PSI. B annulus 320 PSI. 140 1690 2.00 16.00 W.O. M 9 P Perform well III apmaticn, hungered 40 BBL of high vpwsiy pill down A annulus, followed by 810 BBL of 9.3 PPG NaCl time initial pressures of TBG M PSI. A annulus 450 PSI, B annulus 320 PSI, Pirel pressures were TBG 553 PSI, A annulus 363 PSI, a annulus 260 PSI, Nose maximum pressure seen was TBG 584 PSI, A annual 550 PSI, a annulus 470 1890 20:00 4.0 2000 W.O. M 11 P Monitored well after pumping operalbn: Monitored well for over 1 tour, hall pospapperes were Tog at 235 psi, A Annulus at W psi. 0 Annuals at 203 psi. Line an to bleetl through choke to Tiger Tank, Inial strep 3 this. Bled A annulus down to 2 Psi. tale Ming drop in Tog b 20 psi. Returns were fluid pack to Tiger Tank Close in A annulus, prossure mss to 50 psi, Tbg 9 215 to almost Immediately. Attempt to bleed Tag down dropped to 64 psi over6 min period waft A annulus also dropping to 33 toll. Cbse in to monitor and shop bank, 30 bble in Tiger Tank -all code. Tbg pleasure mea to 100 psi, A annulus rase to 53 pal, ever 5 minute period. Open up to bleed Tito again, slowly bled b 60 psi. A annulus remained at 50-51 psi ager 20 minutes, all crude flus returns to Tiger Tank, total in Tiger Tank 40 bb1e. Close In, Tbg rose to 119 psi, A annulus to 60 pal In 14 minutes. After 45 minutes, pressures stabilized at 134 psi on rob, 78 psi an annulus. 20M 0000 4,00 24.00 Joe . M e P Discussed situation with Day Compi For, Operations, and with Drilling Manager. Decision is to weight up flow and re - conduct Bullhead Well w0 empires, crow mob phllg and moving broad salt (Nal Into fluor on rig. Plant notified to begin weight up to 9.9 ppg, lead trucks. Crew preparing paperwork for loading In ddll pipe. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas I%) Mex Connection Gas(%) Avg Drill Gas 1%) Max Drill Gas 1%) Avg Trip Gas 1%) ala Trip Gas 1%1 Daily Mud Volumes ranwaeainpmLozs type Des volume lbbq Tank Surface 415.0 Hole Hole 6950 Loss Formation 215.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume lbblo Additions abl)Gum Addlttona (bbl) Losses (bbl) Cum Losses lbbQ 1.110.0 695.0 0.0 0.0 215.0 215.0 Daily Contacts Position Contact Name Company Title Email ONiceMobile Eni representative wnce Steve Lare Em Drilling Su. pe Ear experiment.. Robert Chiral EN Calling Sups. End representative Mutt Billington Era cog Cleric magclerksdcyoul5@humpeWleum.co do 90].685-0]22 Eni reprompletwe GeoOAcestrom Eni HSE ge.N.z<kerman�enipmaleum.co 9076850]21 Tool Push Taxi Richard Tax Wool Tool Pusher Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/4/2019 Report #: 2 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email I win, Mobile Tool usmen Petle.on Tool Push Jaepn Mores Nemic Nortlic Tool Pusher HSE rigmanager.rig4@nomiccalista.com 907$)D�04 Personnel Log (POB) Company Serv. Type Work H (hr) 1 Sbnd'. H I..Count 1 Nota SHOE (Vetco) Mi Swaco ASRC BHGE(CenmfM) Peak Jacpbs Nordic Wellhead Mud engineer Company Man ESP Equipment Operators Equipment Oparalme Npmlc Personnel 12.50 12.50 12.50 12.50 12 50 1250 1250 1 112.5 2 2 2 4 23 12.5 Hours Houre 25 Hours 25 Hours 25 Hou. 50Hou. 287.5 BOP Stack 8 Components Description Stan Came Last Cemented Data Pressure RatMg (pap Type Mahe Model ID N.ji.) PRange ipail Last Cert Dele -Circulation SIo Rates Pump Number: Make: Model: Start Dan, End Data Liner Size (in) Volume Per Stroke Override (bbl/sir) Max Pressure (psi) Date DeptM1 (hKB) Slow Sptl Strokes (apm) P(pall I EN(%) OFlow tgpm) Daily Bulk 3U Eel, Imm Doa.NpSon: Equipment Fuel Uni[label: gat ua Unit Sixe: Note: Dale Consumed Recelvetl 4/4Y4019 232.0 232.0 Returned Cum Consumed Cum Received 6090 609.0 tum Returned Cum On Loc Not. 00 0.0 Supply Item Dnetlption: Rip Fuel Unil Label: gal us Unit Size: Note: DataConsumed Received 41412019 81].0 00 Returned Cu. Consumed Cum Received 1.6550 6,872 Lum Returned Cum On Loc Note 00 Supplylhm Oe¢dptlpn: Rig Wafer Unit Lebei: bbl Unit Size: Note: Date Consumed Received .412018 1 J.0 0.0 Returned Cum Consumed Cum Receind 24.0 143.0 Cum Returned Lum Cn Loc Note 0.0 118.0 Last Authonly Visit Date The Insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpm Com NORDIC -0 LISTA SERVICES 2 PJSM General Notes emnmene Well Name:P0 Wellbore Name: e: OPO4-0707 Well Code: 23893 Job: WORKOVER 2n i WCER Level: Daily Report Date: 4/512019 Report M: 3 Page: 1 of 2 Well Header PetmiVConceselon N° OPeratw Subsidiary IniBal Lahee Lptle ADL -300583 ENIPETROLEUM ENI Pepoleum CD. Inc. DEVELOPMENT WELL Rotary Table Elevation (it) Ground Level Val First Flan gem, RKB-Base Flange(it) RKS- Tubing Spool (it) 53.20 12.20 Rigs Rig Name Cambe cter Rig Type Rlg Num Rig Bud Data Release Dale RNDRDICCALIBTA LAND RIG 0981 4132019 RI Daily Information WeatherTem".fare(7) Wind Days LTl(days) Days RI (days) PDB Overcast -1 0 NE® ] MPH 410 Safety Incidents - Near Miss Gate Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type *Occur Lasl Date Next Dafe Itlays) Rig inspection 3 4152019 452019 1 Safety Meeting 3 4152019 4/612019 1 Casings seat Cas. Type OD(in) ID lin) Grade Top(ftKB) I Bottom (fine) I TVD BOL(ffKB) Run Dale CASING 13310 12.d2 L -80 -2A20.0 2,420.9 2,080.1 521 00 CASING 95/8 868 L80 -0.9 8,]2].0 ],835.0 W12010 LINER 512 4.09 L-80 4,9080 12,142.0 3,935.6 611W2010 Last Cementing Cementlng Bert Dace: WN2610 Stan:CASIN ,8,727.UUKB Comment .IS X TOP(RKB) Top Meu Mee Bbn (fU(B) C. 1 6,339.0 Volume Calcdalions 8,]21.0 Planned 500' Above top of N Send Job Information Job Ph... warmed Bert Date stare Dace End Data 150 Duration (days) WORKOVER 4/3201900:00 413201900:00 am Daily Summary Operations 2" Forecast Contains NU of BOP. Fill back aitle with 30 bbB 9.0 lung bane. Test BOP. RD BOP Test emanation. Full Bonder, Plug and BPV, pull tubing hanger, circ down tlt9 volume. 2M Summary Roundidp trucking to Mad an 9.9 poll NaCl. Conduct BunM.ad Kill with 9.9 ppb Nad, install BW and ND tree, NU BOP. Dominion at 07.00 Nippling up BOPS. Time Log start End Cum Dur Time Time Durlhr) (hr) Phase Opt. Act. Plan Oper. Descr. 00:00 07:30 750 7.50 Wo 1 P Bring weight of true in pen up to 9.9 PPG (441 , load 60 joints of 5" NC50 unit lupe In pipe shed and tatty same, 9utall steam hose In source box to thaw same. 07:30 09:30 300 9.50 W.O. M 8 P DD PPG NaCl brine arrived loaded pits win same, prop to kill wall, and work on boiler. 0930 11.00 1.50 1100 W.O. M 9 P PJSM, rg up blowdawn hose to S annulus, inspect lines and ensure correct One up. Perform well lull swatch, balanced 1 BBL 9.9 PPG NaCl brine down tubing, at 3 BPM roe, initial pressures TBG 142 PSL A annulus 82 PSI, B annulus 230 PSI. Final pressures TEG 3%. A annulus 171 PSI. B annulus 300 PSI, shut down and monitored Pressure while fining up to Bullhead down B aredus. TBG on Vacuum, A annulus 144 PSI. B annulus 300 PSI 11'.00 13-30 2.50 13 50 W.O. M 9 P Perform well kill operation, bullhead 900 BBL of 9.3 gPPG model brine, de Pressures o TBG Vacuum PSI, A annulus 144 PSI, B annulus 3300 PSI, Final pressures were TBG 349 PSI, A annulus 306 PSI. B annulus 280 PSI. Note maotlmum pressure seen was TBG 349 PSI, A annulus 306 PSI, 3 annulus 340 PSI, 1330 1800 4.50 i 11.00 W.O. M 11 P Sbul down -and well for 2 Hours. TSG 80 PSI, A annulus vacuum. B annulus no PSI. Bled W Bing b bleed trader through 12" hose alt gas, to xem with a very s8ght blow. 18:00 19:00 1.00 ISO W.O. M 1 P PJSM and pefmtt actions to ND free, NU BOP. Diswas se regi 9f BPV, 18:00 00 W 5.00 24.00 W.O. L 5 P Install one. ND bee -u into RIS 0OP bey, I ...... Blau king Plug. NU BOP. as Readings Avg Background Gas 1%) Max Background Gas 1%) Avg Connection Ga. (%) Max nnectipn Ges (%) Avg Drill Gas I%) Max Drill Gas (%) Avg Trip Gas 1 A) Max Trip Gas (%I Daily Mud Volumes TanklAdtlitionlLoss Type Des Volume (tiff) ---74Z-0 Tank Sunace Hole Hole 695.0 Lees Fmmahon 1071 a Cumulative Mud Volumes Active Volume (bot) Hole Volume (bbl) Atldltlons (tiff) Cum Atltlltions (bbl) Losses (bbll Cum Losses but 8390 895.0 0.0 00 1,0]10 1,28fi.0 Daily Contacts Position Contact Name Company Tine Email office Mobile Eni represenettva Steve Lawrence Ent Dulling Supv. Ent represenlows Robert Chad end Bulling Supv. Em monasteries. Much Ellington Ed Rip Clerk alirgdarkedoyont 5®enipatrobum.co an 907-685-0722 Eel repreaent.l. Geoff Ackerman EN HSE geoffa.lonmm@Rupstroleum.co 907$85-0721 Tod Push Richard Twedt Nom. Tool Pusher Tod Push Bran Federson NordM Tool Pusher Tool Push June Morse Rush. HSE rigmanagerdg4®nadocalistacom 907670-8604 Personnel Log (P( 8) company Serv.Tyne Wont HMr) Stand H@n Count Note BHGE (VeMo) 12.50 1 12.5 Hours M, Swaco Mud vad Mud engineer 12.50 1 12.5 Hours ASK Company Men 12.50 2 25 Hours Peak Equipment Operalms 12.50 2 25 Hours GBR Pipe Heading 12.50 3 3].5 Hours Jawbs Equipment Opurdirs 12.50 4 50 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/6/2019 Report 0: 3 Page: 2 of 2 Personnel Log (150B) Company Sol. Type Work N IM) Stantl-by H IM1n count Note SHOE (ntn11R) N.M. ESP1250 NaMic Personnel 12.50 ] 21 8].5 Hours 282.5 Hours BOP Stack 8 Components DeacrlPtlon Start Data Last Certification Data Pressure Rating Ipal) Type Maka Motlel ID Nom lin) PRange (psi) La[Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Data Entl Data liner Size Qnl Volume Per Stroke OVermna lbbVstk) Max Pleasure lPsR Date DePIM1/lace) Slow Sptl Strokes topml —P (Rad) ER Iy.) OFlow 19pm1 Daily Bulk aUPPly Item Otoo aptlon: no Pmenl Fuel Ung Lund!: gal us Unit Size: Note: Data Consumes OISI2019 682.0 Recelvetl 682.0 Returnee euro Con sumetl CUm RaeeNea 1,291.0 1,291.0 Cum Returnetl Cum On Loc 0.0 0.0 Note Supply Rem Description: Rig rue/ Unit Label: gal us Unit Size: Note: Dab Consumed 4/SI20t9 498.0 R.UIVetl 9,800.0 Returnetl Cum Consumetl Cum Recelvetl 2.151.0 16.6]20 Cum Rand rnetl ]Co. On Loc 0.0 14,521.0 Note Supplyltam Deaoaperese Rig Water UNt Label: tel Unit Size: Note: Data Ic.nsunded 4/5/2019 27.0 0.0 Recelvetl Returnetl Gum Consumetl Cum Recelvetl 151,0 143.0 Cum Returnetl Cum On Loc 0.0 92.0 Nota Last Authority Visit Dale I Tot Ina, Nb, Total I.N.C. number Comment STOP Cards ubmitied Company p Rets Com NORDIC-CALISTA SERVICES 1 PJBM General Notes Comment: Well Name:P07 OR Wellbore Name: e: OPO4-07 Well Code: 23893 ani Job: WORKOVER �C111111 WCER Level: Daily Report Date: 4/612019 Report #: 4 Page: 1 of 2 Well Header PemdVconcesslon N° Operator SuUsldlary Initial Lahee Code AOL -388583 ENI PETROLEUM ENIPetmleum CcAme DEVELOPMENT WELL Rotary Table Elevation m) blame Level to) Flet Flange (R) RKB -Base Flange (R) RKB -Tubing Spool Ih) 53.20 12.20 Rigs Rig Name Cpntrectr Rig Type Rig Num Rig Start Det. Rig Release nate RIG NORDIC CAIJGTA LAND RIG 0981 4132019 Daily Information Weather Temperature (°F) Wind Days LTl (days) nays RI (days) P08 Clear -2.3 NES II MPH 410 Safety Incidents- Near Miss Data Category Type Subtype Soviety cause Lost done? Comment Safety Drills Days Until Neat Check Type If Occur Last Date Next Date day:) BOP Pressure Test 1 4162019 4/1312019 ] Rig Immune., 4 41612019 4/)12019 1 Baldry Meeting 4 416/2019 402019 1 Casings seat Cas.Type I On lin) to (in) I Grade I Top Bili Bottom IRKS) I TVO Bat.(ftKB) Run Data CASING 133/8 12.42 L40 -2,420.8 2.420.9 2,O60.t 521/2010 CASING 95/8 808 LBO -0.9 8,]2].0 3,8350 fil1/2010 LINER 512 4.89 L-80 4,9080 12,142.0 3.9356 61132010 Last Cementing Cementing Start Dat: 6212010 Sting: CASING, 8,727.( M(B Comment 510 p Top (RKB) Top Maas Meth BM IM4B) Com `lTop Volume Calculations 8,727.0 Planned 500 Move lop of N Sand Job Information Job Phase Planned Start Debt Start to End Date P50 Duration (days) WORKOVEft 41120190no0 41M01900DO 0.00 Daily Summary Operations 24h Forecast Continue with BOP toning, dear and clean dg Poor of test equipment. Crena lifts to swap out ESP equipment he pulling complance. Pull hmga and space out in BOP, circulate tang volume, pull completion. 24h Summary NO BOP, bed pipe In pipe shed, reteva lest dad in wellheed Rig up east pint, test BOP equipment. NOTE: AOGCC Guy Cook waived wibms to BOP test. operation 007.00 Testing BOP'S. Time Log Stan End Cu. our Time Time our (ea) (hr) Mae. Oil Art. Plan Open. Domr. 00:00 MISS 8.50 6.50 W.O. C 5 Nipple up a PE, make up choke and kill lines connect accumulator Mae and function test BOP. 0630 0900 250 9.00 W.O. C 5 P Lower set of rams not funNoning correctly, replaced hydreulb Mlings in mm door face, cleaned seals and reeasmethod ram. Funerma tsl lower pros all good. Center stack and secure same, imtll flow nipple and air up boat. 099 3: 0 4.50 13.50 WO. C 25 P Make up dummy test joint wdh floor valves and side entry pump in sub. Ruled test pint wide upper Porlbn 0 Vidont leak handed lest dad 13:30 17:30 0.00 17.50 W.O. C 125 P While load pipe in pipe shed, relieved test dart with monshat. 17:30 00.00 550 24G0 W.O. C 12 P Confirm (Mid lineup, assign someone to monitor IA. Attempt to sup pack, leak at Mail. Tighten and continm to Mid pack, leak at choke hose Contact. Replace. Pink pack, test to 2509 psi low / 3500 pd high. Good body test. Conduct eOP Test to 250 pd low / 3500 psi high win 4-12° and Y tst)olds. Test gas alanna. As of MILl A on slight vacuum, OA M 220 Gas Readings Avg Background Gas (%) Max Background Gas I%) Avg Cannedbn Gas I%) Max Connection Gas l%) Avg Grill Ges (%) Max Drill Gas (%) Avg Trip Gaa (%) Max Trip Gas (%7 Daily Mud Volumes TmIdAdditionlLoss Type Des Volume (bbl) Tank Suds. 679.0 Hole Hob 6950 Loss palmetto Cumulative Mud Volumes ACUve eilumelbbp Hale Voluone(bbl) AddMpm(bbi) Cum Additions (hot) Loases(bb) Cum Lomas(bbl) 1,374.0 695.0 S.0.0 00 1,2880 Daily Contacts Position Contact Name Company Title I Small I Dome Mobile Ed repressin Steve tawren. Enl DNIIUIg Suur. Eni repreaentad. Report ONeal Ed Drilling Saw EN representable much Bdlbgton East Rig Clerk ekrigcterksdoyonl S&N,edobum.co an 907485,0722 Em repremnleble Geaff Ackarman Eni HSE geoffackemmnl8�enipehobme cc 907405.0721 Tool Push Richard Teel Nordic Tod Pusher Tad Push Brian Pederson Nortlic Tool Pusher Taal Push Jason Morse Nordic HSE tig.an agecdg4litnomb.fsLLcop 97470-8804 Personnel Log (POB) CO."" Sam. Type Work H (la) stand-by H (M) Count Note FIDE (Vel.) Wellhead 12.50 1 12.5 Hours MI See. Mud engineer 12.50 1 12.5 Hours ASRC Company Men 1250 2 25 Hours Peak EquipmentOperabrs 12.50 2 25 Hours GBR M. Handlitg 1250 3 37.6 Nours Jacobs Equipment Operators 12.50 4 50 Name BHGE(Cannibal ESP 12.50 7 87.5 Hours Nmdo Work Personnel 12.50 21 2625 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 416/2019 Report #: 4 Page: 2 of 2 BOP Stack & Components Dsscrlpnon Stan ooh Last Certification Date Pressure Rating (psi) Type Make Model ID None(in) PRange (pai) Last Can Data Slow Circulation Rates Pump Number: Make: el: aborigine I End pais Liner Siae(In) Volume Per Stroke Override(bMhM) Max Pressure(psq Data I Depth(MUI) Slow Sptl Shokra (.pm) P(PoR EN(%) aNo. (gpm) Daily Bulk SdPPIY Item Deserlptlon: Equipment Fuel Unit Label: gel us Unit Size: Note: Dais Consumetl Received 4lelzol9 Ono Ona Returnetl Cum Consumed 1.Toz.a Lum Received vozo Cum Returned Dp Lum On Lee 00 Note SupP1Y Item Castle Rig Fuel Unit Lapel: gal us Use Size: Note: Dais Consumetl Recelvetl 0/612019 tppp.0 ep Returnetl Cum o umetl 3,1510 ns Gum Ranlvetl 15,0]2.0 Gum Returned 0.0 Cum On Loc 13,521.0 Note Supplyltem Description: Rig Water Unit Label:bbl Unit Size: Note: ate Dpnsturned Roeoleed 41512019 21.0 el) Returned Cum Consumed cl Cum Received 1430 Nm Returned 00 Cum NLoc T1.0 Note Last Authority Visit Dais Tot map. Nor Total I.N.C. number Comment STOP Cards Submitted Company tl Rph Com NORDIC-CALISTH SERVICES 1 PJSM General Notes Comment: Well Name:P070R Wellbore Name: e: OPO4-07 Well Code: 23893 Rite Job: WORKOVER eIt 011 WCER Level: Daily Report Date: 41712019 Report #: 5 Page: 1 of 2 Well Header Pamitl oncessian N' Operator Subsltllary Inldal Lehee Cede ADL -388583 ENI PETROLEUM ENI Petroleum Co.lnc. OEVELOPMEN' WELL Rotary Table Elevatbn IS) GmunE Level (ftl Fear Flange (k) need. - ..as Flange (ft) RKB -Tubing Spool (ftl 53.20 1220 Rigs Rig Name Contractor Me Type Rig Num Rig Sart Data Rig Release Date RIG NORDICCAUMTA I LAND RIG 0981 4132019 Daily Information WeatherTempest I -F) Wind Days LTI(days) Days Rl(days) PDB Ovaries( -20 N @ 10 MPH 41.0 Safety Incidents - Near Miss Data Category Type Subtype Severity Cause Lost time] Comment Safety Drills Type 9Occur Last Data Next Date Days Until Next Check (days) BOP Pressure Test Rig Inapectrod Safety Meeting 1 54(/2019 5 4n20f9 41142019 41812019 422019 41812019 ] 1 1 Casings seat Cas.Type Do (in) I to (m) Grade Top (SHE) aagpm(RKB) I TVD Bot(ftKB) I Run Data G15NG CASING LINER 1338 BSB 5112 12.42 8.4, 4.80 L-0 L80 1.,80 -2,420.8 -0.9 4,908.0 2,420.9 2.080.1 S.]2T.0 3,835.0 12,142.0 3.935.6 521/2010 &12010 6/132010 Last Cementing Cementing Start Date: 6812010 Sting: CASING, 8,M7.0ft Comment: 5tg a Top (RKB) i Top Meas Mem Bi (BKBI Com 1 6,338.0 Volume Calculations 612 .0 Planned 500' Above top of N Sand Job Information Job Phase Planned Start Date Start Oath End DaleP50 Ourabon(days) WORKOVER 413201900:00 413201900:00 000 Daily Summary Operations 24h Forecast Complete eullhg Woing, pull ESP sasembty. Clear and clean rig Poor. Load in 5' OP and 2-]B' work spring. Load In BOT Cbaroul BHA. 24h Summary Complete BOP lest Remove BPV, pull hanger, rig up ESP cable and Capillary fines intends Ley down Wbirg josts W 43]3' MD. Operation at 07.00 Pulling out of hale with ESP completion at 2,000MO Time Log titan Time End Time our (N) Cam our I (hr) Phase Our. Act. Plan Clear. Descr. 0000 08.30 850 8.5D W . G 12 P continua to test ROPE 250 PSI low and 35M PSI high for 5 minutes each on 412" and 5" pipe, mm accumulator depressed test intlial pressure 3000 PSI, draw dawn pressure 20% PSI. 200 PSI recovery 21 seconds. full recovery ]t seconds, a N2 bottle average 2962 PSI. fig dean test equipment. 08'30 09:30 1.00 9.50 W.O. A 25 P Blow down tap time and perform rig servha. 0930 2:0 300 12.50 W.O. A 5 P PJSM, conduct lift missing with at parties, Willard Jecolow chane remove partial ESP cable sF;Tand spacial, alangw partial capillary spool and species. Set empty capillary spool and spoil on dg Mor along with ESP peddler and empty ESP cable spoiler. 12:30 1400 1.50 1-400 W.O. L 5 P PJSM, remove 4" IW type'M1P SW, and Install landing joint, ensure 0 pressure on A annulus, and loaded out look down screws, prep to pull tubing hanger. 1400 1530 1.50 1550 W.O. L 5 P Put Wbing hanger working weight up had 100K, with tubing hangar pulling free at 205K hes up weight I ISK. Pun robing harputo floor, perform electrical checks at,metator. 3.2 phase to phase, add phase to ground infinity, removed ESP cubs from penetrator, disconnect capillary line, break out lubin0 hangar and lay down same. 1590 1630 100 16.50 W.0 L 9 P PJSM, for Pulling out of hole with ESP completion, rigged up and pump H 50 B8L 0.8 PPG NaCl dawn tubing at 2.5 BPM rale. 250 PSI, nate caught pressure at 10 BBL away. i6 30 00:00 I ].50 24.00 vi 4P u oW of hale with E core m 45' W 43]3 (.3110 ), spoo ng SP cable and dapOlaryIna adding 10 BPH 9.9 PPGNeCI b(nmdown AannWuatmelel d4placemeM. Cimulate down table, every 3000'. Gas Readings Avg Background Gas I%) Mas Background Gas (%) Avg Can necnod Gas (%1 Max Conneound Gee(%) Avg Drill Gas I%) Max pull Gas I%) Avg Trip Gas (%) Max Trip Gas (%l Daily Mud Volumes TenklAdditionlLuss Type Des valume("I) TankSuhece Hole Lata Hole Formation fiP.O 695.0 220 0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (till Medicare Joel) Cum Addilons (bbl) Losses (bbl) Co. Lasses lay) 1,312.0 695.0 0.0 l)0 220.0 1 1,5080 Daily Contacts Position Contact Name Company Title Ended oftlae I Middle Edi reDfesenmliva Edi remesentallve Eni representative Eni representalrva Tool Push Tool Push Tool Push Steve Lawrance Rosati Ordeal Mitch Billington Geoff Ackerman Richard Tweet Brian Pederson Jason Morse Enl Eni Ent Eni Needs Nordic Ni IXYling upv. Urging So,. Rig Clam HSE Tool Pusher Tool Pusher HSE akrigderkedoyoni 5diian,simledm.co in geonii,kednan®enipabaktum.co 907-685-0722 WTA85-0721 907-670-8804 Personnel Log (POB) Company Serv. Type Work H @n Stand-by H fin) Coot Note SHOE (Vanish) Wellhead Mi Sworn Mud engineer ASRC Company Man 1 50 12.50 12.50 1 12.5 Hours 1 12.5 Hours 2 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 417/2019 Report M: 5 Page: 2 of 2 Personnel Log (POB) Company Sam. Type I Work H(hill Stantl H(hr) CountI Note Peak GSR Jacobs BHGE(Cenldlll) Nortlic Equipment Operators Pipe Handling Equipment Operators ESP Nordic Personnel 12.50 12.50 12.50 12.50 1250 2 9 4 ] 21 25 Hours 3) 5 Hours SO Houn 0].S Houn 202.5 Hours BOP Stack it Components Oesc"pilon Start Date Last Certification Date Pressure Rating (psi) Type Make Model ID Nom (in) PRange (pai) Last Cert Data Slow Circulation Rates Pump Number: Make: Mggp(: Starttate End Date Liner Site (Int Volume Per Stroke Override lbbllstk) Max Pressure(pal) Date OeptM1 (kKB) Slow Sptli Spoke.(spm) P(pal) En Daily Bulk Supplyltem Desalpbon: EquipmentFuel Unit Lidal: 0alus Unit Size: Note: Dah Consumed Receivetl 4n12019 452.0 452.0 Returned Cum Consumed Cum Received 2,159.0 2154.0 Cum Returned 00 Cum On Loc Note 0.0 Supply (tam Description: Rig Fuel Unit l -abet: gal us Unit Size: Nate: Oete Consumed Recelved Moll) 1.4310 0.0 Returned Cum Cgnaumatl Cum Receivetl 4,5820 16,6]20 Co. Return¢tl 00 Co. On Loc Note 12,0900 SUPMYlddn Deaodpgan: Rig Water Unit label: bbl Unit Size: Note: Data Consumed Received 4n12019 120 0.0 Returned Cum Coneumetl Cum Receivetl 04.11 1430 Cum Returned 0.0 Cum On Loc Note 59.0 Last AUMonty Visit Date Tot lnsp. Nbr DMI I.N.C. number Comment STOP Cards Su m tied Company P Rpta Com N RDIC-CALISTA SERVIULS 2 PJSM General Notes Comment: Well Name: P0 Wellbore Name: me: OPO4-0707 Well Code: 23893 Job: WORKOVER ani WCER Level: Daily Report Date: 41612019 Report 6: 6 Page: 1 of 2 Well Header Permlticonceasion N° Operator Subsl0lary Initial Lan as Code ADL -388583 ENIPETROLEUM ENI Pelmleum Co. Ina DEVELOPMENT WELL Rotary Table Elevation (n) Ground Levin put First Flange (til Hae - Base Flange(k) RKB -Tubing Spool (til 53,20 12.20 Rigs la Noma Contreatw RIO TVpO Rlg Num Rig Star[ Data Rig Release Data RIG 4 NORDIC CALISTA IAND RIG 0881 4132019 Daily Information Weather Temperature(°F) Wind Days LID (days) Days R! (days) POB Overcast t5 WNW @IO MPH 410 Safety Incidents - Near Miss Date category Type Subtype Severity Cause Losttimei Comment Safety Drills Days until Heat Check Type .Occur Last Date Next Dale (days) BOP Pressure Test 1 4/)12019 4/14/2019 6 Kick While Tripping Dnl[ 1 4/82019 4/15/2019 ] Rig Inspection 6 4/02018 4/92019 1 SafetyMeeting 8 4/82019 4/9/2019 1 Casings seat Cas. Type 00 (in) ID in Grade Top (kKB) I Bottom (kKB) I TVD Bot (kK8) Run Data CASING 13 3/0 12.42 L -SD -2,420.8 2.920.9 2.080.1 5212010 CASING 9 518 8. 68 3,835.0 6112%0 LINER 512 4.89 L40 4,908.0 12.142.0 3,935.6 6/13201) Last Cementing Cementing Stall he 61312010 String: CASING. 8.727.OkKS Comment: Sol p Top (kKB)Top Meas Mem Bbn (kKB) Com i 6,339.0 Volume Calculations 8,]2].0 Planned 500' Above lop of N Sand Job Information Job Phase PlannetlStan Date Start Data End Date P50 Duration (ears) WORIGAEft 4/3201900:00 4n20t900.00 0.00 Daily summary Operations 241h Forecast Cleamut SHA 2.7fir he 8 6" drill woristang. Conduct cleanout me into 5' liner and scraper Complete roller change out and maintenance on Irou Roughneck. Single In with Baker Vented (Vacs) with pipe pipe across TAM salon, aa. 20 summary Complete puging out of hole and laying down ESP completron. Service top drM<. send changing miter spinner on iron roughneck. Operation at 07.00 Prepping clean out BHA and welding an Iron mughtreck. Time Log Stan EndCum Dur Time Fine Durind liar) Phase Opr. Act, Plan Oper. Deacr. 00:00 0230 2.50 2.50 W.0, L 4 P Fee out of hole with ESP wmpletdon ham 4373' 10 2579. filling A annulus with 10 BPH of 9.9 PPG N.CI ludo.. 02.30 03:30 1.00 3.50 W.O. L 9 P Pump 40 BBL 9 9 PPG NaCl brine down tubing at 3 BPM 2600 PSI. Remove old tubing ft. pipe shed. 03.30 11:00 7.50 tt 00 W . L 4 P Pull out of hole win ESP completion from 2679'W ESP, filling A annulus win 10 BPH of 9.9 PPG NaCl bmre, mayearg old tubing from pipe shed as required. At 2009 pulled welwim crud s, pump ul a tubing volume of 30 BBL of 99 PPG ukCI bene at 1.5 BPM PSI. 11-00 1600 500 16.00 V5- L 5 P Pull and lay dawn all ESP equipment, had significant scale on by of pump from inside tubing with scale on OD Of motor and seals. Had washed out spot oa shroud locale at Dump intake. 1600 1 :00 1.00 1700 W.O. P PJSM.coMuctt meeting, remove cable -sp-oMMKE spender from rig flaw along with capillary spooler and cap lube removed from OP0407. 17:00 00:00 7.00 24.00 W O. L 5 P Offered Used tubing from dg. Move used ESP edul mens to bakes calwalk, bad in remainder of IF dell pipe. Use Logisfics Zoom Boom the load in Baker fishing tools. Clear and clean rig bell, mobilize tools and pads to conduct change out roller on Iron Roughre k. Gas Readings Avg Background Gas l%l Max Background Gas (yd Avg Connection Gas l%1 Mex Connection Gas �h) Avg Drill Gas (%) Max Orill Gas(%) Avg Trip Gas (%) Max Trip Gas (%l Daily Mud Volumes TanMAdiition/Loss Type Des Volume (told) Tank Sudece 310.0 Hale Hob 730.1 Lass FoME8car 2640 Cumulative Mud Volumes Active Volume(bbl) Hole Volume (bbl) Additions (add) Cum Additions@lel) Lossas(bbil Cum Leaves(bbp 1,048.1 ]30.1 0.0 0.0 204.0 1,i]00 Daily Contacts Position Contact Name Company Title Email OMce Mobile End reDresenlenve Stave lawrema Eni D(Nling Supv. Eel repr.... taku. Robed ONeal Eal pXling Suw. End representative Mitch BilOnpton End Rig Clerk aV,,kM1sdoyoal SQenipstroleumoo an 80]585-0]22 Eni reprssenlaldve Deep Ackerman Eni HSE geoff arlerman@enipabodeum to 90]505-0]21 Too[Push Richard Tweet NDkk Tool Pusher Fuel Push Brian Petletson Norddc Tool Pusher Tool Push Jason Morse Wall. HSE rgmenager rig4ttnmdic-cadista.pom 90]-6]0.8601 Personnel Log (P( iB) Company Barry. TVP. We H(hn SM1ntlbyHlhn count Note ME WeIlM1eatl 12. 1 12.SHoura W Swacp MW engineer 12.50 1 12.5 Hourm ASRC Company Men 12.50 2 25 Hours Peak Equlated Operators 12.50 2 25 Hours GBR Pipe Hand i, 12.50 3 37.5 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 418/2019 Report #: 6 Page: 2 of 2 Personnel Log (POB) Company serv. Type Work H Hurl Standdy x (nr) count Note Jacobs BHGE (Cenlri ifl) Nardlc ERuipmenl OperaiPra ESP Nortlic Personnel 1250 12 50 12 50 4 7 21 SO Houn 87.5 Hours 282.5 Hours SOP Stack & Components BTUtPtion ShrtDah Last Certification Data Pressure Ratio,(pap Type Make Motlel ID Nom (In) PRango(Psi) Leet Cert Dela Slow Circulation Rates Pump Number: Make: Model: Start Dish End Date Liner Sim (in) Volume Per Stroke Override Hb llshl Max Pres sur a 1psg Date Depth HaKB) Slow Bpd Strokes law) I P(p8) ENI%)r 0Fi.jibbed Daily Bulk Supply Ilam Deacdptlgn: Equipment Fuel Unit Label: gal us Unit Sixe: Note: Otle Consumed Received 41812019 2590 Recel Returnetl Cum Consumed Curd! eceivetl 2.413.0 2,413.0 Cum Returned Cum On Loc Note 0.0 00 Su"U'Rem Descdpfign: Rig Fuel Unn Label: gal us Unit Siee: Note: Oale Conaumed Received 4/8/2019 15190 0.0 Returned CUm Consumed Cum Received 6,1010 16,672.0 cum R.WUnw Cum On Loc Nola 0.0 iQA1.0 Supply Item Description: Rig Water Unit Label: bbl Unit Site: Note: Date consumed Receivetl 41812019 224.0 270.0 Returnetl Cum Conaumed 3080 Cum Riscelve4 413.0 Cum Returned Cum On Loc Nate 0.0 105.0 Last Authority Visit Data Tol irtp. Nbr TINaI I.N.C. number Comment STOP Cards Submitted Compan M Rpts Com NORDIC-CALiSTAS RVICES 3 PJSM eneral Notes Cerebrate: Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 q� e'e Job: WORKOVER eni WCER Level: Daily Report Date: 4/9)2019 Report 1 7 Page: 7 of 2 Wel Header PermlNConcession N. Operator Subs tllary Initial Lahee Code AOL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevallon(it) Ground Le 1M) First Flange(k) RKB-Base Flange(N) RKB-Tubing Spool o, 53620 12.20 Rigs lag Name Goal Or RIg Type Rig Num Rig Start Data Rig Release Date RIG 4 NORDIC CALISTA LAND RIG 0981 41312D19 Daily Information Weather Temperature ('Fl Wind Days LTI(days) Days RI (days) POB Gear WC @8' -85 NE@12 MPH 34.0 Safety Incidents - Near Miss Data Category Type Subtype Severity cause Last on Comment Safety Drills Days Until Next Check Type Aoccur Last Date Next Date (days) BOP Pressure Test 1 4912019 411412019 5 Kick While Tripping Dail 1 4/812019 411512018 5 Rig Inspection 7 4/92019 4/1012019 1 Safety Meering ) 4/912018 4/102019 1 Casings seat Cas. Type OD (in) to (in) I Grade Top RKB) IBaNmn INKS) I TVD But (MIKE) Run Data CASING 13318 -8 242 L-00 -2.4208 2,420.9 2,080.1 521/2010 CASING 95/8 8.68 L80 -0.9 8,]Z].0 3,835.0 8/112010 LINER 512 4.09 L-80 4,908.0 t2,142.0 3,935.6 6/132010 Last Cementing CamenNng start Date: 602010 String: CASING. 8.727.01913 Comment: Stg a Top (OKB) i Top Meas Mem 1 Bbn (HKB) Co. 1 6,339.0 I Volume Calcumom. I )2].0 I Planned 500' Above top of N Sand Job Information Job Phase Plenrxtl Start Date Start Date End DateP50 notation (do,) WORKOVER 4132019 W:W 4I32O1900W 0.00 Daily Summary Operations 24h Forecast RIM with BHA to abuse liner hanger at 851T. Stand back) stands, make up remainder of angles and then RIM on Spends whim cmtducrog clamput operation ran into 5.5- it. and sc apar acress TAM stiffing area. POOH, prepare Or mooing TAM Bridge Plug. 2" Summary Service Iron Roughneck 8 Top Drive. Single in Baker Venron (Vaal Cleanout BHA on 2-71W wmksting and Men an 5- drill pipe. Conduct cleanout ran iMa S finer and scraper across TAM semng Brea. Grenada. at 07.W RIM .0 dismal BHA @ 7,790' MD Time Log Start EndCum Dur Time Time Dur MT Ml Please Opr. Ac[. Plan Offer. Dreamt. fill 03:90 3.00 3.90 W.O. M 5 P PJSM, load add step 5" all pipe in pipe shad. along with 2 7/8" PHS robing, while turnaround to work on replacing rollers on Iran roughneck pipe spinner. 0300 09:00 800 900 Install wear ring and engage look down screws to sasses, same. Move GBR 2 AB" GSR tons from pipe shed to ng floor. Serdce blacks and LW drive, move Baker Vac foal while working on Iran roughneck. W:W - a. 9.00 18.00 W.O M 5 P Make up Baker Oil Teol VAC Tool clean out BHA, with 20 joints of 2 7/8' PHO along with 9 518 romper, boot baskels, magnet, jars and bumper sub. 18.00 0000 6. W 2400 W.O. M 4 P RIM with cleanout BNA on angles with 5' all pipe, fill lockable with 10 bbls per hour of 9.9 ppg Nal Run to 4000'dod. undulate down drill qpm. Gas Readings Avg Background Gas I%) ----"audit Gas I%) Avg Connection Gas P%) Max Connection Gas 1%) Avg Drin Gas (Y•) Mak Drill Gas (%) Avg Trip Gas PA) Max Trip Gas (%) Daily Mud Volumes Ta.WAddIllpnlLpa9 Type Des Volumelbb0 Tank Surface 318.0 Hole Hole 727.2 Loss Formation 235.0 Cumulative Mud Volumes Active Volume Mbl) Hole Volume @bl) Additions (bhpLum Addition. (bhp Losses (bhp Cum Losses (bhp 1,103.2 727.2 0.0 0.0 T35.0 2,005.0 Daily Contacts Position Contact Name Company Title Email Olgee MoblN End representative Steve Lawrence End Drilling Supv. 0PPtl1 riggy-cam Ent nomesentalNa Robert ONeal Eni Drilling Supv. OPPtldIlbgieni.com Eni representative Mi1N&Ilington BillRig Clark iddgclerksdoyoni5fMnecn 907805-0722 But representa0re Card Ackerman End HSE geoff.ackemren;.N.cmn W7885.0721 Tool Push Richard Teeth NOmIC Tool Pusher Tool Push Jake Had, Nordlc Tour Pusher Tool Push Jason Mance Noalic HSE Nommacer.ng4@noNlc-celketa.com 907870-8604 Personnel Log (POB) Company Be,. Type work H (nal Stal H Mn could Nose BH E(Valw) Wellhead 12.50 1 12.5 Hours all Sworn Mud engineer 12.50 1 12.5 Hours GOR Pips Metalling 12.50 1 12.5 Hours ASRC Company Men 12.50 2 25 Hours BHGE (CentnlM) ESP 12.50 2 25 Hours Peak Equlpmenl Operatme 12.50 2 25 Hours Jacobs Equipment Operators 12.50 4 50 Hours Nordic Nordic Personnel 12.90 21 262.5 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/912019 Report #: 7 Page: 2 of 2 BOP Stack 8 Components Deacepttim Start Date Last Cerebration Date Pressure Rating (psi) Ty" Make Modal1 ID Nom (in) P Range (pail Last Cert Date Slow CirculationRates Pump Number: Make: al: Start Dale End Date Liner Size(ip Volume Per Stroke Override(bbllsltrl Mas Pressure (pal) Data I Depth RtKB) I Slow Spd Strokes (spin) P(Psi) I EN(%1 0Flow (g,nm Daily Bulk Supply Item Description: Equipment Fuel Unit label: gal us Unitsize: Note: Dale Consumed Recelvetl 419/2019 322.0 322.0 Returnetl Cum Consumed 2)35.0 Cum Recefvetl 2,)350 Cum Remmetl Cum On Loc 0.0 0.0 Note Suppiyltam DinniLPon: Rig Fuel Unit Lebel: gal us Unit Size: Nate: Date Consumed Recelved 41912019 1.655.0 Returned Cum Consumed '!,)56.0 Cum Received 166720 Cum Returnetl Cum On Loc 00 18,916.0 Note Supply Nem Daecrlp#on: Rlg WeMt UnIlLabel: bbl Unit Size: Note: Data Consumed Received 4112019 12.0 0.0 Returned Cum Consumetl 320.0 Cum Received 913.0 Cum Returned Cum On Loc 0 0 93.0 Note Last Authority Visit Dab Tot usp. Nor Tota[ I.N.C. number Comment STOP Cards Submitted Company VRole Com NORDIC-CALISTq SMICES 2 PJSM Oenam Notes Comment: Well Name: P0 Wellbore Name: me: OPO4-0707 Well Code: 23893 /�np Job: WORKOVER lCllllll WCER Level: Daily Report Date: 4/1012019 Report #: 8 Page: 1 of 2 Well Header PermI ....at. N° Operator 5ubsitllary must Latee Code ADL -388583 ENI PETROLEUM 15.M, Co. Inc. DEVELOPMENT WELL Rotary Table Elevation iMi umada Level (Mi First Flange to) RKB - Base Flange 1-1 1 Men - Tubing Spool int 53.20 12.20 Rigs RigName Coneecmr Me Type Me Num RIB Start Data Rig Release Dale RIG4 NORDIC CALISTA LAND RIG 0981 4132019 Daily Information WaaWer Temperature ff) wird Days LTl idays) Days R1 (day.) POB Overcast WC -19- B NE a 14 MPH 34.0 O Safety Incidents - Near Miss Dote Category Type Subtype Severity Cause I Loll Mme] Comment Safety Drills Day. Until Ned Check Type 10 ... r Last Data Next Date (days) BOP Pressure Test 1 4n12019 4/142019 4 Kick While TnPPng Drill 2411012019 4/172018 ] Rig Inspection B 411012019 4111)2019 1 Safety Meeting 8 411012019 4111/2019 1 Casings seat Cas.Tpe DD (in) ID (in) Grade Top lRKei Bottom BXB) I TVD But. BKB) I Run Data ING 13318 1242 4802.4208 2,000.1 5212010 CASING 95/8 0.68 L00 -0.9 8,]2].0 3.8350 611/2010 LINER 5112 4.89 L40 4.908.0 12.142.0 3.9356 WIW2010 Last Cementing Common, Start DMe: W12010 Soll CASING. 8.72].O KB Comment: Slg # Top (MKB) Top Meas Meth Bbn (MKB) Com 1 6,339 0 Volume Cakulolipns 8, ,le Planned 500Above top of N Sand Job Information Job Phase Planes StartDate Strrt Oa[e End Date PSO Duration (days) WORKOVER 4/3201900:00 4/31201900:00 0.00 Daily Summary Operations Zan Forecast POOH, prepare for running TAM Bridge Plug. Ian Summary RIB with BHA to above liner hangar at 8517'. Stand back 7 Stands, make up remainder of singles and Men RIB on stands while conducting cleanout operation (rotate Scraper, circulate down 2-710' worksbingl Conduct candour son Into 5112- liner and senator across TAM set8ng area. POOH to 3104' and LDDP b 2442. Operadon at 07.00 Clearing no Moor and Preparing equipment kv Tam bridge plug son. Time Log Start End Cum Dur Time Time our Bill Mn Paas. OR,. Act Plan Opa, Mae, 00'.00 1000 10.00 10.00 W. . M 4LI nown drill pipe, caught pressure at 20 Was away. Pump tripled! at 52 bbls away, blow down top drive, continue to Chadiansow RIB on singles white mud Pump is being looked at. 1000 16'.30 6 50 6.50 W.O. 6 Conduct deanout son per plan: Wash down wits Venlun canner ladl m 2-7/8' worloding and 9-511Scmper/ dot Basket BHA. Pm shove linertop 152k, SOW ]0k. Conduct cleanout Into SlW oo ed tubing at 6 bpm, 1150-1200 psi, reran, at 10 rpm, odatdng weight105k. Wash downwith 7 stands with no increase in tofque orcimWabon pressures. Rotating weight did drop Mom iOSk tlown W 80k at final depth of 915]'sod. Reciprocate last sound so UM Scraper Nema acress proposed TAM and, Plug sett depth. Scraper son across depth of 837]-046]'sod. 16:30 22.30 6.00 2250 W.O. M 4 POOH wind BHA ham 915]-3f OP, fill backside with 10 bpd plus pipe chelacemanl. 22:30 0000 150 24.00 W. O. M 4 POOH LDDP from 31N to 2442. PJSM, Zoom Boom Tam packers into pipe shad Gas Readings Avg Background Gas 1%) Max Background Ges I I Avg Currentness Gas Phi Max Connecticut Gan (%) Avg Drill Gas 1%) max Drill Gas (%i Avg THP Gas (%) Max Trip Daily Mud Volumes Tanuaeaglgdtpa. ryp. Des vmgma (lobe TankSurface 216 0 Hole Hole 645.9 Loss Fbonalion 1306.0 Cumulative Mud Volumes Active Volume lbbq Hale V0 turns Atlfilions(bbe Cum Addiions(bbi) Losses(bbe Cum Losses Bibb 861.9 645.9 0.0 0.0 1,308.0 3.3110 Daily Contacts Posnr. Contact Name Company Thee Emall Ocoee Mobile End representative Robert Christ Eni Orilling upv. OPPonlrmg@enLmm End represenlaMe Russ Wimmer Enl Drilling Supv. OPPonllmg®eni.cpm 90]4185-0]15 907-3200058 Eel sepmsentalrve Mftch&Ilirgbn End Rig Clerk akrigcleAsdoyonl5@en).com 9074105-0]22 Eel mppeanaltNe Geof Ackaman End HSE geoffackerman@NsLoom 9074185-0721 Tool Push Richard Twedt Noble Tool Pusher Tad Push Jake Henry Nordic Tour Pusher Tool Push Jason Marne Nodic Al Hgmanagevdg4@mdddc-w,I.ta.Com 907-6704604 Personnel Log (POB) Company Sam. Type Werk IN fill 5Mnd-by H fini Count NO. BHGE(voted) a as 12.50 1 125 Hours Mi Swam Mud engineer 12.50 1 12.5 Hours GBR Pipe Handling 12.50 1 12.5 Hours ASRC Company We 12.50 2 25 Hours BHGE(Centridt) ESP 12.50 2 25 Hours Peak Equipment Operators 12,50 2 25 Hours Jambs Equipment Operators 12.50 4 SO Hours N is Nordic Personnel 1240 21 282.5 Hours Well Name: OPO4-1307 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4110/2019 Report #: 8 Page: 2 o12 BOP Stock 8 Components Description stancure Last certification Duh Pmesum Rating (psi) Type Make Model I ID Nairn) Is Range (psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Stan Oeh End Data Llnet sire (int Volume Por Stroke Overrlde(bbllstk) Max Preesurs(psi) Date I Depth (1l I Slow and I Strokes (spm) P (pal) EN IXI O Flow (gDml Daily Bulk Supply Item Description: Equipment Fuel Unit bbel: gal Us Unit Size: Note: etaLonzumad Recelvad fteturnetl 411012019 200.0 2000 Cum Consumed 2.935.0 Cum Received 2.935.0 Cum Returnetl Cum On Loc 00 0.0 Note SASSY Ram Description. Rig Fuel Unit Label: gel Us Unit Size: Note - Date Consumed Recel mut Returned 41IW2019 910.0 60004 Cum onaumetl 8,868.0 Cum Received 22,fi]20 Cum Remrnetl Cum On Loc 00 14,006.0 Note Supply Item Deeoquict: Rig Water Unit Label: bbl Unit Size: Note: Dale Oonsumetl Receivetl Returned 411012019 15.0 0.0 Oum Consumetl 335.0 Cum Receivetl 413.0 Cam Returnetl Lum On Loc 0.0 78c Note Last Authority Visit Date Tot ins, Nbr Total LN.C, numhr Comment STOP Cards Submitted Company 0 Rets Com NORDIC-CALI TA SERVICES I PJSM General Notes comment- Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 Job: WORKOVER ani WCER Level: Daily Report Date: 4/11/2019 Report 9. 9 Page: 1 of 2 Well Header Permi lConcezcI. N° Operalw Subsltliary Initial Lahee Code ADL -388583 ENIPETRDLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table devatlon(tt) Ground Level in) First Flange(dl RKB - Base Flange (tt7 RKB-Tubing Spool (ttl 53 20 2.20 Rigs IN Name LanVamor Rig Type Rig Num Rig Start Date Rig Release Date RIG 4 NORDIC CALISTA LAND RIG 0981 41312019 Daily Information WeatherTemperature ('Fl Wind Days LTI(days) Days RI plays) POB Cloudy, Blowing Snow 88 NE ®2B MPH 138e Safety Incidents - Near Miss Data Category Type Subtype Seventy Cause 1-osttime2 Comment Safety Drills Days Until Next Check Type AOccur last Date Next Date (days) SOP Pressure Test 14R/2019 V1412019 3 Kirk While Tripping Drill 2 4/102019 411712019 6 Rig Inspection 9 4111/2019 4112/2018 1 Safety Meeting 9 4/11/2019 41ID2019 1 Spill Drill 1 41112018 42512019 14 Casings seat Cas.Type I Do (in) to (in) Grade Top(ftKB) I Bottom(ftKB) TVD Bat.(ftKBI Run Data CA ING 13318 12A2 'Lu L-60 -2.420.8 2,4208 2,080.1 521/2010 CASING 9518 Liq A.9 8,92].0 38350 611/2910 LINER 5112 4.89 L-80 4,908.0 12.142.0 3,9356 61132010 Last Cementing Cemendn85hrt Date: WM010 Stdng: CASING, 6.727 OfIKB Comment BE Top (ftKBI Top Meac Meth Bhn (ftK0) Co. 1 8,339.0 Volume Calculations 8,]2].0 Planned 500'Above top ofNSand Job Information Job Phase Planned Start Date Sfarbate End Dste P50 Duration(days) WORKOVER 413201900:00 4/3201900:00 O.OD Daily Summary Operations Uh Forecast POOH packing bark DP and examine Inflatable Packer. Min Summary Complete laying down BOT VAC cleanout BHA. MU TAM Inflatable Bride Plug Packet RIH on hit pipe to 8476'. Dropped bag and positing COE at 8467'. Pump ball down deal string without imaging. Tried different options without seating. Operating rt 0.00 Reverse circulating to retnew 17N' ball Time Log Start End Cum our Time Time our (hr) (M) Phase Opt. I Act Plan Other. Descf. 0000 06:00 6.00 6 00 W O. M 4 P POOH Inyilg down remainder of drill pipe. Speak out Baker VACS Cleanoul assembly and check hoot baskets. Beskels dean. Lay down 2-718° waksh'Ing and BOT vac tool. Af clean. 0600 0830 2.50 850 W.O. M 1 P Ckar t4 floor area, prep for making up TAM Inflatable Bndge Plug Packer. Request Fluid Shat from Prediction, tool broken. Break circulation, calculate depth of fluid at 1580' md. 08: SO 0930 1.00 9.50 W.O. M 25 P Service rig and change riles in iron roughneck. 09:30 2000 10.50 2000 W.O. M 4 P MU TAM Inhatabie Packer assembly. RU -1 with TAM Packer on 63 singles followed by stands to set with center of element at MET 20 OD 21:30 1.50 2150 W O. M 9 P Fill pipe and IA at 28PM for a total of 165 BBLS, 2130 0000 2.50 2400 W.O. M 5 P Dmp 1 Way phenolic ball, Make up totiddve and position doll sMng for WE at MT. Pump down ball at 2 BPM, 36 PSI. Over displaca calculate wlume by 50 BSW without sealing ball. Stopped pumping and discussed option. Gas Readings Avg Background as III Max Background Gas (I) Av9 Connection Gas(%) Max Connection Gaa(%) Avg Ong Gas (%) Max Drill Gas (%I Av9 Trip Gas (%) Max Trip Goa (%) Daily Mud Volumes tanklAdditionlLoss Type Des Volume SM) rank spnaea seta.. Hole Hale 686 e Loss Formation 356.0 Cumulative Mud Volumes Active volume(bbl) Hole Volume(bbp AddiN.na(bb0 Co. Additions(bbp Losses(bb0 Cum Lesses(bb0 1,280.8 686.8 0.0 0.0 3560 3,667.0 Daily Contacts Position Contact Name Company Tme Email Odke Mobile Ent representetNe Robed ONeal EnlDrilling Supv. OPPdnllingQeni con Ent mpresentafwe Russ Wimmer Ent OClllng Supv. OPPdrillingQeni com 907-685-0715 907320.0058 Ent representative Mach Billington Ent Rig Clark, akngckrksdoyonl5iEtenipom 90]-685-0]22 Ent representative Center Ackerman Ent .BE geoeeckermaneffeni.00m 9074 0721 Tool Push Ricbad Twadt Nwdk Tool Posner Tool posh Al Hansen Nodi: Tour Pusher ngmanager rig4@nohJ Cahxta with 907-670-8604 Tool Push Jason Mo. Nod HSE ri9managerrg4®ndiowrd.... 907$70-8604 Personnel Log (POB) Company Serv. Type Work H fir) Stantl ty N(hr) Count Note BHGE (Vete.) Wellhead 12.50 1 125 Hours MI Swaco Mud engineer 12.50 1 125 Hours Tem Packer 12.5(l 1 12.5 Hours ASPIC Company Men 12.5) 2 25 Hours Peak Equipment Operators 12.5) 2 25 Hou. GET Pipe Handling 12.50 2 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/1112019 Report #: 9 Page: 2 of 2 Personnel Log (POB) Company So,. Type Work H(br) Stand-by H(m) Count I Note BHGE( enmkp) Jacobs Nomk ESP Equipment Operators Nam¢ Personnel 12.50 12.50 12.50 3 5 21 37.5 Hours 62.5 Hours 2325 Hours BOP Stack 6 Components Deacrlptionstart Dam Laa[Certllication Date Presnure Ba[Inp lPall Type Make Motlel ID Nom (In) P Rarpe (pap Last Cert Date Slow Circulation Rates Pump Number: Make: Modal: Start Data Enit Data Lmer $ize (in) Volume Per Stroke Ovenitle (bbllsrtr) Max Pressure (psi) Data Depth(fil I Slow Spit Strokas(epnt) Is(Pat) EHI%1 OFIow l9pml Daily Bulk Supply been Demrip6on: Equipment Fuel Unit Label: gal us Unit Size: Note: Date Cansumetl Receivetl 4tl V2019 3610 363.0 Retumatl Co. Compared Cum Rece etl 32980 3296.0 Co. Returned Cum On Loc Note Supply prem Description: Rig Fuel Unit Label: gal us Unit Size: Note: Date Comumetl Receivetl 011112019 1,toD6 0.0 ReNrned Cum Comumetl Cum Receivetl 9]63A 22,6120 Cum Returned m On Lac Note 00 12,9060 Supply Item Description: Fig Water Unit Label: bbl Unit Size: Note: Date Consumetl Recelveit 411112019 126 CO Aemrnetl Cum Caneume0 Gum Receivetl 341.0 413.0 Cum Returned Cum On Loc Note 00 C7 LESIAUITIOnty Visit Data Tot insp. Nor Total I.N.C. number Comment STOP Cards Subly,ittoa Company %Rpm Com NORDIC-CAUSTA SERVICES 1 PJ3M General Notes Comment: Well Name:P070R Wellbore Name: e: OPO4-07 MTN Well Code: 23893 251 a• Job: WORKOVER ea II II WCER Level: Daily Report Date: 4112/2019 Report M: 10 Page: 1 of 2 Well Header PermitiConcesslou N° Operator 5O I Mry Initial Late, Code ADL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation (f0 Grountl Level mt FMngs IRI RKB - Base Flange NU . • Tubing Spots to) I'll 53.20 12.20 Rigs RIg Name ConhacMt Rig Type RIg Num Rig SMrt Data Rig Release Data RIG NORDICCALISTA LANDRIG 0981 41N2019 Daily Information Weamer Temperature YF) Wind Days LIB plays) Dan RI(day.) POB Cliutly, Blowing Snow 41 NE 30 MPH Opium, to 43 MPH 37.0 Safety Incidents - Near Miss Arte Cangory Type Subtype Severity Cause Lost lime? Comment Safety Drills Days Until Next Check Type If Occur Last Data NOW Date (daya) BOP Pressure Test 1 422019 411412019 2 Evacuation all 1 41122019 ]11112019 90 Fire drdl 2 411212019 42612019 14 Kick While Tribal DTII 2 41102019 V1712019 5 Rig Inspection 1041122019 41I 32019 1 Safety Meeting 10 41122019 4/1312019 1 SPIII Dull 1 4111/2019 4252019 13 Casings seat Cas.Type OD (in) IS lin) I Grade Top(ftKB) Bottom INKB) I TOO But. (11116) Run Data CASING 13318 1242 L60 -2p20.8 2,420.9 Z.OBp,t 5212010 CASING 9518 368 L80 -0.9 3]27.0 3.835.0 61112010 LINER 5112 4.89 11 4,908.0 12.1420 3.935.6 61132010 Last Cementing cementing Startpate: 61312010 String: CASING, 8,727,0ill Comment: Stga Top(ftK6) Top Meas Main Ban BIKE) Com 1 6,339.0 Volume CalcNatipns 8,]27.0 Planned 500'Above top of N Send Job Information Jeb Phase Planned Start Dale Start Date End Date P50 Duration (do") WORKOVER 41320190000 413201900:00 0.00 Daily Summary Operations 24h Forecast POOH with Tam packer. Mh Summary After oral cpmmunsatlpns it is suspected that the choke was sheared and could not axil packer, POH, up to 51, overpull on top out. Halt oPer4Wm due M weather (high wands). WOW. Operation at 07.00 Begin POOH wits Tam pecker. Time Log S tare Entl Gum Dur Time Time Dur(m) far) Phase Opr. Act Wan Oisr. Dail 00,00 03'00 3.00 3.00 W.O. M 19 P touched off 0 original SOW anti pulled up to UW. Coati to pump at 2 BPM, 35 PSI wagon sealing bell. Slack o tock over down weight and pumped down W with a pressue, increase to 580 psi than brake over. Tam Rep called non and decided that Me choke must base sheared premafre without any pressure. Decision was made to POOH. 0308 08:30 5.50 8.50 WO. M 4 P Rig up floor to POOH. POOH 1' ng back OP(18476-8070. l k oveaull creeped to 5k overal an tnpoW. Phase3 fimughoul Geld discuss with Superintendent and decade to hall operations due to inability to get medlcal response out at ng. 08:30 00'00 15.50 24.00 W.O. M 22 TW01 Wail on Weather Anempl to All backside, Immediate refms.Indicators that TAM Packer is pal set Make several attempts throughout morning and Osumi full column of fluid Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (A) My Connection Gas (%) Avg prlll Gas A) Max Drill Gas (%1 Avg Trip Gas 1%) Mau'"P... "PGas (%1 Daily Mud Volumes TanIdAkftUMdLms Type Des VOlume(ox) Tank Sudace 639.0 Hole Hole 649.9 Loss Tool 542.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (660 Additions (bbl) Cum Atl firtme (6611 Losses Bing Co. Losses (661) 1.288.8 699.9 0.0 0.0 542.0 4,209.0 Daily Contacts Position Contact Name Company Title Email I Office I MObltc Em represemalwe Robed ONeal End Onlar, Sup, OPPMan"Mrccom End representable Russ Wimmer Em Boiling Sup, oPPdnllin uitwuncom90768&0715 907-320-0058 Ent reprsnnel Milch Whirl Eni Pot Clerk aligclerlcsdoyonl5@ani.com 90]$85-0722 Era nominal Geoff Ackerman Eni HSE gaeffosdurnan@enidom 907665-0721 Tool Push Richard Tweet Nordic Tool Pusher Tial Push Al Hanson Nordic Tour Pusher rgmmnagerrig4ilifnodk-celiata.com 90747011 Toil Push Jason Mone heard HSE rigmanagecdg4@nordiccalisla.com 9074706604 Personnel Log (POB) Company I Sam. Type Werk Hlho Sturall H(hr) Count Na[e SHGE (Velco) Wellhead 12M 1 12.5 on. MI Saaco Mud engineer 12.50 1 12.5 Hours Tam Packer 12.50 1 12.5 Hours ASRC Company Men 12.50 2 25 Hours Peak Equipment Operators 12.50 2 25 Hours GER PIPs Handling 12.50 2 25 Hours SHOE (CentiMt) ESP 12.50 3 37.5 Hou. Jacobs Equipment Operators 120 4 50 Hou. Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 411212019 ReportN: 10 Page: 2 of 2 Personnel Log (POB) Company So,. Type Work HlNn Standby H(m) 1 Count Nate Non is Nortlic Personnel 12 50 21 1262,5 Houn BOP Stack B Components Description Start Data Last Certification Dale Pressure Rating (pat) Type Make Model ID Nom (in) PRange (,I) Leat Cert Date Slow Circulation Rates Pump Number. Make: Model: Start Data End Data Limit Size (I.) Volume Per Stroke Overritle (bbllstk) I Max Pressure (psi) Date Depth (MUS) slow Spd Snake. (am) P(psll I ERI%) OFlow(gPm) Daily Bulk Supply Item Desatiption: Egulp root Fuel Unit Label: gal us Unit Size: Note: Dale Consumetl Receivetl 4/1212019 256.0 250.0 Retonetl Cum Consumetl 3,548.0 Cum Recohetl 3.5080 Cum Returnetl Ea.—On lx 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Lsbai: gal us Unit Size: Note: Oate Consumetl Receivetl 411212019 13000 00 Returnetl Cum Consumed 11,06So Crceivetl 22,W2.0 Cum Retained Cum On Loc 0.0 11,606.0 Note supply Item De¢tlption: Rig Water Unit Label: bbl Unit Sea: Note: Date Consumetl Receive) 4112/2019 13.0 0.0 Remrnetl Cum Consumed 360.0 Cum Reuivetl 413.0 Lum Returnetl Co. On Lac 0.0 53.0 Note LastAuthorify Visit ..to Tot mmol. Nbr Total INC. number Comment STOP Cards Submitted Company At Rots Cam NORDIC - AUSTA SERVICES 3 PJSM General Notes Comment: Well Name: P070R 01 Wellbore Name: e: OPO4-07 Well Code: 23893 �a Job: WORKOVER e �nl n' II II WCER Level: Daily Report Date: 4/13/2019 Report #: 11 Page: 1 of 2 Well Header PeandlConcesslon N° Operator Subsidiary Initial LaM1as Code ADL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Retary Table Elevafion 1Bl Grountl Level (R) First Flange (RI RKB -Base Flange Ph RKB -Tubing 8Pp1(Rf 53.20 12.20 Rigs Rig Name Contractor Rig Type R11 Num Rig Start Data Rig Release Date RIG 4 NORDIC CALISTA LAND RIG 0981 4/32019 Daily Information Weather Temperature PF) Wind Days LTI(days) Days IS (days) POB Cloudy, Blowing Snow 3 3 NE Q 30 MPH Gusting to 35 MPH ae. Safety Incidents - Near Miss Data Category Type Subtype Severity Cause Lost timet Comment Safety Drills Days Unfit Next Check Type #Occur Last Date Next Data (days( P Pipe.. Test 1 422019 4/142019 1 Evacuafion and 1 41122019 7/112019 89 Fire drill 2 4/122019 4262019 13 Kkk Virus Ta,pm, Drill 2 41101 4/172019 4 Rig lnspedwn 11 4/1312019 4114n019 1 SafetyMeeting it 41132019 4/14/2019 1 Spill Drill 1 4I1Inaba 4252019 12 Casings seat Cas. Type OD (in) ID had Grade Top(RKB) I eotlom(kKEe I TVD BOL(RKB) Run Dale CASING 13318 12.42 L -602p"0 112010 CASING 9518 068 L00 -0.9 B,T2].o 3. a 3.8350 &112010 LINER 512 4.89 LA0 4,9080 12,142.0 39356 6/132010 Last Cementing Cementing StartDate: 6W010 String: CASING, 8,727ARK0 Comment: op Meas Melte St9 # Top (it !ST1-PM Btrn (RKB) Com 1 8,3 9.0 Volume Calculations 8,]2].0 Plannetl 500' Above lop of N Send Job Information Job Phase Plannetl Sort DaleStart Deb End Dale P50 Daniel loop) WORKOVER 01900ea 4I3I201900Ao PAo 4 Daily Summary Operations 24h Forecast Complete testing BOPE el 4.5 -ane S test pint. M41 Baker fishing assembly and TIH and latch up on Tam Inflatable packer. 24h Summary Wail on weather, given all clear to go to work at 0530 his by Beide, when field want to Phase 2, POH WM TAM Packer BHA. The Packer had been sheared off in hole. Break down magnet ham Baker BHA, load up waside l eguipral and make up fishing BHA sheet PoU to test ROPE. O a"i al 0].00 Te long Boo 's. Time Log Start End Cum our Time Time our dr) (hr) Phase Opr. Act. Plan Oper. Bass, 00:00 D5:30 5.5D 5.50 W,. M Mai Wee on weather.Pase2liffed.security gives a 11 dear to convayhucks to Deadhoreefor m 0530 0790 1.50 7.00 W.O. M 1 P Prep boor for pulling BHA. Pull POW hom drill plied, mondor well. Wall static since midnight, no ids last to well. Mobitlae TAM Packer rep out to it, PJSM on POH, emphasis on understanding Ouid principles. Manually step pi o, line up Trp tank across annulus for hole fill monitoring. T7 00 09:00 2.00 900 Wo M 20 P Pink up weight hom abmp with Pa rotten at 8057 and is 155k. MU top drive far Want per TAM Rep and begin mtatlng al 10 win attempt to'release- elements white man, and picking up simultataadel, Pick up weght while rotating 1381,. Pull Met stand, - 2 bbd flu d less while Duping bill u soon as pump are off and top drive Broke out fluids released back Into trip tank. Repeal at l0 rpm. same scenario. Increase rotation to 20 Win attempt to'releasi packer ideal rotate PLAN dropped to 122K 0900 10:00 Into law W.O. M 9 P Packer element at 7851me. Lineup and Indeed down 20 tela at %bpm, 680 psi. No pressure bleed pfd, pressure increased slightly to 700 psi right Mend of pumping. 1000 1340 3.50 1350 WI). M 4 P Continue Ip PON with ovary. and pump death 5 bels fluid at Y. bpm every ft. stands (pipe displacement 3.7 hots) b ra igate swabbing effect With Packer element at 6939', when filling down backside, well took fluid without pressWng up as high ss pumped 10 hlgs away When Driller picked up with no rotates, noticeable weight Metal from 1521, down to 148k. 1330 1930 6 00 19.50 Vii M 4P POH with BHA hom 6939' w n reduced ru W. Pump 15 bids down hardest; on hourly basis. At surface the Tam inflatable Acker had been released hom Ne running tool. 19make 30 20:30 1.00 20.50 0, M 5 P Plu Bakerlais and bumper asemhly antl k off magnet sashed ft.Drevlous loot. Brite in craphot aesembty as---------------T- 1W up B[M running assemby sheet fin review. 2030 65 no 3. W 24.00 I ... IC 5 I P I Prep as test ROPE. Pump em sbtl( pull wee bushlnlg, MN floor valve asaemby. imtali test plug, fill tlback and RN lest Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Cannectlon Gas J%) Max Connection Gas PA) Avg Drill Gas Psd Max Orlll Gas 1%) Avg Trip Gas I%) Max Trip Gas Psi Daily Mud Volumes TanklAtlditionaps Type one Velume(bbR Tank Surface 5450 Hate Hole 6890 Laos Fairness 559 Cumulative Mud Volumes Ac9ve Volume lots) Hole Volume ban) Add Bons(IM) Cum Adenine pool) Lpsw(bbl) Cum Losses(bbl) 1234.0 6890 0.0 0.0 55.0 4,264.0 Daily Contacts Position Contact Name company Title Emall Mica I McMb Eni mpreseni a Robed Had Eel DrilOna upv. """on liagairs" oro Eat representathre Russ Winner End Grilling Supv OPPdrillmg@enL. 907-605-0715 907420-0058 Ed i represenbtim Much Billington Ent Rig Clerk armc1eacdoyen15@,ddcam 907-605-0722 Era mpresdntalNe GeofiAckerman Eni HSE ge.Rac1,ermas&dLcem 90]-6850]21 Tod Push Richard Twedt WWI. Tool Pusher Tod Push Al Hansen real Tout Pusher ngmanagenrig4tifnoNio-calista.coan 907-670-8604 Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4113/2019 Report #: 11 Page: 2 of 2 Daily Contacts Position Contact Name Company Tithe Email ONka Mobile Tool Push Jason Morse Nod. HSE 1 rgmanager.y4gnoMWcalise,com 90]870.86 Personnel Log (POB) Company Sero. Type Work H (hr) Sland4ty H (hr) Count Note BHGE (C.NniflAt Mi Swaco Tam Baker fismng NSRC SHOE (Valve) Peek GBR Jacobs Npmic ESP Mud engineer Packer Packer C .,dm, Men Wellhead Equipment Opnators Pipe Handling Equipment Operators NoNk Personnel 12.50 12 50 12.50 1250 12.50 12.50 12.50 12.50 12.50 125) 0 1 1 1 2 2 2 2 4 21 12.5 Hours 12.5 Hours 12.5 25 Hours 25 Hours 25 Home 25 Hours SO Hours 2625 Hours BOP Stack 8 Components Dier,ldion Start Date Last Certification Data Pressure paying (psi) Type Make Model ID Non(In) PRange (,I)Leat Gen Date Slow Circulation Rates Pump Number: Make: Modei: Start Data End Date Liner Size (m) Volume Per 6trolm Override(bbllstk) Mak Pressure(pai) Date I Depth(NKS) I Slow Spd Stroll(spn) PW) Ell OFlaw(gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit label: gal us Unit Size: Note: Dare consumed Received 4113/2019 29fi.0 296.0 ReWrnetl Oum Consumetl Cum Received 3,8440 3,8440 Cum RnWrrced Dum On Loc Note 00 0.0 Supply I%m Description: Rig Fuel Unit "Isil: gal us unit 51ze: Note: Dale consumed Received G13/2019 1.450.0 00 Returnetl Cum Consumetl Cum Received 12,5180 22,672.0 Cum Returned Cum On Loc Note 00 10156.0 Supply Ilam Description: Rig Worst Unit Label bbl Wil arm: Note: DateConsumetl Recelved 4/13/2019 12.0 0.0 Returned cum Consumetl Cum Received 312.0 413.0 Cum Returned Cum On Loc Note 00 41.0 Last Authonly Visit Date tot inap. Nbr Total I.N.O. number Comment STOP Cars Su mitred company a RPM com NORDICCNLISTF SERVICES 1 PJSM General Notes Comment. Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER cin WCER Level: Daily Report Date: 411412019 Report #: 12 Page: 1 of 2 Well Header Peughteoncession N° Operator Subsidiary Initial Laine Cede ADL -386583 ENIPETROLEUM ENI Fermin. Co. Inc. DEVELOPMENTWELL Rotary Table ElWation(n) umped Lavel in) Firs, Flange list R kx Base Flango up n. -Tubing S mo'm 6320 12.20 I Rigs Rig Name Wmracmt Rig Type RIB Num Rg $dirt Oats Rig Release Date RIG NORDIC CRUSTA LANDRIG 0981 d1312018 Daily Information Weather Temperature (-F) Wind Days LTI(days) bays RI (days) POB Cloudy 11,4 ENE @IO MPH 36.0 Safety Incidents - Near Miss Dere Category Type subtype Severpy Cause 1-osttime7 Comment Safety Drills Days Until Next Check Type #Occur Last Date Next Date (tlaysl BOP Pressure Test 2 41 412112019 7 Evacuation drill 1 4112/2019 ]11112019 08 Fre doll 2 41192019 412612019 12 Kxck While Tnpping Doll 34/1412019 4(112019 ] Rig Inspection 12 411412019 411512019 1 Safety Meeting 12 41142019 411512019 1 $pill Sell 1 G112019 4I25n01g 11 Casings seat Cas.Type I Dole) to (in) Grade Top(tKB) Bottom (it") TVD Bot (NKB) Run Dale CASING 133!8 12.42 L-80 -2420.0 2,4209 2,080.1 5...2010 CASING 9518 8.68 LBO -0.9 8,]2].0 J, 8350 61112019 LINER 512 4.89 L-80 4,9080 12,142.0 3,9356 6/1312010 Last Cementing Lamenting StartDate: 61812010 Stang: CASING. 8.1270#KB Common0: Big T.p(ftaTop Meas Math I Bun uuU3) I Com 1 6.339., i Volume Dalculations 1 8.12(.0 1 Planned 500Above top of NSand Job Information Job Phase PI ... 0 Skirt Oat. $tart Date End Date PSO Duration (days) WORKOVER 41WO1900:00 4MI201900:00 0.00 Daily Summary Operations 24h Forecast POH wi@ Tam packer, UD BHA, PIU 8 RIH wGh Baker PIP packer. 24h Summary FIU to tem BOPE. Tot BOP, gas alarms, and conduct accumulator mawdpwn test. all test were goad MU, RIH with SOT Orershot (OT 10) SHA and latch upon TAM packer a ... mbM with 475' OD fishing neck, looking up. Unseat packer and POH fl 8450'-3149' wi1M1 no ovemull. Operation m 07.00 Begin RIH with Baker PIP packer. Time Log $tare End Cum Our Time Time our fled (hr) Phase OP'. Act. Plan Oper. Descr. OP test against 4 -ill an testlmmste 250 psi low 13500 psi high, Test star.. and conduct axumulifie 00:00 09:00 900 W O. C 12 P CMY8450--314W."!t dtest. NI test were good AOGCC Rep Austin McLoed waived whro s of test. 0800 1200 3.00 1200 W.O. C 5 P Cfloor-of lest equipment Install wear ting. MabJize lift sub. Work on by drive connote. 1200 13:30 1.SO 13.50 WO. M 5 P PBaker Fishing BHA#3, OWmhm wl cul lip guide. jars and bumpersub. 1330 1830 500 10.50 W.O. M 4 P T5'. PU W 162K OW ]0k. PAJ single anti tag TO packer @ 8450. Set down 20k, WU 18k aver18.30 1930 100 19.50 WO. M 20 P Pk anti put 10 turns to night and released packer. Set anti let pac er mat Hole look nuid and pumped 15 bble town b1930 00:00 4.50 2400 W.O. M 4 P P0'-3149' at Be FPM with no ovemull. PIJW 100k. Filling 15 bbls every5 slantls. Gas Readings Avg Background Gas l%t Max Background Gas (%) Avg Connection Gas (6) Max Connection Ga. (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max 1 tl0 Ges (•A) Daily Mud Volumes TmIdAddRionlLoss Type Des Volume (w) Tank Surface 563.3 Hole Hole 070.7 Loss Formation 00 Cumulative Mud Volumes Active Volume (bbl) Hole Volume(6b0 Additions(bbl) Cum Atldifions(bbl) L ... be Rib0 Co. Losses(bbl) 1,234.0 670.7 0.0 00 0.0 4,264.0 Daily Contacts Position Contact Name Company Titie Email Wine Mobile Eni repreaenteMe Robed ON.al Eni Drilling Sup¢ OPPonII'mgQch com Eni reprasantaffm Russ Wimmer Eni Drilling Sup, OPPdriBin,ti.b.com 907.68"715 9023200058 Enimpresentathm Mitch Billington She Rig Clink 907.605-0]22 Ent representative G..ff c smm End HSE geoffackemmultax.com 907885-0nl Tool Push Richard Twerp NoMc Tool Posner Tool Push Al Hansen Nordic Tour Pusher rgmanager.ng4®nordiocaAsle.com 90740`0 04 Tool Push Jason Morse Nordic HSE rigmanagenfig4®nordiooagma.som 90]8]041609 Personnel Log (POB) Company Serv. Type Work H(hn I Standby H glr) I Count I Note BHGE (CentrIIM) ESP 12.50 0 BHGE Wetton) Wellhead 12.50 1 125 Hours MI $warn Mud eiremed 1250 1 125 House Tam Packer 12.50 1 12,5 Hours Bakerfisblng Packer 12.50 1 125 ASRC Company Men 12.50 2 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4114/2019 Report #: 12 Page: 2 of 2 Personnel Log (POB) Company SeryType Work H(kr) I Stantl•by H(brl Count Note Peak GSR Jacoba Nordic Equipment paralora Pipe Hantlling Equipment Operators Ncmk Personnel 12.50 1250 1250 12.50 3 '1' 4 21 Houre 3Z5 Hours 50Hqurs 262.5 Hours BOP Stack 8 Components Deacrlptlop start Data Last Ce"Ift.tlon Data Pressure Rating (psi) Type Make Model I ID Nom(in) I PRarpe(pal) Last Cert Date it Slow Circu aoOn Rates Pump Number: Make: Motlal: Start Date jEndOM, Llner Sim (in) Volume Per Stroke Override(bbgatkl Max Pressure (psi) Date I Depth NOUI) ski Spd I Strokes(apm) P(Pei) ER (%) OPlow(gpm) Daily Bulk supplyltam Deacflptlpn: Egwpment uel Unit label: gal us Unit Size: Note: Doh Consumed 4/142018 265.0 Rec...d 265.0 Aemmetl Gum Conaumetl Lum Recelvetl 4,109.0 4,109.0 Cum Relurnetl Cum On Loc Note 00 0.0 Supply Item Deacripaon: Rig Fuel Unit Label: gal us Unit Size: Note: ate Consumed RettNetl 4/142019 1,100.0 0.0 Returned C1m Coneumetl Lum Received 13,616.0 22,6]2.0 Lum Returned Lum On Loc Note 0.0 9,0560 Supply IMm DCSCNPXGn: Rig Watx Unit label: bbl Unit Size: Note' Date Consumed Received 4/1412019 100 0.0 Rscumetl Cum Consumed Cum AeceNetl 382.0 4130 Cum Returned Lum On Loc Note 00 310 Last Authority Visit Date Tot leap. Net Total I.N.C. number Comment STOP Cards Subrumerl cgmpony a Rota Co. NORDIC-CALISTA SERVICES 2 PJ6M General Notes c nnzmnt: Well Name: P07 0R Wellbore Name: me: OPO4-07 Well Code: 23893 rfi� Job: WORKOVER eni WCER Level: Daily Report Date: 411512019 Report #: 13 Page: 1 of 2 Well Header PermltlComesslkin N. perata Subsidiary Initial Lange Lpde ADL -J88583 EM PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENTWELL Rotary Table Elevation (k) Ground Level( -1 Fires Flange I-) me. - Saxe Funge(kl RIDS -Tubi ng Spool I-) 5330 12.20 I Rigs Rig Name Contractor Rig Type Rig Num Rig Start Data Rig Release Date RIG 4 NORDIC CAUSTA I LAND RIG 0981 4132019 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI (days) POB Overcast 11 4 Calm 37.0 Safety Incidents - Near Miss mto Category Type Subtype Severity Cause Lost ttmei Comment Safety Drills Days Unlit Nest Check Type 9occur last Date Next Date (days) BOP Pressure Test 2 4/14/2019 421/2019 6 Evawationdrill 1 4/122019 711112019 87 Fire drill 2 4/122019 42612019 11 Kick While Topping Dmi 3 4/142019 4212019 6 Rig lnspedion 13 4/15/2019 4/162019 1 Safety Meeting 13 4/152019 4/162019 1 Spill Drill 1 4/112019 41252019 10 Casings seat Gas.Type DO (ts) ID (in) I Grade Top (BIDS) Bottom(ftKB) I TVD SOL(ftKB) Run Date NG 133/8 12.42 LA0 -292DB 2,4209 20.1 5212010 CASING 96/8 668 L80 -0.9 e,>2)0 3,83,1185.0 6112010 LINER 512 4.89 L-80 4,908.0 12.1420 3,9356 611312010 Last Cementing CemenSng Start wle: SW2010 String: CASING, 8,727.0101 Commene Stgp Top(ftKB) Top Meas Mein BM take) Co. 1 6.339.DI Volume Calculations 0.7D.0 1 Planned SOD" me top of N Sand Job Information JabPhase Planned Start Date Start Dale End Dale P50 Dmatton (days) WORKOVER 413201900:00 4/3201900:00 000 Daily Summary Operations Lh Forecast POH and UD Baker PIP assembly and WU PIP X2 art Till and set x18467'. 24h Summary POH with Tam packer LD BI dear og Oxer, prep for running PIP BHA, MU BOT PIP (Production Injection Packer) and RIH on S drill pipe to Sinn COE. Fill drill sting and backside. Attempt to set PIP packer without any suttees. Chxked sumacs, equipment art discovered the Prion sensor was not on flow pan. Attempted to teat casing without any success. Cut anal slip 100of doll line. Unseat PIP and POH to 7403 - operation M OT.00 Charging qui packets at surface. Time Log Stam End Cum our Time Time Dur (m) Off Phase 0". Act, Plan Open, Deeg, 0000 no :30 .59 5 50 Won M 4 F FOR with m packer frami 3150 and to sumacs. LD BHA, clear rig floor, prep for running PIP BHA. 05:30 1400 8.50 14.00 W. M 4 P MU BOT PIP (Production Igedmn Packet) and RIH on 5- III pipe to 8467' rod. 1400 1700 3.00 17.00 W O. M 20 P Fill backside with fluid -took 187 ibis. Fill unit pipe to calculated volume without seeing pressure increase. Pumps,tl another 43 bbls without noticing Pressure increase. Shut dawn add check surface equipment and sensor was not reading because ale -tine the naw path. Filled annulus art DP with birds. Noticed nO pipe pressure buildup. Rupture disc sheared while set8ng the Packer assembly. Packer not set as Per procedure. Aflampt to pressure up backside with no Positive result. /named lown TIM plan is W release PIP antl POOH while filum, backside as, per standard procxdure. 17:00 18:30 1.50 18.50 W O. M 12 P With packer set, we attempted to perform casing ted via pumping up to 1000 psi to teal. At bys psi pressure began to himed on Bleed off pressure slowly and suspend operetion. 1830 2200 3.50 2200. W. 25 P PJSM antl cul and slip 100' of tlnking line. Set all Zone Management setting on ng. 22:00 0000 2.00 24.00 WO. M 4 P Release PIP packer and pull up 2' and relax packer for 20 min. Blow down tap -drive and FOR V M76'- 7403' at So FPM, PUW 1501, with no overpull. Gas Readings Avg Background Gas I%)Max wckgraund Ga (%) Avg Connection Gas (%) Mas Connection Gas I%) Avg Drill Gas I%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Daily Mud Volumes Ta erAdditionaoss Type Des Wit.(bbl) Tank Surface 329.0 Hole Hole 647 9 Loss Formation 967.0 Cumulative Mud Volumes Active Volume (ON) Hole Volume(bbl) AddlSons(bbl) Cum Additions(bbg Losaes(bbg Cum Lop ses(bbg 976.9 fi4).9 0.0 0.0 967.0 5,2310 Daily Contacts Position Contact Name Company TSIs Email office M04110 End repress,dlmwe Robed ONeal End Drilling Sup, OPPddlling@eni.com Eni lepra hifive Russ Wimmer Ens Drillmg Supv OPPddllin,@fmi.cam 907-685-0715 9W41204058 Ent mpresentalies Milch Billington Era Rig Clark akrlgderksdoyon15@eni.cum 907-685.0722 Eni reparamitalive Gddf APWrman Em HSE gs,gfl.ackennan®aol.com 907-685-0721 Tool Push Richard Twedt Nordic Tool Pusher Tool Push Al Hansen Nordic Tour Pusher ngmanager.rig440ooMic-calisla cam 907-670-8604 Tool Push Jaron Monte Nordic HSE dgmanagecng44$dordic-calike corn 9078708604 Personnel Log (POB) Company Sam Type Wonk Hlhr) Stand-by H(hr) Court Note BHGE (CenitllM) ESP 12.50 0 TINGE (Vidst Wellhead 12.50 1 125 Hours MI Saxe Mud engilreer 12.50 1 12.5 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 411512019 Report #: 13 Page: 2 of 2 Personnel Log (POB) Company Sew. Type Work H Do) I Stand-by H (hr) I Count Note Baker fishing ASRC Peak GBR Jacobs Nordic Packer Packer Company Man Equipment Operators Pipe Handling Equipment Operators Nordic Personnel 12.60 12.50 12.50 12.60 12.50 12.50 12.50 1 1 2 2 3 4 22 12,5 Hours 125 25 Hours 25Hours 32.5 Hours WHours 225 Hours BOP Stack 8 Components Description Stan Dew Last Certification Oate Pressure Rating (psi) Type Make Model ID Nom (In) I P Range (psi) Last Gert Date Slow Circulation Rates Pump Numbar: Make: Model: Start Date End Date Liner Sze it.) Volume Per Streke Oslurids(bblbtk) Max Pres sure (pal) Date DepM IM1B1 Slow Spd Blrokes (spm) P(psl) EN(%) CFlory (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit LabM: gal us Unit Size: Note: Date Consumetl Recehed 4 /1 512 01 9 Pa t 270.0 Returned Cum Censumetl 4,328.0 Cum Received 4.379 Cum Returnetl Cum On Loc Note 0.0 10D Supply Item Description: Rlg Fuel Unit Label: gel us Unit Slae: Note: Data Consumed Sure In ed 4/1512019 9500 0.0 Returned Cum Consumed 14,566.0 Cum Recused 22.622.0 Co. Returned Cum On Loc Note 0.0 8.106.0 Supply Item Description: Rig Water Unit Label: not Unit 31ze: Note: Date Consumed posts" 4/t5/2019 20.t 1310 Returned Cum Censumetl 402.0 cum Received 5450 Co. Returned Gum On Lac Note 0.0 146.0 Last.4uthonty Visit Date Tot map. Nbr Total I.N.C. number Da omeot STOP Cards Suhmfited Company NFpb Com N RDI LISTA SERVICES J PJSM General Notes Comment Well Name:P0 Wellbore Name: e: OPO4-0707 Well Code: 23893 � tlI��aTee' Job: WORKOVER tell//// WCER Level: Daily Report Date: 4/1612019 Report #: 14 Page: 1 of 2 Well Header Permieeoncession N° Operator Subsltllary Lahee Cada Cltlal ADL -388503 ENI PETROLEUM ENI Petroleum CO. Inc. DEVELOPMENT WELL Rotary Table Eleval Hal Ground Level(h) First Flange til) ROD - Base Flange I-) RKS-Tubing spool (tt) 53.20 12.20 Rigs Rig Name Contrac0or Rig Type Rig Num Rig Start Date Rig Release Date RIG 4 NORDIC CAUSTA LAND RIG 0981 4132019 Daily Information WeatherTemperature(°F) Wind Days LTI(days) Days RI(days) BOB Cloudy 127 WNW �5 MPH 36.0 Safety Incidents - Near Miss Oat. Category Type Subtype Severity Cause Lost tlmei Comment Safety Drills Data Unfit Next Check Type pOccur last Date Next Date (days) BOP Pressure Test 24/1412019 412112019 5 Evacuation doll 1 4/12/2019 7/112019 86 Firedrill 2 4/1212019 VM2019 10 10ck While Topping Drill 44/162019 412312019 7 Rig Inspection 144/1612019 411T2U19 t Safety Meeting 14 4/1612019 4117/2019 1 Sell Drill 1 4/1112019 412512019 9 Casings seat Cas. Type OD (in) ID (in) Grade Top (it") Bottom ME) I TVD BOt(XKB) Run Date CASING 13318 1242 LA0 -2,4208 2.9209 , ;:.JS 52112010 CASING 9518 8.68 L80 -0.9 8,727.0 3,8350 611IM10 LINER 512 4.89 1410 4.9080 12.142.0 3,9350 61132010 Last Cementing extending Shut Date: 6n2010 Stung: CASING. 6,727.01PUB Comment Stgs Top INK!) Top Meas Meth sari (fncB) Com 1 6,3390 Volume Calcuhtions8727.0 Planned 500Above top of N Sand Job Information Job Phase Planned Skirt Dab Snoab End Date Pao Duration(days) WORKOVER 413201900:00 4/3/20190000 000 Daily Summary Operations Iib Forecast Pi and UD Baker running assembly. Begin sersiang BOP equipment. 24h Summary Pi wish Baker PIP from 7403' and UD. Break oil crossovers from SM In preparafien for running second PIP BIN. MU, RIH with second BOT PIP SHA and set ® Sisal COE. Performing 9 541' swung test to 730 psi wit bleed oil. 2M test with 2.5 SPM mentons, pressures for a Mail of SO bus pumped away Operal at 07.00 Rigging up wire line, Time Log SM" End Cum our Time Time our (hr) (h) Phase Our. Act Plan Door. Drill 00'00 He 38 5.50 5.50W.O. M 4 PON who Baker to serial 0530 11.00 550 11.00 WO. M 6 P Smakoffcrossoversusedenfust PIP iMfor peace second BHA. Confirm 41, shear disk, install Mae side door component. MU BOT PIP (Producers Injection Packet with 7.100. Fill fimtp of DP with water and install grease plug in OF 1100 1800 7.00 18.00 W.O. M 4 P RUN wit PIP BHA on 5- unit pipe to 8467' CAE. FII down backsNe with 15 bible 9.9 ppg NaCl per hour while RIH, Well taking fluid. 1800 20:00 2.00 20.00 W . M 5 P FIII ba.kedu wit u -took 201 bbis. Fill drill pTal BPM. A pressure at 320 psi. while Olfng backside and drill pipe Baker set PIP as planned With 50W 100011500/ 2OW 23M psi waiting 10 min between pmMpre changes. lA sealed off, 2000 2200 2.00 2200 W O. M 12 P PJSM. Person assigned to tree, merger CA. Pressuring up IA at25 bpm. At 730 psi, pressure began to leak oft Muni er IA With Phase. declines, to 500 psi in 0 min. U-55- 2390 100 23.00 W -o- 12 P Consult town and send chart and Igonnelion. Initial 07ii@ 200 'M@55 psi. Gagin pressure hating Lk ®.SBPM, 777 pal, OA 250 psi, to 2.5 bpm, 970 pat. OA @ 281 with 25 BBLS pumped At 50 BBLS pumped IN 960 psi, ON 300 psi. 0 24 M 12 P Bbut down mM monilor wit IA bleeding 1c 455 psi, OA 270 pal. Bleed oil OA to 40 psi to bleed troller (.5 bbis). ®410 2390 612:69 1.0.00W.O. psi.,612350 Ws, W 384, ON 50 psi. Gas Readings Avg Background Gas (%) Max Background Gas (X) Avg Connxdon Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%1 Daily Mud Volumes TanWAddltb Lws Type Des Volume(bbl) Tank522 Ce 0 Hole Hole sae a Loss Fmmafion 4820 Cumulative Mud Volumes Active Volume (bM) Hole Volume (Moll Addtow (bbl) Cum Additions (bb0 Losses (bbl) Co. Losses (bi 1,270.0 648.0 0.0 00 482.0 5.7130 Daily Contacts Position Contact Name Company This Enalit Once Mobile Ent representative Robert Ordeal End Drilling Sups. OPPdnlling@eni.com Ent nprearelatis. Russ Wimmer End Drilling Bees. OPPelillingileniwm 907,685,0715 907420-0058 Eel pandeonium Muth allingon EN Rig Clerk akdgcleIXadoyonlSillearcom 907,685-0722 Ed representative Goff Ackeerom Eni HSE geoffatlsrmaiteni.com 90741851 Tool Push Richard Twedt NOMI. Tool Posher Tool Push Al Hansen Nardi. Tour Pusher rigmanager.dg4®neNN-calbita.com 907,670-0604 Tool Push Jason Morse Nwdlc HSE dissenter ng4®noo iccalishcorn 907670.8604 Personnel Log (POB) Company Sere. Type Work Nbr) I Stand-by H(h) I Count Note BHGE (CegM X) E P 12.50 0 BHGE (Vet.) Were ad 12.50 1 125 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 411612019 Report #: 14 Page: 2 of 2 Personnel Log (POS) ComPanY Sony. Type Week H (hr) Starts -by H Mo) Count Note Mi SWaco Tam Sake, fisnmg ASRC Peak GSR Jacehe Nordic Mud engineer Packer packer Company Men Equipment Oparslore Pipe Handling Equipment Operators NoMlc Persomnl 12.50 12.50 12.50 12.50 12.60 12.50 1250 12.50 1 1 1 2 2 2 d 22 125 Hours 12.5 Hours 125 26 Hours 25 Hours 25 H.. 50 Hours 275 Hours BOP Stack 8 Components D9a1p6on Slant Data last Certification Dale Pressure Rating (psi) Type Make Model ID Nom (in) I P Renee (psi) Last Cert Date Slow Circulation Rates Pump Number:Minn.: Model: Sdrt Data End Date Liner Size (In) Volume Per Stroke Ovenide(bbl/stir Mas Press are did) Data I Oeplb(kKal Slow Spd Strokes (spin) I POn') Ea(%i OFlow (gPm) Daily Bulk Supply Item Description: Equipment Fuet Unitlabel: gal us Unit Slze: Note: Date Consumed Received 4/16/2019 1]3.0 1]30 R.1amcd Cum Consumed Co. Received 4,552.0 6,5520 Cum Roturnetl Cum On Loc Nate 00 0.0 Supply Nem Description: Rig Fuad Unit Label: gal us Unit Soo: Note: DataConsumed Ill ..Wad 4/16/2019 5500 0.0 Returned Cum Conaumetl ICU R. Wetl 15,616.0 22.672.0 Cum Returned !Co. 0. Lc Note 0.0 7.2%.0 Supply Item Description: Ris Water Unit Label: bbl Unit Size: Noe: Dale Consumetl Received 411612018 76.0 0.0 Returned Cum Consumetl Cum Received 4780 548.0 1C..Returned Cum On Lou, Note Co 70A Last Authority Visit Dale To1Jmp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company N Rpls Com NORDIOCALISTA SERVICES J PJ SM General Notes Comment: Well Name:P07 OR Wellbore Name: e: OPO4.07 Well Code: 23893 B�d�e' Job: WORKOVER acli II II WCER Level: Daily Report Date: 4/17/2019 Report #: 15 Page: 1 of 2 Well Header PanneWConcesslon N°Operators "I'ltl er, Initial Lease Coda ADL -388583 EMPETROLEUM ENI Petroleum Co. Inc DEVELOPMENT WELL Rotary Table Elevation IM Ground Level (a) First Flange 1m) . Base range (n) -Tubing Spool (n) I. 53.20 12.20 Rigs Rig Name Contractor Rlg Type "Num Rig Start Date RIg Release Data RIG 4 NORDIC CALISTA tAND RIG 0881 4/312019 Daily Information Weather Temperature (°F) Wind Days LTI(days) Days RI (days) POB Overcast 8.8 N C 17 MPH 36.0 Safety Incidents - Near Miss Cate category Type Subtype saina y Cause Lost time? Comment Safety Drills Days Until Next Check Type if Occur Last Data Next Dam (days) BOP Pressure Test 24/16/2018 422/2019 5 Evacuatdondindl 1 41122019 7/122019 0e Fire let 2 4112/2019 427/2019 10 Kick White Tripp? J odll 4 01162019 4242019 7 Rig Inspection M 41162018 4/1812019 1 Safety Meeting 14 4/1612019 41IW2019 1 Split Drill 1 4/1112019 426/2019 9 Casings seat Cas.Type OD (in) to (in) Grade TDp(nKB) I Butt.r0o) TVD But.(aKB) I Run Date CASING 133/6 12.42 L-80 -2.420.8 2,420.9 2,080.1 5121/2010 CASING 85/0 ".BB L80 -0.9 8,72].0 3,835.0 6/112010 LINER 512 4.89 L-80 4,908.0 12,142.0 3,9356 6/132010 Last Cementing Cementing StartDate: 613/2010 SWng: CARING, 8,R.oM(B Comment Seg !.ITop (110(j)Top Meas Meth aft (Nike) Com 1 6,339.0 1 Volume Calculations .7210 Planned 50V Above top of N Sand Job Information Job Phase Planned Start Data Start Dam End DemPs0 Duration (days) WORKOVER 4/3201900:00 4/316/11800:00 000 Daily Summary Operations 2.11, Forecast RIH W/Fishing ASSY 24h summary POH with Baker Strong Toll f/ 7403 to surface. Operation at 07.00 RIH el 5' HWOP and Baker storm packer. Time Log Start End Cum our Time Time Bar(hn @r) Phase Oar. Act. Plan Oper. Baker. 09:00 06:30 6.50 8.50 W.O. M 4 P POH win Baker Setting Tool Y 7403'W surface, Sore available m midnight Pits - 654 BBL Trucking on location- 6% BBL Brine to hole last 24 hours (midnight): 336 BBL Una, Total Brine to hob (midnlghi. 5883 BBL Gas Readings Avg Background Gas (%) Max Background Gas I%) Avg Connection Gas (%) Mas Connection Gas (%) Avg Drill Gas (%) Max Drill Gas(%) Avg Trip Gas 1%) Mak Trip Gas(%) Daily Mud Volumes TereAldiho ll -c s Type Des volume(bbp Tank Surface Hole Hole Loss Formation Cumulative Mud Volumes at` Active Volume(bbD Here Volume lbb8 Additions (hall Cum Additions(bhp Losses tbb0 Cum Losses (bill) 0.0 0.0 loo 0.0 0.0 5,713.0 Daily Contacts Position Contact Name Company This Email Orrice I Motile Enimpmesirt, is Takahao Koea Enl Drilling uDv. PPdnlling�eni.cgm Em repreeantelive Russ Wimmer Ent Drilling Sup¢ OPPdnlling®em.mm 907-605-0715 907-320,0050 End representative Wade Thomas End Rig Clark 907-685-0722 Em repraeentatNe GeoBAckemmn EM NSE geoaamearnan®enicom 907-605-0721 Tool Push Ruhant Tweet NontID Tool Pusher The Push Al Hansen Nordic Tour Pusher ngmanager ag4lQrordio-calista.mm 907-670-8604 Tool Pugh Jason Morse Nordic HSE rigmanagas hg4@nomiocalista.com 907-670-8504 Personnel Log (POB) Company Sem. Type Work H(hit) Stand-by Hhut Count Note BHGE ICenfdlrtp ESP 12.60 0 BHGE (Netto) Wellhead 12.50 1 12.5 Hours Mi Sale. Mud egimer 12.30 1 12.5 Hours Tam Packer 12.50 1 12.5 Hours Baker fishing Packer 12.50 1 125 ASPIC Company Men 12.50 2 25 Hours Peak EquipmentOperators 12.50 2 25 Hours GBR Pipe Handling 12.50 2 25 Hours Jacobs Equipment Operators 12.50 4 50 Hours Nordic Nordic Personnel 12.50 22 275 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 411712019 Report #: 15 Page: 2 of 2 BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating(pl) Type Make Motlel ID Nom (in) PRan,. (,M) Last Cep Data Slow Circulation Rates Pump Number: Make: Model: sun Data End Date Liner S110 (in) volume Per Stroke Override(lobileak) Max Pressure(psi) Data Depth (MB) Slow Sptl I strokes (spm) I P (oil I EX I%) O Flow 19pm1 Daily Bulk Supply Item Descnation; Equipment Fuel Unit Label: gal us Umt Size: Note: Dale Consumetl Ranivatl 41168019 1]30 178.D Remrnetl Cum Consumetl 4,552.0 Cum Received 4.552.0 CUM Returned 00 Cum On Lac 0.0 Note Supply Item Deneriptlan: Rig Fuel Unit Label: gal us Unit Size: Note: Date Consumetl Received 0/168019 850.0 D.0 Relurnetl tum Consumed 15416.0 Cum Received 2$6]20 tum Returned 00 Cum On Loc 7,256.0 Note Sup ply Rem Care pbon: Rig Water Unit Label: bbl Unit Size: Note: Deb Consumetl Recelvetl 4/168019 ]6.0 00 Returned Cum Consumetl d76.0 Cu. Received 548.0 Cum Remrnetl 00 Cum On Loc ]0.0 Note Last Authority Visit Data Tot mep. Nbr Total I.N.C. number Comment STOP Cards Submitted Company A Ruts Com NORDICCALISTA SERVICES 4 PJSM General Notes Comment: Well Name: P0 Wellbore Name: me: OPO4-0707 Well Code: 23893 Job: WORKOVER gni WCERLevel: Daily Report Date: 4/21/2019 Report #: 16 Page: 1 of 2 Well Header PermtUC.ohnsir N• Operator Subsltlbry Indgal Lahee Cotle ADL388503 ENI PETROLEUM ENI Petroleum Co. Inc DEVELOPMENT WELL Notary Teble Elevation(tt) Ground Leks. putFint Fpenge (h) .-Base Flange fellRKB-Tubing BPoel I-) 53.20 12.20 Rigs Rtq NMna Canpractor Rig Typa RIg Num Rig Start Date Rig Release Date RIG 4 NORDIC alLAND RIG 0981 4/312019 Daily Information Weather Temperature(°FI Wind Days LTI(days) Days Rl(days) POB Cloudy i0 N ® 11 MPH 33 0 Safety Incidents - Near Miss Dale Category Type Subtype Severity Cause Lost fima7 Comment Safety Drills Type ,Occur Last Date Neat Date Days UnSI Neat Check wal BOP Pressure Test Evacuation drill Fireddll Kick While Tapping Doll Rig Inspection Safety Meeting Spill Doll 34/2112019 1 4/1212019 2 WIV2019 44/1612019 16 4/212019 16 42112019 1 4/1112019 42812019 1/1112019 42612019 42312019 4122/2019 42212019 42512019 7 01 5 2 1 1 4 Casings seat Cas.Type DID (in) ID (in) Brad. Top(ftKB) Bottom(ftKBI TVD But(ftKB) Run Date CASING CASING LINER 13 318 9519 5112 12.42 0.68 4.89 L-80 L80 L-80 -2,20.8 -0.9 4,908.0 2.420.9 81210 12,142.0 2.080.1 3,835.0 3,935.6 5212010 6112010 511325110 Last Cementing Cementing Sbrt Date: 01312010 Spring: CASING, 8,727.011 Comment: stg k Top (ftKB) I Top Meas Meth Bern (ftKB) I Co. 1 6,3390 I Volume Calculations 8,72.0 Planned SW Move top of N Send Job Information Job Phase Planned Start Date Stan Date End Date P50 Duration (days) WORKOVER 4132019MOO 41320190000 P1712019 N.30 10.00 Daily Summary Operations 24h Forecast WU Baker rMnevamatic and SLB Memory Sensor and RIH 21 spends, WU 21 ill d T HWDP and continua in We to SOW and lest rasing. Continua in hole and Palls problem areas, Me Seminary POH and check junk basket NDl tart recovered. RN and test DOPE n per ACel specs, Witness waived by AOGCL Jeff Jones but wtlnessed by Anchor rep Comte, Steib. R1U SLB wire line equipment MUD WelRec tractor and PDS caliper ock, RIH M 3800' all trader to 8450. Log up hole to su arce. Potential zone of Interest V 7900TOM. Operation at 07.00 RIH Wracks, As, Time Log sort End Cum aur Time Time our(hn (hr) Phase OP, Act. Plan once. Dean. 0400 0700 3.00 3,00 Wo C 11 P PJ9 ,Vetco pull wear bushing and set test plug, Build lest it, fill stack and choke. 0700 030 0.50 3,50 W.O. C 112 P Perform shell test. 0730 1530 8.00 11.50 W . C 12 P Testing BOPS as per AOGCC specs to 25013500 psi. AOGCC Jeff Jones waived Witness, but witnessed by Come, Stab with Archer. 15:30 1630 1.00 12.50 W.O. C 5 P RID testing equyment. Vetco Dull tell plug and installed wear bushing. 16:30 1930 3.00 15.50 W,O, R 5 P PJSM. WU SLB wire line equipment and WU BHA w/ SLB, WellTec and PDS cal tools. 19:30 2200'. 2.50 18.00 W.O. ft 4 RIH wl wire line!cope and stack out,13600'. Pick upend Tractor down to 8450, Watton Omer, 2200 00'.00 2.00 2000 W.O. R 4 P Logging up hole from 8450'. 9.g PPG Bone available at midnight Pits- 480 BBL The lg an location- 775 BBL ends to We last 24 hours (midnight) 0 SBI- BLTend Brine b hole (midnt1h0: 5883 BBL Tend Gas Readings Avg Background Gas (%) Max Background Gas (%1 Avg Connection Gas (%) Mak Consul Gas I%) Avg Drill Gas (%) Max D1t11 Gas Ph) Avg Trip Gas (%1 Mas Trip Gas (%1 Daily Mud Volumes TanWAtlditioNLoss Type Des Volume (I TankSurface Hole Loss Hale Formation Cumulative Mud Volumes Active Volume(bbq Hole Volume(bbp Mergers jbbl) CumAvoidance ell I Losses(bbl) Cum Lossea (bbg 0.0 0.0 0.0 0.0 0.0 5,713.0 Daily Contacts Position Contact Name Company TRIP Email OIBee Mobile End represenlellve Ent represanlaMa End mprveentaNe End representative Fuel Push Tool Push Tool Push Takandm Kosaka Russ Wimmer Wade Thomas Gal Ackerman Refund Twedt Al Hansen Jason Minae End Ent End End Nndlc Noreic Neo is DMlihe Bups. Denning Sups. RIg Cleric HSE Tool Pusher Tour Pusher HSE OPPdollinglteni.com OPPedlldng®ani,com geoNackermantteni core ngmanda,mdg4@noetic-caksta.com ngmanalhig4lItnrne,calistacone 907.895-0715 907985-0722 907985-0721 907970-8604 907-670.86M 907-320-0058 Personnel Log (POB) Company I Sms. Type I Wmk N(hr) I Sta lH(hr) Count Nota BHGE (CenidlM) ESP GBR Pipe Hendldng 12.50 12.50 0 25 Home 7 Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4121/2019 Report #: 16 Page: 2 of 2 Personnel Log (POB) Company Serv. Type work H(hr) Stand-by H ern Count Note SHGE (Vetco) Mi Swaoo Tam BakerNMng ASRC Peak Jacobs Mai Wellhead Mud engineer Packer Packer Company Man Eququnent Operators Equipment Opaulms NOMI Personnel 12.50 1250 12.50 1250 12.50 12.50 12.50 12.50 1 1 1 1 2 2 4 21 12.5 Hours 12.5 Hours 12.5 Hours 125 25 Hours 25 Hours 50 Hours 275 Hours BOP Stack 8 Components Descriom Start Date Last Certification Cate Pressure Rating(ps0 Type Make Mount t0 Nom (In) I P Range gull Last Cert DeOe Slow Circulation Rates Pump Number: Make: Motel: Start Data Entl Date Liner St. (I.) Volume Per Stroke overrun (bMlstp Max Pressure(ps0 Date DepeM1 (KKB) Slow Spd S[mkes(a m) Is (go') EB (SV OFI.W(gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: gal us Unit Slae: Note: Oats LensYma Receivatl 4218019 3090 309.0 Returnetl Cum ConaVmetl 5,032.0 LYm Recelvee 5,032.0 Cum Remrnatl 00 Cum On Lac Note 0.0 SUPPIy Kam Description: Rig Fuel Una Label: gal us Unit Sia.: Note: Date Consume) Receivetl 48112019 10000 0.0 Returned Cum Consumed 17,466.0 Cum Hecelved 30,280 Cum Returned 00 Cum On Loc Nofe 12,605.0 Supply Item Description: Rig W alar Unit Label: bbl Unit Size: Note: Data Consumed Required 4218019 5.0 0.0 Returned Cum Consumatl 483.0 tum Recelvetl 643S Cum ReM metl op Cum On Loc Nofe 160.0 Last Authority Visit Date Totlnsp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company p Rots Co. NORDIC-CALI TA SERVICES d PJSM General Notes Comment: Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 n' Job: WORKOVER e reII II WCER Level: Daily Report Date: 4122/2019 Report #: 17 Page: 1 of 2 Well Header PemdNcanceasion N. ADL -388583 Operator subsltllary Initial Lahee Code ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation 4M Gro..0 Le..VO IIs, 'large In) I Hader -ease long. Hit a. Tubing 5pool(ft) 53.20 12.20 Rigs MIN Nem. Contractor Rig Type Rig Num Rig Start Data Rig Release Date RIG 6 NOROIC CAIISTA !&D RIG 0981 4/32019 Daily Information Weather Temperature ('F) Wine Days LTI(days) Days M(days) POB Clear , fi NE @ 20 MPH 34.0 Safety Incidents - Near Miss Date Category Type Subtype Severt, Cause Lost tine? Comment Safety Drills Type of Occur Last Date Next Date Days Until Next Check (days) BOP Pressure Test Evacuation drug Fire dell Kick While Tripping Drill Rig Inspection Safety Meem, Spill Drill 34121209 1 2 4 16 16 1 4282019 41122019 7/11/2019 4112/2019 4262019 4/162019 4232019 4212019 422/2019 4/212019 422/2019 41112D19 4252019 6 00 4 1 0 0 3 Casings seat Cas.Type I GO (in) ID fin) Grade Top HtKB) Bottom iti TVD BOL(ftKB) Run Data CASING CASING LINER 13 J/8 9518 512 12.42 8.68 4.09 L-80 Lao L-80 -2.420.0 -0.9 4.908.0 2A209 8,72]0 12,142.0 2,080.1 3,835.0 3,935.6 521@010 &112010 6132010 Last Cementing Cerra log Start Data: 6/312010 Sholi CASING, 0,727.007(13 Comment: St, #I Top(ftK8)Tap Meas Meth B. (fixed Co. 6,3380 Volume Calcushxds 0727.0 Planned 509 Move top of N Sand Job Information Jab Phase Planned StartDate Sued Date End Date P50 Duration (days) WORKOVER 413201900:00 413201900:00 41172019030 0.00 Daily Summary Operations ash Forecast RIH m above Baker PIt,. 24h Summary Log up to s efts. and RID PDS tool to dawn load data. Pelimai data has potential arose of interest MM n 780'-7901 Data will be reviewed In town and final Mod sent RID Who Llne tool, add equipment. RIH with Baker rebdeara tic and test casing as directed POH 10 surface with esker teat packer. SLB removed gauge sensor. Down loading dale. Cp.rati.n at 07.00 RIH W1Packer Retrieval Tool Time Log Start End Cum our Time Time Dur ihr) (hq DID, Act Plan Opera Descr. 00,60-03:00 3.00 3.00R 11 P Caliper It, up to surface, Down loo ata- Good. WO 5113/ Welnec rooks and equipment. 0300 05:30 2.50 5.50M 4 P PJSM. RIHw4hBaker reeesadatic to 2008'®60FPM0530 1200 6.SD 12.00M 12 P had 2l ys of Y HWOP t.2652. Cont to RIH with OP to 7700'. Set packer aM test casing#1 to 150 psior 30 charted min. rPh- 1200 1330 1.50 13.50M 12 P RIH 108345' and test casing #2 down with 750 pal and theater, 00. Test wain, ham8345'1. Baker PIP al.75'to 100 psi -Gard 13:30 15:00 1.50 15.00M 12 P Pull up to 8150' #3 and 790' #4 and east between packers to 900 psi- Good 1500 17.30 2.50 17 50M 12 P Pull up to 7700' #5an test casing pressure down to 500 psi for 5 min- ood Put on chart antl pressure t.150 psi for 30 charted min Good1730 00'.00 6.50 24.00M 7 P P H from 7780' to surface. SLB removed gauge sensor and down loading data. 9,9 PPG Brine available at midnight: Pits - 577 BBL Trading on k¢afion- 775 BBL Brine to hole last 24 hours (midnlgM): 0 BBL Total grind to hole (midnight). 5803 BBL Gas Readings Avg Background Gas (%) Max Background Gas M As, Connection Gas (%) Max Connection Gas I%) Avg Drill Gas (%) Max Drill Gas 1%) Avg Trip Gas I%) Max Trip Gae red Daily Mud Volumes TanklAddith.m a Type Des Volume (but) Tank Hole Loss 5uriace Hole Formation Cumulative Mud Volumes Active Volume (bbl)Hole Volume (bbl) ACdlOons bbl( Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 0.0 0.0 0.0 00 0.0 5,713.0 Daily Contacts Position Contact Name Company Title Moral Office Mobile Ent representative End representative Em representative Ent representative Tool Push Tool Push Tool Push Take. Kosaka Russ Widmer Wade Thomas Geoff Ackerman Dave I01.r AI Hansen Jason Mone En Eni Eni Eni hall MONic handle Drdling Sup, Drilling Sup¢ Rig Clerk HSE Tool Pusher Tour Pusher HSE OPPtldlffig ®ani.cam OPPdrillingtinducom geodaclrenoaar@etcom dgmanagor.dg4tindJiucali.ta.wm ngnm.gecrig4@.Mg .fidla.wm ngnumagecrig4tilnortllaca11.1a.can, 97405-0715 907,585-0722 907405-0721 907470-8604 907470-8604 907470-0804 9W-3200058 Personnel Log (POB) Company So,. Type Wod H(hr) I stanbby H(M) I Count I Nota SHOE(CenViIM) GBR E P1 Pipe Handling 12.50 0 0 25 Hours F Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4122/2019 Report IY: 17 Page: 2 of 2 Personnel Log (POB) Company Sera. Type Work H(hr) Standby H Nr) Count Note BHGE (Netto) MI Swaco Tam Baker Bahing SLB NSRC Peak Jacobs Nordic Weillreed Mud engineer Packer Packer Logging Company Men Eeuipment OPoralom Equipment Opemloa Nordic Personnel 12.50 12.50 12.50 12.50 12.50 12.50 12.50 1250 12.50 1 1 1 1 1 2 2 4 21 12.5 Hours 12.5 Hours 12.5 Hours 12.5 25 Hours 25 Hours 50 Hour 275 Hours BOP Stack B Components Description Stan Data Last Cemtwatlon Date pressure Rating (Pat) Type Make Motlel ID Nom (in) P Range (,I) Last Cod Data Slow Circulation Rates Pump Number: Make: Model: Start Date I End Date Liner Size (in) Volume Per Stroke Override (bbll-M) Max Pressure (pap Date Depth(RRB) Slow Spot Strokea(epm) P(pall I N(X) T OFlow(gpm) Daily Bulk Supply Item Description: Eeuipmeni Fuel Unit Label: gal usUnit Size: Note: Dat Consumed 421/2019 309.0 Receivm 309.0 Refumetl Cum Consumed Cum Received 5.320 5,032.0 Cum Returned 0.0 Cum On Lac Note 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: Note: Dat Consumed 421/2019 1,400.0 Received 00 0.emrned Cum Cpnsumeot Cum Received 17,466.0 30,272.0 Cum Returned 00 Cum On Loc N018 12,606.0 Supply Item Denudation. Rig Water Unif LOO bbl Unit Size: Nofe: Dste Consumetl 6(21/2019 5.0 Received 00 Returned Cum Consumetl Cum Recowed 483.0 643.0 Cum Returned 0.0 Cum On Loc Note 160.0 Last Authority Visit Data Tet snap. Nbr Total LN.C. number Comment General Notes comment. Well Name: P07 OR Wellbore Name: me: OPO4-0707 Well Code: 23893 e/g� r� I1 Job: WORKOVER II II WCER Level: Daily Report Date: 412312019 Report #: 18 Page: 1 of 2 Well Header PermibGoncesslon N° Operator Subsidiary Mitlal LaM1ee Lode AOL -388583 ENI PETROLEUM ENI Petroleum Co.lnc. DEVELOPMENT WELL Rotary Table Elevation DO Ground Unnaft) Firs, Flange(N) RKB� Base Flange On RKB-Tubing Spool (ft) 5310 12.20 Rigs Rig Name Central mg Type Rig Num M, Bud Data Rig Release Data RIG NORDIC CALISTA IAND RIG 0901 4/32019 Daily Information Weather Temperature PF) Wind Days LTI ull Days Fil daysl POB Cloudy 50 NE@22 MPH 34.0 Safety Incidents - Near MISS MN Category Type Subtype Severity Oause Losttime7 Comment Safety Drills Days Gain Neat Check Type #Occur last Date Neat Date (days) BOP Pressure Test 3 412112019 fall 18 5 Evacuation all 1 4f122U19 711112019 T9 Fire mall 2 4/122019 42612019 3 Kick While TiAl Drill 4 41162019 423/2019 0 Rig lnapedion 18 412312019 42412019 1 SafetyMeeting 18 412312019 42412019 1 Spill Drill 1 41112019 412512019 2 Casings seat Cas.Type OD (in) ID (in) Grade To,(ftKa) Bottom(ftKB) I TVD But(ftKB) Run Date CASING 13318 12.422,4209 20801 512112010 CASING 9518 868 L80 -D.9 0,]2]0 3.8350 BIi12010 LINER 512 4.89 L40 4,9080 12.142.0 39356 611312010 Last Cementing Cement, Start Date: BrJ2010 Sulia: CASING. 0,727.0111<13 Comment Sig# Top (aided Top Meas Mem BtIRK B) Co. i d"'VV Volume Calculations 8,]2].0 Plannetl 500' Above top of N SnM Job Information Job Phase Planned Stan Dafe Start Dais End Date P50 Duration (days) WORKOVER 413201900:00 4/3201900:00 4/17201906:30 0.00 Daily Summary Operations 24h Forecast RIH W TO Inter alM wdd polish .,If inside X3. POH and rack back OP. UD MITI. 2" Summary UD rebeivama,ic assembly and WU Baker PIP reMeval assembly. RIH redieving tool down to 8475' I00king for obsbucflon. Tag Baker PIP packer at 0475'. Rebase PIP, confirm unset by fluid level all Wall M deflation. Stan POOH. WU Baker Polish Mill Assembly and RIH to 2961'. Optical at 07.00 POOH W/Polish Mill Time Log Stan End Co. Our Time Time Dur (hr) I (M1r) Phase Our. Act Plan Oper. Descr. 0000 0700 re 4 P UDrdh Nama80 assembly and MILL Baker PIP addition assembly and RIH ,0 8373' 0700 1400 7.00 14.00 W.O. M 5 P RIH reWtl W lad down to 75' looking tar obs,mclio Tag Baker PIP pecker at 9475'. Release PIP, confirm umei by fluty laWl all Wad for tleflation. Start POOH. SIM OPS: Service rig and Weaning. 14:00 2200 8.00 2200 W.O. M 4 P POH with Baker PIP at 40 FPM, UD PIP assembly 2200 0040 2.00 4 00 V VO M 4 P MU Baker Polish 10,11 Assembly and RIH 102961'. 99 PPG Brine available at midnight, Ps - 513 BBL Trucking an tical - 775 BBL Brine to hob lead 24 hours (mldnlght): 1 BBL Total Brine to hate (midnight) : 5884 BBL Gas Readings Avg Background Gas ('L) Mea Background Gas (%) Avg Connection Gas (%) Max COnnecibn Gas (X) Avg Drill Gas (%1 Max DNII Gas (%) Avg Trip Gas (%) Mea Trip si (%) Daily Mud Volumes TimidAddii.nlLGss Type De. Volume (bb!) Tank Surtace Hole Hole Loss F.mmtion Cumulative Mud Volumes Active Volume late) Hole Volume(bb) Addlions(bbl) Cum Medical(bbt Losseslbb1) Cum Lassen bb0 00 0.0 0.0 0.0 00 5,713.0 Daily Contacts Position Contact Name Company Title Small Office M0611e Enimpresentatua, Talwhuro Kansas Eni Drilling Supv. OPPtlrillilg®am con Eni representative Russ Wlmmer Ent Drilling Supe. OPPdriOln,@.al.cwn 907,685-0715 907-320U058 Eni representaliva We&Thomas Eni Rig Clerk 907,685-0722 Eni repraden,afaw Geog Ackemmn Said HSE geoftairackan@enkc0m g07,685-0]21 Tool Push Dave His, Nordic Tool Pusher rgmanegecng4@noMipcallsla.cum 907,670-8604 Tool Push Al Hansen Nordic Tour Pusher rgmanagecrig4@noNiawlisla.wm 907,670-8604 Tool Push Jason Mom. Nom. HSE a smanager.ng4idnon iccalism cam 9076]08604 Personnel Log (P( B) Company Sere. Type Weak H(M1r) Staral H(hr) Count Note BHGE (Cenln ) ESP 12.50 0 GBR Pipe Hantlliltg 12.50 0 25 Hours BHGE (Vetw7 W.Ilheetl 12.50 1 12.5 Hours Mi Swal Mud engineer 12.50 1 12S Hours Tam Packer 12.50 1 125 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 412 312 01 9 Report #: 18 Page: 2 of 2 Personnel Log (POB) Company Serv.Type Work H un) Stand-byH join Count I Note Baker fishlrig SLS ASRC Peak Jacobs North. Packer Lagging Company Man Equipment operators Equipment Opemfors NoMIc Personnel 12.50 12.50 12.50 12.50 12.50 12.50 1 1 2 2 4 21 12.5 12.5 25 Hours 25 Had. 50 Hours 275 Hours: BOP Stack & Components DescriptionSreH Dare Last Cert fl.ri i. Dare Pressure Rating (pelt Type Make Model ID Nom (in) P Range (psi) Last can Date Slow Circulation Rates Pump Number: Make: Model: Start Data End Date Liner Size 11.) Volume Per Stroke Override (appeals) Me. Pressura(psi) Date Depth (We) Slow Bad Strokes(spm) P(psi) I ENI°:) DFlow (ppm) Daily Bulk Supply Item Connotation: Equipment Fuel Unit Label: gal us Unit Sire: Note: Data ConsReceived 4I23I2010 4360 439.0 Returned Cum Consumetl Cum ReceWed 6.164.0 6,1640 Cum RetainedCum On Loc Note 0.0 0.0 Sooty Item Description: Rig Fuel Unit Label: gal us Unit Size: Note: Date Consumed Received 4p312019 9460 O.0 Returned Cum Consumed Gum Ramped 19.299.0 35,080.0 Lum Reternetl Cum On Loc Note 00 15,7610 Booty Item Deaeritall RIB water Unit Label: bbl Unit Size: Note: Data Consumed Recelved 41232019 12.11 0.0 Returned Cum Consumed Cum Received 505 0 643.0 Cum Returned Cum On Loc Note 0.0 136.0 Last Authority Visit Date Tot map. Nor Total I.N.C. number Comment STOP Cards Submitted Company ands Com NORDIC-CALISTA SERVICES 4 PJSM General Notes Comment: Well Name:P07 OR Wellbore Name: e: OPO4-0707 Well Code: 23893 Job: WORKOVER eni WCERLevel: Daily Report Date: 412412019 Report M: 19 Page: 1 of 2 Well Header PermNConcesshm N' Opmalm Subsitllary Initial Lobes Cafe PDL -308583 ENI PETROLEUM ENI Peimleum Ca. the, DEVELOPMENT WELL - Rotary Table Elevation (ftI Grountl Level(n, Firct..regain, RKB-Base frange(ft) RIGS -Te ling Spool fit) 53.N 112.20 Rigs Rig Name Control Rig Type Me Num Rig Bert Data Rig Releaze Dale RIG 4 NORDIC CNMSTA LAND RIG 0981 4132019 Daily Information WeaMer Temperature Wlnit Days LTl(days) Days RI(days) POB Clear 8.6 .Eno M MPH 33.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type %Occur bast Date Next Date (days) BOP Pressure Test 3 41212019 412812019 4 Evacuation drill 241242019 ]12312019 M Fire drill 3 4242019 Si 14 Kick White Tripping Dan 441162019 VM2019 -1 Rig Inspection 19 41242019 42512019 1 SafetyMeering 19 41242019 412512019 1 Spill Drill 1 4111/2019 4252019 1 Casings seat Cas. Type I OO (Int to (in) Grade Top(ftKB) Boom bKB) I TVO Bm(l Run Date CASING 13318 1242 L-80 -2A208 2,420.9 2,0801 52120ID CASING 9518 0.68 L80 -09 B,T2].0 3,8350 6n2p10 LINER 512 4.89 1.40 4908.0 12,142.0 3,935.8 8/132010 Last Cementing Cementing StartDate: 6132010 Stake: CASING, 8,]2].ORKB Comment: Sig g Top (aKB) I Top Meas Meth Bbn (ftKB) Co. 1 6,3,bir 1Volume Calculations Ili I Planned 500Above lop of N Sand Job Information Job Phase Planned Start Oats Start Doh Ertl Date P50 Duration (daysd WORWVER 4(3201900:50 4132019 WUO 4n ]201908:30 0.00 Daily Summary Operations 241, Forecast Run antl set 7- scab Inver. PON Liner merger setting tool. 24h Summary H1H wdh Baker Polish mill, Polish PBR, POH and LO BHA. RV GBR equipment Load casing and Baker equipment to Mpe shed. Opened, at 07.00 RIH WBcab Liner Time Log Start End Cu. our Time Time our (m) (h) PM1ase Op, Act Plan Cox, Deal 0000 0500 5.50 500 W. M d P RIH Baker Polish mil PU14D SOW. Tag Liner Top @8517'w2K 0500 MOO 100 600 W.O. M 19 P Polish Liner Top 8 PBR @8517' RPM30 Tp12.5 pumping 3 bpm. Lost 85 Mil, 06:00 12:00 6.00 1200 W O. M 4 P POOH Baker Polish mill hour 8517 to surface 8 LD, 1290 1930'. 7.50 1950 W.O. M 1 P Load and all 7H 26a LBO THW3 casing 1930 0000 4.50 24.00 W.O. M 5 P RU and calibrate GBR equipment. SIM OPS: Savy walkdown 8 PJSM. Load Baker equipment with ZpdmBaam. Gas Readings Avg Background Gas (%) Max Background Gas (%I Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas t%d Max List as (%) Avg TOP Gas (%) Max Trip Gas VA) Daily Mud Volumes TanklAddiBonlLoss Type Des Volume goal) Tank Budace Hole Hole Loss Formalion Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Addllons(bbl) Cum Additions(bb0 Losses(bbl) Otim Losses(bbl) 0n 0.0 0.0 00 0.0 57130 Daily Contacts Position Contact Name Company Title Email Office Mobile Ed representative Takandne Kosaka Eni Drilling Supv. OPPtlnlling@am corn Ent representative Steve Lawrence Ent Drilling Sol OPPdr0x*@emearn Ent representative Wood Thomas End Rig Clek 90]828]22 Ent representative Geoff Ackerman Ent HSE 9brefackerom @audcom 907S859721 Tool Push Dave Hlier Nal la Tool Pusher rgmanagerng4@nordio allsta.com 90]6]0d6041 Taal Push Al Hansen Nordic Tour Pusher rgmanagecrig4@nmtliocallsta.cam 90]8]0.8604 Tani Push Jason Morse Nordic HSE dgmanager.ng4@noMiccalista.com 907870.0804 Personnel Log (POB) Company Sam. Type Work H (br) StamMo, H (nt) I count Note tel (CentdlM) ESP 12.50 0 Peak Equipment Operators 12.50 0 2Hours GBR Pipe Handling 12.50 0 25 Hours SLB Logging 12.50 0 12.5 BHGE (Vi Wellhead 12.W 1 12.5 Hours as Sam. Mud engineer 12.50 1 12.5 Hours Tam Packer 12.50 1 12.5 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 412412019 Report #: 19 Page: 2 of 2 Personnel Log (POB) Company Sere. Type Work H(hit Stand-by H(N) Loom Note Baker raking ASRC Jacobs Nortlic Packer Company Men Equipment OParmon NOMic Personnel 12.50 12.50 12.50 1250 1 2 6 21 12.5 IS Hours 50 Hours 275 Hours BOP Stack 6 Components 0escriptlon Start Data Last Cer[Hkadan Dote Pressure Rating (pa) Type Make Model ID Nom Qnl PRange (pill) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Data End Date Liner Size pn) Volume Per Snake Override(blellatk) Moa Pmasure(pi) Date I Deplo(IRKS) Slow Sted Strokes lapm) I P(psQ Ell 1%) OFlow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: gal us Uni[ Sbe: Note: Dale Cona.med Received 0242019 O.D 0.0 Remrnetl Cum Consumed Lum Received 6,164.0 6,169.0 Cum Returned 0.0 Cum On Loc Note 0.0 supply Item Description: Rig Fuel UMt Label: gal us Unit Size: Note: Wte Clonturned Received 42412019 9014 0.0 Returned Cum Consumed Cum Received 20,2(10.0 350600 Co. Returned OU Cam On Lac Note 14.860.0 5u11Imm Dabuptian: Rig weer Unit Laoel: bbl Unit size: Nolo: Data Consumed Received 4MV2019 11.0 0.0 Returned Cum Consumetl Cum Received 5160 fi43.0 Cum Remrnetl DO Cum On LOC Note 12].0 Last Aumodfy visit Date 1 Tot Imp. Nor Total LN.C. number Comment STOP Cards Submitted Company is Rptn Co. NOR ICGCAUSTA SERVICES 4 PJSM General Notes Comment: Well Name: P07 0R Wellbore Name: me: OPO4-07 Well Code: 23693 Job: WORKOVER aniWCER Level: Daily Report Date: 4125/2019 Report #: 20 Page: 1 of 2 Well Header PermNConcrestoo N° Operafm Scholtllary Initial Lahee Code ADL -388583 EMPETROLEUM ENI PMruIeum Co. Inc OEVELOPMENTWELL Rotary Table Elevation mitGround Level in) First Flange I,, RKB-bass Flange ib) RKB-Tubing diamee) 53.20 12.20 Rigs RigName Combined( Rig Type Rig Num RIg SVM Data Rig Release Data RIG 4 NORDIC CALISTA LAND RIG 0981 4/3/2019 Daily Information Weather Tempxistul, (•F) wine Days LTI (days) Days RI (days) POB Overcast 14.o E@to MPH 35.0 Safety Incidents - Near Miss pap Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Gold Ne# Check Type #Occur Last Date Next Date (days) BOP Pressure Test 3 4/2112019 4/2812019 3 Evacuamb drill 2 4/242019 72312019 89 Fire drill 3 4124@019 518/2019 13 Kick While Tripping Drill 4 411612019 4232019 -2 RIg Inspectlen 20 4/25/2019 4262019 1 Safety Meeting 20 4/252019 4262019 1 Spill Onll 1 41112019 4252019 0 Casings seat Cas.Type OD (in) 10 (in) Grade Top(RKB) Banom(IKS) TVD Bot(ftM) Run Date CASING13318 12.42 L-80 -?420.8 2.4209 2,0801 521/2010 CASING 9518 8.68 L80 -D9 8,]27.0 3,6350 01120ID LINER 512 4.89 1410 4,9080 12,142.0 3,9356 6/1312010 Last Cementing Cernentirg Surt Dale: 6132010 actual CASING, 8,727.0111 Comment Stg # Top SKBI Top Meas M04 Ban (RKB) Care 1 6.398 0 Volume Celcok m a 0.727D Planned SOD Above top of N Sand Job Information Job PhaseStanennatl Stan Doh start Oah End pate P50 Duration (days) Pl WORKOVER 4/3201900:OD 4/3x201800:00 4/171201906:30 000 Daily Summary Operations 2,14, Forecast Slip and out drUeng line. RIH to 8509and set 5.112" Rebhvamatio packer inside 5-12- liner. 24h Summary Pick up sub liner run In tale and stab into eastern goer top be back seal bare M 8517 saft, new 7- ecap human hanger and packer Mud Inner top at 7709. Test liner cap packer to 1000 PSI to 30 minutes all good. Pull out of hole wish liner hanger running topic tram 7709 to surfill Operation at 07.09 Slip 0 Cut hall line Time Log End Co. Dur Time Deur) (err) Phase 0". Act Plan Open Dela. 05:00 5.00 V L 1 P tie ick ua assembly wish 1 Imnh of T' 26# TM631 ua ce, liner tengerl paler along with running lools. Rig Sam, GBR longs. 1200 7.00 1200.W.O. M 4 P FIR with T' subfiner assembly to top of 9518" x 512' liner at 8517'. 13:30 1.50 1350 W.O. M 9 P Obutnupanddawnweighu140KUP.95KDNenterUebacksealboreandriagoouial851T. Setdown10Kpickupto L12,OO 130K and filled drill pipe x using annulus, with annulus taking 21 BOL to fill. Dropped 15/8-phynalic ball dawn ern pipe. ewad Into dd11 pipe and pumpetl ball bown at 3 BPM at 75 BBL away slowed pump to 1 BPM, with ball seating at 110 BBL pumpetl. Pressured up b 2350 PSI sml had good Indication of liner burger sating, Moused to 3500 and seen shift Indicating netts inflon and packer Setting, increased to 5000 PSI and seen wdure disc shear. Top of liner at 77091430 1.00 1450 W.OM 12 P Line up and pressure test eer tap Packer at 7709' to surface b 1000 PSI fe 30 minus, goad teal. i8:J000 18.50 W.O. M4 P Trip out of hole wit T sIMP manningtools from 770w to surface 2200 3,50 22.00 W.O. 1 P LD Liner Hanger conning tont, Load 2-7/8' DP. 3.12' DP wal Model 'EA' Radmovi ma c pan r to ppe shed. 2200 00:00 2.00 2400 WO. M 4 P MUpackarand RlHwdh2-010'DP. Ord DP to 2.22'. Brine to hole last 24 boon (midnight)'. 352 BBL TDW Brine to hole (midnight): 6509 BOL Gas Readings Avg Background Gas (%) Mm Background Gas I%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas p6) Max DNII Gas (%) Avg Trip Gas (%) Max Trip Gas (%7 Daily Mud Volumes TanMAddilion/Loss Type ods Volume Bal Tank of Hole Hole Loss Fonmaticn Cumulative Mud Volumes Active Volume Sahli Hole Volume(bbl) Ad0ltions(bbi) Cum Additions (bbl) Losses(bbl) Cum Losses (00 00 0.0 00 0.0 0.0 5.7130 Daily Contacts Position I Contact Name Company Title I EmeltI chaus I goblin En representee Tal®hlro Kosaka Enl ONllIng $UFV. PPtldllingQeni.um Ent representative Steve Lawrence Ent Ddle, Scapa OPPddlling@eni.cam End representative Wed. Thomas Em Rig Clerk 907605-0722 Ent epessnWNe Geom Ackerman Ent HSE geuffeckermangrameom 907685-0721 racialist Dave Hilar Nodi Tool Pusher rigmanagerAg«nodtccalitla.um 907670-0604 Tool Push Al Hanun Nordic Tour Pusher rigmanagectlg4@nodtocalista.um 907670-8504 Tool Push Jason Mame Nordic HSE dgmanager.rig4tlndic-calldepann 907670 -Bet Well Name: OPO4-PO7 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/25/2019 Report #: 20 Page: 2 of 2 Personnel Log (POB) Company Sari. Type Work N un StandAy H (bp Count Note SHOE (Cerappe t Peak SLB SHOE (Valeo) MI Swaco GBR Tam 6a1erfishing ASRC Jacobs Nordic ESP Equipment Operators Logging Wellhead Mud engineer Pipe Handling Packer Packer Corp., We Equipment Operators Nmdlc Personal 1 1250 1250 12.50 12.50 12.50 12.50 12.50 12.50 12.50 12.50 1250 1 0 0 0 1 1 1 1 1 2 7 1 21 25 Hours 12.5 12.5 Hours 12.5 Hou. 25 Houle 12.5 Hours 12.5 25 Hours 50 Hours 275 Hours BOP Stack B Components Description spartudato Last Cerfiff. on Data Pressure Rating IPsI) Type Make Motlel ID Nom lln) PRange (ps0 Last Cert Date Slow Circulation Rates Pump Number: Make: otlel: Stanoate End Date Liner Size (in) Volume Per Sucks Override(bbllstk) Max Pressure(psi) Date I Depth (Wel I Stewspd I itmkes(apm) I P(psi) Ell r%) OFlow (gpm) Daily Bulk supply lam Oescrip on: Equipment Fuel Unit Label: gal us Unit Size: Note: Oat. Lonsumetl 42512018 185.0 Recelved 1850 Returned Cum Consumed Cum Resolved 6,349.0 6,349.0 Cum Returned Qum On Loc Note 0.0 0.0 Supply Item Description: Rig Fuel UPS Label: gal us Unit Size: Note: Date Oonsumetl eenetl 412512019 1,178.0 0.035,060.0 ReWrned Cum Consumed Cum Reeeivetl Cum Resumed Cum On Loc Note 0.0 13,882.0 Supply Item Daaeriptlon: Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Recelved 412512019 8.0 Dg Return" Cum Consumed Cueceetl 524 m RN .0 643.0 m Rm Cuetuatl Cum On Lac Note 00 119.0 Last Authority Visit Date Tot man. Nbr Total I.N.C. number Comment STOP Cards Submitted LomWnY a Rota Com NORDIC LISTA SERVICES 4 PJSM eneral Notes Comment: Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 anill Job: WORKOVER II II WCER Level: Daily Report Date: 4/26/2019 Report p: 21 Page: 1 of 2 Well Header PemdUGorgessipn N° Operator ad India, hutial" hi Cada AOL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENTWELL Robry Table Elevation fail Ground Level (ft) Plret Flange top RKB - Base Flange (ft) h. - Tubing Spool (ft) 5320 12.20 Rigs RigName Contractor Rlg Type Rlg Num Rig Start Data Rig Release Date RIG4 NORDIC CALISTA UWDRIG o9Bt 4132019 Daily Information Weather Temperature (°F) Win Days LTI (days) Days RI (days) POB Overcast 107 SW d@ 2 MPH 350 Safety Incidents - Near Miss Dale category Type Subtype ¢verity Cause Lost time? Comment Safety Drills Days Unit Next Check Type III occur "at Date Near Data (tlays) BOP Pressure Test 34/2112019 4282019 2 Evacuation i ill 2 4242019 7232019 88 Fire drill 3 42412019 5`812019 12 Kick While Tnpping D611 44/1&2019 4212019 3 Rig Inspection 21 4/2&2019 42]2019 1 Sate7Meefing 21 42812019 41272019 1 Spill D611 1 4/1112019 4/25/2018 -1 Casings seat Cas. Type OD (in) ID (in) Grade I Top late) Bottom SKB) TVD But(ftKB) Run Data CARING 13318 12.42 L-80 -27208 2,620.9 2,080.1 112010 CASING 9518 868 l -O9 8,]27.0 3,835.0 &12010 LINER 5112 4.89 480 4.9080 12,1420 3,935.6 &132010 Last Cementing Cementing Start Di 62200 String: CASING, 8727gftKB Comment: Big b Top (ftK8) Top Meas Mem Bbn (aiK8) Com 1 8339.0 Volume Calculations 8,727.0 Planned SOP Above top of N Sand Job Information Job Phase Manned Start Date Start Date Entl Dale P50 Duration (days) WORKOVER 413201900:00 4132111900:00 4/171201806:30 000 Daily Summary operations 24h Forecast Continue to POI to surface and LD teal packs. Rig up and test BOP. 2M Summary Run in hme with 5-%- feat packer. Test casing a1 8551 85118 8580 and 8588' without sucrose. Start out out of hale to surface. operation at III Prep For HOPE Test Time Log and End Cum Our Time Time our In,) Phase Our. ACL Plan Open Descr. 0000 0300 3.00 3.00 W.O. M 4 P Run in hole wall 5 % Baker Remevama4c test packer from 472 to 802 on 3 % drill pipe, change elevators to 5' and continue Mfip in hale on 5- Gill pipe b 14W 0300 05:30 2.50 5.50 W.O. M 4 P Pi wt and slip 100of drilling line 05:30 13'.30 8.00 13.50 W.O. M 4 P Continue to trip In hale with Baker 5%' Reldevamatip teal packer from T1100' to top of i goal liner at 7709'. PU1405091. SIMOPS' Recalibrafa ¢ane management system along with Parson functions, clean fggt from man rider cable and sheaves. 13:30 1540 1.50 1500 W O 4 P Continue to Mp In hole with 9 : lest packer from lop of scab liner at 770% and Ihroul top o ,net at 8517 to 8578' anti sat same. 1500 law 3.00 18.00 W.O. M 12 P Test casing to laid psi. Pressure fall to 1090 psi In 30 min. Repeal test with 1700 psi. Pressure fall to 1120 psi in 30 in Bleed pressure and gel pecker at 0568'. Repeat Mat with same moult. 1800 1900 1.00 1900 W.O. M 12 P Moved packer io 8558' and lesl casing to 1000 psi. Pressure fall W 600 psi N 30 mat, Bleed pmasum aM reoprecate from 8558' M ldrde whits pumping 3 bpm dawn backside. 1900 2030 150 2050 W.O. M 12 P Set packer AT Saw and fast Casing to I IM psi. Pressure fall to 930 psi in 30 min. Increase pressure to 1800 psi. Pressure tall to 1.350 psi in 30 in 20:30 OD40 350 2400 W.O. M 4 P unsettest packer end POH from 8500' to 6577' 1 i Bane b hole last 24 hours (midnight): 312 BBL Total arms to hole (mMnight): 5901 BSL Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg connect" Gas (%) Max ConhwBon Gas (b) Avg Drill Gas(%) Max [ITS Gas (YI Avg Trip Ga. f%) Max Trip Gas (%) Daily Mud Volumes TanklAddition/Loss Type Des Volume)bbl) Tank Surface Hole Hole Los, Folmallon Cumulative Mud Volumes ACLve Volume (bbl)Hole Volume (big) neighbors (bm) Co. Additions (kill Losses (blit CUM Losses glag 0.0 0.0 0.0 00 00 5,713.0 Daily Contacts Position Contact Name Company Title Email I Office I Mobile Eni representative Takashi. Osaka Enl Drilling Sup V. OPPtlIn ng(19an,com EmrepresenMrwe Steve Lawrence Em Drilling Supv. OPPdnlling@leni.wm EM representable Wade Thomas Eni Rig Clark 907-685-0722 Enl ropresenlmive Gaul Ackerman Em HSE geoH.ackerman@ani.mm 907-605-0721 Taal Push Dave Hiler fill Tool Pusher dgmaager. dg4@noMc-ulisM.com 907-670-8604 Tool Push Al Hansen dark. Tour Pusher dgmanagecdg4®nanliculisla.wm 907-670-8604 Tool Push Jaron Mone Nonlic HSE rigmauger.694yanoMltrwllsla.mp 907-670-8604 Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 412612019 Report #: 21 Page: 2 of 2 Personnel Log (POB) Company Su,r. Type Work H(hr) Stand-leyH Inn Count Note BHGE(Camnlil) Peak SLB BHGE (Velcro) MI Swaop GBR Tem Baker fishing ASRC Javbs Nordic ESP Equipment Operators Logging Wellhead Mud engireer Pipe Hanchng Packer Packer Company Men Equipment Opmalms Nordic Personnel 1 12.50 12.50 12.50 12.50 12.50 12,51) 12.50 12.50 12.50 12.50 12,50, 0 0 0 1 1 125 1 1 2 7 1 21 25 Hours 12.5 12.5 Hours 12.5 Hours Houn 12.5 Homs 125 25 Hours 50 Houn 1275 Hours BOP Stack & Components Deacriptlmi Start Data lmst CerMication Date P—,e; Rating fret) TYPke MaModel IO N. go) PR+nge(paTire, Last Cert Date Slow Circulation Rates Pump Number: Make: Motlel: Start Oat End Data Liner Size (in) Volume Per Stroke Override (bbIISfM) Man Pressure(ps0 Date Depth(MB) Slow Spd Strokes(apm) P(psi) EH 1X1 OFlm limed Daily Bulk Supply ltm Deecrippon: Equlpmmd Fue Unit Label: gel us Unit Size: Not: Oats Consumed Recarvetl 4/2612019 61) 0.0 Returned Cum Consumetl Cum Received 6.349.0 6,349.0 Cum Returned 0.0 Cum On Loc Note SO Supplyltem Description: Rig Fuel Unit Label: gal Us Unit Size: Note: Date Consumetl Revived 41M2019 7160 0.0 Returned Cum Consumed! um Received 22,094.0 35.060.0 Cum Returned 0.0 Cum On lx Note 12.996.0 Supplyltsm DeacnpUon: Rig Watr Unit Label: her Unit Size: Note: Data Consumetl Received 4126/2019 50 950 Returned Cum Consumed Cum Received 529.0 >38.D Cum Rearned I. Lum On Los Note 2090 Last Autbonty Visit Date I Tot snap. Nbr Total I.N.C. number Comment STOP Cards Submitted company 9 them C. NORDIC -CACI A ERVICES d PJSM General Notes comment: Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 r�1II Job: WORKOVER e IIII WCER Level: Daily Report Date: 4/2712019 Report #: 22 Page: 1 of 2 Well Header PermI'Mcmcession N° Operator $ubsdlary Initial Lahee Corte NI Petroleum Co. Inc. I DEVELOPMENT WELL ADL -388583 ENIPETROLEUM ED', Rotary Table Elevation JIM Ground LW.. 04 Firs. - dne-in) RKB-Base Flanged) RKS-Tubing Spoof IN) 53,20 12,20 Rigs Rig Name Contractor Wg Type Rg Num Rig Stare Data Rig Release Date PoG 4 NORDIC CRUSTA LAND RIG 0981 4132019 Daily Information WeatherTem",Mo.(°F) Wind Days 171 (days) Days Rl (days) POB Overcoat 14 5 @ 6 MPH 30.0 Safety Incidents- Near Miss Gate Oaogory Type Subtype Severity Cause Loathing) Comment Safety Drills Days until Next Check Type 9Occur Last Oate Next Date (days) BOP Pressure Test 3 4212019 4282019 1 Evacuation drill 2 4242019 )23/2019 87 Fire and 3 4242019 5182019 11 Kink White Tripping gain 44/102019 4232019 4 Rig Inspection 22 42712019 4282019 1 SafetyMaeting 22 4272019 4282019 1 Spill DIII 1 4/11/2019 4252019 -2 Casings seat Col. Type OO (in) ID he) Grade Top(ftKEq I indom(ftKB) I TVD BOt(ftKB) Run Data CASING 133/0 12.42 LBa -2,420.0 2,420.9 2.080.1 Srd..... CASING 9518 0.68 L80 -0.9 0,)220 3.8350 &12010 LINER 512 4.89 L-80 4,900.0 12.142.0 3.935.8 WIX2010 Last Cementing Cementing Shrt Date: W32010 Spend: CASING. 8.727 Linda Comment: Stg pTop (ft!a) Top Maas Main Bob (MIKE) Cam 1 e..., ... me Calculatlonz 8)2/.0 P1mrmd 500Above op of hlSand Job Information Job Phase Plannatl Start Date stare Da.e End Dale Pyo Duration (days) WORKOWR 41320190000 4/3/201900:00 N1]201908:30 0.00 Daily Summaryperaffons But Forecast WH to 0500. Set T test packer in ]' arab Ines Tes18-SIB- 8 T casing and liner cop paakd. 24h Summary Trip out of hole with SS Baker Retrievama8c test pecker from 657T to surface. Test BOP. Run in hole wgM1 ]' Baker Rebievametic last Dadplr. Operation at .1.00 Testing Casing Time Log st.rc End Cum our Time Time Dm Mhr) (hr) Phase Our. Act Plan Oper. Descr. 00:00 06:30 6.50 6.50 W O M 4 P PJSM, top out of hole with S.5" Baker Rembouratle test packet from 657T to 882, change elevators to 312 and continue to tap Out of hole b 93', change elevators to 2 718" and lay down 3 jands oft 7W PH6 tubing, inspect test packer and lay down same. 06:30 ID0D 3.50 10.00 W O. C 1 P OMain wank bay palmi. or prepping for BOP testing. Remove wear bushing, set teat plug, bull testjoinls, ng up BOP tesfing equipment, and rig up 2 -fig hose to", nnulus. 1000 14.00 4.00 1400 W.O. C 12 P Flood B PE and shell test In 250 PSI low and 3500 PSI high. SIM OPS'. Remove Baker liner hangar selling tools, along with ESP equipment from OPO4 decomplason. 1400 21'.00 TOO 21.00 W.O. O 12 P Test GOP to 250 PSI low and 3500 PSI high for 5 mantes each. Test witnessed by AOGCC Inspector Mr. Guy Cook. Rig down BOP test equipment and blowdown op Make, install wear pushing. 1:00 0000 300 24.00 W.O M 4 P Make up Baker ]' -EA' Relaevamatic test poker and RIH T14.£59' Bane to hole last 24 hours (midnight). 245 SBL Tocol Brine to hole (mkNght) 7146 BBL Gas Readings Avg Background Gas (%1 Max Backgrounall Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Unit Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Daily Mud Volumes TanklAddlOonlLoas Type Des Volume (bbl) Tank Sunace Hale Hole Lasa Formation Cumulative Mud Volumes Active Volume (OM7 Hole Volume (bbl) Additions (DM) Cum Additon. (bbl) Losses (bbl) Cum Losses Mbg 0.0 00 0.0 0.0 0.0 5,7130 Daily Contacts Fashion Contact Name Company Tib. Email OlflceI Mobile End repmsentatdve Takahim Kosaka Eel Drilling Ba, OPPdr4ling,teni.com Em representation Steve Lawrence Eni Dnlling Supe. OPPdnlling@eni.com Eel re,mossnterve Wade Thomas End Rig Clain 907485-0722 End repasentsbve Geoff Ackerman Eni HSE greff.co men@entmm 9074854721 Tool Push Dave Hider Nordin Tool Pusher agm nagerng4@nordic-calista.com 9074704604 Tool Push Al Hansen Nmdic Tour Pusher Minuaneger.rig4fitinordivalista.eom 9074708604 Tool Push Jason Morse NoMie HSE rdgmanager ag4@harddowlisia coin 907b708604 Personnel Log (POB) Company Gary. Type Work H(hr) Stand-by H 0 1 count tote Pea Equipment Operators 12.50 OUR Pare Handddng 12 50 0 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 412712019 Report #: 22 Page: 2 of 2 Personnel Log (POB) Company Se W. Type Work H(hr) Stand-by H fir) count Note To.- 81.8 SHOE(Waso) Mi Swaco ASK SHGE (Centpli t) Jacobs Norsk Packer Lagging Wellhead Mud engineer Company Man ESP EquIpme d Operators Norsk Personnel 12.0 12.50 12.50 12. W 12.50 12.50 1250 1250 0 0 1 1 2 6 7 21 125 ours 12.5 12.5 Hours 12.5 Hours 25 Hours 75 Hours SO Hou. 275 Hours BOP Stack & Components Oescdptbn Start Date Last Lertiflcatbn Date Pressure Rating 1psq Type Make Moral ID Nom (In) PRanBe (psi) Lart Cert Oam SIOW Circulation Rates Pump Nurd er: Make: Model: Start Date End Ooh Liner Slze (Int Glenna Per Stroke Oesinuds (bbllstq Max Pressure (psi) Data Depth (NKe� Slow spd Strokes (apml P(ps0 Efl�b) OFlow (gpml Daily Bulk Supply Item Ddacriptian: Eouipment Fuel Unit Label: galus Unit Size: Note: Oate Consume0 Recelvetl 0272019 .F 2260 Returnetl Cum Lassumed cum Receivetl 6,575.0 0 oum Returned c0 Cum On Lee Note 0.0 Supply Item Description: Rig Fuel Unit Lepel: gal us Unit Size: Note: Date 7" Proton Received 62L2019 ]830 0.0 Returnee um Consumetl Oum Reca,dtl 22,8]7.0 35,060.0 Cum Returned 00 Co.Ou Loc Nole 12,1530 Supply Ilam Description: Ri Wabr UnlWbel: bbl Unit sire: Note: Gate Consumetl RemNetl 62]I2019 110 0.0 Returned Cum Consumetl Gum Received 562.0 ]38.0 Lam ReNmdtl 0.0 Cum On Loc Note 196.0 Last Authority Visit Date Tot Inap. Nb, Total I.N.C. numbr Comment STOP Cards Submitted Company Il Rats Com NORDIC -Cr LISA SERVICES if 4 1 PJSM General Notes comment: Well Name:P07 OR Wellbore Name: e: OPO4-0707 Well Code: 23893 rip• Job: WORKOVER ani WCER Level: Daily Report Date: 4/28/2019 Report p: 23 Page: 1 of 2 Well Header PermlVConceas1. N° Operator Su I Iary Initial Lahee Code ADL -308583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation ug Ground Level(h) Flnt Flange (fl) RKB - Base Flange(h) I a.-Tubing-pool(h) 53.20 12.20 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Dab Rig Release Data RIG NORDIC CALISTA LAND RIG 0961 4/32019 Daily Information We Temperature PP) Wina Day: LTI (days) Dry& RI hays) FOR Clear 104 S�12 MPH 36.0 Safety Incidents - Near Miss Dare catagpry Type Subtype Severity Cause Losttlmei Comment Safety Drills Days Date Rea, Check Type NOccur Last Date Next Date (days) AuthorityVeO 1 427/2019 &2112019 29 BOP Pressure Test 4 42]/2019 514/2019 6 Evacuationdrill 2 42412019 72312019 86 Fire drill 3 4242019 WW2019 10 Kick While Tripping Drill 4 4/162019 a2WZ018 -5 Gg lnspectbn 23 42612019 412912019 1 Be" Meeting 23 42812019 412912019 1 Spill Drill 1 4/1112019 42512019 -3 Casings seat Cas.Type OD (in) ID(m) Grade Top (PIKE) Bottom(ftKB) I TVD BUL(ftKB) Run Data CASING 13318 12.42 L80 -2.420.0 2.420.9 2,080.1 5212010 CASING 9518 868 L80 8.9 9,727.0 3,835.0 &112010 LINER 512 4.89 L80 4,908.0 12,lQS 3.9356 611312010 Last Cementing Cementh,Start Data: ft&2010 String: CASING. 6.721011" Comment: Sig p Top (ftKB) Top Meas Meth Bad (RK Com 1 6.339.0 Volume Calculations 8,]2].0 Planned 500Above top of N Send Job Information Job Phase Plennetl Start Data Start Oata End Date P50 Duration (days) WORKOVER 4/3201900:00 4/32019&:00 4/1]20190630 000 Daily Summary Operations 246 Forecast Load pipe shed with complebon tubing, and ESP southern. Prep to ren completion. 2M Summary Trip in hole with 7" War packer and set same at 8486, test casing to 1500 PSI all good, sinew out o/ hole laying down drill pipe. Operation at 01.00 Prepare to min Compietim Time Log Start End Cum Our Time Time our(hr) (M) Phase Our. Act- Plan Door. Descr. 0000 06:00 6.00 800 W.O. M 4 P Conifinue to hip in how with 7" Baker ReMevamadc lest packer tomr4 Rto 8490' and set same with COE at 8486'. M140K DW 91K WO -0 0730 150 7.50 W.O. M 12 P Fi ed casing, took 20 BBL to fill, dosed annular preventar, and pressure tested to 1500 PSI for 30 minutes, chering same. Good Test 0730 1200 4.50 12.00 W.O. M P Released packer and singe one of haw wiU T' Baker ReNevamahc test packer ham 84W to 6750' IaNrg dawn drill pipe, and offloadag pipe shed as required. 12 00 0000 1-200 26 00 W.O. M 4 P PJSM, ontmue -to out of hold with 7 Baker Rehievamatic test packer ftom 6750 to 900' laying down drill pipe, and offloading pipe shed ra required, grime lost to haw last 24 hours (mwnight) 330 BBL Total Brine but to how (mldnght7484 BBL Gas Readings Avg Background Gas I%) Maz Bapkgromd Gas I%1 Avg Connection Gas (%) Maa Connection Gas (%) Avg Drill Gas 1% Max Drill Gas ('hl Avg TNp Gas (%) Mea Trip Daily Mud Volumes TanklAdditionlLoss Type Des Volume (bbl) TankSuaace Hole Acle Lass Formation Cumulative Mud Volumes Active Vowme (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses @b0 Cum Losses (bb0 0.0 0.0 0.0 0.0 00 5,713.0 Daily Contacts Position Contact Name Company Tltie Email Office Mobile Eni representatirve Takahho Kocaka Eni Dnlling Supv. OPPtlnlline�eni.wm Eni Wanarllative Stave Lawrence EN Calling Su, OPPtltllling@eni.com Eni represerm iva Wade Thomas Eni Rig Clerk 9078054722 Eni re nanswlrve Geph Ackerman Eni HSE geohackermanleni. 9078058721 TOW Push Dave Hite, Noa1b Tool Pusher rigmaeagecrg4®nordmidaute core 9078708604 Tod Push Al Hansen Nordic Tour Pusher Mrandager Eg4@nods-oahsta.com 907870.8604 Teal Push Jason Morse North. HSE doranda wo,4®nordis-cobble oro 907870-8604 Personnel Log (P( B) CompanySere. Tried Work H (M) Stara -by H (hr) I count I Note Peak Equipment Operators 12.50 0 25 Hours GBR Pipe Handling 12.50 0 25 Hours Tam Packer 12.50 0 12.5 Haurs SLB Logging 1250 0 12.5 Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/28/2019 Report #: 23 Page: 2 of 2 Personnel Log (POB) Company Sarv. Type Werk H (hr) Stand-by H (hr) Coum Now BEGS (Veme) Mi S,m.. AS BHGE(C.S161h) Jacobs Nordic Wellhead Mud srgIneer company Men ESP Equipment Operators Nordic Personnel 12.50 1250 12.50 1250 1250 12.50 1 1 2 675 7 21 12.5 Hours 12.5 Had 25 Hours Hours 50 Hours 275 Hours BOP Stack 8 Components Description Stan Dew Last CertNwaeon Dew Pressure Rating (psi) Type Make Motlel 1 I Nom (In) I P Range (psi) laat Cert Date Slow Circulation Rates Pump Number: Mike: Mail Start Date End Sate Liner Site (in) Volume Per Stroke Override (bblla[k) Max Pressure 1psp Date DepM(rit. Slow Son I Spoke. (Son) P(Pe0 EN(%I DFlow (gpm) Dairy Bulk Supply Iwm Deacriptim. Equipment Fuel Unit Label: gal us Unit Size: Note: Date Consumed Re. elved 42012019 1230 1230 Returned Cum Consumed Cum Receivetl 6,698.0 6.690.0 Cum Retunretl Cum On Loc Note 00 00 Supply Bem Deserlpthm: Rig Fuel Unit Label: gal Us Unit Size: Note- Oaw Consumed Rettiv¢tl 412012019 1.082.0 DO Returrwd Cum Lonsumetl Cum Received 23,958.0 35,060.0 Cum Returned Cum, Lac No[e 00 11,101.0 Supply lwm Deserlpaon: RMWater UnH Label: bbi Unit Size: Note: Data Consumetl Racewetl 412012019 9.0 O.p Returned Cum Consumwtl Cum Receivetl 551.0 738.0 um Roomed Co. On Lee Note 0.0 187.0 Last Authority Visit Date Tot snap. Nin 4171201 Total I.N.C. number Oamment AOGCC Guy Cook witnessed BOP Test. NSA test due 5/412019 STOP Cards Submitted C." 0 Rab Com NORDICALISTA SERVICES 4 PJSM General Notes Command- Well Name:P0 Wellbore Name: e: OPO4-0707 Well Code: 23893 d�T1n Job: WORKOVER (211 1111 WCER Level: Daily Report Date: 412912019 Report 4: 24 Page: 1 of 2 Well Header PermdOConcession N° Operator fiubsltl ary Initial Lahee Code AOL -308583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation in) Ground Lovel(N) Firat Flange(N) RKB- Base".age I-) RKB- Tubing Spool IN) 5320 1220 R19S Rig Name Contractor Rig TYPa PIg Num Rig Stan Date Rig Release Dao RIG 4 NORDIC CAUSTA IAND RIG 0981 4132019 Daily Information Weather Temperature ('F) Wine Deys LTl(day.) nays Rl (days) POB Cloudy, 248 SW @ 15 MPH 40fl Safety Incidents - Near Miss m Category Type Subtype Severity Cause Losttime] Comment Safety Drills Days Until Next Check Type 9Decur Last Data Next Date (days) Authorty Visit 1 4'272019 52712019 28 BOP Pressure Test 4 42]2019 51412019 5 Evacuation drill 2 4124/2019 ?232019 85 Fir. drill 3 4242019 SAW2019 9 nck While Tripping Drill 4 41162019 4232019 Rig Inspection 24 4292019 413012019 I Sandy Meeting 24 41292019 4'302019 I Spill DOR 1 4'112019 42512019 4 Casings seat Cas.Type I 00(m) ID Jim) Grade Top(ftKB) I Same.(ftKB) TVD Bot.(NKB) Run Date CASING 13318 12.42 L -BO -2.420.8 2,420.9 2A80.1 5212010 CASING 9510 8.68 L00 -09 8.]2]0 3.8350 BI1I20f0 LINER 512 4.89 L -BO 4,9090 12,142.0 3,935.6 WIN2010 Last Cementing Cementing Start Date: 6'32010 Stang: CASING, 8.727 ONKB Comment: See 1 Top(NKB) i Top Meas Mem Ban (ME) Com t 1 6,339.0 Volume Calculations 8,727.0 I Planned SW Above tap of N Sand Job Information Job Phase Planned stars Date sun Date EM DataP50 Duration (days) WORKOVER 413201900:00 413201900:00 411]1201906:30 0.00 Daily Summary Operations 24h Forecast Connect ESP cable, caVdlbry tube, and lest Came. Run in hob with 4-1Q- tubing ta 75M Makeup mt! bred tubing harper. 24h Summary Single out of hole with T baker test packer hung down doll pp., off bad all drill pipe from pipe shed, crane ESP equipment 10 rig floor. Load 4.12' Completion tubing, drift and stop. Pick up Shroud and make up ESP assembly. Operation at 07.00 RIH WIESP Assembly at 1,000 Time Log Start EM Cum Dur Time Time Do, rO (b) PhasetAct Oper. Deacr. 00 00 UT 4 N 400 WO. Continue tosingleout Fele with ]" Baker Retevamatk test packer laying dmvn@ill pipe ham 90V insurface. hapeded test Packer bund We" x L4' long screw misshg, with no other damage or significant wear, laid dawn test packer.0400 1930 1550 1950 W.O. mond remainder of drill pipe m pipe shed. load 4 12" HYD 503 Completion tubing in pipe shed. drlltimg and abapping me. Stage ESP pump and equipment, slope GBR longs and mn hoses to sameSIM OPS: PJSM. UN Me adng,and Cons in ESP Cable spoil, Capillary spool and sprolen for each. 19.30 00:00 4.50 24.00 W.O. Pick up Shmund and ..it, no ESP s.Cambly. Brine Inst b bob last 24 hove (mWnight) 210 BBL Total Brine bat to hole (mddnigMl]694 SBL Gas Readings Avg Background Gar I%) Max Background Gas led Avg Connector Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas ( ) Avg Tdp as (%) Max Trip one (%) Daily Mud Volumes TiOWAdmtimul-mis Type Des Volume (hot) Tank Surface Hole Hole Less Formation Cumulative Mud Volumes oculist Volume@d) Hole Volume Admtions(Wall Cum Additions (ball Losses @b9 Cum Losses (ball DO 0.0 0.0 0.0 0.0 5.]130 Daily Contacts Position Contact Name Company Thus Email Once I Mobile End epr.Cenlativ. Takandro K..aa Ent millirg ..' OPPdallaulperniociono pal e,areenletwe Steve Lawrence Ern Data' Sup, OPPdnlidng@erl.cOm Em representative Wada Th.. End Rig cash 907505-0722 End representative Geaffft saner, Em HSE geoff,aclumman@ehicom 9W68S0721 Tod Push Dave Hilar Need. Tool Pusher rigmanageCdg4@noMio lista.com 907670.8604 Top Push Al Hansen Nordic Tour Pusher ngmanager.ng4@noa1d 1ista.Com 907670.0604 Tool Push Jason Morse Nordk HSE ngmawgetrlg4@nonlacausta Com 907670.8604 Personnel Log (Pil Serve TYPe Work N Ihrl Stand-by H Ihrl CountI=C—P--Y .,Man, OPeratoe 1House0Packer 12.50 0 12.5 HouLogging 1250 0 125 Welheed 12.50 1 12.5 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/29/2019 Report #: 24 Page: 2 of 2 Personnel Log (POB) Company Serv. Type I Wad H (b) I Stand-by H (hal I Count I Note Mi Swam Aspic GBR BHGE(CreumigX) Jambs Nordic Mud engineer Company Man Pipe Handling ESP Equlpmem Operators Nordic Personnel 12.50 12.50 12.50 12.50 1250 12.50 1 2 3 6 7 20 12.5 Hours 25 Hours 25 Hours 75 Hours 50 Hours 275 Hours BOP Stack 8 Components Description Stent Data Last Certification Dah Pressure Rating goal) Type Make Model ID Nom (in) P Range (pail Last Cert Date Slow Circulation Rates Pump umber: ice: Model: Stan Data End Date Liner Size(in) Volume Per Shake Oomide (bbVstk) Mas Pres"M(Pull Date DepIM1 (IIKSt Slow Sptl St.. jasper) P(Poll EX(%) 0Fla. (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: plus Unit Size: NOW Data COnsumetl Received 419/2019 00 00 Returnetl Cum Consumed Cum Received 8,690.0 6,698.0 Cum Ratumed Cum On Loc Note 0.0 0.0 Supply Ilam Description: Rig Fuel Unit Label: gal us put Size: NOW Data Consumed Received 41ZW2018 633.0 00 Returned Cum Consumed Cum Racelved 24,592.0 35,0800 Cum Raturned Cum On Lac Note 11.0 10,4680 Supply Item Description: Rig Water Unit Label: bbl Unit 511e: Note: Date Consumetl Received 4/29/2019 ].0 0.0 Returned Cum Consunwd Cum Received 558.0 ]380 Cu. Returned Cum On We Note 0.0 180.0 Last AUthOrity Visit Date Totlnip.Nbr 4/27/2018 1 1 Total I.N.C. number Comment AOGCC Guy Cook witnessed BOP Teal. Neat test due 5141019 STOP Cards Submitted Company N Rpta Com NORDIC-CALISTA SERVICES 4 PJSM General Notes Comment: Well Name:P07 OR Wellbore Name: e: OPO4-07 Well Code: 23893 Job: WORKOVER en i WCER Level: Daily Report Date: 413 012 01 9 Report It: 25 Page: 1 of 2 Well Header Permitl0oncessian N° Operator SubsidiaryIMtim Lease Code ADLU8583ENI PETROLEUM ENI Pelmleum Ca. lire DEVELOPMENT WELL Remark Table Elevation (R) Ground Level(R) First Flange(MI RKB - Bas. Flange in) RKB - Tubing so., IN), 53.20 12.20 Rigs Me Name ConlmeMs Rig TYpe RIg Num Rig Start Date Rig Release Date RIG NORDIC LISTA LAND RIG 0981 4/32019 Daily Information Weather reemeratore (°fi Wmcl Days LTl /days) Days R! (days) Poe Fog 24.8 NE4 MPH 40.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Gaese Lost timet Comment Safety Drills Days Unill Next Check Type #Occur Last Data Next Date (days) AuthortyVirg 1 4/27/2019 527/2019 27 BOP Pressure Test 44/27/2019 942019 4 Evacuation drill 2 4/24/2019 7232019 0a Fire doll 3 4/24/2019 5/862019 8 Kkk While Trapping Drill 44/1MO19 4232019 -7 IN Inspection 25 4/392019 5/12019 1 $stely Meefing 25 OW2019 5/12019 1 Spill Drill 1 4/11/2019 4252019 -5 Casings seat Cas.Type OD link to (I.) Grade Top(ftKB) Soft—(ftKB) TVD But(RKB) Run Data CASING 1J ]IB 1242 L-80 -2,420.8 2,420.9 2980.1 521201¢ CASING 95/8 8.68 L80 -0.9 8.72].0 3,8350 8/12010 LINER 512 4.89 LA0 4908.0 12,142.0 3.935.6 WIM010 Last Cementing Cementing Stan Date: 602010 S61ng CASIlklr,8.72TOMKB Comment: Stg # Top (ftM Top Mea. MeM Bob eucB) Co. 1 -6,339.0 Volume Cakulations 97270 Planned 50(' Above top of N Sand Job Information Job Phase Planned Sun Date Stan Data End DataPSo Duration (days) WORKOVER 4/3201900:00 VMO1900:00 4/17/2019&:30 000 Daily Summary Operations 24hForecast Cut ESP cable, offload spool tlmm wiM ESP cable aft load empty drum wim crane, cantlnue pull aN of hole with completion. 24h Summary Make up ESP equipment antl from here with same. Operation at 07.00 Replacing ESP Stealer Time Log Start End Cum our Time Time our gm) lml Phase Opr. Act Plan Open Door. 00:00 0490 T 00 400 W.0 K 5 P Make up dischsarge gauge assembly, make tranaumon splice from Vi to Xi on exploary testing splice to 250PSI low and 1001) PSI, all good Make up centralizer amid handling pup, prep to pick up Nble9 Moo 12:00 8.00 12.00 W.O. K 4 P Top in hole with ESP assembly M 3024', conducting elemdcal checks every 100KY all good, OIUrq casing vkh 10 BPH of 9.9 PPG NSCI bmre. 12.00 13.00 Too 1390 W, —0 N 9 P PJSM, Pump tubing volume of 50 BBL, of 99 PPG NaCl burro at 2 BPM rete, and 550 PSI. 13:00 17.00 4.00 1700 IN . K 4 P Continua to trip in hog, with ESP assembly from 301 to SOOG', performkrp electricel checks every 1000. Pumping 10 8PH of 9 9 PPG NaCl brine, down casing. 1700 22:30 550 22 50 W.O. K 25 U Failed elecrical test at 5023. Resistance dropped horn 3.360 at 4000'to 70MO at 5023'. Called town, Eeciskn made to POCH and check the cable. 22:30 0000 1.50 2490 W.O K 4 X003 While POOH, shaft and bearing on BLIGE ESP cable sp rMiW at 2.9GV Berne lost to hole last 24 hours Branix last to hag, Net 24 hours (midnight) 221 SBL Total Stine last to hob (deidnght)7915 BBL Gas Readings Avg Background Gas I%I Max Background Gas P hl Avg Connection Gas I%) Max Connection Gn (/) Avg Drill Gas (%) Max Drill Gas 1°6) Avg Trip Gas (%) Max Trip as I%I Daily Mud Volumes TanMAddi4omLnse T Dee wIF Vame(" Tank Surface Hole Hale Loss Formation Cumulative Mud Volumes Active volume (Ii Hole Volume (hot) Additions (b I) Cum Additions (hot) Losses(bbl) Cum Losses lbbg 09 0.0 ora 00 00 5,713.0 Daily Contacts Position I Contact Name Company Title Small I Office I Mobile Ent mpresenmWe Takebiro K ... or Eni Dolling Supv. OPPorlllirg®am core Eni represidents. Steve Lawrence Eni Dolling Supv. OPPddilingtiI.i.aom Eni depreaentween Wade Thomas Eni Rig Clan 907-685-0722 Eel repreaentene. Geoff Ackerman Eni HSE ...M.eckmmuntierstiom 907-6850721 Text Push Dave Hilar Nmdic Toel Pusher rgmanager.rag4®rinds,-celisM.cam 907870.8604 Tool Push Al Hansen Nordic Tour Pusher rgmanagecragl@dardiacalisu.cam 907-6768804 Tool Push Japan Morse bank, HSE sgramuGand,412nomio-caAafa.cono 907-670-8604 Personnel Log (POB) Company Sam. Type Wars, H(m) I SM.d-by H(hr) 1 Count 1 Note Peak EgWpmanf permors 12.50 0 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 4/3012019 Report #: 25 Page: 2 of 2 Personnel Log (POB) Company Sam. Type Wok H(hr) Stand-by H(hr) Count Nam Tam SLB SHOE (Vetco) MI Swaco ASRC GSR BHGE (Oadrief) Jacobs Nordic Packer Logging Wellhead Mud engineer Company Men Pipe Handit, ESP Equipment Operators Month. Personnel 12 50 12.50 1250 1250 12.50 12.50 1250 1250 1250 0 0 1 1 2 3 6 7 20 12.5 Hours 125 125 Hours 12.5 Hours 25 Hours 25 Hours 75 Hours 50 Hours 275 Hours BOP Stack 8 Components Oescripton Start Data Last Certification Date Pressure Rating("") Type Make Model I 10 Nom lin) I P peaks. (Psi) Last Cert Data Slow Circulation Rates Pump Number: Make: Model: Start DateEnd Dale Liner Sun (I.) Volume Per Stroke Override /bbl/sik) Max Pressure(psi) Data OeplM1 (tel Slow Spot SNoke$(spm) P(pall EN (%) OFlaw(gpm) Daily Bulk supply Item Description: Emporium Fuel Unit Label: gal us Unit son: Note: Date Consumed ReceivedReturnetl 4/30/2018 177.0 1]].0 Cum Consumed Cum Receive Cum Returned Co. On Loc Note 6.875.0 6,8]5.0 00 0.0 Supply Ile. Description: Rlg Fuel Unit Label: gal us Unit size: Note: Date Consumed Received 4/30/2019 694.0 0.0 Returnetl Cum Consumed Cum Received Cum Returnetl Cum On Loc Note 25.285.0 35,080.0 0V 9,774.0 Supply Item Description: Rig Water Unit Label: bbl Unit Siae: Note: Date Consumetl Receivetl 4A0/2019 12.0 0.0 Rep metl Cum Consumed Cum Received Cum Returned Cum On Loc Note 570.0 738.0 10V 168.0 Last Authority Visit Oat. TotinsP. Nb, 4/2]2019 I Total I.N.C. numbs, Comment AOGCC Guy Cook wlmessed SOP Test, NevI test due 5/4/2019 STOP uams Submitted Co." N Rpt. Com NORDIC-CALISTA SERVICES 4 PJ M General Notes comment: Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 Job: WORKOVER ani WCERLevel: Daily Report Date: 6/112019 Report #: 26 Page: 1 of 2 Well Header PermorConcession N°Oaide ADL -388583 aubaltltsry Initial LaM1ee Code ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotery Table Elevation lft) Broued Leve, of First F.age to, RKB - Base Flange in) I RKB-TBeing aped in) 53.20 12.20 Rigs Me Name Contractormg TYPe Rig Num Rig Stan Data Rig Release Data Moo NORDICCaiUSTA LANDRIG 0981 4142019 Daily Information WeatherTemperature(°F1 Wind Days LTI(days) Days in (days) POB Overcast 294 E 1l MPH 42.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost lime] Comment Safety Drills Type a Occur Last Data Nexl Data Days UnXI Next Check (days) Aulhomy Visit BOP Pressure Test Evacuation drill Fire drill Kick While Topping Dnll Rig lic,xvbn Safety Meeting Spill Dell 1 4 2 3 4 26 26 1 4I2W2019 52]12019 412712019 5412019 412412019 723/2019 4/242019 5182019 411612019 4232019 5112019 522019 5112019 522019 411112019 4252019 26 3 83 7 -0 1 1 E Casings seat Cas.Type Do (in) 10 (in) Grade Top(ftKB) I Bottom lftKB) I TVD But.(RKS) Run Date CASI CARING LINER 13318 9518 512 1242 068 4.89 L-80 L80 L-80 -2.420.8 -0.9 4,9oso 2,420.9 872].0 12,1420 2,OB9t 3.8350 3,935.6 5I2t12010 6Itl20to 611312010 Last Cementing Cementing Alan Dab: EG2010 String: CAGING. 8,727.01MB Comment: Stg p Top (ftKB) Top Meas Meth Bbn (kKB) Com 1 6,339.0 Volume Calculations 8.7210 Planned 500' Above tap of N Sand Job Information Job Phase Planned Bion Data Short Dab Ertl Dale P50 Duration (days) WORKOVER 4/31900:00 413201900:00 417201906:30 000 20 Daily Summary Operations 2" Forecast Splice ESP cable. Witness requed by E.1 eleddciai David Delgado. RIH with 4-11V completion tubing. 2atl Summary Change out ESP lobster, POOH F15,024' MD 8 UD ESP assembly, change out came, spools, shot WU shroud 8 ESP assembly. Operation at 07.00 Splicing ESP cable. Time Log Sion End Cum Dur Time Time Dur(ho (len Phase Opt. Act Plan Oper. basc, 00'00 05:30 5.50 5.50 W.O. K 25 U Service in, white acquiring ESP specter. 0590 0800 2.50 $00 W.O. K 5 U UX meeting. Offload partial ESP spool and domagetl specter from do. Load nsw specter and parlial spool back to M. 0800 1090 2.00 1000 W.O. K 4 U Attach E P cable to parlial spool and resume pulling out of hear with ESP assembly, Inspecbg cable and taking eledecal readings every 10 joints, from 6024' to 2019' 1000 14.30 4 SO 14.50 W.O. K 4 U Pump 30 bbl of 9 9 PPG NaCl bene down tubing m 2 bpm. Comms to pull out of hale from 2019 to surface Inspecting ESP cable 1430 15:30 -1 OD 15.50 W.O. K 12 U Perform electrical lest. ESP cable passed and motor tiled the test. 1530 19:30 4.00 19.50 -W K 5 U Iry down ESP anembty and prepare for spool change white acquiring a ESP mote 19:30 2230 100 22.50 W.O. 5 U PJSM, Change out ESP cable spool with crane. 22:30 0000 1 S 24.00 W.O. U Load new ESP motor and seats w86 ZoomBoom. PKk up Blamed and start mating up ESP assembly. Gas Readings Avg Background Gas (%] Max Background Gas (%) Avg Connection Gas (y) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%i Avg Trip Gas (%) Max Trip Gas (%) Daily Mud Volumes TanklAtltli[ionlLoss Typo Des Volume (temp Tank Budace Hale Hole Loss Farmatien 4]] 9 7276 324.5 Cumulative Mud Volumes Active Volume (labl) I Hob Volume (bbl) Addition, (bop Cum Additions (bbQ Losses (bbl) Cum Losses (bbl) 1,204.6 ]2].8 0.0 0.0 324.5 CD37.5 Daily Contacts Position Contact Name Company Tilde Email OfficeMobile End representative Edi apresencifive End apresendadve End representative Too, Push Tod Push Tool Push Takahiro Kosaka Sfeve tawanbe Mitch Blllinyton Geoff Ackerman RicheN Twetll Jake Henry Jason Moae Eni Eni Eni EA Nordic NONic Nbrtlic Drillhg Supv. Drilling Supv. Rig CIeM HSE Tool Pusher Tour Pusher HSE OPPEnbing@hmixom OPNnhing@ani.com AKRIg0leMeOoyonl 5@yve com geoNackerman®eni.cem rigmanagetdg4@tnrdic-cahsta.win 907.88&0722 907$85-0]21 907467048604 Personnel Log (POB) Company Sen. Type Work Harn Sand4ay H(hn Count Net. BHGE (Veteb) Mi peace ASRC GBR In it Mud engineer Company Men Pipe Handling 12.50 12.50 12.50 1250 1 12.5 Houn 1 125 Hours 2 25 Home 3 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 511/2019 Report All: 26 Page: 2 of 2 Personnel Log (POB) company Sam, Type I Work H inn Stand-by H (bol I Count I Note BMGE (Cemell ) Jacobs Nor ESP Equipment Opmators Pereannel 12.50 1250 -c'. 1250 ] ] 21 0].S Hours e].S Hours 262.5 Haure BOP Stack 8 Components Description Start Bah Last Certification Data Pressure Rating (psi) Type Make Model IB Nam(in) PRan,e(paR I Last Cert Data Slow Circulation Rates Pump Number. Melee: Motlel: Skirt Data End Date Liner I ire (in) Volume Per Stroke overrate (bbl,sik) Max Pressure Pal) Data Depth (NKBI Slow Sod Strok ct pli m) I P (pal( EH (%7o Flow (gpm( Daily Bulk Supply Item Description: Equipment Fuel UMt label: gal us Unit 9lze: Note: Gate Cpnsumetl 511,2019 105.0 Receivetl 1060 Returned Cum careened Cum Recalvetl ],060.0 '/,0600 Cum Returned Lum Loc Note DO 0.0 Supply Item Description: Rig Fuel Unit Label: gel us unit Size: Note: Data Conaumetl Received 5/iR01B 6]20 0.0 Returned Cum Consumed Lum Receivetl 25,9580 35.060.0 Cum ReturnedCu-. On Loc Note ou 9,102.0 Supplyltam Description: Rig Water .1111Label: bbl Unit Size: Note: Date Consumed Receivetl W112019 60 0.0 Returned Cum Consumed Cum Receivetl 5]8.0 ]380 Lum Returned Cum on Loc Note 0.0 1620 LastAuthonry Visit Data Tot lnap. Hbr 4Y2]12019 Total I.N.C. number Comment AOGCC Guy Cook witnessed BOP Test Next test due 51412019 STOP Cards Submitted Company 0Rate I Com NORDIC-CHLISTF SERVICES 3 PJSM General Notes Comment: Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 Job: WORKOVER ani WCERLevel: Daily Report Date: 51212019 Report #: 27 Page: 1 of 2 Well Header PermtiConcesslon N° 0,iftw 8Ery Initial Lahee Cotle AOL -388583 ENIPETROLEUM Co. Inc. DEVELOPMENT WELL Rmary Table Elevation( ft) Ground..lo) First Flange (ft) RKB-Base Flange fH) RKS - Tubing Spool lft) 53.20 12.20 Rigs Rlg Name compound, Rig Type R19 Num Rig Start Data Rig Release Date RIG 4 NORDIC CALISTA LAND RIG 0981 4/82019 Daily Information Weather Temperature wind Days LTI(days) Oat's III (days) Poe Partly Cloudy 19.9 E@3x MPH 430 Safety Incidents -Near Miss Date Category Type Subtype Severity Cause Lost firma? Comment Safety Drills Days Until Ned Check Type aoccur Last Date Next Date (days) Authority Visit 1 4n72019 5272019 25 BOP Pressure Test 44/272019 57412019 2 Evacuation drill 2 41242019 7232019 82 Fire drill 3 41242019 518/2019 6 Kick While Thai Drill 40162019 4232019 -9 Rig Inspection 27 5122019 51312019 1 Safety Meeting 27 612/2019 513/2019 1 Spill Drill 1 41112019 425/2019 7 Casings seat Cas.Type I OD lin( 1 10 Ind Grade Top fftKB) I B¢KOIn(HKB) TVD Bot(ft"I Run Date CASING 13318 12.42 480 -2.4208 T,4T0.9 2.000.1 Ani 0 CASING 95IB 860 Leo -0.9 5,7270 3,8350 H12010 LINER Sin 4.89 L-80 4,908.0 12,1420 3,9356 6013I2010 Last Cementing Cememng Start Date: fi3QG10 SMn, CASING. 8,727.Oftn Comment: Stg a TO' Iff Ed Top Meas Meth Btrn lttKe) Com 1 6,339.0 Volume Calculations 8,]2].0 Planned 500' Abovetop of N Sand Job Information Job Phase Pbnnetl Star( Dab Start Date End Date P50 Duration (days) WORKOVER 41320190:0 4/320190000 4/1720190:30 0.00 Daily Summary Operations 24h Forecast Continue to mV In hole with ESP completion to 750'. Make up Tubing Hanger. Terminate ESP cable and Capillary line. Land Tubing Hanger. NO BOP NU Tree. Test This. France ported. RDMO 24h Summary Make up pump and equipment and [rip in hole wIN 106509' MD. Operation at 07.00 Prepping to tend hanger Time Log Stan End Cum Dur O Descr. Time Time our (to) Ihr) Ph... Opr. Act Plan per. 00.00 03:0 3.00 30 W.O. K 24 U PTSM continue b clean rig floor add pipe shed, continue with cleaning and general maintenance while walling on motor coupler to amve from Dead hone. 03:00 07:00 4.00 7.00 W.O. K 5 D Make up and sen4oe motor and seals, make up capillary line to MGU sentmlixer, connect 1 was to MGU, inatall MLE to pothead, prep MILE to for splice and, termini, I yore at DGU. 0700 10:00 3.00 10.00 W.O. K 5 U Splice mold - lead b ESP case, wimessed by ENI eNcbcian Dave Delgafo. 1000 1100 1.00 11.00 W.O. K i2 U Pump through capllbry spool establishing a pump pressure of 1350 PS, make transition splice in captlary Wine from 1/4" to 318;' pressure test splice to 250 PSI, Increase to 100 PSI record pressure on dab logger for 10 min., Increase to 2000 PSI record pressure on data logger for 10 min. 1100 0000 13.0 24.0 W.O. 4 P Tripk hole with ESP completion to 6509, performing electric checks on ESP cable every 1007, maintaining 1000 PSI on capillary line and pumping 10 BPH of 9.9 PPG Naa brine down casing. Pump Tubing volumes 45 bbl of 9.9 pW Nil brilw down tubing. Max 2 bpm Max pressure 685 psi. Gas Readings Avg Background Gas I%) Max Background Gas (Y.) Avg Connecrlon a.. (%) Max Connection Gas l%) An Drill Gas (°:1 Max Drill Gas DLI Avg Tnp Gas (%1 Max Trip Gas red Daily Mu plumes TinkiAtldKbnf,ask Type Des Volume (ball TankSu ace 264.0 Hole Hak 716 3 Lasa FohnaBon 2243 Cumulative Mud Volumes Active Volume @617 Hol¢Votume(bbl) AddlHons(bbI) m Additions fbbg Losses(b60 Cum Losses (bid) G.U.0 980.3 716.3 0.0 2243 6,261.8 Daily Contacts Position Contact Name Cwnpany Tile Email OHad Mobile Eni representative Takakm Kosaks Em Drill, Su,. OP"mang®as End representative Steve Lawrence End Grilling Supv OPPdMlingi.cam End repmsenb8ve Mitch Bilfinglon End Rig Clem, AKRIgCknsDoyxnlS@eni.com 907505-0722 Ent represenblive Geoff Ackerman End HSE ge.ff irs rman0eni.com 907505-0721 Tad Push Richard TweM Nordic Tool Pusher Tool Push Jake Henry Nordic Tour Palmer Tool Push Jason Morse Non is HSE rigmanager dg4®nwd mhsU.com 907570-0604 Personnel Log (POB) Company Serv. Type Work H linty I Stand-by Hlhr) I Count I Nob BHGE (Vets)Weltheatl 12.50 1 12.5 Hours Ml Swaco Mud engineer 12. 0 1 t22 S Hours ASRC Company Men 12.50 2 25 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 5/2/2019 Report #: 27 Page: 2 of 2 Personnel Log (POB) Company Serv. Type Work H(hH I ShnM1by H(hr) I Coed Note GBR SHOE (CentdeR) Jacobs Nordic Peantlliy ESP Equipment ODeralers Nordic Personnel 12.50 12.50 12.50 1250 3 7 B 21 25 on. 825 Hours 100 Hours VOS Hours BOP Stack 8 Components Oe.vlplion 8teb Pressure Rrtin R ate Last Consolation Dag ("I) Ty" Make Model ID Nom (in) PRange/pep Last Cert Date Sow Circulation Rates Pump Number: Make: Model: Start Dars End Dars Liner 51. (in) Volume Per Stroke Override (bbllsik) Max Pressure (psi) Oars Depth (RNs) 1 Slow Sptl Strokes (spm) P (pap En (%) O Flow (gpm) Gaily Bulk Supply Item Description: Equipment Fuel Unit Label: gal us Unit Size: Note: Dale Consumed Recelvetl 522019 226.0 229.0 Returned Cum Consumed Cum Received 7,2890 7,289.6 mReW... d Cu. On Loc Note 0.0 00 Supply Ibm Description: Rig Fuel Unit Label: gal us Unit Size: Note: Date Consumetl Recebetl 522019 565.0 8.366.0 Returnetl Cu- ConsumetlCum Cebetl 28.523.0 01,4460 Cum Returned Cum On L. Note 00 14,9236 Adustmment to on, Supplylhm Uescrlption: RigWafter Unit Label: bbl Unit Size: Note: Oete Consumed Recelv.d 5IS2019 7.0 0.0 Returned Cum Consumetl Lum Receivetl 583.0 >38.0 Cum 0.etumetl Gum On Loc Nate 00 1550 Last Authority Visit Daft, TIN snap. Nor 4278019 Tool I.N.C. number Comment gOGCC Guy Cookwilnessed BOP T..l. Next lest due 514/2019 STOP Cards Submitted Company SRph Com NORDIC-CALISTA SERVIGEB 2 PJSM General Notes Cerement Well Name: P07 OR Wellbore Name: me: OPO4-07 Well Code: 23893 �Job: WORKOVER ani WCER Level: Daily Report Date: 5/3/2019 Report #: 28 Page: 1 of 2 ell Header PevritiConcesslon N' Operator Subdtltery Mal Lehee Cottle ADL -388583 ENIPETROLEUM ENIPelrebum Cu. Inc. DEVELOPMENT WELL Rotary Table Elevation In) Ground Level(tt)First Flange (ttl RKB - Base Flange(tt) RKB-Tubing it". to, 53.20 12.20 Rigs alg Name ontraRig Type Rig Num Rig Stert Date Rig Release Data RIG 4 NORDIC CALISTA /AND RIG 0981 4132019 =11"D1 Daily Information Weather TempenNrel'F) Wind Days LTl fdayst Days RI fdayst POB Clear 27.5 E 18 MPH 30.0 Safety Incidents - Near Miss Orta Category Type Subtype Severity Cause Last dmei Comment Safety Drills Days Lutll Neat Check Type IfOccur Last Date Next Date (days) Authority Visit 1 4/2712019 52712019 2 BOP Pressure Test 4 412712019 51412019 1 Evacuation Mt 2 41242019 72312019 81 Fire unit 3 412412019 5IBIN19 5 Kick While Tripping Drill 4 411612019 42312019 -10 Rig Inspection 28 5132019 W412019 1 Safety Meal 28 5132019 5142019 1 Spill Drill 1 411112019 42512019 4 Casings seat Cas. Type OD fin) ID (in) Grade Top(hKB) I Bottom INKBI TVD Bat. IttKBI Run Date CASING 1131 8 12.42 L -80 -2820.8 ,420.9 2.080.1 5212010 CASING 9518 0.68 L80 -D9 8)27.0 3,835.0 8112010 LINER 512 4.89 L-80 4SMD 12,142.0 3,9356 61132010 Last Cementing Cementing Start Data: W32010 String: CASING, 8,727.OftKB Comment Stg 0 Top (it Ell Tap Meas Mem Bbn (fUOB)Com 1 B, IJeb Volume Calculations 8727.0 Planned 500'Above top of N Sand Job Information Job Phase Planned Start Date Stert Date End Dab P50 Ouration(days) WORKOVER 41320190000 4/3201900:00 411]1201906:30 0.00 Daily Summary Operations Mh Forecast Continue Tree Paeapart Testing Bean pits, prep rg for move. 24h Summary Run ESP completion In 7482'. Land Tubing Hanger. Nipple down BOPE Nipple up Tree. Begin Passport Test. Operation at 07.00 Cleaning pita, prepping ng tar move. Time Log Star[ End cum Our Time Time Durfhr) (hr) Phase 0". Act. Plan Oper. Oescr. 0000 02:30 2.50 2.50 W . K 4 P Trip in hole wlln E P completion from 65M t0 74431 pedomal electrical checks on ESP came every 1000', maintaining 1000 PSI on copper, line and pumping 10 BPH of 9S PPG Nal bine down casing. UW 100K, DW 75K. 02:30 0400 1.50 4.00 W.O. K 5 P Make up tubing hanger wilt awrvelkent orient hanger. Install appling Pant 04:00 0730 3.50 7.50 WG K 5 P Install pene0alor in tubing target, and partmm peoetratar connector splice with ENI electrician Dave Doglike w8necturg e. Terminete capilkry wttll tubing hanger feed through lest capillary connections to 250 PSI increase pressure to1000 PSI, and monitor pressure for 10 minutes on data logger, actual pressure to 2000 PSI and monitor same on date logger for 10 unkides. Increase pressure and aheardhc at 5300 PSI, continue pumping through ceplllury a12700 PSI for 5 minutes, shut down pump and monitored pressure w8M1 check valve closing at 2000 P51. 0730 0830 1.00 8.50 W.O. K 5 P Pull Du bangs, land tubing hangerwtlh ESP compleace 97482' PU INK. S0 70 Tobi Crass coupling clamp 207, Pump damp 3, Splice clamp 1, Proleaolizer 3. 08 ,30 11.00 250 11.00 W.O. K 12 P Perform electrical checks via ESP umbilical, all good, test upper and lower tubhrg hanger seats to 5600 PSI for 10 minutes each. Pull and lay down landing joint. 1100 15:30 450 15.50 W.O. C 5 P Nipple down and Riser. 1530 1]:30 2.OD P.50 W O. C 5 P Nipple up Tree: Test void to 5000 psi 10 min. 1730 00:00 6.50 24 00 W.O. C 12 P StartPassport Teal. Teal wing varve to 30011 psi 30 min. Shell test 3000 psi Include, Gas Readings Avg Background Gas 1%I Max Background Gas (%) Avg Connection Gas I%) Was Connection Gas CA) Avg Drill Gas(%) Max rural as ill Avg 1 u Gas l%I Max Trip hes f%) Daily Mud Volumes TankJAdifiHmi Loss Type Des induced (Wt) Tank SWace Hole Hale Loss Formation Cumulative Mud Volumes Active Volume(bbO Hale Volume (bull Additions (bull Cum Additions (bLosses fbbl) Cu. Losses(Ill) ok 0.0 0.0 0.0 0.0 6,2618 Daily Contacts Position Contact Name Company I red. I Small OMice I Monk Enirepnomat. TakahirO Kmedus Eni OI at, Supv. OPPonBing enLcom Ea reoresecall Steve Lawrence Sol Done, Su" OPPdrilling®eri.ca Ea rummanamos Mltcb Billington Eni Rig Clerk AKM,Cler1cDcmni 511eni.com 97£850]22 EM representative GeaBAckerman Ent HSE geottacllameartteincom 8074305-721 Tool Push Richard Twedt Nordic Tool Pusher Tool Push Jake Henry NoMic Tour Pusher Tool Push Jason Morse NaNlc HSE Mmanager.d94®nordicwlista.com 907470.8604 Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 5/3/2019 Report #: 28 Page: 2 of 2 Personnel Log (POB) Company Sam. Type Work H (M) I Stand-by H IMI I Count Note GBR BHGE (Vetco) Mi Swacp ASRC Junes BHGE(CeninIM) Nordic Pips an Iing W¢Iloead Mud engineer Company Men Equipment Operators ESP Nwdk Personnel 1250 12.50 1250 1250 12.50 12.50 12.50 0 1 1 2 S 7 21 25 Hours 12.5 Hours 12.5 Hours 25 Hours 100 Hours $1.5 Hours 2625 Hours BOP Stack & Components Deieuptlim Stall nota Last Conflinilme Date Pms%ere Rating (Psi) Type Make it Model ID Nom (in) PRanpe lP%ll Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Data End Data Liner Site (in) Volume Per Stroke Override lbbllstle) Max Pressure (psi) Date Depth (WB) Slow Sytl strokes (sPm) P (Pat) EN (%I O Flow (,ora) Oaily, Bulk Supply lam Description EquipmentFuel 5--FG-01 gelus Unit Size: Note: =Oete Consumed 019 165.0 Recetvetl 188.0 Returnetl Cum Consumed Cum Received Cum Rammed Cum On Loc Note 7,45](1 145]0 00 0.0 Supply lam Description: Rig Fuel Unit Label: gal us Unit ta,s: Note: Data Consumed ReceNetl 5/32019 791.0 0.0 ftseemetl CVM Consumed Cum Received Cum Returned Cum Oa Lac NOIe 2],314.0 41,44fi0 0.0 14,1320 Supply lam Description: Rig Water Unit Libel: bbl Unit Size: Note: baa Consumed Received 51312019 16.0 0.0 Returned Cum Consumetl Cum ReceNed Cum Returned um,0d Lac No[e 6010 ]380 00 13)0 Last Authority Visit Data Tot Ins, Nor 4218019 Total I.N.C. number Comment AOGCC Guy Cook witnessed BOP Test. Nest teal due U412019 STOP Cards Submitted Care,, wags Cram NORDIC-CAUSTA SERVICES 3 PJSM General Notes Comment: Well Name: P07 OR Wellbore Name: me: OPO4A7 Well Code: 23893 Job: WORKOVER ani WCER Level: Daily Report Date: 5/4/2019 Report k: 29 Page: 1 of 2 Well Header PermidCencesslgn N° Operator subsidiary Inidai Lahae Coda 'DL3138583ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation (h) .1 turn Level to First Flonge(h) RKB Base Flange 1.) RKB - Tubing Spool(bit 53 20 12.20 Rigs Rig Name Conbacmr Rig Type Rig Num Rig Start Date Rd Release Date RIG d NORDIC CALISTA I LAND RIG 0981 4132019 Daily Information Weathm Temperature PF) Wind Days LTI(days) Days RI (days) POB Overexert 34M5 E @ 14 MPH 330 Safety Incidents -Near Miss Data Category Type rity Cause stdme7 subtype SeveLo Comment Safety Drills Days Unfit Neat Check Type AOccur Last Data Neat Date (day.) Aubmity YSK 1 4272019 52]2019 23 BOP Pressure Test 44/2)/2019 5/4/2019 0 Evacuation drill 2 42421119 723/2019 80 Fire drill 3 41242019 51812019 4 Kick While Tripping Drill 44/162019 42312019 -11 Rig Inspection 28 5132019 5/412019 0 Safety Meeting 28 WW2019 5/4/2019 0 Spill 0,111 1 4/1112019 412512019 -9 Casings seat Ce.. Type Do (mi to Grade Intel"") I Bod. large) I TOO act DtKB) Run Date CASING 133/8 1242 LA0 -2,920.8 2,4209 208D.1 52112010 CASING 95/8 B.fiS L80 -0.e 8,72]0 3.835.0 6112010 LINER 512 4.89 LAO 4.908.0 12,1420 3,935.6 W1M010 Last Cementing Cementing Start Data: 6OCZ010 Shing: CA N . 8,727.01 Commem: Big X I Top(KB) Top Mee. Meth Bbn (itl(B) i Com 11 8,3N.e Volume Calculations 8,T2 .0 I Planned 500Above I, of N Send Job Information Job Phase Planned SMRD.W Shed Data End Date PSY Duration Joey.) WORKOVER 4/3201900:00 41M01900:00 Mi"20190:30 O.OD Daily Summary Operations 24h Forecast Continue to prep rig for move, RDMO. 84h Summary Complete passport inspection, perform maintenance on M equipment, inspect and prep equipment for rg move 0,nomflon at 07.00 Nation, rig for move. Time Log Start End Cum Dur Time Time our (hit (m) Phase Opr. Act Plan Oper. Descr. 00:00 01:30 1.50 150 W.O. C 12 P Complete passport testing per Vetro procedure 01 30 0530 4.00 5.50 W.O. Ah25P Pedom maintenance on pipe skale removed back kicker cylinder no lightened hose connections. Clean and lube one grooves on ROPE equipment, and secure BOP enchsure. 05:30 0:30 1 00 6.50 W.O. CP Remove 1Be flange rom A annulus and meted spool from diesel line valve to A annulus. 06.30 12:00 550 1200 W.O. AP Remove kickerham drillers side of pipe skate to off dogma side, replacing failed ryiinder. Service iron Roughneck. Start preparation to handover well b production. 1200 0000 12.00 24.00 W.O. A Service Air Compressor. Perform pre rig move chestion. Wood remaining 4-1 W tubing from pipe shed. Check callbrefmn on Accumulator gauges. Gas Readings Avg Background Gas I%) Mea Background Gas J%) Avg Connection Gas J%) Mex Connection Gas I%) Avg Drill Gas (%) I Max Drill Gas (%) Avg Trip as (%) Mak Trip Gas (%) Daily Mud Volumes TanklAddlElonlLps. Type Des Vale.(hbD Tank mon Hole le' Hole Lass F.hem n Cumulative Mud Volumes Adel Volume(bM) Hole Volume (hot) Addition. (hot) Cu. Additions@bg Losses lbbg Cum Losses(bbl) 0.0 0.11 00 0.0 0.0 6,261.8 Daily Contacts Position Contact Name Company Tithe Email mi.. Mobile Eni representative Twol Kource End Drilling Supv. OPPdollm,@enlcom Eni representative Steve Lawrence Ed Drilling Supv. OPPdrille@enicom Eni representative Mitch Blinel Eni Rig Clark AKRIgCleftDoyon15@em.com 907,685-0722 Enl representative Gam Ackerman Eni HSE geoffackerman@enLcan 907485-0721 Tool Push RicilaN Twedt NOMk Tool Pusher Tool Push Jake Henry Nomk Tour Pusher Tool Push Jason Minae Nmdb NSE ngmanager.dg4@noMicceiista.com 907470-8804 Personnel Log (POB) Company Servs TYM Work H(hr) Standby H ain Count Nd. GBR Pipes Handling 1250 0 25 Hours BI -DE (Velco) Wellhead 12.50 1 125 Hours MI Svaco Mud engineer 12.50 1 12.5 Hours ASPIC Company Men 12.50 2 25 Hours SHOE (Cerral ESP 1250 2 87 5 Hours Jacobs Equipment Operators 12.50 6 i0 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 6/4/2019 Report #: 29 Page: 2 of 2 Personnel Log POB) Company Seers. Type Work H (hr) Stand-by H Ibn Ceunt Note Minim Nordic Personnel 1250 21 2625 Hauls BOP Stack 8 Components Description Start Date Last Certglutlon Date Pressure Rating (,all Type Make Motlel ID Nom (in) P Range 1%11 Last Cert Date Slow Circulation Rates Pump Number: Make: Model: start DateEnd nate Llner Sinjin) Volume Per Stroke Ovenlde(bbllstk) Mas Pressure(peg Dale DepIb (RKS) slow Spd Strokes (epm) I P(psi) EH(b) aFilm (gpm) Daily Bulk Supply Item Dnthptlpn: Equipmeal Fuel Unit Label: gal us Unit Sire: Note: OMeConsumed Received 5/44019 131.0 131.0 Returnetl Cum Consumed ],5880 Cum Recelvad ],366.0 Cum Returned Cum On Loc 0.0 0.0 Note supply Item Caa criptlon: Rig Fuel Unit Label: gal us Unit St.: Note' Date Consumed ReceNed 8/44019 580.0 0.041,446.0 Retain Lum Consumetl mRecelved Cum Returnetl cum On Loc 00 13,552.0 Note Supply Item Macdptlon: Rig Water Unit Label: bbl Unit Sire: Note: DateConsumed ReCoined LI20'a 6.0 0.0 Returned Cum Constituent! TO Cum Received ]38.0 Co. Returned Cum On Loc 00 131.0 Note Last Authority Visit Date Tot map. Nbr 447/2019 Total I.N.C. number Comment AOGCC Guy Cook witnessed BOP Teal. Next test due N44019 STOP Cards SuDinittend Ccann,amy Rpie Com NORDIC�LISTA SERVICES 1 PJ6M General Notes Comment: Well Name: P0 Wellbore Name: me: OPO4-0707 Well Code: 23893 rr��1p Job: WORKOVER e111111 WCER Level: Daily Report Date: 515/2019 Report #: 30 Page: 1 of 2 Well Header PemJOconceasion N" Operatd SubaMlery Ill Ilse Code AOL -38B583 ENI PETROLEUM ENI Peirolaum Co. Inu DEVELOPMENT WELL Rotary Table Elevation di Groun. Level Vol Fires Ftange(R) RKB - Base ..age I-) RKS-Tubing aPad(R) 53.20 12.20 Rigs HIS Name Contactor Rlg Type RIO Num RI9 Start Data Rig Release Date RIG 4 NORDIC CALIBTA IAND RIG 0981 4/3@019 5/512019 Daily Information Weather T.perat... ff) Wind Days LTI(dayal Days RI(day.) POB Overrzsl 257 E ® 22 MPH 33.0 Safety Incidents - Near Miss Data Category Type Subtype Severely Cause Lost timet Comment Safety Drills Days until Next Check Type #Occur Last Onto Next Date (day.) Aumormyvidt 1 427a 9 519/2019 22 BOP Pressure Test 4 4/912019 51412019 -1 Evacuation end 2 42412019 72312019 79 Fire drill 3 4/2412018 5/8/2019 3 ION, While Treeing Grill 4 4/162019 4232019 -12 Rig Inspection 29 5/42018 5/52019 0 Safety Meeting 29 5142019 WS2019 0 Spill DCII 1 4/11/2019 41252019 -10 TT Camp Fee Dull 1 WW2019 &1192019 14 TT Fire Onli 1 5152019 61192019 14 TT HUS Dell 1 5152019 WW2019 90 TT Kkkwhile dealing 1 5152019 5/19/2018 14 TT Rig Ex.mbon Dill 1 5150019 WW2019 90 TT Spei Drill 2,51512019 SIIW2019 14 Casings seat Cas. Type OD (in) to (in) Grade Top IRKB) Bonn. fl KBI TVD But. (RKBI Run Date CASING 133/8 1242 480 -2.420.8 2, 208 2,000.1 5121/2010 CASING 95/8 8.60 Loo -0.9 8,72]0 &8350 add!. LINER 512 4.89 L-00 4,900.0 12.142.0 3,835.6 6/13/2010 Last Cementing Cemantlng Short Daft: 1 Sbing: ING 8,727.0 B Comment: SyY TOP(RKB)Top Meas Meth a.(f1KB) Com 1 6.339.0 Volume Calculations a,727.0 i Planned 500' Above top of N sand Job Information Job PMw Planned! Short Date Stan Dew Entl Gate PSa duration(drys) WORKOVER 4/3201900:00 413201900:00 4117/201906:30 0.00 Daily Summary operations 24h Forecast Move in all up to well OP10-09, This k the last RNO report for OPO4-P07. 24h Sammary Prepping ry for move, General eg emineximene, and table lop dolls. Opefatlonat0T.00 Moving og. Time Log Start EndCum Dur Time Time our dr) (rah Phase Op. Act Plan Open Oescr. OD 00 1200 12.00 2 00 vs -, A 1 P Servke skate. continue Is meal dg floor Gramme cache manifold leaped de ick Imo rept, shackles. pI, shed bolt inspect bond slips secured roughneck area. I 12'00 D0:00 12.00 24.00 W O. A 1 P Inspect kPong one arching equipment. Rig coven cuffing box and containment berm around rig Level ground in perpetrated for 1 1 I AS mwe. Released! from OP0407 at WS1201924:00. Gas Readings Avg Background Gas I%) Max Background Gas (y) Avg Connedlon Gas (%) Max Connection Gas 1%) Avg Drill Gas I%) Max Drill Gas (%) Avg Trip Ga. I%) Max Trip Gas Old Daily Mu Olumes T..WMdltb.iL . Type Ge. Vol... (led Tank 6uRace Ible Hole Lose Fprmalipn Cumulative Mud Volumes Active Volume SM) Hole Volume (bbl) Mudan.(hb0 Co. Additions@bq Losses(bbl) Cum Losses SIA) 0.0 00 00 0.0 0.0 6,261.8 Daily Contacts Position Contact Name Company Title Email Mo. MOMIe Ertl representative Taushim Kcaaka Ed. Dming Sup, OPPtlolling@eni com Eni representative Steve Lawrance Eel Drilling Sups. OPPduhrgr@enl com Edi representative Mich Billingkn Sol Rig Clerk AKRIgOterks0oyon15ttleni.mm 907 -085 -OM2 San representative Geoff Petrarchan Enl HSE geoR.ackenn ettenLcom 907-685-0nt Tool Puna Richard reach Nonik Triol Pusher Tool Push Jeke Hemy Nordic Tour Pusher Tool PIMM1 Jason Morse Nerdlc HSE rigmanagersig4ttnmdic-calista.com 907-6708 Personnel Log (POB) Company I Sets. Type Work H(an I Stand-by H(hq Count Note GBR Plpe Han hng 13.50 0 25 Hours BHGE (Voice) WeIlM1eaa 12.50 1 12.5 Hours MI Swaco Mud engineer 12.50 1 12.6 Hours Well Name: OPO4-P07 OR Wellbore Name: OPO4-07 Well Code: 23893 Job: WORKOVER WCER Level: Daily Report Date: 5/512019 Report #: 30 Page: 2 of 2 Personnel Log (POB) Company I Sam. Type I Work N(bp I Stentl-by H(W) Count Note ASKCompalry BHGE(Cemnliti) Jacobs NaMic Men ESP Equipment Opemlms Noetic Personnel i .50 12.50 1250 12.50 225 2 6 21 Hours 25 Hou rs 100 Houm 2825 Hours BOP Stack 8 Components Do ItbnLast Start at.Certification Dart Pressure Raling(,I) Type Make Model Nom lin) PRange (psi) Last Cert Dart Slow Circulation Rates Pump Number: Make: btotlel: Sam Date Entl Dale Liner Sbe (in) Volume Per Stroke Override (bblletk) Max Pressure (psi) Date Daplb lXtfa) slo.sptl Slmkes (spm) P(psi) EX(%) OFlow(gpm) Daily Bulk Supplyltem Description: Equipment Fuel Unit label: gal us unit Slee: Note' M.Consumetl Receivetl SI52019 253.0 253.0 returned Cum Consumetl Cum ReceWetl Wm Returned Cum On Loc Nate ],841.0 ].841.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Lobel: gal us Unit Size: Note: Date Lpnaemetl RaceNetl 5/SI2019 693.0 0.0 Retumetl Cum Consumetl Lum Recelvatl Cum Retumetl Cum On Loc Note 28,58].0 41,4480 0.0 128590 Supply lWm Description: Rig Water Unit label: bbl Unit.me: Note: DataConsumetl Recelvetl 5/5/2019 8.0 80.0 Retumetl Cum Consumetl Cum RaceNetl Cum ReWrmtl Cum On Loc Note 815.0 818.0 0.0 2030. Last Authority Visit Data I Tot msp. star 412112019 Total I.N.O. number Comment AOGCCOuy Ceokarftesse0 SOP Test. NeatteSttlue 5/42019 STOP Cards Submitted Company p Rpls Co. NORDICCALISTAS RVICES 1 PJSM General Notes Comment: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Operations Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OPO4-07 Permit to Drill Number: 208-199 Sundry Number: 319-121 Dear Mr. Pierfelici: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.olaska.gov Enclosed is the approved application for the 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, V4��� Daniel T. Seamount, Jr. Commissioner DATED this day f March, 2019. 00 STATE OF ALASKA `�, ,r ^I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS f 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Wdl ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Change out Q 2. Operator Name: 4. Current Well Class: 5. Permit to Dnil Number. Eni US Operating Co. Inc. Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 208-199 r 3. Address: 6. API Number. 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 . 50-029.23409-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? P A Yes ❑ No Etl OPO4-07 9. Property Designation (Lease4lumber): 10. Field/Pool(s): ADL337J94-ADL355024, ADL390616 0 1 Nikaitchug Schrader Bluff Oil Pool 11. '47-3901 -1y-k.6—'3h3,9 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12144 3936 12142 3936 1227 NIA WA Casing Length Size MD TVD Buret Collapse Structural Conductor 160 20" 154 154 Surface 2455 13375 2455 2097 5,210 2,480 Intermediate 8750 9-5/8" 8750 3838 6,890 4,790 Production Liner 3625 5-112" 12142 3936 Slotted Slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8750-12142 3838-3936 4-1/2" L-80 7864 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): NIA WA 12. Attachments: Proposal Summary El Wellbore schematic El 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Tommaso Mallano Authorized Title: Well Operations Proj!V Manager Contact Email: Contact Phone: 907-227-2235 Authorized Signature: Date: OA O 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test [( Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 SOLI /J 5 � 60P Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Q' Subsequent Form Required: u f APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3Jf��,a u iK 1(i I 3'AW_!7 Submit form and Form 10-403 Revised 4/2017 V Approved application is valid fly Aare jrftapproval. _ i Attachments in Duplicate $*Cinii Petirolleviinnl eni 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone(907)865-3320 Email: Stefano.pierfelici@eni.com February 27', 2019 Alaska Oil and Gas Conservation Commission 333 West 7'" Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OPO4-07 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OPO4-07. OPO4-07 was originally completed on OPP on May 10fl' 2010 with a through -tubing conveyed electric submersible pump TTC-ESP set at a depth of 7,868' MD. In August 2015 a workover was done on the well and completed with a conventional ESP. Since February 12th 2019 the well is shut down because of a suspected tubing leak, Plan is to pull out TTC-ESP completion and complete it with new tubing an conventional ESP system. The estimate date for beginning this work is March 30" 2019. 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 Tommaso Mallano at 907-227-2235. Sincerely, � �, f Stefano Pierfelici Well Operations Project Manager OPO4-07 Workover — Summary Page PTD#:208-199 Current Status Well OPO4-07 is currently down due to a tubing leak, waiting for a rig workover. Scope of Work Scope of this workover is to pull the current ESP tubing completion and run in with a new ESP tubing completion.� -�e s C ,5 ; 'D s4 Uo General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1250 psi (3,936' 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/blind/vbr/pipe rams TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8" was tested to 3000 psi prior to drill out on June 6`h 2010. Well type: Producer Estimated start date: March 30st 2019 Drilling rig: Nordic 4 Completion Engineer: Tommaso Mallano: tommaso.mallanoAeni.com Sr. Drilling Engineer: Amjad Chaudhry: amiad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Stefano Pierfelici: Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure: 1. MIRU Nordic 4. 2. Tubing has a suspected leak (if leak in tubing confirmed circulate 9.0 ppg 3 % KCl/NaCl kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 5. Circulate out remaining production fluid. 6. Continue POOH and lay down ESP assembly. 7. PU test packer and RIH to 8450' 8. Pressure test casing to 1500 psi, POOH and LD the test packer. 9. MU new ESP assembly and RIH to setting depth. 10. Land hanger, and test it. 11. Install BPV and nipple down BOP. 12. NU tubing adapter and tree. 13. Pull BPV, install test plug and test tree.(5000 psi test) 14. Circulate Freeze protect through tree down IA. 15. Shut in well. 16. RDMO. Below the current schematic of the well: Surf. Casing 13.3/8", 68 All 2,455 MD. 2.097 TVD 60P Inc. 0A Eni 2,204' MD, 1,954' TVD, 50 deg Inc. - GLM, KBMG. 4-'r; x 1", with 2000 psi STS -1 SOV installed 4-1/." 12.6 ppf Production Tubing 4-%" cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line Ein�ii Peurralleuunna OPO4-07 Oil Producer with ESP Lift As Completed 8/03/2015 7,657' MD, 3.625' TVD, 74 deg Inc. - GLM. KBMG, 4-X" x 1", with 3.100 psi STS -1 SOV installed / 7,765' MD, 3,654' ND - Discharge Gauge Sub 7,826' MD. 3.670' ND, 75 deg Inc — Bottom of Motor Centralizer /Centrilift ESP, 134 -stage 38OP18 SXD + 20 -stage GINPSS SXD pump, 513 GST3 seal, 126 HP MSPl-250 motor 7.889' MD, 3.686' TVD. 75 deg Inc. 23# shroud assembly with eagle and chemical injection line feed-thrus, 3.5" perforated gas dispersion tube HAL Zonal Isolation 8,517' D. Baker SLXP Swell Packers liner Hanger/Packer \ Interm. Casing 9-5/8", 47 # 8,750' MD, 3.838' TVD 84- Inc. Nikaitchuq Field - Confidential Oliklok Point Pad 5- ;" Silver Bullet Ecc. Nose Guide Shoe Slotted Liner, 5AS 17 ppf 12,142' MD, 3,936' TVD VetcoGray MB -247 SURFACE COMPLETION SYSTEM PRP 10161, NC 10 OF 10 23 JANUARY 2009 , GE mocinaoon o:.vork Rig Nordic #4 Well OP -18 Stack measurements Rotary Table Note: To be confirmed when rigged up 2-7/8" x 5" VBR rams INSIDE KILL KILL 4-1/2" pipe rams KILL LINE TOP OF WELL HOUSE 13' 10" to GL RAIAS MAIMAL 4: M: R R !15" 13J 2" 14 3" 29.5" CHOKE LINE 85" Top Flange RISER Upper Lock Down Screws 16' 4" Projected 4' 9" 34' to GL (Nordic Rig 4 25Y 3 RKB 33.5' + 6" mats) Draft 09-28-18 • • Toa ixm F2 8 O N m O LL Y ^� 0) of o r 0 N r ca mrn CO N n n .- coo CO n m 0 at 0)) m N j V 0 , [p U I ) y 2 co N O ymj M N m co cs. ^D n N ' co 1... N1.- 0) .- 0 m N M O O �n O `y "� r/ Q N N CO M N �} N N CO 'C N �} M. •t vz V 0W S tn.. p .a' 1a! 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Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Pump Change Out E 2.Operator Eni US Operating Co.Inc 4.Well Class Before Work: 5.Permit to Drill Number: Name. Development ❑✓ Exploratory ❑ 208-1990 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service ❑ 6 API Number: AK 99503 50-029-23409-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: 0373301,0355024,0390616 OPO4-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Nikaitchuq/Schrader Bluff Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,142 feet Plugs measured feet true vertical 3,936 feet Junk measured feet Effective Depth measured 12,142 feet Packer measured feet true vertical 3,936 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 154 154 Surface 2,455 13 375 2,455 2,097 5,210 2,480 Intermediate 8,750 9.625 8,750 3,838 6,890 4,790 Production Liner 3,392 5 5 12,142 3,936 slotted slotted Perforation depth Measured depth 8750-12142 feet PPNWsti? I11bIC True Vertical depth 3838-3936 feet �b� Tubing(size,grade,measured and true vertical depth) 4.5" 12.6 ppf L80 7,889 3,686'TVD Packers and SSSV(type,measured and true vertical depth) 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: 403 127 299 0 183 Subsequent to operation: 452 119 298 0 182 14.Attachments(required per 20 AAc 25.070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations E Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work. Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-371 Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature 4dPhone (907)865-3328 Date 8/7/2015 Form 10-404 Revised 5/2015 ik -1,31,s' Submit Or' nal Only V// RBDMS AUG 1 4 2015 U W O N (f)Pi a) 000 C a > y a) -O T- N� CD . O NSM }�i cOn O \ N O 0 w • - LQ \ Z I I " M JQ Q =oo. E N ii 1 I Ca Mo v a uU •-o � o � 4111 o r _� C N73 07 � � '2 oi LO . • /� ON c LLU _o p Vit LI _N O N 4 N p + O L O J wm ❑ N U .c-75Q �� I Q V (A U C N i? M in 2 cMSa) � I I; iim Jcl_ CT Zr 2 � Q u) , co t O J L Q � ~ MCD -0 COa I I - m CTS a) co CLS L � 0- ❑ >' p (va_ c C ia) CD -0 O H �' E a) �r �._ O � b OMM CD a) 0 0 . .I I V 73 > d N. N N- '-cc _ H COMCO 03 O (� (� J �--, co- � (� CO- -O M ti L - N- p Li ._ H a w M ❑ 0 (L) LC) C ❑ I I > � N — cn ... a) H O U CO_ a N N C s- CO It CO CC') N •N *k co — co Q) f� oo Li aM CO a) � () .- � ❑� d" .0 •- 2 > // a) � M c M m Q N.: u) \ C O O 0 � \, � NI ti N X 4 4 U CO \ \\\ ,*4 ‘,,,,,,,, , Z lb" \ ../# \ "*".\\ I U (7 a) CL LO p) O LL c `t c; d O CO Cr'5 C� CV N _ a U Y •- O (6 Y 2O '.....- Eni E&P DiVISIOt. Well Name:OPO4-P07 OR • r '}-7 ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq • APIIUWI:50-029-23409-00-00 ^n Date:7/22/2015 - Report#: 1 lam" 1'I' page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1890.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 36.0 2.2 Fog NE @26 MPH Daily summary operation 24h Summary Rig accepted at 12:00.Prepare for rig move.Level grade on pad.C/O Iron roughneck spinner Assy.Housekeeping,paint floor in pump room.Stage Herculite and rig malts.Unable to lay Herculite due to high wind.Cont.to prepare for rig move. Operation at 07.00 Prep to lay out Herculite. 24h Forecast Spot Herculite and rig malts after wind dies down.Prep rig,Lamsons,inner connects and well bay.Spot rig over SP04-07. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1030.5 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 00:00 12.00' 12.00 W.O. 'A 2 P Rig accepted at 12:00.Prepare for rig move.Level grade on pad.CIO Iron roughneck spinner Assy.Housekeeping,paint Floor in pump room.Stage Herculite and rig mans.Unable to lay Herculite due to high wind.Cont.to prepare for ng move. Daily Contacts Position Contact Name Company Title E-mail'- Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL)'.,. --P Surf Applied(kgf)cm°) Eq.Mud Weight(g/L) P LeakOff(kgflcm°) 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 FEni E&P Divisioi. Iweu Name:0=04 Pm OR ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq coni Date:7/23/2015 - Report 2 APIIUWI:50-029-23409-00-00 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1891.81..:. Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 37.0 2.2 Overcast NE @ 9 MPH Daily summary operation 24h Summary Cont.waiting for wind.Prep for rig move,housekeeping,laid felt on walkways,replace air boot on flow line,inner connect rubbers in pits and blow down water in Sub Mod.Lay down Herculite and rig malts.Logistics graded pad for Lampson travel.Removed OPO4 Well Bay hatch.PJSM W/crew,jacked both Sub and Utility Mods.Move Sub Mod east and swapped rig malts and staged.Cont.moving Sub Mod east over well.Check level and shim as needed.Move Utility Mod,spot and level W/shims as needed.Swap power to main generator.Shut down cold start generator.PJSM W/crew,connect inner connects,Pits,Flow Line and Gas Buster.Berm around rig and spot cutting box. Operation at 07.00 Cont.to rig up. 24h Forecast Cont.to rig up.Unload Brine to Pits.R/U to well and kill.Set BPV and N/D Tree.R/U BOPE and test. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1030.5 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 W.O. 'A 1 P PJSA Cont.waiting for wind.Prep for rig move,housekeeping,laid felt on walkways,replace air boot on flow line,inner connect rubbers in pits and blow down water in Sub Mod. 04:00 12:00 8.00 12.00 W.O. A 2 P PJSM Lay down Herculite and ng malts.Logistics graded pad for Lampson travel.Removed OPO4 Well Bay hatch.PJSM W/crew,jacked both Sub and Utility Mods.Move Sub Mod east and swapped rig malts and staged. 12:00 00:00 ' 12,00 24.00 W.O. A 2 P PJSA Cont.moving Sub Mod east over well.Check level and shim as needed.Move Utility Mod,spot and level W/shims as needed.Swap power to main generator.Shut down cold start generator.PJSM W/crew,connect inner connects,Pits, Flow Line and Gas Buster.Berm around rig and spot cutting box. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 fp*diow, Eni E&P Divisiol° I Well Name:OPO4-P07 OR I` ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq l n Date:7/24/2015 - Report#: 3 APIIUWI:50-029-23409-00-00 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OPO4-07 WORKOVER 1892.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 38.0 1.7 Overcast N @ 8 MPH Daily summary operation 24h Summary Cont.to R/U Inner connects,berm containment around rig.Lowered sheave F/Derrick to rig floor for improvement for ESP and CAP lines.R/U steam and H2O to Sub Mod.Take on 8.6 ppg 3%KCL Brine to Pits.Set Cutting Box and secure containment.Adjusted all landings and housekeeping.Install Well Bay cover on OP16.Press.wash Lampson motor.Lower Dixie Cup,move well head sign and post on rig.Prep 90 bbl 8.6 ppg Brine DF03004 Antifoam.PJSEA and Permitting for Well Bay.Gather up Misc.2"HP hose,swings,plug valves and Tee's.R/U to Tree.Bull head down 4.5"Tubing 40 bbl 8.6 ppg 120°F 3%KCL Brine W/Antifoam @ 76 GPM,780 PSI.Bull down IA 9 5/8"X 4.5"40 bbl 120°F 3%KCL Brine W/Antifoam followed by 450 bbl 8.6 ppg 3%KCL Brine @ 165 GPM,485 PSI.Shut in 4.5"Tubing W/120 PSI at well head.IA Press.55 PSI.R/U Bleed Tank and HP 1"hose.Bleed Press.F/4.5"Tubing down to 75 PSI.Line up and U-Tub Tubing and IA to 75 PSI.Cont.to attempt to bleed Press.F/4.5"Tubing F/75 PSI to Bleed Tank.IA Press.65 PSI.Order 290 bbl 9.0 ppg 3%KCL Brine from Deadhorse.Prep and stage KCL in Pits to weight up F/8.6 ppg to 9.0 ppg. Operation at 07.00 Bleeding off Well. 24h Forecast Cont.to attempt to bleed down 4.5"Tubing to Bleed Tank to set BPV.Bring 290 bbl 9.0 ppg 3%KCL and load it to rig.If unable to bleed tubing,bull head 32 bbl 9.0 ppg 3%KCL Brine down 4.5"Tubing and 450 bbl 9.0 ppg 3%KCL Brine down IA.Set BPV and N/D Tree.N/U and test BOPE. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1030.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dexter. 00:00 12:00 12.00 12.00 W.O. A 2 P PJSA Cont.to R/U Inner connects,berm containment around rig.Lowered sheave F/Derrick to rig Floor for improvement for ESP and CAP lines.R/U steam and H2O to Sub Mod.Take on 8.6 ppg 3%KCL Brine to Pits.Set Cutting Box and secure containment.Adjusted all landings and housekeeping.Install Well Bay cover on OP16.Press.wash Lampson motor.Lower Dixie Cup,move well head sign and post on rig.Prep 90 bbl 8.6 ppg Brine W/DF03004 Antifoam. 12:00 14:00 2.00 14.00 W.O. C 5 P PJSEA and Permitting for Well Bay.Gather up Misc.2"HP hose,swings,plug valves and Tee's.R/U to Tree. 14:00 17:00 3.00 17.00 W.O. L 9 P -PJSEA Bull head down 4.5"Tubing 40 bbl 86 ppg 120°F 3%KCL Brine W/Antifoam @ 76 GPM,780 PSI.Bull down IA 9 5/8"X 4.5"40 bbl 120°F 3%KCL Brine W/Antifoam followed by 450 bbl 8.6 ppg 3%KCL Brine @ 165 GPM,485 PSI. 17:00 00:00 7.00 24.00 W.O. L 11 P PJSEA Shut in 4.5"Tubing W/120 PSI at well head.IA Press.55 PSI.R/U Bleed Tank and HP 1"hose.Bleed Press.FI 4.5"Tubing down to 75 PSI.Line up and U-Tub Tubing and IA to 75 PSI.Cont.to attempt to bleed Press.F/4.5"Tubing F/ 75 PSI to Bleed Tank.IA Press.65 PSI.Order 290 bbl 9.0 ppg 3%KCL Brine from Deadhorse.Prep and stage KCL in Pits to weight up F/8.6 ppg to 9.0 ppg. Daily Contacts Position Contact Name Company Title E-mailOffice Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Dulling Tool Pusher Tool Push Michael Coker Nabors Alaska Dulling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892'L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 • Eni E&P Divisio►.T �weu Name:OPO4-Pm OR � . ifil* ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq • Date:7/25/2015 - Report#: 4 APUUWI:50-029-23409-00-00 iii page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER __ 1893.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 38.0 1.7 Overcast NW @ 8 MPH Daily summary operation 24h Summary Cont.to bleed down 4.5"Tubing Press.to bleed tank.Tubing Press.75 PSI,IA 65 PSI.Bring on 290 bbl 9.0 ppg 3%KCL Brine.Cont.to bleed Press.from well.Weight up Brine in Pits F/8.6 ppg to 9.0 ppg.Transfer 290 bbl 9.0 ppg Brine to Pits and blend W/active system.Bull head 40 bbl 9.0 ppg KCUBrine down 4.5"Tubing©92 GPM 630 PSI.Bull head down IA 500 bbl 9.0 ppg KCL/Brine 252 GPM 790 PSI.Shut in Press.99 PSI Tubing and IA.Bleed down Tubing and IA F/25 PSI to 5 PSI. Take on 290 bbl 9.0 3%KCL Brine.Cont.housekeeping.Press.wash Lampson engines.Prep freight elevator basket for paint.Clean out connex and load W/critical spare Equip.PJSM W/all essential personnel for slick line operations.Ensure proper permitting completed.Stage tools and Equip.to Pipe Shed.Clean and clear rig floor.P/U M/U Tools and Equip to rig floor.M/U Halliburton 7"X 6"Otis X/O,Pump In Sub,Mini BOPE and Lubricator section to rig floor.Hang slick line sheave in Elevators and raise to height.Tubing and IA Press.55 PSI. Operation at 07.00 Monitor and bleed down tubing. 24h Forecast Cont,to rig up slick line.Slick line crew timed out.Cont.to monitor Press.Tubing and IA.M/U slick line tools and PT Lubricator.RIH set catcher,pull sheared GLM valve,set dummy valve,pull catcher. R/D Halliburton slick line.Bull head 9.0 ppg 4.5"Tubing volume to lower GLM.Bleed down tubing Press.and set BPV as per Vetco Grey. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper_Descr. 00:00 05:30 5.50 5.50 W.O. L 11 P -PJSEA Cont.to bleed down 4.5"Tubing Press.to bleed tank.Tubing Press.75 PSI,IA 65 PSI.Bring on 290 bbl 9.0 ppg 3%KCL Brine. 05:30 09 30 4.00 9.50 W.O. L 20 P PJSEA Cont.to bleed Pressfrom well.Weight up Brine in Pits F/8.6 ppg to 9.0 ppg.Transfer 290 bbl 9.0 ppg Brine to Pits and blend W/active system. 09:30 11:30 2.00 11.50 W 0 L 9 P PJSEA Bull head 40 bbl 9.0 ppg KCUBrine down 4.5"Tubing @ 92 GPM 630 PSI.Bull head down IA 500 bbl 9.0 ppg KCL/Brine 252 GPM 790 PSI. 11:30 12:00 0.50 12.00 W.O. L 11 P PJSEA Shut in Press.99 PSI Tubing and IA.Bleed down Tubing and IA to 25 PSI. 12:00 20:00 8.00 20.00 W.O. L 11 P PJSEA Cont.to bleed down Tubing and IA Press.F/25 PSI to 5 PSI. Take on 290 bbl 9.0 3%KCL Brine.Cont. housekeeping.Press.wash Lampson engines.Prep freight elevator basket for paint.Clean out convex and load W/critical spare Equip. 20:00 00:00 4.00 24.00 W 0 R 20 U PJSM W/all essential personnel for slick line operations.Ensure proper permitting completed.Stage tools and Equip.to Pipe Shed.Clean and clear rig floor.P/U M/U Tools and Equip to rig floor.M/U Halliburton 7"X 6"Otis X/O,Pump In Sub, Mini BOPE and Lubricator section to rig floor.Hang slick line sheave in Elevators and raise to height.Tubing and IA Press. 55 PSI. Daily Contacts Position Contact Name Company -' Title E-mail - Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com '907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Dolling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7"" e Eni E&P DiviSioi. (Well Name:OPO4-P07 OR ENI Petroleum Co.Inc. Daily Report Well Code:23893 . Field Name:Nikaitchuq Date:7/26/2015 - Report#: 5 APIIUWI:50-029-23409-00-00 " " page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1894.81 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 37.0 2.8 Overcast NW @ 8 MPH Daily summary operation 24h Summary Rig up slick line and tools.Slickline timed out.Weight up Brine on rig to 9.0 ppg.Clean around rig.Check slings.Work on studs for DSA for choke line.Unload mud product.PJSM W/all essential personnel for slickline work and Press.testing Lubricator.M/U Slickline BHA W/Catcher.Press.test Lubricator to 1,000 PSI.RIH attempt to set Catcher below GLM,could not release.Pump 40 bbl 9.2 ppg Brine @ 100°F @.5 bpm,480 PSI.Unable to set Catcher,POOH.RIH 2,163'WLM W/OK6-1 1/4"JDC Pulling Tool.Assist running tool pumping 2 bpm,480 PSI.Pull Shear Valve.POOH.RIH W/ 1"Dummy valve pumping 1 bpm,0 PSI 9.2 ppg Brine.Making several attempts to set Dummy valve.Slickline broke at spooling unit.Was able to set safety clamp.Make PJSEA for reknotting slickline. Have PJSM WI ENI Co Rep,ENI Safety Rep,Nabors and Halliburton personnel.Secure slickline to top of Lubricator with Tee Clamp.Lower Blocks and perform slickline knot. Re spool 5 wraps on to drum.Halliburton HES supervisor was notified.Kuparuk Supervisor,Halliburton Service Manager&FSM on location.Cont.to try and set 1"Dummy valve,assist W/pumping 1 bpm,0 PSI.No success. POOH to check if Dummy valve was still on setting tool.Dummy valve was seen at surface.The 4.5"Tubing went on vac.Decision was made to R/D Wireline.PJSM W/all essential personnel for R/D Wireline.R/D Lubricator and Sheave. Operation at 07.00 N/D Tree as per Vetco Grey 24h Forecast Cont.to R/D Slickline.Set BPV as per Vetco Grey Rep onsite.N/D Tree and N/U BOPE.Test BOPE. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 W.O. R 20 'U PJSEA Rig up slick line and tools. 01:00 07:00 6.00 7.00 W.O. R 20 'U PJSEA Slickline timed out.Weight up Brine on rig to 9.0 ppg.Clean around rig.Check slings.Work on studs for DSA for choke line.Unload mud product 07:00 08:00 1.00 8.00 W.O. R 20 U PJSM W/all essential personnel for slickline work and Press.testing Lubricator. 08:00 12:00 4.00 12.00 W.O. R 19 U PJSEA M/U Wireline BHA W/Catcher.Press.test Lubricator to 1,000 PSI.RIH attempt to set Catcher below GLM,could not release.Pump 40 bbl 9.2 ppg Brine @ 100°F @.5 bpm,480 PSI.Unable to set Catcher,POOH. 12:00 14:00 2.00' 14.00 W.O. R 19 U PJSEA RIH 2,163'WLM W/OK6-1 1/4"JDC Pulling Tool.Assist running tool pumping 2 bpm,480 PSI.Pull Shear Valve. POOH. 14:00 17:30 3.50 17.50 W.O. R 19 'U PJSEA RIH W/1"Dummy valve pumping 1 bpm,0 PSI 9.2 ppg Brine.Making several attempts to set Dummy valve. 17:30 21:30 4.00 21.50 W.O. R 20 XS03 Slickline broke at spooling unit.Was able to set safety clamp.Make PJSEA for reknotting wireline.Have PJSM W/ENI Co Rep,ENI Safety Rep,Nabors and Halliburton personnel.Secure slickline to top of Lubricator with Tee Clamp.Lower Blocks and perform slickline knot.Re spool 5 wraps on to drum.Halliburton HES supervisor was notified.Kuparuk Supervisor, Halliburton Service Manager&FSM on location. 21:30 23:00 1.50 23.00 W.O. R 19 'U PJSEA Cont.to try and set 1"Dummy valve,assist W/pumping 1 bpm,0 PSI.No success.POOH to check if Dummy valve was still on setting tool.Dummy valve was seen at surface.The 4.5"Tubing went on vac.Decision was made to R/D Wireline. ---... - 23:00 00:00 1.00 24.00 W.O. R 20 U PJSM W/all essential personnel for R/D Wireline.R/D Lubricator and Sheave. Daily Contacts Position Contact Name Company Title Email _ Office - Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Dolling Tool Pusher Last Casing seat Cas.Type OD(in) 1D(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 Em E&P DIVlslo.. 'Well Name:OPO4-P07 OR I. l . ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq e n n Date:7/27/2015 - Report#: 6 APIIUWI:50-029-23409-00-00 'I "I' page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1895.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POE Temperature(°C) Weather Wind 0.00 36.0 1.7 Overcast N @ 9 MPH Daily summary operation 24h Summary Rig down and lay down slickline tools and BOP.Blow down and rig down 2"HP hose and manifold in Well Bay.Pull Otis cap on top of Tree and set BPV as per Vetco Grey.N/D Tree and set back in cellar as per Vetco Grey Rep onsite.N/U BOPE.Set HP Riser on well head and made Grey Loc as per Vetco Grey Rep onsite.Pick up Stack and M/U to HP Riser.Vetco Rep M/U Speed Head.Put turn buckles on BOPE,M/U Kill and Choke Line,Flow Line,Bell Nipple and Katch Kan.P/U M/U 4.5"Test Joint,X/0 Subs.Welder installed hand rail pockets on rig floor.Monitor IA Press.while N/U 0 PSI. M/U X/O for 4.5"Test Jnt,Test Dart and test joint to Hanger.When filling BOPE notice Flow Line dresser sleeve leaked and riser Katch Kan.Isolate Riser and Cont.to fill Kill&Choke Manifold.Fix dresser sleeve on Flow Line.Re silicone Katch Kanto Pitcher Nipple.Test BOPE.Test waived by AOGCC John Crisp. Operation at 07.00 R/U Baker Centralift tools and Equip. 24h Forecast Finish BOPE test.R/D test Equip.Pull BPV and set landing joint and floor valve.Well on vac and 0 PSI on IA.R/U Baker Centralift Sheaves,elephant trunk,Herculite and ropes for lines.R/U GBR tools and Equip.Pull Hanger and test.L/D Hanger and decomplete well. Lithology Shows MAASP(kgflcm.) Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr, Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 W.O. R 20 P PJSM Rig down and lay down slickline tools and BOP. 02:00 02:30 0.50 2.50 W.O. C 20 P PJSEA Blow down and rig down 2"HP hose and manifold in Well Bay. 02:30 03:00 0.50 3.00 W.O. C 19 P PJSEA Pull Otis capon top of Tree and set BPV as per Vetco Grey. 03:00 04:00 1.00 4.00 W.O. C 5 P PJSEA N/D Tree and set back in cellar as per Vetco Grey Rep onsite. 04:00 12:00 8.00 12.00 W.O. C 5 P PJSEA N/U BOPE.Set HP Riser on well head and made Grey Loc as per Vetco Grey Rep onsite.Pick up Stack and M/U to HP Riser.Vetco Rep M/U Speed Head.Put tum buckles on BOPE,M/U Kill and Choke Line,Flow Line,Bell Nipple and Katch Kan.P/U M/U 4.5"Test Joint,X/O Subs.Welder installed hand rail pockets on rig floor.Monitor IA Press.while N/U 0 PSI. 12:00 16:00 4.00 16.00 W.O. C 20 P PJSEA M/U X/O for 4.5"Test Jnt,Test Dart and test joint to Hanger.When filling BOPE notice Flow Line dresser sleeve leaked and user Katch Kan.Isolate Riser and Cont.to fill Kill&Choke Manifold. 16:00 17:00 1.00 17.00 W.O. C 20 P PJSEA Fix dresser sleeve on Flow Line.Re silicone Katch Kanto Pitcher Nipple. 17:00 00:00 7.00 24.00 W.O. C 12 P PJSEA Test BOPE:W 4.5"Test Joint.Test Annular Preventer to 250 PSI low and 2,500 PSI high.FSVO,TIW,Valves 1- 16,Kill&Choke Manual and HCR,Upper and Lower IBOP,Demco Kill,Upper and Lower Variable Rams and Blind Rams to 250 PSI and 3,500 PSI high.Test Manual Choke A&B and Super Choke to 1,500 PSI.All charted.Nitrogen 5 bottle average 2,040 PSI.Perform draw down on Koomey.Test waived by AOGCC John Crisp. Daily Contacts Position Contact Name Company -Title _ E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm.) 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 Eni E&P D%Vi$io•_ 'Well Name:OPO4-P07 OR ENI Petroleum Co.Inc. Daily Report Well Code:23893 **141111w Field Name:Nikaitchuq s' �t Date:7/28/2015 - Report#: 7 APIIUWI:50-029-23409-00-00 efli1i page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 1622 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1896.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 33.0 1_7 Overcast NW @ 9 MPH Daily summary operation 24h Summary Complete BOP test,UD test equipment&blow down choke manifold.Test waived by AOGCC John Crisp.Insure well is dead&pull BPV.Hang Baker Centrilift double sheave and elepahant trunk for ESP cable&control line.R/U GBR casing tools.Install flagging around ESP spooling unit.Pull hanger to rig floor,unseated with 120K.BCL tested conductivity.L/D hanger&1 VIT jt.Moblize Baker Fishing Tools,to pull damaged VIT jt.with spear&grapple.POOH laying down 4.5"production tubing F/7,805 T/6,443'Filling hole with 12 bbls 9.2 ft brine every hour. Operation at 07.00 Continue POOH and lay down 4.5"production tubing 24h Forecast Continue POOH and lay down 4.5"production tubing to upper GLM.Rig up to pump down tubing&shear lower GLM. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 W.O. C 12 P PJSM:Complete BOP test,L/D test equipment&blow down choke manifold.Test waived by AOGCC John Crisp. 01:00 01:30 0.50 1.50 W.O. C 20 P PJSM:Insure well is dead&pull BPV. 01.30 07:00 ' 5.50 7.00'W 0. L 20 P PJSM:Hang BCL double sheave for ESP cable&control line.R/U GBR casing tools.Install flagging around ESP spooling unit. 07:00 12:00 5.00 12.00 W.O. L 4 P PJSM:Pull hanger to rig floor,unseated with 120K.BCL tested conductivity.LID hanger&1 VIT jt. 12:00 17:00 5.00 17.00 W.O. L 13 TR99 PJSM:Moblize Baker Fishing Tools,to pull damaged VIT jt.with spear&grapple. 17:00 00:00 7.00 24.00 W.O. L 4 P PJSM:POOH laying down 4.5"production tubing Ff7,805'T/6,443'Filling hole with 12 bbls 9.28 brine every hour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Satch Bowe ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,659.99 1,168.91.VersaPro OBM 1054.5 72.5 1675.2 195.7 • Eni E&P Divisiof. IWell Name:OPO4-P07 OR ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq • e II II o Date:7/2912015 - Report#: 8 APIIUWI:50-029-23409-00-00 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1897.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 36.0 1.4 Overcast E @ 14 MPH Daily summary operation 24h Summary POOH laying down 4.5"tubing F/6,643'T/5,688'Pressure test surface lines to 3,500 psi.Pump down tubing to shear lower GLM,sheared at 2,200 psi.Pump 90 bbls.heated 9.2 ppg brine W/3%KCL. Cont.laying down 4.5" tubing F/5,688'T/190'Filling hole with 12 bbls 9.2#brine every hour.Throuough prejob conducted with all pertinent personnel including ENI Safety.R/U Halliburton,RIH to retrieve slip stop&tag up 20'high.Note:Sand present on running tool.RID Halliburton.PJSM with BCL to lay down remaining completion components.POOH laying down 4.5" tubing F/190'T/90'Attempt to free pump X/O.No success.Disassemble&UD upper&lower seal sections.L/D motor&pump.Clean&clear rig floor.Load pump&equipment into shipping crates&remove from pipe shed. Operation at 07.00 Rigging up to run ESP Completion.Note hanger test run was good. 24h Forecast Rig down Baker Centrilift&prep new equipment for completion run.Perform test run with hanger.Slip&cut drilling line.Rig up Baker and run completion. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 W.O. L 4 P PJSM:POOH laying down 4.5"production tubing F/6,643'T/5,688'Filling hole with 12 bbls 9.2#brine every hour.Inspect threads,strap&deft tubing. 02:30 03:30 1.00 3.50 W.O. L 9 P PJSA:Pressure test surface lines to 3,500 psi.Pump down tubing to shear lower GLM,sheared at 2,200 psi.Pump 90 bbls.heated 9.2 ppg brine W/3%KCL. 03:30 15:30 12.00 15,50 W.O. L 4 P PJSM:POOH laying down 4.5"production tubing F/5,688'T/190'Filling hole with 12 bbls 9.25 brine every hour.Inspect threads,strap&drift tubing. 15:30 20:00 4.50 20.00 W.O. L 15 P PJSM:Throuough prejob conducted with all pertinent personnel including ENI Safety.R/U Halliburton wire line sheaves& running tool.RIH to retrieve slip stop&tag up 20'high.Note:Sand present on running tool.R/D Halliburton. 20:00 23:30 3.50 23.50 W.O. L 5 P PJSM with BCL to lay down remaining completion components.POOH laying down 4.5"production tubing F/190'T/90' Attempt to free pump X/O.No success.Disassemble&L/D upper&lower seal sections.UD motor&pump. 23:30 00:00 0.50 24.00 W.O. L 5 P PJSA:Clean&clear ng floor.Load pump&equipment into shipping crates&remove from pipe shed. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Satch Bowe ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 Eni E&P Divisiot. I Well Name:OPO4-P07 OR EN!Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq • API/UWI:50-029-23409-00-00 einl Date:7/30/2015 - Report#: 9 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1898.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 36.0 3.3 Overcast/Fog E @ 22 MPH Daily summary operation 24h Summary Pull ESP cable&cap tube back onto spooling unit.Finsh cleaning floor from tubing pull. P/U landing jt.&M/U to hanger.Set hanger and run in lock downs.Test seals for 10 minutes each to 5,000 psi. Tests good.L/D both landing jt.&hanger.Perform slip&cut of drilling line.UD elephant trunk,change out ESP spools,pull ESP cable&cap tube over sheaves.M/U shroud assembly.Bring BCL tools to rig floor.Baker Rep.made up motor,seals&pump.M/U cap tube,tec wire&MLE.RIH with 1 jt.4.5" M/U to 3,800 FT/Lbs.BCL performed gator splice,witnessed by ENI Rep.&ENI electrcian. Conductivity test good. Operation at 07.00 Running in hole with 4.5"completion string. 24h Forecast Finish 4.5"completion run. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur.(hr) Phase Opr. Act. Plan Oper.Descr.. 00:00 01:00 1.00 1.00 W.O. L 5 'P PJSM:Pull ESP cable&cap tube over sheaves back onto spooling unit.Finsh cleaning floor from tubing pull.Remove pulled pump from pipe shed. 01:00 03:00 2.00 3.00 W.O. M 12 P PJSM:P/U landing jt.&M/U to hanger.Set hanger and run in lock down screws.Test both upper&lower tubing body hanger seals for 10 minutes each to 5,000 psi.Tests good.L/D both landing jt.&hanger. 03:00 04:30 1.50 4.50 W.O. K 20 P PJSA:Perform slip&cut of drilling line.Cut 38'.Perform rig service,lubricate draworks&top drive. 04:30 12:00 7.50 12.00 W.O. K 1 P PJSM:L/D elephant trunk,change out ESP spools,pull ESP cable&cap tube over sheaves.M/U shroud assembly.Bring cannon clamps,Esp motor oil&miscellaneous BCL tools to ng floor. 12:00 21:30 9.50 21.50 W.O. K 5 P PJSM:With ENI/Rep,Baker Centrilift,GBR&Nabors rig team.Baker Rep.made up motor,seals&pump.M/U cap tube, tec wire&MLE.RIH with 1 jt.4.5"12.6#L-80 IBTM/M/U to 3,800 FT/Lbs. 21:30 00:00 2.50 24.00 W.O. K 5 P PJSA:BCL performed gator splice,witnessed by ENI Rep.&ENI electrcian.Conductivity test good. Daily Contacts Position Contact Name Company _ Title E-mail . Office Mobile Eni representative Satch Bowe ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.cam 907-685-0722 Eni representative Steve Millea ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 volt Eni E&P Divisiot. Well Name:OPO4-P07 OR ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name: Nikaitchuq • APIIUWI:50-029-23409-00-00 e 11 11 I'n Date:7/31/2015 - Report#: 10 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1899.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 36.0 8.1 Overcast/Light Rain WSW @ 20 MPH Daily summary operation 24h Summary RIH with Jt.#2 of 4.5" tubing.Spooling unit shorted out.Call ENI electrcian to trouble shoot.Wait on ENI electrician to repair rheostat switch on control panel in ESP spooler.RIH W/4.5"tubing Jt.#2, Attempt to make up lower GLM.The tubing coupling on tubing Jt.#2&pin end on the GLM would not make up.Damaged threads occurred.Replaced coupling on tubing and pup Jt.on GLM.Cont.to RIH with 4.5"tubing Jt.#3,spooler switch stalled again.Operator tightened switch and it was operational.Continue to RIH to Jt.#7 at which time the switch fully tripped damaging the ESP cable.Notify ENI Electrcian.Wait on ENI electrcian to make repairs.Loose wire was located on the VFD,tightened&tested good.BCL cut out damaged ESP cable&tested.No conductivity.Decision made to POOH& check for cable damage.ESP cable pulled out of gator splice at the Motor Lead Extension. Swap ESP cable reels.Restring line to rig floor.Hold Pre Job Safety Meeting.PJSM-With ENI Rep.Baker Rep.&Nabors crew.Pull new ESP cable over sheave&down to rig floor.Baker Rep made gator splice from MLE to cable.Pumping 10 bbls 9.2 brine down back side of tubing.RIH F/179'T/221'S/0 50K,retest cable.Baker rep&electrcian fixed cap line spooler.Continue to RIH F/221'T/1,281 5/0 58K P/U 59K.Building 100 bbls 9.2#Brine.Test Cable every 1,000'.Rig down GBR power tongs, hoses&remove elevators.Bring up GBR elevators&Volant CRT tool&make up. Operation at 07.00 Running in hole with 4.5"completion string. 24h Forecast Finish 4.5"completion run. Lithology Shows MAASP(kgf/cm2) Mud Weight(gIL) 1102.4 Time Log Start End Cum •• Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 00:30 0.50 0.50 W.O. K 4 P PJSM:Prepare to RIH with jt.#2 of 4.5"12.6#L-80 IBTM tubing.Spooling unit controls shorted out.Call ENI electrcian to trouble shoot. 00:30 02:00 1.50 2.00 W.O. K 23 TS99 Waiting on ENI electrician to repair rheostat switch on control panel in ESP spooler. 02:00 03:00 1.00 3.00 W.O. K 4 P PJSA:RIH W/4.5"tubing Jt.#2,Attempt to make up lower GLM.The tubing coupling on tubing Jt.#2&pin end on the GLM would not make up.Damaged threads occurred.Replaced coupling on tubing and pup Jt.on GLM. 03:00 04:30 1.50 4.50 W.O. K 4 P JSA:Cont.to RIH with 4.5"tubing Jt.#3,spooler switch stalled again.Operator tightened switch and it was operational. Continue to RIH to Jt.#7 at which time the switch fully tripped damaging the ESP cable.Notify ENI Electrcian. 04:30 07:30 3.00 7.50 W.O. K 23 TS99 Wait on ENI electrcian to make repairs.Loose wire was located on the VFD,tightened&tested good.BCL cut out damaged ESP cable&tested.No conductivity.Decision made to POOH&check for cable damage.ESP cable pulled out of gator splice at the Motor Lead Extension 07:30 10:00 2.50 10.00 W.O. K 4 TS99 PJSM:POOH with 4.5"tubing checking for any damage.The ESP cable was found to have pulled out of the gator splice at the Motor Lead Extension. 10:00 12:00 2.00 12.00:W.O. K 20 TS99 PJSM:Swap ESP cable reels.Restring line to rig floor. 12:00 14:00 2.00 14.00 W.O. K 20 TS99 Hold Pm Job Safety Meeting 14:00 17:00 3.00 17.00 W.O. K 20 TS99 PJSM:With ENI Rep.Baker Rep.&Nabors crew Pull new ESP cable over sheave&down to rig floor. 17:00 22:30 5.50 22.50 W.O. K 20 TS99 PJSM:Baker Rep made gator splice from MLE to cable.Pumping 10 bbls 9.2 brine down back side of tubing.RIH F/179' T/221'S/0 50K,retest cable.Baker rep&electrcian fixed cap line spooler.Continue to RIH F/221'T/1,281 5/0 58K P/U 59K.Building 100 bbls 9.2#Brine.Test Cable every 1,000'. 22:30 00:00 1.50 24.00 W.O. K 4 P •PJSM:Rig down GBR power tongs,hoses&remove elevators.Bring up GBR elevators&Volant CRT tool&make up. Daily Contacts Position Contact.Name Company Title E-mail Office Mobile Eni representative Satch Bowe ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigderksdoyon15@enipetroleum.corn 907-685-0722 Eni representative Steve Millea ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7. ' .110* Eni E&P Divisio,. 'Well Name:OPO4-P07 OR ENI Petroleum Co.Inc. Daily Report Well Code:23893 Field Name: Nikaitchuq • API/UWI:50-029-23409-00-00 en I'n Date:8/1/2015 - Report#: 11 I"' page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) •RKB-Tubing Spool(m) 16.22 3.72 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OPO4-07 WORKOVER 1900.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 37.0 3.0 Overcast W @ 6 MPH Daily summary operation 24h Summary RIH W/4.5"12.6#L-80 IBTM tubing,ESP&CAP line W/GBR Volant CRT,F/1,281'MD T/7,849'MD.Baker checking conductivity every 1,000'MD.Filling annulus with 10 bbls of 9.2 ppg brine every 2 hours.PJSM Held with Baker,GBR,Vetco&ENI Rep.Change out elevators,rig down Volant tool.P/U hanger&landing joint,M/U to string,lower to rig floor.Baker&Vetco made final termination of ESP&CAP line.Tested,good.Land hanger in well head @ 7,889'MD,run in lock downs,test hanger body seals,upper&lower to 5,000 psi.for 10 minutes.Good test. Operation at 07.00 R/D Baker Centrilift Sheave From Derrick. 24h Forecast UD landing joint.R/D GBR,N/D BOPE&Riser.RD Baker Centrilift,N/U Tree&test 500 psi for 10 Min.&5,000 psi for 10 Min.,Baker perform ESP cable connection test. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 W.O. K 4 P PJSM:RIH W/4.5"12.6#L-80 IBTM tubing,ESP&CAP line W/GBR Volant CRT,F/1.281' T/5,252'MD.Baker checking conductivity every 1,000'MD.Filling annulus with 10 bbls of 9.2 ppg brine every 2 hours 12:00 20:00 8.00 20.00 W.O. K 4 P PJSM:RIH W/4.5"12.6#L-80 IBTM tubing,ESP&CAP line W/GBR Volant CRT,F/5,252' T/7,849'MD.Baker checking conductivity every 1,000'MD.Filling annulus with 10 bbls of 9.2 ppg brine every 2 hours. 20:00 00:00 4.00 24.00 W.O. C 20 P PJSM Held with Baker,GBR,Vetco&ENI Rep.Change out elevators,rig down Volant tool.P/U hanger&landing joint, M/U to string,lower to rig floor.Baker&Vetco made final termination of ESP&CAP line.Tested,good.Land hanger in well head @ 7,889'MD,run in lock downs,test hanger body seals,upper&lower to 5,000 psi.for 10 minutes.Good test. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Satch Bowe ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigderksdoyonl5@enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Dolling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm.) Eq.Mud Weight(gIL) P Lea kOff(kgflcm.) 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 1. loos, Eni E&P D%Vi$ioi- I Well Name:OPO4-P07 OR 1 EN!Petroleum Co.Inc. Daily Report Well Code:23893 Field Name:Nikaitchuq or Date:8/2/2015 - Report#: 12 APIIUWI:50-029-23409-00-00 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 372 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OPO4-07 WORKOVER 1901.81 Daily Information End Depth(mKB) End Depth(ND)(...Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 38.0 7.0 Overcast Light Rain W @ 7 MPH Daily summary operation 24h Summary Lay down landing joint.Rig down&lay down all GBR equipment.UD all Baker Centrilift equipment.Lower ESP sheave from derrick&L/D.Clean rig floor,flush kill line,flow line&blow down top drive. Pull katch can&pressure wash,pull bell nipple&UD to pipe shed.Remove rams from BOP stack&clean.Flush lines&blow down mud pumps.Clean possum bellys.Remove choke line&kill line, Nipple down BOPE,take off hydraulic koomey lines&install plugs.Remove turnbuckles,hook up bridge cranes,Set BOP back on stump&secure.Rig down riser,pull to rig floor&UD.Empty out cuttings tank&mud pits.Pick up tree from cellar&lower into well bay.Install grey lock&pull BPV.Install test plug&fill tree with diesel,test hanger void to 5,000 psi for 10 minutes.Test tree to 5,000 psi for 10 minutes& record on chart.Pull test plug.Raise dixie cup,fold up curtains&install temporary roof cap on well bay.Move ESP spooling unit from rig to Airforce pad.Take fresh water in sub side of rig.Cleaning mud pits.Install flange,plug valve on choke&kill lines.Secure tools&clean rig. Operation at 07.00 Cleaning mud pits,prepping for rig move. 24h Forecast Finish cleaning mud pits.Prep for ng move. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 W 0. K 5 P PJSM:Finish clean up in well bay area after hanger test.Lay down landing joint. 01:00 04:00 3.00 4.00 W.O. 'K 5 P PJSM:Rig down&lay down all GBR equipment.UD all Baker Centrilift equipment.Lower ESP sheave from derrick&UD. 04:00 06:30 2.50 6.50 W.O. C 5 P PJSA:Prep BOPE for nipple down.Clean rig floor,flush kill line,flow line&blow down top drive to bleeder on mud pump. 06:30 12:00 5.50 12.00 W 0. C 5 P PJSM:Pull katch can&pressure wash,pull bell nipple&UD to pipe shed.Removed all rams from BOP stack,cleaned rams&ram cavities.Flush lines&blow down mud pumps.Clean possum bellys 1&2.Remove choke line&kill line. 12:00 15:00 3.00 15.00 W 0. C 5 P PJSM:Nipple down BOPE,take off hydraulic koomey lines&install plugs.Remove tumbuckles,hook up bridge cranes,Set BOP back on stump&secure.Rig down riser,pull to rig floor&lay down to pipe shed.Empty out cuttings tank&mud pits. 15.00 18 00 3.00 18.00 W.O. C 5 P PJSM.Pick up Vee from cellar&lower into well bay.Install grey lock&pull BPV.Install test plug&fill tree with diesel,test hanger void to 5,000 psi for 10 minutes.Test tree to 5,000 psi for 10 minutes&record on chart.Pull test plug. 18:00 00:00 6.00 24.00 W.O. A 5 P PJSM:Raise dixie cup,fold up curtains&install temporary roof capon well bay.Move ESP spooling unit from ng to Airforce pad.Take fresh water in sub side of rig.Cleaning mud pits.Install flange,plug valve on choke&kill lines.Secure tools&clean ng. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Satoh Bowe 'ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyon 15@enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 111011111Th, Ent E&P Divisioi. Well Name:OPO4-P07 OR ENI Petroleum Co.Inc. Daily I y Report Well Code:23893 Field Name:Nikaitchuq g APIIUWI:50-029-23409-00-00 Date:8/3/2015 - Report#: 13 page 1 of 1 Wellbore name: OPO4-07 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 208-1990 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 1622 372 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mIhr) DFS(days) OPO4-07 WORKOVER 1902.81 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mIhr) POB Temperature(°C) Weather Wind 0.00 36.0 5.7 Light Rain/Fog W @ 7 MPH Daily summary operation 24h Summary Clean Pits of Brine.Clean up around dg for stack out.Disconnect Flow Line and Gas Buster.Break hoses in charge pump room.Remove bails from Top Drive and L/D.Clean suction screens on Mud Pumps.Clean Cutting Box.Due to Penterator line up,decision was made to pull the Tree and tum the Penetrator.Make sure all permits filled out W/DSO.Check IA and Tubing Press.prior to work.Life Critical operation for removing hatch covers for well bay.As per Vetco Grey Pull Tree cap,install BPV and remove Grey Clamp.Lift Tree to cellar.Baker Centrilift orient Penetrator.Set Tree back down and M/U Grey Clamp.Test void to 5,000 PSI.Pull BPV and install TWC.Fill with Diesel and test Tree to 5,000 PSI for 10 Min.on chart.Remove TWC.All witnessed by Co Rep onsite.Clean up tools and Equip. Operation at 07.00 Cold Stack Procedure 24h Forecast Release Rig from well OPO4-07 @ 24:00 8/3/2015,Start Nabors Cold Stack Procedure. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 09:30 9.50 9.50 W.O. A 1 P PJSEA Clean Pits of Brine.Clean up around rig for stack out.Disconnect Flow Line and Gas Buster.Break hoses in charge pump room.Remove bails from Top Drive and UD.Clean suction screens on Mud Pumps.Clean Cutting Box. 09:30 14:00 4.50 14.00 W.O. C 5 TS01 PJSEA Due to Pentrator line up,decision was made to pull the Tree and tum the Penetrator.Make sure all permits filled out W/DSO.Check IA and Tubing Press.prior to work.Life Critical operation for removing hatch covers for well bay.As per Vetco Grey Pull Tree cap,install BPV and remove Grey Clamp.Lift Tree to cellar.Baker Centrilift orient Penetrator.Set Tree back down and M/U Grey Clamp.Test void to 5,000 PSI.Pull BPV and install TVVC.Fill with Diesel and test Tree to 5,000 PSI for 10 Min.on chart.Remove TWC.All witnessed by Co Rep onsite.Clean up tools and Equip. 14:00 '00:00 10.00 24.00 W.O. A 1 P PJSEA:Install temporary roof cap on well bay.Finish cleaning pits.Power wash choke manifold 8,interior area on off drillers side.Organize 8.power wash pipe shed. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Bruno Ravagli ENI Superintendent Eni representative Satch Bowe ENI Drilling Supv. 685-0710 Eni representative Oliver Amend ENI Drilling Supv. 907685-0715 Em representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Steve Millea ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Michael Coker Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.892 L-80 1,495.96 3,700.88 6/13/2010 Last Leakoff Test Depth(mKB) •TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,659.99 1,168.91 VersaPro OBM 1054.5 72.5 1675.2 195.7 77‹OF 7•y hw\� //7 ?6N THE STATE Alaska Oil and Gas � :4, ofALAS K /` Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: ALAS' E® 0 Q D .. Fax'v 907.279.1433 G L907.276 7542 NNJU SCgwww.aogcc alaska goy Davide Simeone Well Operations Project Manager O t Eni US Operating Co. Inc. a 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OPO4-07 Sundry Number: 315-371 Dear Mr. Simeone: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4e)//— Daniel T. Seamount, Jr. Commissioner DATED this icday of June, 2015 Encl. RECEIVED ' STATE OF ALASKA JUN 16 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 56c-(AAI4 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Q' Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 % Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other. _ESP Change Out Q. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Eni US Operating Co. Inc. Exploratory ❑ Development Q• 208-199• 3.AddressStratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23409-00-00 7.If perforating. 8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No E OPO4-07• 9.Property Designation(Lease Number): 10.Field/Pool(s): 0373301,0355024,0390616 • Nikaitchuq Schrader Bluff Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft)• Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,144 _ 3,936 ' 12,142 • 3,936 N/A N/A Casing Length Size MD TVD Burst r Collapse Structural Conductor 160 20" 154 154 Surface 2,455 13.375 2,455 2,097 5,210 2,480 Intermediate 8,750 9.625 8,750 3,838 6,890 4,790 Production Liner 3,625 5.5 12,142 3,936 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8750-12,142 ' 3,838-3,936 4 1/2 L80 7,864 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12 Attachments. Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development❑.r . Service ❑ 14.Estimated Date for 15-Jul-15 15 Well Status after proposed work: Commencing Operations. Oil E ' Gas ❑ WDSPL ❑ Suspended E 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroIeum.com Printed Name Davide Simeone Title Well Operations Project Manager Signature , _ Phone Contac 907-865-3328 Date 6/15/2015 QA COMMISSION USE ONLY Conditions royal: Notify Commission so that a representative may witness Sundry Number: 315--;/ k Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: f5005- `� !e.5 f ( /14A-S,17-12 /s Spacing Exception Required? Yes ❑ No IZ( Subsequent Form Required: /6 -- 41lJY diP / APPROVED BY / Q C Approved by: lir COMMISSIONER THE COMMISSION Date: 1 L ` l 1J �f V Submit Form and Form 10-4 (Revised 10/2012) p I 1�N y/A�'\J or 12 months from the date of approval. Attachments i D plicate -,4' .� RBDMS JUN 2 5 2015 vot • Enii troIIeuim 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907) 865-3320 Email: davide.simeone@enipetroleum.com June 16`h, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OPO4-07 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OPO4-07. OPO4-07 was completed by ENI Petroleum at Oliktok Point on June 17th, 2010 with a Thru Tubing Conveyed Electric Submersible Pump(TTC-ESP) set at 7,864' MD. Currently the well is down due to an electrical problem on May 8th, 2015. The estimated date for beginning this work is July 15th, 2015. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Giuseppe Maugeri at 907-865-3328. Sincerely, Davide Simeone Wel Opera '•ns Project Manager 11 —00f* OPO4-07 Workover— Summary Page OPO4-07 Rig Workover PTD#:208-199 Current Status Well OPO4-07 is currently down for electrical issue. Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and run in with a new ESP system. General Well info Reservoir Pressure/TVD: The ESP downhole gauge is currently down. Reservoir depth is 8,750'MD/3,838'TVD. This well is expected to have a static max bottom hole pressure of approximately 1,300 psi during the time of workover, which places the fluid level well below surface. 1300 — 3 Y" = Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi 7 2.. p s BOP configuration: Annular/pipe/blind/Flowcross/pipe r,e- rx 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 June 3`d 2010. Well type: Producer Estimated start date: July 15th 2015 Drilling rig: Nabors 245 RWO Engineer: Giuseppe Maugeri: Giuseppe.Maugeri@enipetroleum.com Work: 907-865-3328 Well Operations Project Manager: Davide Simeone: Davide.Simeone@enipetroleum.com Work: 907-865-3320 Procedure: 1. MIRU Nabors 245. 2. Shear upper GLM valve and pump 9.1 ppg 3% KC1 brine inside tubing through tree and circulate to surface. 3. Ensure well is dead. 4. Set BPV. N/D tree and N/U BOP and test to 3500 psi. 5. Pulling tubing to upper GLM. 6. Pressure up and shear lower GLM, pump 9.1 ppg 3% KC1 brine inside tubing and circulate to surface. 7. Pull tubing to ESP and lay down ESP assembly. 8. MU new ESP assembly and RIH to setting depth. 9. Land tubing hanger and test it. 10. Install BPV and nipple down BOP. 11. NU tubing adapter and tree. 12. Pull BPV, install test plug and test tree. 13. Circulate Freeze protect through tree down IA. 14. Shut in well. 15. RDMO. Below the current schematic of the well: Vacuum Insulated Tubing(VIT),4-'4"x 5-'14", �1 approx 80',two joints OPO4-07 2,164 MD-GLM,KBMG, 4-%"x 1", Oil Producer with ' with 650 psi STS-1 SOV installed ° Eni Petroleum ESP Lift 1,111 i 4-14"12.6 ppf Production Tubing VA"cable clamps,for ESP Power As Completed Cable,(1)3/8"Chem Inj Line 6/17/2010 7,662 MD-GLM,KBMG, 414"x 1", with 2,000 psi STS-1 SOV installed \. 7,864 MD—Bottom of Motor Centralizer Surf-Casing Centrilift TTC-ESP,116-stage 380P18 pump,513 13-3/8".68# 11111 GST3 seal,126 HP MSP1-250 motor 2.455 MD. 2.097 TVD 60°Inc. 8,517'MD,Baker SLXP Liner Hanger/Packer HAL Zonal Isolation 5-''14"Silver Bullet Ecc , SSwwell Packers Nose Guide Shoe i Interm Casing Slotted Liner, 9-5/8",47# 5-%'17 ppf 8,750'MD,3,838'TVD 12,142'MD, 84°Inc 3,936'TVD Nikaitchaq Field- Oliktok Point Pad Confidential 1 a pip g w `aa 11-111111 '—Vu-- F a �ypBypaaa p i_____ I,I-I R .. W 3 4 . I i $ !(gW <n =—__.] 11 5 acii 11 W I U ` .'. LL CC 4 d I m z N d 4 : �-. ° Imp I�[�J W N Y 1i • la.•l I' T T ��W "WW.,_-- a l _ Ii„ a R tza I* I iii:::��iii 01' ^..I si r'ir. `-'ZS' ....., i 1 oZ m<0 1 yp ap N leli 2 11 11 3W 1.,-g , .s1:4 . . �; WI . 1 /51v o �3 —--_ 1111111��1 IIIIJZ --- RI1 �I� �I �II Qfir RIIII111111N1 I NU :iiiI �_ Y m I A q � � f—?• Nom, I h .Y/i,-.B VetcoGray MB-247 SURFACE COMPLETION SYSTEM N/CL "3 5. 37.1• ........j. ,irri.jiiip !I -� ��1_U. 111q4K13 rkle IMI/Iir-_-)lid.:!WII �� 1+, as T.O.S. EL 26' 5-3/4" � I' 1.062 OFFSET C/L I S.O.S. EL 25 7-1/4" r.l✓J TOP OF WELLHEAD 5.00" EL 25' 2-1/4" 1 01 10 [n' ' PFT q 3 ELECTRICAL•oho d U 21.81 1 %m.�l;7 11� 13-5/8'5000 PSI w VG 5137 CLAMP mg__ 4-1/18" ' II'n •'" ��. 5000 PSI F,c C J 1oa.o iIIiiI!iiI437 OFFSET,.......„ 6.50"- .III111 _{. z-116' 11 5000 PSI H _1 .7.} __�._ 2-1/16' :*"� S._ � 5000 PSI C : ' 66.71 OUT OF ' c, _ I, 13'5000 PSI POSITION _�5 � tin,52.96" VG 1a4 "O.Ti 26.5.M. �1 0l �' '•S•-i1;�!i 34.00' 5000 PSI 2-1/16" 111�" 1 OUT OF 24.2 t I 1 15.25" POSmON ■—11 I _• TOG TOP OF GRADING rli: -l7 EL 16' 1-1/4" I L1.00 vROPIRrNft N011CQS �trlii. . y�agray' 20" OD 133# K-55 s�3',7rC�.:�" «..wrrr 13-3/8" 0D 68# L-80 am.IENI ALASKA I J.ALVARADO 4-5/8" OD 53.5 L-80 mow, HORIZONTAL MULTI-BOWL SYSTEM 4-1/2" 00 WITH 6-5/8 VIT IMP. 20 X 13-3/8 X 9-5/8 X E BOWX 4-1/2 WITH 6-5/8 VIT AND ESP FLAT CABLE uAPEL06 41.E T1 11173370-1 0o.r Wit w..e —..r XXXI.w+0 aa/ X I wea i ii PRP 10161, NC 10 OF 10 23 JANUARY 2009 GE Imagination a.work 1 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ca0 2 - J(/' q Well History File Identifier 9 � Or anizin (done) El Two 1 1 1111 III NI ❑ Rescan Needed IM 11111 I I 9 RE AN DIGITAL DATA OVERSIZED (Scannable) C r Items: l❑ Diskettes, No. 75s: Greyscale Items: ❑ Other, No/Type: er Items Scannable by a Large Scanner 1 ...... 0 G.3 ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: PT BY: Maria Date: Li' 3 /s/ Proofing II MI 11111 Project g BY: - Date: /1 /3 /s/ x 30 = � I I O + c = TOTAL PAGES __ 6 Scanning Preparat `' f (Count does not include cover sheet)', BY: Maria Date: /s/ Production Scanning II 111111 1111 i5 A" (COUflt � Stage 1 Page Count from Scanned File: a does include cover sheet) Pa.e Count Matches Number in Scanni g Preparation: 1/ YES NO BY: Date: Li- / 1.3 /s/ f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point oint unless rescanning is required. ll 11111 II I III ReScanned II11E11 I BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc *- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t '(4 DATE: March 19 2011 P. I. Supervisor FROM: Chuck Scheve, SUBJECT: No Flow Petroleum Inspector Nikaitchuq OPO4 -07 PTD 2081990 Saturday, March 19, 2011: I traveled to the ENI Nikaitchuq field and witnessed a no -flow test on well OPO4 -07. I arrived on location and found the well bled off and opened to atmosphere with no - detectable flow of gas or fluid evident. The well was then shut in and a pressure build of 7 psi in the first hour was observed on the tubing. No further pressure increase noted on the tubing, the IA had a slight vacuum throughout the test. When reopened to atmosphere the pressure dissipated rapidly with no measurable flow observed. SUMMARY: Nikaitchuq Well OPO4 -07 meets the AOGCC requirements for no flow status. STATE OF ALASKA I ALASKA. AND GAS CONSERVATION COMMISS• WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil El Gas ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1 b. Well Class: 20AAC 25.105 20AAC 25 110 Development IS • Exploratory❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other❑ No. of Completions: Service ❑ Stratigraphic Test❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: ENI US Operating Co Inc Aband.: 6/16/2010 • 208 -1990 - 3. Address: 6. Date Spudded: 13. API Number: 3800 Centerpoint Drive Suite 300, Anchorage 99503 5 • t '1 - ii."-' 50- 029 - 23409 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: /` • j P Well Name and Number: Surface: 3216' FSL, 1541' FEL, S5 T13N R9E UM • 6/10/2010 • OPO4 -07 • Top of Productive Horizon: 8. KB (ft above MSL): 53.2 • 15. Field /Pool(s): 4909' FSL, 1361' FEL, S32 T14N R9E UM Ground (ft MSL): 12 • Nikaitchuq . Total Depth: 9. Plug Back Depth(MD +TVD): 3075' FSL, 1409' FEL, S29 T14N R9E UM 12144 MD/3936 TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 516739.27 • y- 6036569.44 • Zone- 4 • 12144 MD/3936 TVD • 355024, 373301, 390616 TPI: x- 516882.5 y- 6043540.49 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 516815.63 y- 6046986.53 Zone- 4 none ADL 417493 18. Directional Survey: Yes ❑ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 1763' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ RES/ Neu/ Den 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 178.89 X -65 SURFACE 154 SURFACE 154 30 Cement to Surface 13 -3/8" 68 L -80 SURFACE 2421 SURFACE 2079 16 355 bbls AS Lite, 73 bbls Litecrete 9 -5/8" 47 L -80 SURFACE 8727 SURFACE 3835 12.25 139 bbls Deeperete 5.5" 17 L -80 8518 12142 3806 3936 8.5 slotted liner 23. Open to production or injection? Yes ii Nor] If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) slotted liner 4.5 7865 NA / ESP completion COMPLETION 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. • . • DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ' <, ..,. go 26 PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NA (to be Jan 1, 2011) ESP Comoletion Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: NA NA Test Period -► Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate -0. 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No o Sidewall Cores Acquired? Yes ❑ No li . 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. RECEIVED ii 22?O1! Alaska O! Et Ca: COIL Cemn ssio 1 Anchsrage G Form 10 -407 Revis JUL 2 2 ONTINUED ON REVERSE /114, , / 0 1 , 10 TL, 2 8. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E 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. Permafrost - Base 1932 1763 OA sand top 8702 ' 3833 Formation at total depth: OA sand 12144 3936 30. List of Attachments: Summary of Daily ops, Directional survey, wellbore schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907 - 865 -3321 Si'lo' Printed Name: Maurizi Grandi Title: Well Operation Project Manager Signature: it s...... ,_ Phone: b6533 32. Date: 04/19 ( 1o0 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 Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 in Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: 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 29: 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 2/2007 I, r - _ - Eni E&P Division Well Name: 0PO4 -07 — ENI Petroleum Daily Report Well Code: 23893 CO. Inc. Field Name: Nikaitchuq ! Wellbore name: OPO4 -07 Date: 5/14/2010 - Report #: 1 API/UWI: 50 -029 -23409 -00-00 �' -- page lofi1 – Well Header T - -- -- - -- -- Permit/Concession N° !Operator ENI Share ( %) Well Configuration type 208 ENI PETROLEUM i 100.00 !DIRECTIONAL Rotary Table Elevation (ft) 53 20 ( 1 Ground Level (ft) 20 — Mater Depth (ft) 0.00 RKB - Base Flange (ft) RKB - Tubing Spool (ft) . Rig information Contractor NABORS ALASKA Rig Name Rig Type NABORS 245 E LAND D RI G Job Information Wellbore 'Job Phase Spud Date T rget Depth (ftKB) 'Target Depth (TV... Depth Dr. (MD) (R) Drilling Hours (hrs) Average ROP (ft/hr) ' DFS (days) OPO4 -07 - DRILLING - 5/19/2010 I 12,0 I 3,940.3 12,3 220.07 56.3 -419 Daily Information Depth End (RKB) Depth End (TVD) (... Depth Progress (ft) !Drilling Hours (hrs) !Average ROP (ft/hrffPOB Temperature (°F) Weather Wind I 80.0 10.6 Cloudy ViC +2.3° 43° NE @ 12.1 mph Daily summary opera tion 24h Summary ACCEPT NABORS 245E @ 5/14/2010 00'00 hrs. i Prepare for rig move. Continue to clean pits and RD drilling/ utility module. Demob overboard cuttings box and CCB equipment Disconnect lines between drilling and utility module and spot same over slot 4. Build berm around rig and hookup utility/ service lines. Operation at 07.00 Continue prepanng to spud OPO4 -07. 24h Forecast — Continue preparing for spud. Install dixie cup curtains and continue prepanng civerter. Lithology Shows IMAASP Pressure (psi) Mud Weight (lb /gal) I Time Log — Cum Start End Our Dur Time Time (hrs) (M) Phase Opr. Act. Plan Oper. Descr. 00:00 06.00 6.00. 6.00 MOB A 2 P RDMO - Accept Nabors 245E 0 5/142010 00:00 hrs., I Hoist dude cup and secure same. RD flowlme and degasser line. Continue to clean pits, blowdown mud pumps, I centinfiguals and transport lines. Demob overborad cuttings box and CCB equipment. f 06: 6: 00 1230 I _ _ -_ 00 10:30 4.50 10.50. MOB A 2 P t RDMO - Blow down steam and water line on drilling module. Roll up Lampson curtains and disconnect lines between 150 12.00 'modules. i MOB IA 2 P RDMO Jack up (tilling module and install crib blocks. Drive forward 1 ft and disconnect electrical connections between ", modules 112:00 * 21 00 A 2 P _ rMIRU Move drilling module to East and spot over slot 4. Move utility module East and spot next to drilling module. 21 00 100 00 3.00i 24.001MOB �A :2 !P - 1MIRU - Build up berm around nd rig and hook up utility/ service lines - Daily_ Contacts - - -- - — Ti Position Contact Name Company Title f Email Office Mobile 'Eni representative iScott Beauchamp 'ENI :Drilling Supervisor Scott.Beauchampgenipetroleum.com 907 -670 -8623 907- 841 -8759 IEni representative !Joe Longo !ENI ! Drilling Engineer joe longo(genipetroleum com ,907870 -8623 907- 947 -4323 I Eni representative 'Tom Norvig !ENI Rig Clerk AKRigClerks245e @enipetroleum.com 907-670 -8607 907-229-6100 Eni representative -Greg Parker ,ENI I Expediter Greg Parker @enipetroleum.com I 907-980-7545 Eni representative Jack Potter I ENI IDrilling HSE Jack Potter@errpetroleum.com 907-670 -8624 Eni representative Jack Keener ENI Drilling Supervisor jack. keener@enipetroleum.com 907-670-8623 907- 715 -6434 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date Last Leakoff Test Depth (ftKB) TVD (RKB) Fluid Type Fluid Density (lb /gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) it II i !I -- — — — -- • ° Eni E &P Division Well Name: OPO4 -07 D aily Report Well Code: 23893 - EN! Petroleum Field Name: Nikartchuq • Co. Inc. Date: 5/15/2010 - Report #: 2 API/UWI: 50 -029- 23409 -00-00 n I — page 1 of 1 Wellbore name: OPO4 -07 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12 20 0.00 -- - - - - -- - Rig information C ontractor [Ri Name 'Rig Type NABORS ALASKA 1- NABORS 245E (LAND RIG - I Job Information Wellbore .Job Phase Spud Date 'Target Depth (RKB) I Target Depth (TV... [Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) I DFS (days) 0PO4 -07 DRILLING 5/19/2010 i 12,031 0 I 3,940.3 j 12,382 00 220.07 56.3 -3.19 Dail n [Depth - Information Pr - Drilling Hours (hrs) Average ROP (Mir) IPOB Temperature ( °F) Weather Wind I_ 78.0 i 21 4 ,Overcast WC +6.8 11° N @ 19.7 mph e th End (RKB) Depth End (TVD) (... Depth Progress (ft) '� Daily summary operation 124h Summary Continue RU for spud NU VetcoGray diverter riser/tee and set hydnl. Continue working on overboard cutting line and drag Chan. Install knife valves on trouser leg. Install and function test diverter knife valve. NU flow nipple and insert flow line. Load pipe shed with 240 jts 5" DP Continue welding / fabncating diverter line !Operation at 07.00 Spot diverter line on top of well containment shelter. Continue NU flowline Continue preparing for spud 24h Forecast Set diverter line on top of well containment shelter and continue fabncation Continue NU flow line. Finish installing overboard cuttings line. Continue running CCB transport lines. Build containment and spot GCBs and overboard cuttings tank. Lithology - -- Shows IMAASP Pressure (psi) Mud Weight (lb/gal) I L ■ Time Log Cum Start End Dur Dur Time Time (hrs) (has) Phase Opr. Act. Plan Oper. Descr. 100.00 06:00 6.00 6 00 MOB A '2 P MIRU - Continue berming up rig containment. Hook up steam, water and electrical lines. Prepare pits for spud. Clean up previous dnl site. Continue running CCB transport Ines. 06:00 _ 10'00 _ 4.001 10.00 MOB A _ 2 P MIRU - NU VetcoGray diverter rise/tee and XO. Connections tested to 500 psi for 10 min - Good Test 10:00 12.00 2.00 12.00 MOB A 2 P MIRU - RU diverter hoist system and set Hydnl. 1 12.00 18:00 6.00 18 00 MOB A 2 P MIRU - Turn targeted 90 on diverter upright section. Fabricate hatch for top of well containment shelter. Work on drag I :chain overboard dump line Install knife valves on overboard dump line and trouser leg. Load 5" DP in shed, strap and I tally. 1 - 18:00 00.00 6.001 24 00 MOB A 2 P MIRU - Continue to dress drag chain. Finish loading 5" DP in shed - 240 jts. total. Continue welding on overboard I cuttings line. Install diverter knife valve and function test. GBR continue welding on diverter line, Install flow nipple and insert flow line. Daily Contacts L - Position Contact Name Company [ Tide E-mail Office Mobile ,Eni representative Scott Beauchamp ENI ,Drilling Supervisor iScott.Beauchamp @enipetroleum com 907 - 670 -8623 907 -841 -8759 [Eni representative Joe Longo ENI 'Drilling Engineer joelongo@enipetroleum.com 907-670 -8623 907 - 947 -4323 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245eleripetroleum.com 907 -670 -8607 907 - 229 -6100 Eni representative Greg Parker .ENI Expediter Greg.Parker ©enpetroleum.com 907- 980 -7545 Eni representalve Jack Potter 'ENI Drilling HSE Jack.Potter @eripetroleum corn 907-670 -8624 E ni representative , Dave Smith I ENI _ [Drilling Supervisor J _ 907- 670 -8623 Last Casing seat � Cu. Type OD Qn) ID (in) Grade Top (ftK6► Bottom (ftK6)_ Run Date . Last (ftKB) TVD (fdCB) Fluid Type - ' Test Depth ;Fluid Density (lb /gal) I P (Surf) (psi) IEq. Mud Weight (Iblgal) Leak Off Pressure (psi) K6) - - -- - - - -- - - - -- - -- - - -- - - -- - - - - - - -- t -- - - - L - -- - - - - - - - - - - -- -- -- i I I i � 1 II t III ill It* Eni E &P Division Well Name: 0PO4 -07 ENI Petroleum Daily Report Well Code: 23893 Field Name: Nikaitchuq • CO Inc. ate: 5/16/2010 - Report #: 3 API /UWI: 50-029- 23409 -00-00 ( � q Wellbore name: OPO4 -07 C it (1 [) page 1 of 1 [Well Header {Pennit - -- UConcession N ;Operator 2081990 r � 100.00 ',ENI Share ( %) ( Well Configuration type ENI PETROLEUM ' ,DIRECTIONAL o - - t on (ft) �- - - - r - - - - - -- - RKB - Base Flange 9 P Rotary Table Elevation (ft) I Ground Level (ft) - I Water Depth (ft) g (ft) RKB - Tubing Spool (ft) 53.20 1 12.20 0 00 Ri Information ', Contractor 1 Name Rig Type NABORS ALASKA 1 -- NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (ftKB) 'Target Depth (TV... 'Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) IDFS (days) 0PO4 -07 DRILLING 5/19/2010 12,031.0 I 3,940.3 12,382.00 220.07 56.3 I -2.19 Dail r�lnformation Depth End (ftKB) Depth End (TVD) (... ` Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather Wind 81.0 21.4 Cloudy, Blowing 30° NE @ 27 mph Snow, WC +3.7° Daily summary operation 24h Summary • • r, ; ,. k • ow line. Con tinue workine on diverter line. Operation at 07.00 PJSM for PU 5" DP. 24h Forecast Continue PU 7500' 5" DP, Finish Diverter line welding. Continue work on trouser leg Lithology Shows MAASP Pressure (psi) Mud Weight (lb /gal) Time Log Cum I 1 Start End Dur Dur Time Time (his) (WO Phase Opr. Act. I Plan Oper. Descr. --- -- - MIRU - -- - -- --- -- — -- - - -- 0000 06:00 6 00 6 00; MOB i 2 P - Attempted to o i nstall flowline to pitcher nipple outlet to tall, remove for modification. Pick diverter line with crane onto wellbay roofs as per GBR to welder together. Spot cutting tanks and CCB frame work for measurement to berming out h druatc oil in kommey s Change ou y y stem system - -- -- i - - -- - -- -( -- - - -- - - -- 06:00 1 12:00 i 6 00 12.00 + MOB IA 2 P , MIRU - Welders align diverter line on roof, weld together and target tees on same, installing clamps. Continue modification of outlet for flowline on pitcher nipple Replace paddles on drag chain, crib up pipe rack floor on driilers side, for level working area Continue welding modification on cuttings drop for drag chain. I 12 00 '18-00 -- -- -- -- - - - - -- - - -- -- - - - --- -- - - -- _- ' 6 00 18.00 1MO6 A 2 P MIRU - GBR continue welding out welding out and fabrication on diverter line and Peak finished pitcher nipple modification Finished building up pipe rack area, drag chain replacement of paddles and drag chain dump, change out (3 6 00' - - - -- - 'total) thread rings on suction pods on #2 & #3 mud pumps. - L 18:00 100:00 24 00 'A 2 �P MIRU - Install pitcher nipple and connect flowline, install catch can on same and seal up. Clean out rod wash reservoirs Dally Contact -__Ion all mud pumps. Continue welding out diverter line. S -- ac - - -- -- . Position Contact Name Company -_- _ _ Title _ —_ E-mail - -- Office Mobile Eni representative Scott Beauchamp ENI 'Dulling Supervisor Scott.Beauchamp(aL7enipetroleum.com 907-670 -8623 907 -841 -8759 Eni representative Joe Longo ENI 'Drilling Engineer joe longoi enipetroleum.com 907-670 -8623 907- 947 -4323 Eni representative 'Tom Norvig ENI Rig Clerk AKRrgCbrks245e @eripetroleum.com 1907 -670 -8607 907 - 229 -6100 Eni representative Greg Parker ENI Expediter Greg. Parkeri enpetroleum.com 907 - 980 -7545 Eni representatve Jack Potter ,ENI Drilling HSE Jack.Potter @enipetroleum com 907 -670 -8624 Eni representative Dave Smith ENI Dnlling Supervisor 907 -670 -8623 Eni representative Michael Seward ENI Drlg. Fac. Adv. Michael.Sewardkenipetroleum.com 907- 952 -7880 I Last Casing seat Cas. Type OD (in) I ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date [Last Leakoff Test (ftKB) Depth (ftKB) iTVD (ftK8) !Fluid Type Fluid Density (lb /gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) I i I I! i I j ill Eni E &P Division Well Name: OPO4 -07 ENI Petroleum Daily Report Well Code: 23893 Field Name: Nikaitchuq w Co. Inc. Date: 5/17/2010 - Report #: 4 API /UWI: 50-029 - 23409 -00-00 if r) 'f page 1 Of 1 Wellbore name: OPO4 -07 — Well Header Permit/Concession N° Operator ENI Share ( %) - Weil Configuration type 2081990 ENI PETROLEUM 100 00 ;DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) I RKB - Base Flange (ft) RKB - Tubing Spool (ft) 5120 12.20 0.00 1 Rig Information ,Contractor - Rig Name Rig Type NABOBS ALASKA NABORS 245E LAND RIG ;Job Information Wellbore (Job Phase Spud Date T rget Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) i 0PO4 -07 _j DRILLING 5/19/2010 I 12,031.0 3,940.3 12,382.00 220.07 56.3 -1.19 I Daily Information E ... -__. ( Dept End (RKB) D epth End (TVD) (...JDepth Progress (ft) 'Drilling Hours (hrs) Average ROP (ft/hr) IPOB Temperature CF) Weather Wind 91.0 25.0 Cloudy, Blowing 23° NNE @ 20 mph Snow, WC +19° wily summary 24h Summary P/U 5" dill pipe 240 jts. and drift, welders continue workjngoon diverter spool, trouser legs and CCB dumps - lay liner and spot dump tank and CCB units with crane, build beming for same Operation at 07.00 Continue working on diverter line and CCB dump tank connection. 24h Forecast Spot cuttings tank and CCB units to install dumps lines Install diverter spool off knife valve AOGCC witness if required Off load spud mud and build volume. P/U BHA with Schlumberger [Spot (Shows MAASP Pressure (psi) I Mud Weight pblgal) I --- - - -- - -- - --- -- -- -- - -- ---- - ' Time L_o° _ r_____ Cum Start End Dur Dur Time Time (his) (h►s) Phase Opr. Act. Plan Oper. Descr. 00:00 03.00 3.00 3.00 MOB A 1 P MIRU - Remove flowline from pitcher nipple to replace airboot and reinstall same, align pitcher nipple to hole center of rig, clean - up cellar area. Continue welding on diverter line and fabricate dump tank for Swaco GCE 03:00 706:00 3.00 6.00 MOB A 1 P Pick -up 5" drill pipe and rack back in derrick as stands, strap and SLM - 2.563" drift all tubular. Continue welding out I ! diverter line target tees and fabrication for CCB dumps. ! 0600 !08:00 2 00 8.00 MOB A 1 P I Service rig and add non -skid matting to off driller side pipe rack. Welders moved inside to work on trouser leg dumps due weather condition. 08 I 00 21:00 13.00 21.00 MOB A 1 P Continued picking -up 5" drill pipe from pipe shed and stand back in derrick - strap and SLM - 2.563" drift all joints. Total I 180 stands in derrick with over all length of 7,657.43'. Welders worked on trouser leg damps to Swaco CCB units and fabricate XO flanges to hose connection — — 21:00 22:00 1.001 22.00 MOB A 1 P Install mouse hole and clear floor of thread protectors. Service crown, blocks, TD and drawworks. Welders continue working on CCB and diverter alignment spool from knife valve. Remove dump tank and mats from rig. 22.00 00:00 2 001 24.00 MOB A 1 P Swaco and rig crew laid out felt and liner for CCB units and dump tank, set matting boards in place and spot frame base for tanks Assisted GBR welder with cellar box curtain braces and hang curtails on catch can under rig floor and Peak j welder continue fabricating XO spools for dumps Daily Contacts 1 Position Contact Name Company Title E -mail Office . Mobile Eni representative Scott Beauchamp [ENI Drilling Supervisor Scott Beauchamp @enipetroleum.com 907 - 670 -8623 907 -841 -8759 Eni representative Joe Longo !ENI (Drilling Engineer Ijoe.longoesnipetroleum.com 907870 -8623 907 - 947 -4323 IEni representative Tom Norvig I ENI (Rig Clerk AKRigClerks245e @erupetroleum.com 907-670 -8607 907- 229 -6100 [EN representative Greg Parker ENI ,Expediter [Greg.Parkerlenpetroleum.com 907- 980 -7545 [En' representaive iJack Potter ENI Drilling HSE IJack Potters errpetroleum.com 907 - 670 -8624 Eni representative [Dave Smith 'ENI Dnling Supervisor I 907 - 670 -8623 :EN representative Michael Seward [ENI :Dr/g Fac Adv. 1Michael.SewardIenipetroleum.com 907- 952 -7880 Last Casing seat Cas. Type OD fin) r _ _ _ ID (in) f Grade Top (RKB) Bottom (RKB) Run Date I . -- - 1. i - - - - - - -- - - -- - - -- - - - - -- - - - - - -- - -- - - - -- - - - ' -- -- Last Leako/f Test 'Depth ( itKB) - - -- - -- TVD D (RKB) Flu B) id Type ,Fluid Density (lb/gal) I P (Burt) (psi) Eq. Mud Weigh (lb/gal) Leak Off Pressure (psi) -I • 101/141 Eni E &P Division ;Well Name: 0PO4 -07 Daily Report ENI Petroleum Wen Code: "" 23893 Field Name: Nikaitchuq •(� Co. Inc. Date: 5/18/2010 - Report 5 API/UWI: 50-029- 23409 -00-00 to E) , Wellbore name: OPO4 -07 �I!! �n� p age 1 of 1 Well Header Permit/Concession N° Operator ENI Share ( %) [Well Configuration type 2081990 1 ENI PETROLEUM 100.00 1DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (R) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 1 12.20 0 00 R i g Information C- Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) OPO4 -07 DRILLING _ 5/19/2010 12,031.0 3,940.3 12,382.00 220.07 56.3 -0.19 I Dail Information Depth End (RKB) Depth End (TVD) (... Depth Progress (R) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather Wind 96.0 25,7 Cloudy, Blowing 15° NNE (,:g2 20.6 Snow, WC 10.4° mph Dail summary operation 24h Summary Finished R/U of Diverter and tested with AOGCC witness - • load mud and build 100 bbls. volume - test systems [Operation at 07.00 Pick -up BHA - From 3:00 -4:00 am: Simulate D3 Diverter drill and hold evacuation drill; Held per -spud meeting with all personnel involved with the operation. - Clean out conductor with 16" assembly. 124h Forecast 1 Picked -up BHA - Drills - d nll 16" surface section as per SLB and gyro stand or as requred . Lithology Shows I MAASP Pressure (psi) Mud Weight (lb/gal) Time Lo Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 MOB A 1 P Spot CCB unit in berm area, connect dump lines to each module. Spot cuttings tank and complete berm around both. -- i y ' ; Installing angle frame for curtains stars hanging same around bottom of cellar box. 06:00 L 3:30 7.50'i 13 50 MOB IA 1 ;P I Finished curtain on cellar box, install diverter line saddle clamps and complete installation of bolts in flanges. Change out 1 saver sub on top drive Set in short spool on diverter knife valve section, align and weld as GBR Install gaskets and final � 1 saddle clamps on diverter Total length of diverter 460' and outside of utility module to end is 390'. Load 14 joints of 5" 1 i HWDP and BHA assembly in pipe shed. Secure and build up step platforms around rig. Install temporary well signs on (both sides of ng. 1530 MOB C - -- -- - - -- - " -- -- - ._ --- 13'30 ,15.30 2.00 f 12 ] P 1 Test de/after system, witness pv AOCzCn - John Cns Cnso and BM Nnhla fiintinn test OK_ Tot all gas alarms, PVT pit 1 sensors system, flow line paddle sensor - Preformed accumlator draw down test - all tested passed AOGCC approved to move forward with drilling operation. Diverter knife opened in 10 seconds and annular closed 45 seconds. Kommey test I, i 'recover time 200 psi in 28 seconds and final in 126 seconds Nitrogen back -up bottles (g) 3200 psi average. 15.30 18:30 3.00 18.50 MOB A 1 i P I Finished hanging containment traps around cellar area and build mini containment on wet house roof under cellar box. 1 1 Spot cutting bucket under end of diverter line and berm around same. Preformed demck inspection and grease top drive ! rails. 18:30 19.00 0.50 19.00 MOB A 1 MIN Pick -up 5" HWDP and stand back in derrick (4 stands) - strap and 2.563" drift. 19'00 00:00 500 24.00 MOB A 8 P Load pipe shed with 49 joints of 13 3/8" csg. Off load 50 bbls. of mud to Swaco WIF for spud. Fnished off mud into ng active pits, (tested 8.6 ppg. - 71 vis . 22# bbl gel) from mud plant. Mixed to 8.8 ppg with a 110 vis. Rig up regulated bottle of nitrogen to operate knife valve to cuttings dump and function tested, good. Fill stack with mud no leaks - test high pressure line from mud pumps to Top drive to 2500 psi, good. Daily Contacts Position I Contact Name Company Title Email Office Mobile Em representative Scott Beauchamp ENI Drilling Supervisor Scott. Beauchamp (genipetroleum.com [907- 670 -8623 907 -841 -8759 !Eni representative Joe Longo EM Drilling Engineer )oe.longolenipeVOleum.com 907-670 -8623 907 - 947 -4323 !Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @eripetroleum.com 907-670 -8607 907-229-6100 1Em representative Greg Palter ENI Expediter Greg.Parker @enipetroleum.com 907 -980 -7545 Eni representable Jack Potter ENI Drilling HSE Jack.Potter@enipetroleum.com 907-670 -8624 Eni representative !Dave Smith ENI Drilling Supervisor 907 - 670 -8623 Eni representative ;Michael Seward ENI Ng Fac. Adv. Michael Sewardienipetroleum.com 907- 952 -7880 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (ftK6) I Bottom (RKB) Run Data _ Last Leako ff T est ! r - - "" -- Fluid Density (lb /gal) IP (Surf) ��Depth (RKB) TVD (RKB) (Fluid Type � ( (Psi) Eq. Mud Weight (1b/gal) Leak Off Pressure (psi) 1 ii • 1 i ell Name: OPO4 -07 Eni E &P Division Daily Report [ W -- I Well Code: 23893 - - ENI Petroleum I Field Name: Nikaitchuq CO. Inc. Date: 5/19/2010 - Report #: 6 API /UWI: 50-029 - 23409 -00-00 eni page 1 of 1 Wellbore name: 0PO4 -07 1 ° *ell Header _ I Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 t 0.00 Rig Information Contractor [Rig Name Rig Type NABORS ALASKA NABORS 245E [LAND RIG Job Information _ Wellbore m o b Phase ;Spud Date Target Depth (RKB) ;Target Depth (TV... Depth Dr. (MD) (ft) [Drilling Hours (hrs) i verage ROP (ft/hr) ;DFS (days) 0PO4 -07 DR ILLIN G -- - - I 5/19/2010 12 3 12,38200 22007 56.3 L 0.81 [ Dail End (ftK6 Informati 568.0 K 565.9 56600 H.20 91.3 - - ) ;Depth End (TVD) (... [Depth Progress (ft) TDrilling Hours (hrs) iAverage ROP (ft/hr) POB [Temperature �°F) Weather Wind 94.0 24.0 Cloudy, @ Blowing 122° NNE 20 mph 1 Snow, WC 10° L 'Daily summary operation 24h Summary P/U BHA #1 - Drills & pre -spud meeting - prespud check list - drill to 175' - POOH & P/U remaining BHA - dnll t/ 566' - Cbse approach to tolerance line of future well OP5 -P06 - P3 - consult with town for option - POOH & change motor ABH to 2 12 degree - start back in hole. [ Operation at 07.00 Drilling surface hole and sliding as requred. 24h Forecast - - - _ - - -- - -- --- - - - -- - -- Drill ahead to SLB DDS requirement - circulate clean - POOH and P/U SchlumbergerMWD /LWD tools- RIH and contnue to drill surface. Lithology IShows MAASP Pressure (psi) Mud Weight (Ib /gal) -- -- I - 8.80 Time Log Cum Start End Dur Dur Time Time Mrs) (h) Phase Opr PIM Open. Descr. '00:00 02:00 2.00 _ 2.00 DRILL E 4 P Pick -up BHA #1 as per Schlumberger OD - onent sub to motor. Install secondary containment berm between well house and ng sub -base. 02:00 03:00 1.00 3 00 DRILL A 1 I P Complete secondary berm - perform final work around rig before spudding.well. Held brief meeting on responsibilities of I I rig personal during surface hole. 03:00 04:30 1.50 4.501 DRILL I -1 1 ;P Simulate D3 Diverting Shallow Gas drill, which followed by Rig Evacuation drill - total time 2 minutes 40 scond to safe brief i area, conduct roll cal. Held per-spud meeting with all personnel and preform preform pre-spud checks list. 04:30 06:30 2 001 6.50 DRILL E 6 P Ream/wash conductor- tag @ 110' - pumping 504 gpm with 325 pail 30 rpm with no torque. Start drilling f/110' - U175' @ / 550 gpm with 450 psi. / 30 rpm with 2-4K torque - WOB 10 -15K - Up wt. 82K - Dn wt. 82K - Rot wt 82K. Circulate clean. 06.30 08:30 2.00 8.50 DRILL E 4 P POOH f/175' -1/39' @ stab - Held PJSM - Pick -up BHA #2 ( drill collars & jam). _.- - - 3 - -- 20 -- -- - o - - - -__- 08:30 10:30 2.00 10,50 DRILL E 20 ,P R/U Schlumberger E -line and P/U Gyro Data tools string - RIH with same taking Gyro survey. - -- --- - - -- - -- -- - -- - - f /1 ' - g 600 - 5K / 10 f 12:00 - F 1.50 12.00 DRILL E 3 IP Dnll f /175' - U22T - pumping 600 gpm with 630 psi / 30rpm with 2K torque on bottom / WOB 10.15K / Up wt. 82K / Dn wt + I 82 / Rot wt. 82K Gyro every 90' Ciculating large amounts of clay out. 112:00 __ 13:00 _ _ 1.00 - 13.00 DRILL E 7 U [Clean clay out of flow tine and re- establish circulation. ,13 :00 :20:00 7 00 20.00 DRILL E - + 3 P `Rotate drill & slide f/ 227' - U 566' / Gyro survey every 30' - pumping 600 gpm with 700 psi: (reduce rate to build angle) / WOB 20K / Up wt 82K / Dn wt 82K / Rot wt. 82K - sliding 100% from f/441 - t/566'. Close approach to tolerance line of .future well OP5 -P06 P3 - consult with town for option. ` 22 OO�DRILL E 4 U Monitor well bore - POOH 2000 1 2200 - -- - 200, H f/ 566' to surface - gauge sta and remove bit. - -- - - - - - -- -- - - - - -- - - - g -- -- ,200 00:00 2.00 24 00IDRILL .E 4 C U ,Change motor ABH from m 1.83 to 2 12 degree e - P/U Hughes s bit MX1 Re- onentate UBHO sub to motor- RIH to/ 131' Daily Contacts -- - -- - - -- - -- [ Position Contact Name Company 1. Title I E-mail 1 Office j Mobile ,Eni representative ( Scott Beauchamp ENI Dnllmg Supervisor Scott.Besuchamp@empetroleum.com 907- 670.8623 1907- 841 -8759 1Emrepresentative Tom Norvig '!ENI 'II Rig Clerk I AKRigClarks245e @erspetroleum.corn 907.670 -8607 907-229-6100 Eni representative :AlvinCnswell ,ENI I Expediter 1Alvin.Cnswell @empetroleumcom 1907- 980 -7545 I Eni representatve 'Jack Potter iENI I Dnlling HSE Jack Potter @eripetroleum.com 907 -670 -8624 Eni representative Dave Smith I ENI I Dnlling Supervisor , 907 - 670 -8623 Eni representative Michael Seward ENI IDrlg. Fac. Adv. I Michael .Seward@enipetroleum.corn 907- 952 -7880 Last Casing seat _ Cas. Type OD (In) _ ID (in) Grade Top (ftKB) Bottom (RKB) __ Run Data Last Leakoff Test Depth (ftKB) TVD (ftKB) Fluid Type Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) I l i 1 i I i Eni E &P Division Well Name: OPO4 -0� Daily Report ENI Petroleum y p Meg code: " 23893 'Field Name: Nikaltchuq fililaliTh • CO. Inc. Date: 5/20/2010 - Report #: 7 API/UWI_50 -029- 23409 -00-00 i (� ` Wellbore name: OPO4 -07 H e B � page 1 of 1 Well Header _ _ Permit/Concession N° Operator IENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM I 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 I 12.20 0.00 Rig Information Contractor !Rig Name Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore Job Phase ISpud Date (Target Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4 -07 DRILLING i 5/19/2010 j 12,031.0 3,940.3 12,382 00 220.07 56.3 1.81 Daily Information Depth End (ftKB) I Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) F Average ROP (ft/hr) I POB Temperature ( °F) Weather I Wind 881.0 I 875.4 315.00 2.80 112.5 94.0 27.7 Overcast, Fog, WC 118° NNE (g 7.8 mph I 19.4° Daily operation ' 24h "S ummary I POOH to increase ABH V 2.12 and build angle to get back on line - survey 30' - POOH 881' and P/U schlumberger tools for (MWD & LWD) - change oil in TD - incident with dropped object - inspect TD - ' RIH I/ 854'. Operation at 07.00 Drilling /slidng as required by Schlumberger DD Depth © 0400 hrs: 1191.4' MD, 1177 4' ND 24h Forecast Drill ahead as wet plane. Lithology TShows MAASP Pressure (psi) Mud Weight (Iblgal) 8.90 Time Log Cum Start End Dur Dur 1 Time Time (hrs) (hrs) Oper. Descr. 0 :00 0 1 50' 'DRILL Phase Opr. Act. Plan -LL E 25 - U R 00 _ 01:30 1.50; I RIH V 566' w /BHA #3 (2.12 ABH motor) - Run Gyro for tool face 1: 1 _ 6.0 R - - - r-- - 1 5KG 6.00 DRILL E 3 - P Dnll / Slide f /566' - V 690' - pumping � 400 gpm w/ 760 psi - WOB 20-25K Gyro every 30' - Up wt. 83K / Dn wt. 83k 8.07. 01:30 06:00 4.50' I - - - -- - Survey Depth 645' MD - Inc.- 9.38 / Az - 359.52 DSL - -- - -- --- - - -- -- -- -- - -.. -- -- - -- --- - - 06.00 08'00 2.00 8.00, DRILL E 6 U I Ream out 8 dogleg - 600 gpm w/ 667 psi / 30 rpm © 1 -2K - Ran second gyro survey (g 645' MD Inc. 7.37 / Az 8.54 / DLS 4.2 - OK 08:00 113:00 5.00 13.00 DRILL E ,3 1 1 Drill & slide f/ 649' - V 881' pumpimg (g 550 gpm w/ 750 psi. / WOB 20K / Gyro survey every 30' Rop 50' - 100' fph / Up wt. - 84k /Dn wt. 84k / Rot wt. 84K 13:00 14:30 1.50 14.50 DRILL E 7 P Circulate 30 bbl calcarb hi -vis sweep around - no signs of increase in cuttings returns - CBU 3 times. I 114:30 716.30 2.001 16.50: DRILL _ 4 I P POOH f/ 881' - slick hole condition - no trouble. 1 ' 17.00 0.501 17.00! DRILL • ,� E 2 P R/D Schlumberger and Gyro data equipment to pipe shed - on stand -by until Schlumberger tools in hole and survey check out 17:00 18 30 1 50 18.50 DRILL E 4 P Pick -up BHA # 4 - Schlumberger tools and orient to motor - re-onentate to UBHO sub. 18'30 19:00 -4- " 0.50 19.00 DRILL E 25 P rig - change gear oil in top drive. 19:00 '20:30 1.50 20.50 DRILL E 25 U 1 Down time - on Top Drive - due to oil change.. 20:30 1 1.00 21.50 DRILL E 4 P I RIH f/ 96' - U 575' with proper displacement. Tag a bridge & shim fell from Top Drive guide pads - dropped 20' (size 2 "x 5 "x I 1/8 ") Appx wt 3.5 oz. - Shut down operation. 21:30 23:30 2.00 23.50 DRILL E 25 U Safe out Top Drive and assess situation - preform complete inspection of equipment - replace shim and check torque on all guide bolts - install safety wires on all Notified all personnel of incident 23.30 1.00:00 0.50 24.00 DRILL E 4 P Continue RIH f/ 575' -V 854' Up wt. 90k / Dn wt. 90k.- Tag bridge (1-D 705' & 775' - work through - OK. Daily Contacts Position Contact Name Company Title E-mail Office Mobile ,Eni representative Scott Beauchamp ENI ,Dolling Supervisor Scott. Beauchamp ©enipetroleum.com 907 -670 -8623 907 -841 -8759 'Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245el errpetroleum.com 907 -670 -8607 907 - 229 -6100 I Em representative Alvin Criswell ENI 1Expediter Alvin.Criswelli enipetroleum.com 907- 980 -7545 ',Eni representalve Jack Potter ENI 'Drilling HSE Jack Potters errpetroleum.corn 907-670 -8624 Eni representative Dave Smith ENI !Drilling Supervisor 907 -670 -8623 Eni representative ;Michael Seward ENI Drig. Fac. Adv. Michael.Sewardl enipetroleum.com 907- 952 -7880 Last Casing seat Cas. Type I OD (Fn) 1 _- _ _ ID (in) I _ _ _ - Grade I Top (ftKB) Bottom (ftKB) Run Date r r- - Last Leakoff Test Depth (RKB) �,TVD (ftKB) �,�Fluid Type pe Fluid Density (lb/gal) (lb/gal) P (Surf) (psi) Eq. Mud d Wei ght (lb/gal) Leak Off Pressure (psi) 1 • I -- • • r Eni E &P Division Well Name: OPO4-07 ENI Petroleum Daily Report Well Code: 23893 Field Name: Nikaitchuq p • Co. Inc. Date: 5/21/2010 - Report #: page 1 of 1 8 API/UWI: 50 029 - 23409 - 00 - 00 I) Wellbore name: OPO4 -07 u tl — 'Well Header Permit/Concession N° Operator ENI Share (%) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) (Ground Level (ft) [ Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53 20 i 12.20 - I _ 000 _ - Rig Information Contractor -__ (Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG 1 I Job Information 1 Wellbore fJob Phase i Spud Date Target Depth (ftKB) TTarget Depth (TV... 1 Depth Dr. (MD) (ft) Drilling Hours (hrs) [Average ROP (ft/hr) IDFS (days) D a / InfOrm aG [ Depth End (TVD) ( :DRILLING , 5/19/2010 12,031.0 3,940 3 12.382 DO L 220.07 56.3 2.81 O De - - - _ y - - - - -- - - - -- - (fUhr) POB — 'Temperature °F) Weather - - - - - -- ` Wind 2 193.0 - -- [Depth End (ftKB) 1,947,1 � OO (ft) [Drilling 2 00 (hrs) 1 5a6 — - 92.0 26.8 Overcast. WC +17 6 24 NNE 10 mph -. I Daily summary operation 24h Summary Drill and side from 881' to 2,193' as per directional plan _ _ Operation at 07.00 Drilling and sliding ahead as per directional plan. ;Depth at 0400 hours. 2,375' MD 2 4h Forecast Drill ahead to planned 16" hole total depth as per well plan. Circulate hole clean. Make a short trip. Circulate and condition hole. Pull out of hole and run 13 -3/8" casing. Lithology Shows MAASP Pressure (psi) Mud Weight (lb /gal) 9.30 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 1 4.50 4.50�DRILL E 3 P DRILL AND SLIDE from 881' to 1,198'. GPM 650 ; PSI 1,060 on and PSI 970 off; TO 2K -3K on and 1.5K off; RPM 30; 1 Pick up 100K Slack off 98K Rotate 98K; WOB 15K -30K. Flow check every connection. 04:30 4 105 00 0.501 5.00!DRILL I E 6 P IREAMINGANDWASHING 6 + dogleg 1,130'to1,198'. GPM 650, PSI 980, RPM 30 as per directional driller. 05'00 - --- 5. 10.30 50' 10.50r DRILL --- - -- 1 50 ' 10 50: IE t 3 P 1 DRILL AND SLIDE from 1,198' to 1,452'. GPM 650; PSI 1.050 on and 940 off; TO 2K -3K on and 1K-2K off; RPM 35; Pick up 106K Slack off 98K Rotate 100K; WOB 20K -30K. Flow check every connection. AST - 4.20 hrs; ART - 0.79 hrs 10:30 f 12 00 (DRILL 8 7 IP Shut down drilling operations due to large ice chunks falling from derrick to rig floor. Derrickman de -iced the derrick. Circulate hole slaw at 100 GPM and 280 PSI Work pipe as needed. No hole problems. 00 00 12.00 -- - -- - - - - - - - - -- f 1 - ( DRILL AND SLIDE from 1,452' to 2,193' GPM 550; PSI 950 on and 720 off; RPM 35; WOB 10K -30K; TQ 3K -4K � - 1 , 24.00 ~ DRILL E 3 � 12'00 1, on and 2K off, WOB 20K -25K ADT - 7.21; ART - 1.87; AST - 5,24 1 Daily Contacts j Position 1 Contact Name 1 Company Title I E-mail Office Mobile Pan y l Eni representative 'Scott Beauchamp ENI Drilling Supervisor ;Scott Beauchamp @enipetroleum.com 907-670-8623 907- 841 -8759 Eni representative Alvin Cnswell 'ENI 1Expediter 'Alvm.Cnswell @empetroleum corn 907- 980 -7545 Em represertative Michael Seward ,ENI IDrig Fac. Adv 'Michael.Seward @eripetroleum.com 907 -952 -7880 Eni representative Bernie Lees IENI 'Rig Clerk AKRigClerks245e @eripetroleum.com 907-670 -8607 907 - 575 -9427 Eni P Pete Adams ENI Drilling HSE Pete.Adams @enipetroleum.com 907-670-8624 907 -440 -0806 [Eni rep esental 1 ve - [Gary Goeriich , ENI ., upennsor Drilling S [907- 670 -8623 907-441-6585 ( Last Casing seat Gas. Type t OD (in) ID (In) )_ Grade Top (ftKB) I Bottom (ftKB) Run Date CASING - 13 3 /81 12 4151-80 p _ o 2,420.9 5/21/2010 Last Leakoff Test Depth (ftKB) TVD (ftKB) '[Fluid Type (Fluid Density (lb /gal) 'P (Suit) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 1 - -- Eni E&P Division Well Name: OPO4 -07 I irs* Daily Report EN/ Petroleum (Well Code: 23893 'Field Name: Nikaitchuq 1 • Co. Inc. Date: 5 /22/2010 - Report #: 9 API/UWI: 50 -029- 23409 -00-00 -- rr 1 0 Page 1 of 1 Wellbore name: 0PO4 -07 N Il tl - Well Header Permit/Concession N° 'Operator ENI Share (k) Well Configuration type 1 2081990 IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) ! "Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53 20 12 20 0.00 R Information Contractor - 1RigName Rig Type NABORS ALASKA l NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase 'Spud Date Target Depth (ftKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) I OPO4 -07 'DRILLING I 5/19/2010 �- 12,0310 3,9403 12,382.00 220.07 56.3 3.81 Daily Information Depth End (ftKB) Depth End (TVD) (... ;Depth Progress (ft) ;Drillin Hours (hrs) Average ROP (Whr)1POE Temperature (°F) Weather Wind 2,455 0 2,096 5 262.00 5.00 52.4 93.0 24.4 Overcast. Fog. WC 46NE @ 26 mph i +8.4 -_ Daijy summary 24h Summary -- -- -- - -- --- - - - - -- - - -- -- Completed drilling 16" surface hole section. Drilled to total depth of 2,455 MD. Circulated and conditioned hole. Back reamed on a wiper trip to heavy wall. Tnpped back to bottom and circulated and conditioned hole. Pulled out of hole on elevators and layed down BHA. Operation at 07.00 Rigging up to run 13 -3/8" casing - 24h Forecast iC omplete hu u ylaying down BHA Rig up and run 13-3/8: casing Cement casing Shows MAASP Pressure (psi) I Mud Weight (Iblgal) 9.50 ; Time Log - T I Cum ) Phase Opr. (hrs) Ihre O ? . Act. Plan Oper. Descr. Dur � Time Start End Dur 05 00 S.00i 5 OO:DRIIL E T �3 100 P ,DRILL from 2,193'10 2,455' MD 2,103' TVD Total depth for 16" surface hole section. GPM 660; WOB 25K -30K; RPM 30, TQ on 4K -6K, TO off 3K -4K; PSI 1100 - 1320. UP WT 130K; DN WT 100K, ROT 110, ART - 0 61; AST - 1.30; i,ADT - 1.91; Jar Hours - 20.8. 0500 108:30 3.50T 8 50jDRILL E 7 I. CIRCULATE AND CONDITION HOLE. Pump a 35 bbl. 10 5 ppg high vis sweep. Circulaste bottoms up 4 times GPM 08:30 12.00 3.50 12.00 DRILL d P 700; PSI 1240 Monitor well for 10 minutes. E 4 BACK REAM OUT from 2,455'to 1,645' RPM 35; TQ 4K-6K; GPM 750; PSI 1380. Hole unloading from 1,930'to 1,660' GPM 499, PSI 530. 12:00 1230 0.50 12.50 DRILL E 4 P _BACK REAM OUT to 1,525' At 1,630' able to increase pumps to 625 GPM; PSI 1,165; RPM 35-40; T� 38K -4511 ' ' 0.50 13.00 DRILL E 4 P _ STRIP IN HOLE high side tool from 1,525' to 2,000 Hole slick. I 12:30 '13:00 _ __- 13.00 1 1 17:00 4.00 17.00 DRILL E 4 P IBACK REAM OUT from 2,000' to 481'. GPM 815; PSI 1,550; TQ 38K -42K; Large amounts of cuttings returns over shakers. j 17 :00 18:00 1 00 18.00 DRILL E 4 P TRIP IN HOLE 481' to 2,385'. No tight spots. UP WT 139K; DN WT 100K. 18:00 20:30 2.50 20.50 DRILL E 7 P CIRCULATE AND CONDITION HOLE. Break circulation. Pump 35 bbl high vis weighted sweep. Follow with 3 5 bottoms up. GPM 800; PSI 1,600. 20:30 23:00 2 50 23.00 DRILL E 4 P TRIP OUT OF THE HOLE. Tnp out to BHA. No tight spots. 23:00 00.00 1.00 24.00 DRILL E 4 P LAY DOWN BHA. Clean off stabilizers. Stand back drill collars. Daily Contacts - _ Position Contact Name Company _ I Title E-mail Office Mobile Eni representative Scott Beauchamp ENI Drilling Supervisor i Scott.Beauchampienipetroleum.com 907 - 670 -8623 907 - 841 -8759 Em representative Alvin Cnswell ENI (Expediter IAlvin.Criswell©enipetroleum.com 907- 980 -7545 Eni representative Michael Seward ENI IDrig. Fac. Adv. Michael.Sewardienpetroieum.com 907- 952 -7880 Eni representative Bernie Leas ENI 'Rig Clerk AKRigClerks245e ©eripetroleum.com 907-670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI I Drilling HSE Pete Adams @enipetroleum.com 907 - 670 -8624 907 -440 -0806 Eni representative ;Gary Goerlich 'ENI 'Drilling Supervisor L. 907 - 670 -8623 907 - 441-6585 -1 Last Casing seat _ Cas. Type I OD (in) ID (In) Grade Top (ftKB) - __.. _ _ _ Bottom (ftKB) Run Date CASING - -- 13 3/8 12.415 L -80 i 0.0 2,420.9 5/21/2010 Last Leakoff Test -- Depth (ftKB) TVD (ftKB) Fluid Type Fluid Density (lb /gal) I (Surf) (psi) Eq. Mud Weight (Ib/gaI) Leak Off Pressure (psi) - - • Iiifiliil Eni E &P Division �.} Well Name: 0PO4 -07 ENI petroleum Daily Report Well Code: 23893 Field Name: Nikailchuq CO. Inc. Date: 5 /23/2010 - Report #: 10 A 50-029 - 23409 -00-00 n I _ page 1 of 1 { ellbore name: OPO4 -07 Well Header Pennit/Concession N° 'Operator ENI Share (%) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12 20 0.00 _ Rig Information - .Contractor IRig Name Rig Type . 'NABORS ALASKA NABORS 245E LAND RIG I OPO4 -07 "DRILLING - - -- - -- Spud 5/19/2010 Target Depth 'Target Depth � pth - -- - 1 ---- - --- 1 Job Information (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) [Average ROP (ft/hr) IDFS (days) 'Depth End (ftKB) De th End (TVD) ... De h Progress (ft) (Drilling Hours (hrs) 'Average ROP (R/hr) POB _12,382 -00 - Temperature rF) IWeather 56.3 Wind 4 81 Daily Information tion 1 1 T P ( 11 Pt 2,455.0 _ i 2,0965 1 0.00 -_ -�I - �__ - - -_ -_ - _ _92.0 252 (Cloudy. WC +12.7 18 NNE @ 15 mph Daily summary operation 24h Summary Layed down BHA. Rigged up and ran 13-3/8" L :80 68 ppf BTC casing. Cemented casing. Nippled down diverter. Operation at 07.00 Nippling down diverter. 24h Forecast Nipple down diverter. Nipple up BOPE. Test BOPE. Pick up BHA #5. Lithology Shows MAASP Pressure (psi) Mud Weight (lb/gal) 9.40 Time Log Cum Start End Dur Our Time Time (hrs) WO Phase Opr. Act. Plan Oper. Desor. 00.00 103:00 100 3.00 DRILL _ E 4 P LAY DOWN MWD, stabilizers and bit Clear and clean rig floor. 0300 '04:00 1.00 4.00 DRILL E 13 P Lifting ejectors on skate would not eject collars off skate. Worked on same and corrected problem. -- - - - - -. ...- -- -- ---- -- -- - - --- --- 04:00 ,05.00 0 � 1.00 5 00 DRILL D LL E 4 P SLAY DOWN MWD, motor, stabilizers and bit down the beaver slide ,05:00 109:00 4 00 9.00 DRILL E 15 [ P Hold PJSM to rig up casing equipment. Make up Frank's tool. Pick up Vetco Gray landing joint and change out bottom [ 1 i i pup joint to slick joint. Perform dummy run on hanger. Good test Witnessed by Vetco Gray representative. ;09:00 115'00 600 15.00 DRILL IE 119 IP !Make uo shoe track and Bakerloc same. Fill shoe track with mud and confirm floats are draining. Install tansdem rise i centralizers as follows: two each on stop rings 5' and 8' above float shoe; one 10' above float collar on stop ring; one on collar every joint; from joints #3 through joint #15; and one on collars on joints #56 and #57 inside of 20" conductor Run 13 -3/8" L-80 68 ppf BTC casing to 1,961' filling every joint on the fly At 1,961' break circulation. Good circulation. Continue runnnmg casing to 2,379'. 15'00 16.00 1.00 16 OOIDRILL E 19 P Make up landing joint and casing hanger Lay down casing tongs. Break circulation slowly and establish parameters at 2,420' MD. Circulation at barrels per minute at 200 PSI. UP WEIGHT: 195K; DOWN WEIGHT; 145K. Increase pump rate slowly to 8 bbls per minute at 400 PSI. Increase pump rate to 8.5 bbls per minute at 478 PSI, Circulate and reciprocate 35' stroke while circulating bottoms up. 16:00 117:00 i 1.00 17 00 DRILL E 19 IP Istage down pumps and land casing on hangar. Lay down Franks tool and make up cement head. Circulate and condition mud PJSM with all personnel � l invol l in cement job. top to . Rig pump Displace 17.00 -20:00 3.007 20.00 DRILL E 9 ' IP Stage down pump and line up to Schlumberger cementers. Schl. Pump 5 bbls H2O, Test lines to 3,000 PSI, Schl. pump 100 bbls 10.5 ppg mud push II 4 bpm, drop btm plug, Schl. mix & pump 355 bbl; 10 7 one Lead slurry (441 sks / 4.52 /�.fl yield ) � 5 bpm, Schl. mix & pump y 73 bbls Tail Slurry (268 sks / 1.62 yield) @ 5 bpm, Drop to plug, R' place w/349 bbls mud @8.5 bpm, Slow pump to 3 bpm @329 bbls away, 1 349 bbls dispaced bump plug, FCP (g300, bump i plug to 800 Psi (500 over FCP) Hold f/3 minutes, bleed off & check floats- Floats holding good Reciprocate casing ° [ ,, [, dunng cement job Land casing at 2,420'. P/u Wt- 195K, S/o Wt- 145k. Total of 115 bbls Cement to Surface. (Cement in _ i - - place @2015 hours). C i • 300x23.00 _ _ I 20.00 23'00 - - -- - -- - -- -- - - - - -- - i Blow down cement lines. Rig down cement head and casing tools. Pick up Johnny Whacker. Flush out stack. DRILL i,E 20 P I -- -- _ -- --- __ -__- 23 :00 00.00 1.001 24.00 DRILL - LE 120 P I Nipple down diverter system. Daily Contacts Position Contact Name Company I Title Email Office Mobile Eni representative S cott Beauchamp ENI 'Drilling Supervisor � Scott.BeauchampUenipetroleum.com 907 -670 -8823 907- 841 -8759 Eni representative Alvin Criswell ENI Expediter Alvin Criswell @enipetroleum.com 907- 980 -7545 Eni represertative [ Michael Seward ENI Ddg. Fac. Adv. Michael. Seward(©eripetroleum.com 907 -952 -7880 Eni representative 'Bernie Leas (ENI Rig Clerk AKRigClerks245e @enpetroleum.com 907-670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI Dnlling HSE Pete Adams @enipetroleum.com 907 - 670 -8624 907 - 440 -0806 Eni representalve Gary Goerlich ENI Drilling Supervisor 907-670-8623 907 - 441 -6585 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Data CASING 133/8 12.415,L -80 0.0 2,420.95/21/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type Fluid Density (lb /gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) ! � I II'I -- - V11114/ -- -- -- �- Eni E &P Division .. [Well Name: OPO4 -07 -- --- -- ---- - ---- -- Daily Repot t Well Code: 23803 --- -- ._._. - --- - - - - - -- ENI Petroleum Name: Nikaitchuq p • p Co. Inc. Date: 5124/2010 - Report #: 11 APUUWI: 50 -029- 23409 -00-00 in tl -_ page 1 of 1 Wellbore name: OPO4 -07 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 0.00 Riig Information - -_ Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (ftKB) Target Depth (TV.. Depth Dr. (MD) (ft) 'Drilling Hours (hrs) 'Average ROP (ftlhr) DFS (days) 0PO4 -07 DRILLING 5/19/2010 : 12,0310 L_ 3,940.3 12,382.00 1 220.07 I 56.3 5.81 ■ Daily Information Depth End (ftKB) Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (ftihr) POB Temperature ( °F) Weather Wind 2,455 0 2,096.5 0.00 92.0 29.5 Overcast. Fog. WC 66NNE © 13 mph 19.4 Daily summary operation _ -- 24h Summary Nippled down civerter system. Installed wellhead and ressure tested to 5 000 PSI for 10 miagjettippled up BOPE. Tested BOPE . Tested annular to 250 PSI low and 2,500 PSI high. Tested other equipment to 250 PSI low and 3,500 PSI high. BOPE tests waived by Jones with AOGCC. Operation at 07.00 Operation at 0400 Hours: Changing out upper IBOP on top drive. 24h Forecast 1 I Change out upper IBOP on top dnve Complete testing BOPE Pick up BHA #5. Drill ahead in 12 -1/4" hole as per directional plan. Lithology 'Shows 1MAASP Pressure (psi) Mud Weight (lb /gal) -- - -- 9.40 I Time Log 7 Cum Start I End Dur Dur Time Time (hrs) (his) Phase Opr. I_ Act. 1 Plan Oper. Descr. J [00 00 06,30 6.501 6 50 DRILL C 5 P Nipple down diverter system, knife valve, and hydril - - - - - :- - - -- - -- - - - - - - - -- - ;06.30 111 '� 4.501 11.00 DRILL ' C 5 P Clean speed head. Install wellhead. Pressure test to 5,000 PSI for 10 minutes. Install annular valve. Install riser from ' wellhead. Install gray lock clamps. 111:00 12 1 00l 12 00'bRILL [C 5 P Nipple up BOPE. Install bridge crane on BOPE. Prepare to lower dixie cup. Diverter line in the way of of dixie cup. Need to cut diverter line off. 12:00 -[ r17.00 5.00 17.00 DRILL C 5 P Cut off section of diverter. Lower cellar box and change out adapter spools on bottom of stack. Nipple up stack. Install choke and kill lines. Install bell nipple and flowline. 17:00 19:30 2.50 19.50 DRILL C 5 P Change out door seal on middle ram door. Adjust roller on brake bands on drawworks. ( 19:30 22:00 2.50 22 00 DRILL E 5 P Slip and cut drilling line 84'. 22:00 22:30 0.50 22.50 DRILL C 5 P Pick up test joint and set test plug. 22.30 00:00 1.50 24.00 DRILL C 12 P Fill stack and test BOPE. Test annular to 250 PSI low and 2,500 PSI high. Test all other equipment to 250 PSI low and 3,500 PSI high. Hold test pressure for 5 minutes. BOPE tests waived by Jeff Jones with AOGCC. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Scott Beauchamp ENI Drilling Supervisor Scott.Beauchamp ©enipetroleum.com 907 -670- 8623 907- 841 -8759 Ent representative Alvin Criswell ENI Expediter Alvin.Criswell ©enipetroleum.com 907- 980 -7545 Eni representative Michael Seward ENI Drlg. Fac. Adv. Michael.Sewardienpetroleum.com 907 -952 -7880 Eni representative Bernie Leas ENI [Rig Clerk AKRigClerks245eleripetroleum.com 907-670 -8607 907-575-9427 Eni representative ;Pete Adams ENI Dnlling HSE Pete.Adams(cilenipetroleum.com ; 907- 670-8624 907 -440 -0806 1 Eni representalve 'Gary Goertch :ENI Drilling Supervisor 1907- 670 -8623 907 - 441-6585 Las t C asing seat ;CASING Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 13 3%8 12.415 L -80 0.0 2,420.9 5/21/2010 I I I Depth (ftKB) Density 1 Last Leakoff Test !TVD (ftKB) Fluid Type Fluid Density Qb /gal) P (Surf) (psi) Eq. Mud Weight QWgaq Leak Off Pressure (psi) -- - - � i - - - - - - -___ - - -_____ `_ -- - --1 I i 1 1 I � _ • - I ilrill41 Well Name: 0PO4 -07 Eni E &P Division Daily Report - - ENI Petroleum Well Code: 23893 Field Name: Nikartchuq • CO. Inc. Date: 5 /2512010 - Report #: 12 API /UWI: 50 -029 -23409 -00-00 en n fl page 1 of 1 Wellbore name: OPO4 -07 (1 Well Header Pennit/Concession N° Operator IENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL I Rotary Table Elevation (ft) I Ground Level (ft) !Water Depth (ft) I RKB - Base Flange (ft) 1 RKB - Tubing Spool (ft) , 53.20 12.20 0.00 - Rig_ Information `Contractor - -- - Rig Name !Rig Type ;NABO S ALASKA L NABORS 245E (LAND RIG Job Information Welibore 1Job Phase iSpud Date 1Target Depth (ftKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) 1DFS (days) 0PO4 -07 1DRILLING J 5/19/2010 1 12,031.0 I 3,940.3 I 12 382.00 220.07 56.3 I 6.81 Daily Information Depth End (ftKB) Depth End (TVD) (... [Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature ( °F) Weather Wind 2,455.0 2,096.5 0.00 90.0 29.5 Overcast. VVC 22 3 348 @ 7 mph Dail summaryoperation 24h Summary Tested BOPE, choke and floor equipment. All tests passed except IBOP valve in top drive Replaced IBOP valve and retested. Good test Picked uo 12 -1/4" BHA Tested casing successfully. Drilled cement, float collar and float shoe. Circulated and conditioned hole. Operation at 07.00 Operation at 0400 Hours: Change over mud system to LSND. Run leak -off test. 24h Forecast _Perform leak-off test. Drill ahead with 12 -1/4" hole as per well plan and directional plan. Lithology r Shows MAASP Pressure (psi) Mud Weight (lb /gal) : 940 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act, Plan Oper. Descr. 00:00 05 00 500 5.00 DRILL E 12 P Pressure test BOPE, choke and floor equipment to 250 PSI low and 3,500 PSI high. Tested hydril to 250 PSI low and 2,500 PSI high as per AOGCC Upper IBOP test failed. Function tested all gas alarms Witnessing tests waived by Jeff !Jones AOGCC. 05:00 , F11:00 I 6.00 11.00 DRILL E 5 1)(R99 !Replace upper IBOP valve on top drive. 11:00 1 11:3 0 T 0.50 11.50 DRILL E 12 P 'Retested upper IBOP valve to 250 PSI low and 3,500 PSI high. Good test. 11:30 12:00 0.50 12.00 DRILL E 5 ,P _ { i Rig down test equipment and install wear bushing (12 - 11/16 "). 12:00 12:30 1 0.50 12 50 DRILL E 5 1P Set wear ring. Lay down test joint. 12:30 13'00 0.50 13.001DRILL E 4 P Pick up BHA. Pick up bit, stabilizer, ghost reamer, and lifting sub -- -- -- - - 13:00 13:30 0.50 13.501DRILL E 25 P Cleanice from derrick. 13:30 18:00 4.501 18.00 [DRILL IE 14 P Pick up BHA. Dress new bit with 6-16 jets. Change out stabilizer with bad threads. PJSM. Load Schlumberger nuke _ t 0 50 18 50 source 18:00 18.30 !DRILL FE j4 P Pick up 12 joints of drill pipe 15 -- - - - h - - - 1 1 18'30 1 19 00 i 0 50 19 00 ! F D R ILL 7 {P �Crculate and fill pipe Shallow test MWD Calibrate Schlumberger weight indicator. - - -- - - - - l - ,19 00 � 20 00 0 1 00, 0 00 i DRILL � E 4 P �Tnp in hole Break circulation and tag at 2,326'. Up weight = 130K, Down weight = 95K. -- -- - - -- - - - -- - 2000 20 30 0.50 20 50'DRILL,E 7 : P 'Circulate and condition hole Circulate bottoms up with 600 GPM and 850 PSI j P - -- - a -- -- - 120 30 2130 1 00: 21.50�DRILL E 12 'Pressure test casing and shoe Test casing to 2,500 PSI for 30 minutes Good test. Record test on chart. - 121'30 00:00 2 501 24 00'1 DRILL 'E 3 I P ,Drill cement plugs, float collar, and float shoe to 2,455' Circulate out cement. Up weight = 130K; Down weight = 95K, Rotating weght = 110K RPM 80, VVOB 2K -12K, TO 5K-6K; GPM 750; PSI 1,300. Daily Contacts r __ E ni representative jS cott Beauchamp Name L Company Title --- -..._. -_ -- E-mail --- Office Mobile -_. -- ENI Drilling Supervisor Scott .Beauchamp(ienipetroleum.cow 907-670-8623 907- 841 -8759 Eni representative 1Alvm Criswell , ENI i Alvin.Cnswelliempetroleum.com 907- 980 -7545 Eni represertative ;Michael Seward 'ENI ;Dig. Fac Adv. Michael Seward( eripetroleum.com 907 -952 -7880 I Eni representative Bernie Leas I ENI 1 Rig Clerk AKRigClerks245ece ripetroleum.com 907-670-8607 907 - 575 -9427 Eni representative Pete Adams ENI 'DnllingHSE Pete Adamsienipetroleum.com 907 - 670-8624 907-440-0806 Eni representalve Gary Goerlch IENI Drilling Supervisor 907-670-8623 907-441-6585 Last Casing seat Caa. Type 00 (in) ID (In) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L -80 0.0 2,420.9 5/21/2010 Last Leakoff Test Depth (ftKB) TVD (ftKB) Fluid Type Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 2,421 0 2,079.91 LSND 8 80 320.0 11.76 1,270.8 ij I � I I ; I,I VIR41 Eni E &P Division -- - - - - - - - - -- - - -- -- .._ N [Well Name: 0PO4 -07 D aily Report Well Code: 23893_ ENI Petroleum Field Name: Nikeitchuq n 1) Co. Inc. Date: 5126/2010 - Report #: 13 •API/UWI: 50 - 23409 - 00 - 00 L- Welibore name: OPO4 -07 t, pa ge 1 of 1 Well Header -- - -_ - - -� v- -- - -- -� Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) (Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 I 12.20 0.00 Hi! Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (ftKB) (Target Depth (TV... ;Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4 -07 DRILLING 5/19/2010 1 12,0 3,940.3 1 12,382.00 220.07 56.3 7.81 Daily Information Depth End (ftK6) !Depth End (ND) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather Wind 4,2200 2,648.6 1,765.00 19.50 90.5 90.0 27.5 Overcast Fog. WC 17NNE 13.4 mph 1 i Daijsummary operation I 24h Summary I Dnlled 20' gt new 12 -1/4" hole. Changed mud system to LSND. Pertormed LOT. Obtained baseline ECD's. Dnlled ahead from 2,475' to 3,645'. Circulated and conditioned hole to lower ECUs. Drilled ahead in 12 -1 /4" hole from 3,645' to 4,220' - -1 `Operation at 07.00 !Operation at 0400 Hours Drilling ahead in 12-1/4" hole at 4,506' problems. with no blems, -__ P 9 " p J 24h Forecast Dell ahead towards total depth in 12 -1/4" hole as per wet plan and directional 'Lithoiogy Shows .MAASP Pressure (psi) Mud Weight (Ib /gal) - -- - - - - -- - - - -- 9 00 Time Log Cum Start End Our Dur Time Time (hrs) (ft Phase Opr. Act. Plan I Oper. Descr. 00:00 '00.30 0.50 0.50 DRILL E ;3 , P 'Drill from 2,455'to2,475'. Up Weight = 135K Down Weight = 90K Rot Weight = 110K. WOB 8K; GPM 750; PSI 1 I 1,340. 00:30 03:00 2.50 3.00 DRILL E 7 P Change out mud system to LSND. Circulate and condition hole LD 0300 04:00 1.00 4.00 DRILL E 11 P Perform LOT. Broke down at 440 PSI. Mud weight = 8 8 PPG. EMW = 12.4 PPG. Inject 3 barrels and received back 2 'barrels. 04:00 04:30 0.50 4.50 DRILL E 11 P Circulate to obtain base line ECD's. GPM 600 ECD = 9.11; GPM 700 ECD = 9.13; GPM 800 ECD = 9.14. GPM 800 RPM 80 ECD 9.17. 04:30 12:00 7 50 12.00 DRILL E 3 P DRILL from 2,475' to 3,200'. Up Weight = 125K; Down Weight = 85K; Rot Weight = 110K. WOB 10K; GPM 800; PSI 1100 -1140; RPM 140; TO 5K-6K; ADT = 4.66. Jar hours = 25.48. 12'00 16'00 4.00 16.00 DRILL E 3 P DRILL from 3200' to 3,645'. Up Weight = 150K; Down Weight = 80K; Rot Weight = 105K. RPM 120; TO 10K -11K; GPM 800, PSI 1,230; WOB 4K -10K; Original ECD baselne at 9 2 ppg has slowly increased to 9.68 ppg 16:00 16:30 0.50 16.50 DRILL E 7 IP Circulate and condition hole to lower ECD's GPM 800; PSI 1,475. Continue to backream all stands dnlled. ECD's 1 lowered to 9.3 ppg. 16 00:00 t 7.50 24.001 iE 3 IP ±DRILL from 3,645 to 4,220'. Pumped 45 barrel weighted sweep at 3 ,741'. Up Weight = 155K; Down Weight = 82K; Rot Wei 105K GPM 900; RPM 130; SPP 1,620; TO 9K -12K WOB 6K -10K Daily Contacts Position Contact Name Company Title I E-mail Office Mobile ,Eni representative Scott Beauchamp ENI Drilling Supervisor 'Scott.Beauchamp@enipatroleum.com 907-670-8623 907 -841 -8759 Eni representative Alvin Caswell ENI , Expediter AIvm.Cnswell ©enipetroleum com 907- 980 -7545 /Emnrepresentative Michael Seward ENI 1 Dng.Fac.Adv. Michael.Sewardleripetroleurn.com 907 -952 -7880 Eni representative ,Michael Leas ENI Rig Clerk AKRigClerks245eleripetroleum.com 907-670-8607 907 -575 -9427 Eni representative (Pete Adams ENI Drilling HSE Pete.Adarns @enipetroleum.com 907 - 670-8624 907 -440 -0806 Eni representatve (Gary Goertich LENT Drilling Supervisor 907 - 670 -8623 907 - 441 -6585 Last Casing seat Cas. Type ! OD (In) ID (In) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 133/8 12.415.L -80 - 0.0 2,420.9521/2010 [Last Leakoff Test !Depth (ftKB) ID (ftKB) 'Fluid Type Fluid Density (lb/gal) iP (Surf) (psi) !Eq. Mud Weight (lb /gal) !Leak Off Pressure (psi) 2,421.0 I 2,079.91 ,LSND 8.80 320.0 j 11.76 i 1,270.8 ■ I i pott Eni E &P Division [ Name: OPO4 -07 Y Dail Report _ ENI Petroleum I Well Code: 23893 Field Name: Nikaitchuq Co. Inc. Date: 5/27/2010 - Report #: 14 API /UWI: 50-029- 23409 -00-00 } n page 1 of 1 � Wellbore name: OPO4 - 07 II 11 11 — -- --- - - -- Well Header Permit/Concession N° !Operator ENI Share ( %) Well Configuration type 1 1 2081990 !ENI PETROLEUM 100.00 DIRECTIONAL be Elevation a — 11 Gr nd Level Rotary Table Elevation (ft) Ground Level (R) 1 Water Depth (ft) TRKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 1 12.20 i 0.00 ( ' Rig Information - - - - -- -- -- -- - - - - -- - -- Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore I Job Phase 1Spud Date Target Depth (RKB) 'I Target Depth (TV... 1 Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) � 10PO4 -07 DRILLING 5/19/2010 i 12,0310 L 3,9403 1 12,382.00 220.07 56.3 8.81 !Daily Information 1Depth End (RKB) ,Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) [Average ROP (ft/hr) IPOB Temperature (°F) Weather Wind 5,605.0 3,037 1 1,385 00 24.00 57 7 90 0 28.8 Overcast. Fog. WC 1N @ 4 mph L - -` 25.5 Daily summa ope ration - -- --- -- -- -- 24h Summary Dnlled 12 -1/4" hole from 4,220' to 5,605' as per SLB DDS directional plan. Operation at 07.00 Operation at 0400 Hours. Dolling ahead at 5,880'. I– 4h Forecast _ -- Dill ahead with 12 -1/4" hde towards casing point at 8,488' as per well plan. Lithology Shows MAASP Pressure (psi) Mud Weight (lb/gal) 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (mss) Phase Opr. Act Plan Oper. Defier. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING from 4,220' to 4,683' MD, 2,775' TVD. Up Weight = 130K; Down Weight = 96K; Rot Weight = 110K WOB 20, GPM 900; PSI 1690; RPM 140; TQ 9K-11K ADT = 8.65; Jar Hours 40.69; MW 8.9. 12:00 00:00 12 00 24.00 DRILL E 3 IP [ DRILLING from 4,683' to 5,605' MD. Up Weight = 148K; Down Weight = 85K; Rot Weight = 112K. WOB 10K -15K; [ 1 135; TQ 10K -12K PSI 2125; GPM 900; ECD 9.9 ppg; ADT 8.98; Jar Hours = 51.6. Daily Contacts . _ Position 7 Contact Name Company Title E-mail Office — Mobile Eni representative Scott Beauchamp ! ENI IDnIling Supervisor Scott .Beauchamp@enipetroleum.com 907 - 670 -8623 907- 841 -8759 Eni representative Alvin Criswell I ENI !Expediter !Alvin Criswell @enipetroleum.com 907 -980 -7545 I Eni representative IBemieLeas ,ENI I Rig Clerk I AKRigClerks245e @errpetroleum.com 907-670 -8607 907 - 575 -9427 I Eni representative I Pete Adams I ENI Dnlling HSE 1Pete.Adams@enipetroleum.com 907 - 670 -8624 907 -440 -0806 Eni representaive Gary Goerlich !ENI Dnlling Supervisor 1907- 670 -8623 :907 - 441 -6585 Last Casing seat 1 Cas. Type 1 - - OD (in) ID (in) f Grade I Bottom (ftKB) Run Date ',CASING _ - 13318 12415 L- 80_.... - - _- -_ T Top (ftKB) 00 - -- 2,4209 5/21/2010 Last Leakoff T e st Depth (RKB) TTVD (ftKB) ;Fluid Type !Fluid Density (1b/gall • P ( Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) - -- _ - -- 2,421.0 L 2,07991 LSND 680 I 320.0 11.76 I 1,270.8 Ii Ii - -- Eni E &P Division Well Name_ 0PO4 07 ..__ l ENI Petroleum Daily Report Wen Code: 23893 Field Name: Nikaitchuq Co. Inc. Date: 5/28/2010 - Report #: 15 API /UWI: 50-029 - 23409 -00-00 fi page 1 of 1 Wellbore name: OPO4 -07 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB • Tubing Spool (ft) 53 20 12.20 0.00 - - -- -- - -- -- Rig Information Contractor ;Rig Name Rig Type NABORS ALASKA 1 NABORS 245E LAND RIG ' I Job Information Wellbore 'Job Phase - -- - i Spud Date !Target Depth (RKB) Target Depth (TV... ?Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (tt/hr) DFS (days) OPO4_ -07 DRILLING _ ` 5/19/2010 12,031.0_ _ _ ! 3,940.3 1 12,382.00 220.07 56.3 9.81 1 6,655 0 3,347 9 1,050 e 20 00 52.5 Daily Information 1 ( Depth End (RKB) itepth End (TVD) (.. Depth Progress s (ft) drilling Hours (hrs) 'Average ROP (Mr) IPOB !Temperature (°F) Weather !Wind 88.0 31 5 Overcast Fog. WC 1 217SW a 13 mph _. - - - -� - - -- 21.7 Daily summary operation 24h Summary Dnlled from 5,605' to 6,655'. Started seeing losses at 6,441'. Losses estimated at 75 bph. Circulated and condtioned hole. Pulled 3 stands and spotted 35 barrel calcium carbonate pill and circulated at 900 GPM and 2,250 PSI. Hole losses minimal. Drilled ahead. Operation at 07.00 Operation at 0400 Hours: Drilling ahead at 6,900' as per directional plan 24h Forecast Drill ahead with 12 -1/4" hde to casing point as per well plan. Lithology - -- - -_ - - - - - -- Shows _ -- MAASP Pressure (psi) Mud Weight (Ib/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper. Descr. 00:00 112:00 12.00 12 00 DRILL E 3 IP DRILLING from 5,605 to 8,260' MD 3,226' TVD Up Weight = 155K; Down Weight = 85K; Rot Weight = 115; WOB 15K -20K; GPM 900, PSI 2240; RPM 140; TQ 11K; ADT • 8.49; Jar Hours = 60.09 Charge pump discharge pressure gauge broke off and spilled 7 barrels in charge pump room and 3 barrels leaked through seam on floor and into containment area onto rig mats. 12:00 4 ,15:30 3.50 15.50 DRILL E 3 P DRILLING from 6,250' to 6,441'. Up Weight = 155K; Down Weight = 90K; Rot Weight = 115K. WOB 2K; RPM 135; TO 10K-11K; GPM 898; PSI 2296. ECD clinbed to 10 ppg. Start to see lost circulation. Initial loss rate estimated at 1 1 100 BPH. 15.30 -17:30 2.001 17.50 DRILL E 7 F TP01 CIRCULATE AND CONDITION hole due to lost circulation. Pull 1 stand back. Circulate 2 bottoms up. Reduced ECD's to ' 9.69 ppg. Loss rate estimated at 22 -25 BPH. 17'30 18:30 1 00 18.50 DRILL I0 3 P DRILLING from 6,441' to 6,486'. Loss rate approximately 75 BPH. 18:30 11960 [. - . 0.50 19.00 ,DRILL E 7 P CIRCULATE AND CONDITION hole. Spot 35 barrel LCM pill on bottom. Pull up to 6,124'. 19:00 +20.00 r 1 00 20.00 - DRILL I E 7 .- - TP01 CIRCULATE AND CONDITION hole 900 GPM; 2250 PSI. (20,00 :20:30 _ r 0.50 20.50 JE 4 P TRIP IN HOLE to 6,420'. Wash down to 6,486'. Plugged jet. 1 0.30 0000 3.50 24.00 DRILL E 3 P ;DRILLING from 6,466' to 8,655'. Up Weight = 165K; Down Weight = 85K; Rot Weight = 120K. WOB 10K -20K; RPM I 1140; TQ 11K; GPM 902; PSI 2,480; ECD 9.69 PPG. Jar Hours = 66.4; ADT = 6.33. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter Alvin.CrisweII1 enipetroleum,com µ 907- 980 -7545 Eni representative Bemie Leas ENI Rig Clerk AKRigClerks245eaertpetroleum .com 907-670 -8607 907 -575 -9427 Eni representative Pete Adams ENI I Dnlling HSE Pete.Adamsaenipetrdeum.com 907 - 670 -8624 907 -440 -0806 Eni representalve Gary Goerlich Dolling Supervisor 907-670-8623 I ENI Eni representative Jack Keener !ENI 1Dnllmg Supervisor jack.keeneraenipetroleum.com 907 - 670 -8623 907 - 715 -6434 Last Casing seat Cas. Type ! OD (in) _ ID (in) I _ Grade Top (ftKB) Bottom (ftKB) Run Date CASING 133/8 11 12415!L -80 _ - - -- -- - 0.0 - -- -- - 2,42091/2010_ Last Leakoff Test , Depth (MB) TVD (RKB) !Fluid Type iluid Density (lb /gal) TP (Surf) (psi) !Eq. Mud Weight (lb/gal) !Leak Off Pressure (psi) 2,4210 2,07991LSND i 880 ' 3200 I - 11.76 1,270.8 11� — _— — i Irl* Eni E &P Division Well Name: OPO4 -07 � ENI Petroleum Daily Report Well Code: 23893 Field Name: Nikaitchuq p « Co. Inc. Date: 5/28/2010 - Report #: 16 API /UWI: 50-029 - 23409 -00-00 1) pa 1 of 1 Wellbore name: OPO4 -07 ' I PertniUConcession N° (Operator 1 Well Header ' ENI Share ( %) 'Well Configuration type I 208 EN I PETROLEUM _ 100.00 'DIRECTIONAL Rotary Table Elevation (ft) 53. Ground Level (ft) 20 !Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) I - - - - - -- - . - - -- - - 0.00 - Rig Information Contractor 'Rig Name Rig Type 1NABORS ALASKA I NABORS 245 LAND RIG Job Information :Wellbore 'Job Phase Spud Date .Target Depth (ftKB) Target Depth (TV... "[Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) '0PO4 -07 'DRILLING 5/19/2010 i 12,031.0 3,940.3 1 12,382.0 220.07 56.3 10.81 'Daily Information Depth End (ftKB) Depth End ITVD) (... {Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) IPOB Temperature (°F) Weather Wind 7,734 0 3,645 5 1,079.00 21.50 50.2 91,0 26.8 Partly Cloudy. Patchy 32 NNE @ 5 mph j Fog WC 20.7 Daily summary operation 24h Summary Drilled from 6,655' to 7.734'. Encountered lost circulation at a rate of 25 bbls per hour. Circulated and conditioned hole, Pumped LCM pill with good results to reduce seepage. Operation at 07.00 Operation at 0400 Hours. Drilling ahead at 7,760' MD. From 0000 -0130 hours, circulated and conditioned hole -. 24h Forecast Drill ahead in 12 -1/4" hole tow ards 9 -5/8" casirg point. Lithology 'Shows MAASP Pressure (psi) !Mud Weight (lb /gal) I i 9.20 Time Lo Cum Start End Dur Dur Time Time (hrs) (hrs) . Phase Opr. Act. Plan Oper. Descr. 00.00 '07:00 7 00 7.001DRILL ;E 3 P DRILLING from 6,655' MD to 7,149' MD 3,481' TVD Up Weight = 170K; Down Weight = 85K; Rot Weight = 120K. WOB 20K; GPM 900; PSI 2,520 - 2,540, RPM 140; TQ On 12K -13K; TO Off 11K-12K; ADT = 5.16; Jar Hours = -71 56. Well started to take fluid 15 bbts at start with static losses of 25 bph. 1 I — 107'00 '09.00 2 00 9.00 DRILL E 7 ,TP01 ( CIRCULATE AND CONDITION hole due to lost circulation. Circulate bottoms up two times. GPM 900; PSI 2,500 String in Mix II. Reciprocate and rotate on the way up. Back pumps down to 600 GPM on the way down. I 09'00 1700 3.00 12 00 DRILL � t3 IP 1DRILLING from 7,149' l0 7,264' MD 3,519' TVD. Up Weight = 180K; Down Weight = 80K; Rot Weight = 125K WOB 20K, GPM 900, PSI 2,550, TQ 13K -14K, ECD 9.65; ADT = 1.73; Jar Hours = 73.60. Total loses for 12 hour tour = 144 ' ' bbls 12.00 1230 0.50 - -_ - -_ - - -- -- — -- — - I ' I 12 50'DRILL E 25 P Service fig and top drive. 112.30 00.00 r 11 50 24.00,DRILL 'E 3 IP 'DRILLING from 7,264' to 7,734' MD 3,650' TVD. Up Weight =192K, Down Weight = 78K, Rot Weight =128K. WOB 1 '20K, GPM 902. RPM 100 -140, TQ On 13K -16K TQ Off 13K; PSI 2,450; ECD 9,65 Add fluid to pits at 20 bbls per 1 hour MW In 91 ppg, MW Out 9 2 ppg Fluid losses this tour = 91 bbls. i- _ Daily Contacts — Position Contact Name Company _ Title _ E-mail Office Mobile Eni representative Alvin Criswell - ENI ,Expediter Alvin.Coswell@enipetroleum.com 907 -980 -7545 Eni representative Bemie Leas I ENI (Rig Clerk AKRigClerks245e @ertpetroleum.COm 907-670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Dulling HSE j Pete Adams @enipetroleum.com 907 - 670 -8624 907 - 440-0806 Eni representatve Gary Goerlch ENI Drilling Supervisor 907 - 670 -8623 907 - 441-6585 Eni representative I Jack Keener ENI Drilling Supervisor jack keenernenipetroleum.com 907-670-8623 907-715-6434 Last Casing seat C as. Type OD (In) ID (In) Grade Top (RKB) Bottom (ftKB) Run Date CASING I WW 133/8 12,415,L -80 0.0 2,420.95/212010 Last Leakoff Test D epth (ftKB) 1TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 2,421.0 I 2,079.91 LSND 1 8.80 320.0 11.76 1,270.8 i li l — — - - - i 1 Viiiiiti Eni E &P Division Well Name: 0PO4 -07 ENI Petroleum Daily Report Well Code: 23893 CO. Inc. Field Name: Nikaitchuq eni — Date: 5/30/2010 - Report #: 17 APIIUWI: 50-029- 23409 -00-00 Wellbore name: OPO4 - 07 page 1 of 1 I Well Header Permit/Concession N° ;Operator 'ENI Share ( %) Well Configuration type 2081990 IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) 'Water Depth (ft) :RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 , 0.00 Rig Information Contractor -- - - - - -- - -- - -- - - - - - -- Rig Name Rig Type [ NABORS ALASKA NABORS 245 E LAND RIG Job Information jWellbore ;Job Phase 'Spud Date Target Depth (RKB) (Target Depth (TV... (Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) I OPO4 -07 :DRILLING 1 5/19/2010 12,031.0 I 3,940.3 1 12,382.00 220.0 56.3 11.81 ■Daily Information :D epth End (RKB) 1 Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather Wind 8,510.0 3,804.4 776.00 22.50 34.5 91 0 28.6 Partly Cloudy. Patchy 350N fffl 6 mph I Fog WC 22.1 (Daily summary operation .24h Summary -- - - - - -- - -- -- -- - --- -- - - - - -- - -- -... -- - -- - _. ._ I DnIled 12 -1/4" hole from 7,734' MD to 8,510' MD (3,828' TVD). At 7,734' circulated and conditioned hole with a 10.5 ppg weighted and Lube 776 pill. Total fluid losses for 24 hour penod was 259 barrels Operation at 07.00 ' Operation at 0400 Hours: Dnlling ahead at 8,700' MD 24h Forecast l Drill ahead in 12 -1/4" hole to 9 -5/8" casing point. MAASP Pressure (psi) I Mud Weight (lb/gal) Lithology ?Shows , 1 9.30 Time Lo Cum Start End Dur Dur Time Time (hrs) Ihrs) Phase Opr Act. Plan Oper. Descr. 00.00 01:30 1.50 1 50 DRILL E 7 P CIRCULATE AND CONDITION hole. Circulate a 10.5 ppg high viscosity and Lube 776 pill. GPM 900; PSI 2,450; RPM I 145; TQ 11K. Rotate and redprocate drill string. 1 b1.30 112:00 10.50 12.00 DRILL E 3 P DRILLING from 7,734' to 8,092' MD, (3,736' TVD). Up Weight = 185K; Down Weight = 75K; Rot Weight = 125K. WOB 15K; GPM 900; PSI 2,560; RPM 140; TQ On 15K -16K; TO Off 13K; ECD 9.75; ADT = 7.75; Jar Hours = 91.5. Total fluid for tour = 137 barrels. 1- 00:00 T 12.00 24.00 DRILL E 3 P !DRILLING from 8,092 MD (3,736' TVD) to 8,510' MD (3,828' TVD). Up Weight 175K, Down Weight 90K; Rol Weight 125K. WOB 10K -20K; GPM 902; PSI 2,600; RPM 80 -140; TQ On 12K -15K; TQ Off 10K. At 8,360' MD (3,810' TVD) ECD = 9.89; Jar Hours = 100,6, ADT = 9.13. Total fluid loss for tour = 122 barrels. -- --- - -- -- --- --- -- --1-- -- Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter Alvin.Criswell@enipetroleum.00m 907- 980 -7545 Eni representative 1Bemie ENI ,Rig Clerk AKRigClerks245e (gerrpetroleum.com 907-670 -8607 907 - 575 -9427 1 Eni representative Pete Adams ,ENI ,DrillingHSE Pete.Adams1enipetroleum.com 907 - 670 -8624 907-440 -0806 Eni representalve (Gary Goerlich (ENI !Drilling Supervisor 907 - 670 -8623 907-441-6585 Eni representative (Jack Keener (ENI (Dnlling Supervisor Ijack.keenerIenipetroleum.com 907- 670 -8623 907- 715 -6434 Last Casing seat Cas. Type OD (In) ID (In) Grade Top (RKB) 1 Bottom (RKB) Run Date — CASING 13 3/8 12.4151L -80 - 0.0' 2,420.9 5/21/2010 : Last Leakoff Test - - – — -- ;Depth (R T TVKB) D (RKB) KB) T Fluid Type [Fluid Density (lb/gal) IP (Surf) (psi) Eq. Mud Weigh (lb/gal) Leak OR Pressure (psi) 2,4210 2,079.91 1 LSND 8.80 I - - -__ 3200 11.76 1,270.8 i I I I • • Eni E &P Division 'Well Name: OPO4-07 irl* /� co.lnc. Dail Re port ' Y � I W ell Code: 23893 - -- -- - -- - - - - -- - * Field Name: Nikaitchuq 1 ENI Petroleum 1 Date: 5/31/2010 -Report #: 18 LAPI/UWI: 50-029-23409-00 -00 t i( (t tl page 1 of 1 Wellbore name: OPO4 -07 ' Well Header ; --- - - - - -- - PermlUConcession N° ,Operator 7ENI Share (%) WellConflgurationtype 2081990 _ ENI PETROLEUM I 100.00 'DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) 1 RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12 20 000 12/Information 1Contractor Rag Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore lob Phase Spud Date Target Depth (ftKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4 -07 [DRILLING 5/19/20 12,031.0 3,940.3 12,38200 220.07 56.3 1281 Daily_ Information Depth End (RKB) (Depth End (TVD) (... Depth Progress (ft) 'Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature ( °F) Weather Wind 8,750.0 3,836.9 240.00 J 4 50 53.3 91.0 34.2 Cloudy. Light rain. 347 NNW @ 7 mph WC 28.2 Daily summary operation 24h Summary Dnlled 12 -1/4 hole to total depth of 8,750' MD and 3,834' TVD. Circulated hole. Back reamed 01.8 of hole from 8,750' to 133 /8" casing shoe at 2,420'. Tnpped in hole from 2,420' to 4,507'. Operation at 07.00 Operation at 0400 Hours Tnpping in hole at 8,600'. 24h Forecast 'Tnp in hole to 8,750' Circulate and condition hole Pull out of hole on elevators Lay down BHA Rig up and run 9-5/8" casing. Cement casing. rlithology - -_ - -- — _ - - - -- - - - -- _ -- ' Shows - -- JMAASP Pressure (psi) Mud Weight (lb/gal) i 9.30 :Time Lo r Cum Start End Dur Dur Time Time (hrs) (hre) Phase Opr. Act. Plan Oper, DesCr. 00:00 04'30 4 50 I 4.50 DRILL E 3 iP DRILLING TO TOTAL DEPTH OF 12 -1/4" hole from 8,510' to 8,750' MD (3,839' TVD). Up Weight = 180K; Down Weight = 80K; Rot Weight= 125K. WOB 20K; GPM 900, PSI 2,650: RPM 140; TQ On 14K -15K; TQ Off 11K -12K ECD = 0.50 5.00 E - 7 i 9.98 ppg; ADT = 3,67; Jar Hours = 104.30. 0430 10500 T I - { -- - - ---- 1 - - t-- - --- - - -- - -- - -- - 1 P CIRCULATE AND CONDITION HOLE. HO HOLE. E. Circulate high viscosity sweep GPM 900; PSI 2650. Rotate and reciprocate drill [string. ,05'00 106.30 1 1 50' 6.50 :E 7 tTRO3 'DOWNTIME ON ENGINES Auto fill for motors day tanks breaker tripped. Low level alarm was on the same breaker and caused motors to stop 0:30 107 0 i 1 0E !DRILL E 7,7 P 'CIRCULATE AND CONDITION Continued pumping high viscosity sweep. GPM 900; PSI 2,650 Monitor well for 10 - -- 7 ;minutes Well static. 107 30 109.00 F T 1 50f 9.00 DRILL rE 4 'P ,TRIP OUT OF HOLE. Trip out of hole from 8,750' to 7,500'. No problems. Up Weight = 185K. -- -- - - -- - -- :09.00 1700 1 3.00 12.00 DRILL 1E 1 4 P SACK REAM OUT OF HOLE. Back ream from 7,500` to 5,880'. GPM 650; PSI 2,040; RPM 100: TQ 9K -10K. Up Weight = 120K. No problems while back reaming. Total fluid losses for tour = 80 barrels. 12:00 21:00 1 9.00j 21 00IDRILL 'E .4 P BACK REAM OUT OF HOLE. Back ream from 5,880' to 13 -3/8" casing shoe at 2,420'. GPM 850, PSI 1,500; RPM 120; TQ 4K-6K Fluid loss of 6 barrels on back ream 2 1 -- 21'00 21:30 0.50' 21.50,DRILL 1 17 - IP 1CIRCULATE AND CONDITION HOLE. Circulate bottoms up at the 13 -318" casing shoe with 3,000 strokes. GPM 850; 1 'PSI 1,500; RPM 60; TQ 4K; Rot Weight = 100K 21:30 T22:00 _ _ 0.50 _ 22.00 DRILL 1 E 25 IP 1 SERVICE RIG. Service top drive and service crown. 122.00 - 1 ,00 : 00 2.00 � - 24.00 DRILL E 4 ,IP TRIP IN HOLE. Trip in hole from 2,420' to 4,507' Down Weight = 70K. Fill pipe. Daily Contacts - — -- Position Contact Name Company Title E-mail Office Mobile _ Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representatve Gary Goerlich ENI LDnliing Supervisor 907 - 670 -8623 907 - 441 -6585 Eni representative Bernie Leas ENI Rig Clerk AKRigClerks245e @eripetroleum.com 907-670 -8607 907- 575 -9427 Eni representative Pete Adams 'ENI DnlhngHSE IPete.Adams @enipetroleum.com 907 -670 -8624 907 -440-0806 Eni representative Alvin Cnswell ENI Expediter 'Alvin.Criswell @enipetroleum.com 907 - 980 -7545 Last Casing sea t Cas. Type r OD (In) ID (In) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 13 3/8 12 415 L -80 0.0 2.420.915212010 Last LeakoffTest Depth (ftKB) ;TVD (ftKB) Fluid Type 1Fluid Density fib/gal) P (Surf) (psi) IEq. Mud Weight (]b /gal) 'Leak Off Pressure (psi) 2,4210 2,079.91 LSND I 8.80 320.0 r 11.76 1 1,270.8 d � - -- 11011k/ W Eni E &P Division ,_ ell Name: 0PO4 -07 ENI Petroleum Daily Report Well Code: 23893 Field Name: Nikaitchuq Co. Inc. Date: 6/1/2010 - Report 9: 19 API /UWI: 50 -029- 23409 -00-00 page 1 of 1 Wellbore name: OPO4 -07 Well Header PermiVConcession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL I Rotary Table Elevation (ft) 'Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 0.00 ---- -- ------ -- -- - -- ' Rig Information - - -- -- -- - -- - - -- - - -- Contractor IRig Name Rig Type ;NABORS ALASKA NABORS 245 E LAND RIG Job Information j Wellbore Job Phase Spud Date ( Target Depth (ftKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ff/hr) DFS (days) 9PO4 -07 DRILLING 5/19/2010 i 12,0310 3,940.3 12,382.00 220.07 56.3 13.81 Daily Information Depth End (ftKB) Depth End (TVD) (... Depth Progress (ft) 'Drilling Hours (hrs) Average ROP (ft/hr) IPOB ITemperature ( °F) Weather Wind 8,750.0 3,836.9 0.00 94.0 j 37 8 Cloudy. Fog. WC 343 NNW @ 8 mph l '- - - - - -- -- ' - - - -- - - -- - - - - - -- - - -- -i.- - -- i - -- -- 31.8 -- - -� - --- -- 1 Daily summary opera tion -; 24h Summary Run in hole to bottom on wiper tnp Circulated bottoms up 4 times Monitored well for 10 minutes Well static. Tripped out of hole on elevators with no problems Layed down BHA. Made a dummy run and spaced out landing jonnt_Cbang •- ••. • • :" • -_ u. • -.. • P I_I • - n. 3 500 P I high_ .Operation at 07.00 Operation at 0400 Hours. Running 9-5/8" casing, l NOTE. IN THE 12 -1/4" INTERMEDIATE HOLE SECTION, TOTAL FORMATION LOSSES WERE 486 BARRELS 124h Forecast [ Run 9 -5/8" 47# L80 R-3 BTC Mod casing. Cement casing. Nipple up and test ROPE. 3 Lithology Shows MAASP Pressure (psi) Mud Weight fib /gal) 9.20 I- Time Log Cum Start End Dur Dur Time Time (hrs) Mrs) Phase Opr. Act Plan Oper. Descr. 00:00 03:00 3 00 3.00 DRILL E 4 P TRIP IN HOLE from 4,507' to 8,750'. Fill hole every 15 stands. No fill on bottom. 03:00 06:30 3.50 6.50 DRILL E 7 P CIRCULATE AND CONDITION. Circulate bottoms up 4 times. Up Weight = 130K; Rot Weight = 125K. 900 GPM; PSI 2,520, RPM 120; TO 9K -10K Monitor well for 10 minutes. Well static. 06:30 12:00 5.50 12.00 DRILL E 4 P TRIP OUT OF HOLE from 8,750' to 488', No problems on trip out. Pumped dry job at 7,762'. Stand back HWDP Total fluid losses for tour = 47 barrels. 1200 12:30 _ 0.50 12 50 DRILL ;E 4 P Continue stand back 5" HWDP 12.30 ;13:00 0.50 13.00 DRILL E 4 P PRE JOB SAFETY MEETING with Schlumberger on laying down BHA and pulling radioactive source. 13:00 x17.00 r 4 00 17 00 DRILL E �4 P LAY DOWN BHA to pipe shed. Lay down jars, float sub, 3 NM collars, stabilizer, bit, MWD tools and rotary steerable tool. ,17:00 118.00 1 00 18.00 DRILL E 4 i p :CLEAR AND CLEAN off rig floor of handling tools. ;18:00 '19:00 1.00 19.00 DRILL E 5 P :REMOVE wear bushing. 119:00 20'00 I 1.001 20.00 DRILL E 12 'P PICK UP landing joinrt. Run in hole for dummy run. Space out landing joint. 3 :- - - -- LL - -- - - 22.50 DRILL E _ 5 ! P _ _ _ CHANGE RAMS. Swap upper variables to 9 -5/8 ". Function test rams. 20:00 22'30 2.50. _ 122.30 00:00 1 501 24.00. DRILL E 12 tI RUN IN HOLE with test plug and test joint. Test 9-5/8" rams to 250 PSI low and 3,500 PSI high. Drain stack. 1 I NOTE: IN THE 12 -1/4" INTERMEDIATE HOLE SECTION, TOTAL FORMATION LOSSES WERE 486 BARRELS. L Daily Contacts Eni representa ne 4 J a ck Keener :ENI Name Company _ -,___ i _.._.. Tom I __._._ -. E-mail Office I Mobile ',ENI 1DrillingSupervisor Ilack.keener@enipetroleum.com 907 -670 -8623 '907- 715 -6434 Eni representalve :Gary Goerlich ENI Dolling Supervisor 907- 670-8623 907 - 441 -6585 'Eni representative Bernie Leas ENI ;Rig Clerk AKRigClerks245e @enpetroleum.com 907-670 -8607 907-575-9427 - -- - - - - Eni representative Pete Adams ENI Dulling HSE 'Pete Adams@enipetroleum corn 907 -670 -8624 1907440 -0806 Eni representative 'Alvin n ' Cnswell ENI ;Expediter 'Alvin Criswell @ernpetroleum wm i 907- 980 80 -7545 Last Casing seat --- Cas. Type i OD T r Grade - - -.. -- ___ 9 ' ID (inl Gde lop (ftKB) Bottom (ftKB) Run Date (CASING 9 518 B 6811L80 1 -0.91 8,727,0 6/1/2010 Last Leakoff Test Depth (ftKB) I ITVD (ftKB) (Fluid Type Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (lb /gal) Leak Off Pressure (psi) 2,421.0 2,079.91 ILSND 880 320.0 11.76 1,270.8 i i I fi _ . • .. .... 410- - • 4* Eni E &P Division Well Name: OPO4 -07 Daily Report EN/ Petroleum ' Well Code: 23893 Field Name: Nikaitchuq • Co. Inc Date: 6 /2/2010 - Report 13: 20 APUUWI: 50 -029- 23409 -00 -00 n 0 p age l of t Wellbore name: OPO4 -07 Well Header Permit/Concession N° ' I ENI Share ( %) I Well Configuration type 2081990 JENI PETROLEUM L 100.00 !DIRECTIONAL Rotary Table Elevation (ft) (Ground Level (ft) Water Depth (ft) I RKB - Base Flange (R) TRKB - Tubing Spool (ft) 53.20 I 12.20 0.00 L - 1 Rig Information Contractor --- - - - - -- 1Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) ! OPO4 -07 DRILLING 5/19/2010 12,031.0 3,940.3 12,382.00 220.07 56.3 14.81 Daily Information Depth End (ftKB) Depth End (TVD) (.. Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather Wind 8,750.0 3,8369 0.00 930 32.2 Cloudy. Fog. WC 23 NNE CO 16.5 mph L 21.4 Daily summa _ rUh Summary ;Ran 9-5/8" casino to 8.726'. Circulated and conditioned well. Rigged up to cement 9-5/8" casing. Operation at 07.00 -- - - - - - -- -- From 0000 -0400: Layed down casing tools. Rigged ip SLB for cement job. ;Operation at 0400 Hours. Cementing 9 -5/8' casing. - 24h Forecast Rig up and cement casing. Nipple up and test BOPE Pick up BHA #6. Lithology Shows MAASP Pressure (psi) Mud Weight (lb /gal) -- -__ 9.40 1 Time Log Cum Start End Dur Dur Thne Time (hrs) (mss) Phase Act. Plan Oper. Descr. -- 2 - RI L... rams 00:00 ',02.30 2.50 2 50 DRILL G ' 12 P Test 9-5/8" rams to 3,500 PSI. Lay down test joint. PJ SM with GBR on running casing Pick up and rig up casing tools. 02.30 ,09:30 700 9.50 DRILL G 4 10- ' Make up 9-5/8" L80 47# BTC. casing. Check floats at 2,400'. Circulate bottoms up at the 13 -3/8" casing shoe. GPM 300; �09 30 1300 3.50 13.00 , _ ' 180 PSI Clear ice from derrick. - -Y DRILL - - -- - -- 4 'P ' u - -- - - -- to G � Run 9-5/8" L80 47# BTCM casing from 2,405' to 4,400'. Up Weight 185K; Down Weight 105K. Take drag readings every I :10 joints. Zero mud losses. 3 '� 13.00 �� 13330 0.501 13 50 DRILL iG '7 �P ,Circulate and condition Reciprocate casing string. GPM 300; 200 PSI. Up Weight = 185K; Down Weight = 105K. ,Circulate 2,400 strokes. 1 ; , , H3:30 116:30 3 1- -- ,DRILL 1G t4 1 P Run casing from 4,400' to 6,460' -- - - - - - -- - -- - -- - -- -- - -- - - - -- - ---- - -- 16:30 � 1730 00' 17.50 1 1. Up Weight = 240K; Down WEsight = 105K. 1 DRILL G 7 P ; Circulate bottoms up. 3,500 strokes; GPM 300; PSI 500. 16.30 300' 20 50 r DRILL iG '7 P Run casing from 6,460' to 8,000'. Up Weight = 310K; Down Weight = 100K. 20:30 21'30 2030 * - -- -- - - - - -- - - - -- -- - -- - -- -- -- -- 1,001 21 50 DRILL 0 7 P 'Circulate bottoms up. GPM 300; PSI 500; 4,500 strokes. _ 21'30 23.00 1 1.501 23 00 1 DRILL G } 4 P 11 casing from 8,000' to 8,726' total depth. Ran a total of 210 joints of 9 -5/8" casing. Pick up hanger. Pick up landing 2300 100:00 1.00, 24.00 DRILL G 7 ijoint Up Weight = 330K, Down Weight= 100K i P Circulate and condition. Circulate bottoms up at 5,000 strokes. GPM 300; PSI 500 With pump: Up Weight - 290K; I 1 1 Down Weight = 110K Daily Contacts Posidon Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum coin 907 -670- 8623 907- 715 -6434 Eni representatve Gary Goerlich ENI Dnlling Supervisor 907-670-8623 907 - 441-6585 Eni representative Bernie Leas ENI Rig Clerk AKRigClerks245e @eripetroleum.cem 907-670- 8607 907-575-9427 Eni representative 1PeteAdams ENI Drilling HSE Pete.Adams @enipetroleum.cem 907-670-8624 907 -440 -0806 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum com 907-670 -8623 907 - 947 -4323 Eni representative Greg Parker ENI Expediter Greg.Parker @enpetroleum.com 907 - 980 -7545 _ Last Casing seat Cas. Type OD (In) _ _ ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 9 5/8 - 8.681 L80 -0.9 8,727.0 6/1/2010 Last Leakoff Test Depth (RKB) !TVD (ftKB) Fluid Type Fluid Density fib/gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 2,421.0 i 2,079.91 LSND 8.80 320.0 11.76 1,270.8 I ' II , ' � I L -- 1 I! iirilibil.- Eni E &P Division Well Name: OPO4 -07 ENI Petroleum 1 Daily Report Well Code: 23893 i Field Name: Nikaitchuq ! Co. Inc. I Date: 613/2010 - Report #: 21 API/UWI: 50- 029 -23409 -00-00 en !I(1 page 1 of 1 Wellbore name: OPO4 -07 1 Well Header 1 Permlt/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 _ ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) I Water Depth (ft) RKB • Base Range (ft) RKB - Tubing Spool (ft) L 5320- __- _--- - -__ -_ - 12.20 I 0.00 Rig Information !Contractor i Rig Name Rig Type NABORS ALASKA j NABORS 245E LAND RIG Job Information 'Wellbore '!Job Phase TSpud Date Target Depth (RKB) ]Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 10PO4 -07 'DRILLING 5/19/2010 12,0310 i 3,9403 J 12,38200 220.07 56.3 15.81 Dail Information Depth End (RKB) ii Depth End (TVD) 3,836.9 d (T TVD) (... j Depth Progress (ft) Drilling Hours (hrs) !,Average ROP (ft/hr) TPOB ]Temperature (°F) Weather 1 Wind 0 00 87.0 i 30.9 Partly Cloudy. WC 24° NNE (fp 34.4 j 15.4 ]mph Y summary 'Dail summa operation 1 124h Summary Cemented 9 -5/8" casing @ 8726' MD/ 3835' TVD Pumped 5 bbls water, tested lines to 4500 psi - Good Test, 70 bbls 12.5 PPO Mud Push II, 139 bbls 12.5p00 DeepCrete. Displaced with 624 bbls 8 8 ppg OBM. Pumped plug Checked floats - Holding. RD Schlumberger and GBR Install packoff and test to 5000 psi for 10 min - Good Test. Drained stack and CO rams. RU Little Red Services and I Freeze protect well with 146 bbls. Tested BOPE 250/3500 psi - Good Test RIH with 5" HWDP and 5" DP Operation at 07.00 Currently RIH with 5" DP 24h Forecast Continue to LD 5" DP due to excessive wear while dnlling 12 -1/4" Intermediate hole section. PU BHA 86. RIH, Test casing, dril out shoe track and 50' new hole and LOT. Lithology Shows MAASP Pressure (psi) Mud Weight (lb/gal) ] 9.30 • Time Log Cum Start End Dur Dur Time Time (hrs) () Phase Opr. Act. Plan Oper. Descr. 00.00 00:30 0.50 0.50 DRILL G 7 P CIRCULATE - Continue to circulate and condition mud while reciprocating. Prepare rig floor for cementing. ] -295 gpm, 500 psi [1:10:30 0. 1 50 _ AO DRILL H t 5 P RU CMT EQUIPMENT - LD Frank's fill up tool and install Schlumberger cement head. 01:00 04 00 3 OO 4 00 DRILL H P ;CIRCULATE - Continue to circulate and condition mud while reciprocating. Continue to prepare pits and lines for cement ;lob. �, �'1 -295 gpm, 500 psi 1 04:00 0 .00 4 00 8.00 DRILL H 7 ' . PP CMT CSC; - RU cement lines and pump 5 bbls water. Test lines to 4500 psi - Good Test. Pumped the following: 'l1 - 70 bbls 12 5 Mud Push II - 139 bbls 12.5 DeepCrete w/ 1.0 ppb cello flake (511 sks, 1.53 ft3 /sk) - Dropped wiper plug followed by 5 bbls water to flush cement lines. - Displaced with 624 bbls 8.9 ppg OBM. Plug landed (fp 6249 stks I . ] - Pressure up to 1050 psi - Check floats, Holding. . ! - Cement in place CO 07:30 hrs. ] l Reciprocated pipe untill 700 stks from plug bumping ; DRILL 1 108:00 1000 200 10,00 - - -- - -- y H 5 �P 'RD CMT/ CSG EQUIPMENT - RD Schlumberger cement head and GBR 9-5/8" casing running equipment. Suck out stack land flush with water LD VetcoGray landing joint. 111 .00 10,00 } - -- 1 1 1.004 11 00 DRILL 1C �5 P i INSTALL PACKOFF - Install VetcoGray 9 -5I8' pack off and test to 5000 0 psi si for 10 min -Good Test. 111 00 1 _ I 00 - 00 T - -- CO RAMS - CO upper rams from 9 -5/8" to 4 -1/2 x 7' VAR -- _ _ -- - - - -- + -- -- - - ' - - e - f - -- - -- 15.30 1600 0 50' 16 00 DRILL C 9 P _ ]FREEZE PROTECT RU Little Red Services and freeze protect 9-5/B "Annulus with 148 blots. - ;16.00 421.30 5 5 21 50DRILL C 112 _ P .TEST BOPE - Test BOPs 250/3500 psi - Good Test. DRILL ;- E 4 2130 '22 :30 1 00� 22.50; - - --- -- -- - " HWDP and DP due to excessive wear while drilling 12-1/4" Intermediate hole section. RIH with 5" HWDP F and 1 Stand 5" DP - -- ! P 1: LD DP - LD 5 22'30 23'00 _ 0.50 23.00 DRILL E :1 ;U :TROUBLE -Down time, working on drawworks. 1 2300 , 00:00 1.001 24.00 DRILL E 4 I P ILD DP - Continue RIH with 5" DP Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative f Jack Keener ENI Dulling Supervisor jack.keener@enipetroleum corn - 907 - 670 -8623 907- 715 -6434 Eni representatve Gary Goerlich ;ENI Dnlling Supervisor 907 - 670 -8623 907-441-6585 Eni representative Bernie Leas !ENI Rig Clerk IAKRigClerks245e @errpetroleum.com 907-670 -8607 907- 575 -9427 Eni representative 1 Pete Adams 'ENI Drilling HSE ;Pete Adamsgenipetrcleum com 907 - 670 -8624 907- 440 -0806 Eni representative Joe Longo ENI Drilling Engineer joe.longo (genipetroleum.com 907-670 -8623 907- 947 -4323 Eni representative (Greg Parker ENI Expediter IGreg.Parkernenpetroleum.com 907 -980 -7545 Last C asing seat Cas. Type OD (in) I ID (in) Grade Top (ftKB) Bottom MKS) Run Date CASING 9 5l 8� 8681 L80 -0.9 8,727.0 6/1/2010 I Lastleakoff Test ( - - -- ---- - - - - - -- -- Pressure (Depth (RKB) TVD (RKB) (Fluid Type Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pres (psq 2,421.0 2,079.91 LSND 8.80 320.0 i 11.76 1,270.8 • ______.________ 41 * ■ Eni E&P Division 1 WO Name: OPO4-07 ENI Petroleum : Daily Report I Well Code: 23893 _ I : Field Name: Nikartchuq CO. Inc. , Date: 6/4/2010 - Report #: 22 API/UWI: 50-029-23409-00-00 n • , . . , . page 1 of 1 Welibore name: OPO4-07 1 Well Header Permit/Concession N° Operator ENI Share (%) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) IWater Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 I 0.00 LRig Information IContractor Rig Name Rig Type 'NABORS ALASKA NABORS 245 E LAN!) RIG Job Information Welibore Job Phase Spud Date 'Target Depth (ftKB) Target Depth (IV_ [Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4-07 DRILLING 5/19/2010 12,031.0 3,940.3 I 12,382.00 220.07 56.3 16.81 Daily Information Depth End (ftKB) I Depth End (TVD) I... Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (F) Weather Wind 8,750.0 3,836.9 0.00 90.0 30.0 Overcast, Fog, WC 30° NNE I 21.3 1 16° mph Daily summary operation 24h Summary Lay dn wom DP Operation at 07.00 Laying down 5" DP ,24h Forecast Continue to LD 5" DP due to excessive wear while drilling 12-1/4" Intermediate hole section PU BHA //6. RIH, Test casing, dril out shoe track and 50' new hole and LOT. Lithology IShows MAASP Pressure (psi) Mud Weight (lb/gal) I i 9.10 Time Log Cum I I I Start End Dur Dur I Time Time (hrs) (ftra) Phase Opr. j Act. : Plan Oper. Descr. 00.00 0200 2 001 2 00 4 DRILL E 14 , U ,Cont RIH 1136 - 3814 ft I , :02.00 ,0300 100 3 00:DRILL .E 1 25 ,P PJSM, Slip / cut drIg line 84 ft 0300 :03'30 0.50 3 50:DRILL IE 25 P , PJSM. Service ng —I '0330 12.30 900 12 50IDRILL :E i 'U :PJSM, P01-1 laying down drill pipe in singles. Hard bands wom down beyond service limit specs. Cont lay dn to HWDP. .1 1230 1390 0 50 1300 DRILL 1 :25 P : Service ng, demck inspection, remove ice from beams 1300 I 1500 2 00 1500 DRILL :E VI U 1 PJSM. RIH DP from mast for lay down to 4950 ft. 1500 0090 9.00 24 00:DRILL : 6 ,4 U IPJSM, POH laying down drill pipe in singles. Hard bands wom down beyond service limit specs. Cant lay dn to 670 ft. Daily Contacts r Position I Contact Name Company I Title E-mail Office T Mobile lEni representative ,Jack Keener - f ENI Dnlling Supervisor jack keenentpenipetroleum.com 907-670-8623 ;907-715-6434 I Eni representative 1Dave Morns ENI ,Drilling Supervisor 907-670-8623 I ENI I Eni representative : Tom Norvig IRig Clerk AKRigClarks245e@enipetroleum.com 907-670-8607 907-229-6100 , Eni representative Pete Adams ENI Dnlling HSE Pete.Adams@enipetroleum.com 907-670-8624 907-440-0806 Eni representative Joe Longo ENI Drilling Engineer joe.longo@nnipetroleum.com 907-670-8623 907-947-4323 Eni representative Greg Parker ENI Expediter Greg.Parker@enpetroleum.com 907-980-7545 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 95/8 8.681 L80 -0,9 8,727.0 6/1/2010 Last Leakoff Test Depth (ftKB) TVD (ftKB) Fluid Type Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (ib/gal) Leak Of Pressure (psi) 2,421.0 2,079.91 LSND 8.80 320.0 11.76 1,270.8 I- 1 : , I . _ I r • Eni E &P Division Well Name: 0PO4 -07 ENI Petroleum Daily Report Well Code: 23893 . Field Name: Nikaitchuq Co. Inc. Date: 6/5/2010 - Report # 23 API /UWI: 50-029 - 23409 -00-00 ( :- if page 1 of 1 Wellbore name: OPO4 -07 Well Header Permit/Concession N° 1 Operator ENI Share (h) Well Configuration type 2081990 [ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) `Ground Level (ft) 1Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 1 0.00 Rig Information . Contractor : Rig Name ;Rig Type NABORS ALASKA L NABORS 245E ;LAND RIG _ _ Job Inform ation 1Wellbore 1Job Phase 'Spud Date 'Target Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) ;Drilling Hours (hrs) Average ROP (ft/hr) 1DFS (days) � -07 ;DRILLING 5/19/2010 12,0 0 3,940 3 12,382 0 ; 220 07 56.3 i 17 81 Daifv Information _ _ Depth End (ftKB) Depth End (TVD) (...'Depth Progress (ft) 'Drilling Hours (hrs) ,Average ROP (ft/hr) -POB :Temperature (°F) Weather , Wind 8,750.0 3,836 9 0 00 87 0 32.7 Clear, W C 22 8° 48° N E @ 15 8 mph Daily summary operation 24h Summary Lay dn 5" DP, PU new DP, RIH same, circ / balance wellbore fluids. Operation at 07.00 Operation at 0400 Hours: Pulling out of hole, should be MU BHA #6 between 0400 -0500 hours. 24h Forecast Circ/ balance wellbore, POH standing back, MU BHA _ Lithology Shows MAASP Pressure (psi) Mud Weight pb /gap 6.60 Time Log Cum Start End Dur Dur Time Time (hrs) (s) Phase Opr. Act. Plan Oper. Descr. 00 02.30 • _ 2.50 2.50 DRILL E 4 U Cont lay dn 5" DP, lay dn HWDP. 1 02:30 '07:30 5.00 7.50 DRILL E 4 U MU mule shoe, follow with 105 jts new 5" DP to 3250 ft. 0730 08.00 0.501 8.00 DRILL E 7 U tCirc /cond fluids, confirm pipe clean /free. 08:00 09:30 0890 1.50 9.50 DRILL E 4 U POH, stand back in mast. 10 00 _ 0.50 1 11 10.00 DRILL E 25 P Service rig. 10'00 22.00 12.00 22 00 DRILL E 4 U RIH 258 jts 5" DP in singles to 8200 ft. — _ _� 22 :00 ',0000 2.001 24.00DRILL 1E 7 U I Wellbore out of balance. Heavy flow back. Circ / cond Fluids, balance mud wt. 1 Daily Contacts Position Contact Name Company r— Tide E-mail Office Mobile Em representative Jack Keener ENI ;D Supervisor jack.keeneraenipetroleum.com 907 -670 -8623 X907- 715 -6434 Eni representative 'Dave Morns ;ENI Drilling Supervisor 907- 670 -8623 :Eni representative Tom Norvig ; ENI Rig Clerk IAKRigClerks245e (c�eripetroleum.com 907 -670 -8607 907 - 229 -6100 1 Eni representative ! Pete Adams !ENI Drilling HSE I Pete @enipetroleum com 907 - 670 -8624 907 - 440 -0806 Eni representative !Joe Longo ! ENI ;Drilling Engineer ijoe longo @enipetroleum.com 907870 -8623 907- 947 -4323 Eni representative ;Greg Parker ENI _ ,Expediter 1Greg.Parker@enpetroleum.com 907- 980 -7545 Last Casing seat _ Cali. Type OD ID (in) Grade Top (RKB) Bottom (RKB) Run Date -- - -- CASING i 95/8 8.681 L80 -0.9 8,72706/1/2010 Last Leakoff Test Depth (RKB) ITVD (RKB) !Fluid Type 1 Fluld Density (lb/gal) IP (Surf) (psi) Eq. Mud Weight fib /gal) Leak Off Pressure (psi) 2,421.0 2,079.91 �,LSND 880 3200 11.76 1,270.8 i III it ; s D Viii‘S Eni E &P Division ;wen Name: 0PO4 -07 Daily Report — — ENI Petroleum i Well code: 2389a — Field Name: Nikaitchuq ref t • 1 ate: 6/6/2010 - Report #: 24 API /UWI: 50-029 - 23409 -00-00 ti Ii 11 CO. 0. Inc. page 1 of 1 I- Wellbore name: OPO4 -07 Well Header - _ - -- - -- Operator - -- --- iENI Share ( %) Well Configuration type 2081990 ENI --- E PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) round Level (ft) Water Depth (ft) I RKB - Base Flange (ft) RKB - Tubing Spool (ft) F 12.20 I 0.00 j Rig Information ' Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (fUhr) DFS (days) 0PO4 -07 ! DRILLING 5/19/20 12,031.0 3,940.3 12,382.00 220.07 I 56.3 1881 Daily Information Depth End (ftKB) Depth End (TVD) (... Depth Progress (ft) 'Drilling Hours (hrs) Average ROP (ft/hr) IPOB Temperature ( °F) Weather Wind 8,750 0 3,8369 0.00 1 1 88 0 I 32.9 Clear, WC 23° 38° NE @ 16 3 mph Daily__summary operation 24h Summary MU BHA #6, RIH same, drill shoe track perform LOT, Operation at 07.00 (Drill ahead 8 1/2 hole. Depth © 0400 8891' MD 'Drill Forecast - - -- -- - -- - Drill ahead 8 1/2 hole towards TD Lithology Shows MAASP Pressure (psi) Mud Weight (lb/gal) 8.80 • Time Log Cum Start End Dur Dur Time Time (hrs) Mrs) Phase Opr. Act Plan Oper. Descr. 100:00 04 4.00 4.00 DRILL E '4 U POH standing back 5" DP in mast. 04:00 00 0 00 - l _ - - - -- _- __ 500 DRILL �E 4_ U PJSM, RIH BitsHWDPmsmgles _- _ _ - -- -- . - - - - - -- - U - -- ,Girt / cond - - r -- 5 50 E } 7 � Fluids, Confirm HWDP free / clean 0400 0500 1.00 00 --- - - - - -I - -- - - -- -- 05:30 10 00 0 50 6 00' DRILL E �4 U PJSM. POH HWDP, stand back in mast 05.00 OS 30 0.501 10 00 :DRILL E �4 P PJSM, MU BHA #6. 8 -12 drctnl assy.RIH same to 465 ft a '1000 1030 050, DRILL ' 7 P C!rc surface test BHA. 14 30 14 30 1 00 16 00 DRILL 1E 4 P PJSM follow BHA with 5" DP to tag fill at 850011 -- - 7 1430 16'00 150 _ cond - -- � 10 00 10 30 0 50 10 50 7 ' � DRILL iE 7 P �Clrc /conddrlgnuids -- - - - - 0 - 1700 118:00 1 00, 18 00rDRILL �E 12 P PJSM, test 9-5/8 csg 3000 psi 130 min Test successful No re-tests. Wash fi / cmt 8500 to tag float collar at 8644 ft Commence drill 9-5/8 csg shoe track, float collar, 80 ft cmt, guide shoe Float collar 8844 ft, Shoe 8728 ft. Hard dense 121:00 23:30 � 2.50�I 21.00�DRILL E 19 P cmt. D RILL 18 00 21'00 ? 3 OO ' 23.50 DRILL tE :3 yP Drill ahead new hole 8728 - 8758 ft for LOT r f - i -- - 23 30 00:00 0 50T 24.0OtDRILL LE I7 _ - �P Circ / re-cipe pipe while link Schlum tools to surface equip. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keenernenipetroleum.com 907 -670 -8623 907- 715 -6434 Eni representative Dave Morns ENI Drilling Supervisor 907 - 670 -8623 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @enipetroleum.com 907 - 670 -8607 907 - 229 -6100 Eni representalve Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907-670-8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907-670- 8623 907- 947 -4323 Eni representative Greg Parker ENI Expediter Greg.Parker ©enipetroleum.com 907-980 -7545 Last Casing seat Cas. Type _ I OD (in) ID (in) Grade Top (ftKB) Bottom (MOP Run Data CASING - -- - - -- 9 5/8 8,681 L80 -0.9 8,727.0 6/1/2010 Last Leakoff Test __ Depth (RKB) TVD (RKB) Fluid Type !Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (Ib /gal) !Leak Off Pressure (psi) 2,4210 I 2,07991 LSND 1_.. 8.80 3200 11.76 1 1,2708 -- -- - - - -- - — I i II - -- * -__ 1FY* Eni E &P Division Well Name: 0PO4 -07 ENI Petroleum Daily Report Well Code: 23893 « CO. Inc. Field Name: Nikaitchuq Date: 617/2010 - Report #: 25 API /UWI: 50 -029- 23409 -00-00 Wellbore name: OPO4 -07 _ pagelofl Well Header I PermitConcession N° Operator ENI Share (%) Well Configuration type !2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) !Water Depth (ft) RKB - Base Flange (ft) RKB • Tubing Spool (ft) 53 20 12.20 0.00 Rig information Contractor I Rig Name Rig Type NABORS ALASKA I NABORS 245E LAND RIG - ---- -- - - - - --- -- -- Job Information - Wellbore TJob Phase [Spud Date ,Target Depth (RKB) ;Target Depth (TV... Depth Dr. (MD) (ft) ;Drilling Hours (hrs) Average ROP (ft/hr) (DFS (days) 0PO4 -07 IDRILLING 5/19/2010 12,031.0 I 3,9403 12,3 22007 56.3 I 19.81 I [Daily P 9 670 O KB) iDepth 3,867 D DI ( • L�Pth 912 Progress (ft) J Ddllin9 Hours 21.50 (hrs) 'Average ROP (ft/hr) POB 8 0 Temperet ('F) W ea t h er 26.8 WIn NNE 0 6.7 mph 1 Dai Information i Darr summary operation 24h Summary - -- - -- - - - -- - -- Drill new 8 -1/2 hole for LOT. Perform LOT 14 # EMW. Dnll ahead 8 -1/2 hole. Operation at 07.00 Drill ahead 8 1/2 hole. Depth 0 0400 10036 5' MD 24h Forecast Drill ahead 8 1/2 hole towards TD Lithology ;Shows MAASP Pressure (psi) Mud Weight (lb/gal) 8.90 Time Log Cum Start End Dur Dur Time Time (hrs) (Wars) Phase Opr. Act. Plan Oper, Descr. 00:00 0030 0.50 0.50 DRILL E 3 P Drill 8 -1/2 hole drctnl 8758 - 8793 ft. Totaling 45 ft for LOT 00:30 01:00 0.50 1.00, DRILL E 7 P Circ / cond fluids for LOT. 8.8 ppg in and out. q 01:00 10230 1.50 2.50 DRILL ' E 19 P PJSM, RU and perform LOT at 8793 MD / 3843 TVD. Build surface press to 1043 psi / .5 bpm. with 8.8 ppg drlg fluid. No i i 1 formation leak off. Proceed with FIT resulting in 14 ogq.FMW. Hold 30 min, natural bleed to 730 psi and stable. RD all test equip, prep for drilling. :0230 1200 9 50 : 12 00 DRILL E 3 ' P Drill ahead 8-1/2 hole drctnl, 8797 - 9254 ft. WOB 20K, RPM 90, GPM 660, SPM 154, SPP 2700 Up 162, Dn 85, Rot 105, Tq on 8000, Tq off 6500 SPR #1 220 / 280, #2 200 / 265, ADT 14.21 hrs, AST 0 hrs ECDs - 10.4 to 10.7 12'00 ;00:00 12.001 24.00 DRILL !E 3 P Drjll ahead 8 -1/2 hole drctnl. 9254 - 9670 ft. ! ,WOB 20K, RPM 90, GPM 660, SPM 154, SPP 2700 [ Up 162, Dn 85, Rot 105, Tq on 8000, Tq off 6500 i SPR #1 220 / 280, #2 200 / 265, ADT 14.21 hrs, AST 0 hrs I ECDs - 10.5 to 10.8 I _L [ Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative ,Jack Keener ENI Drilling Supervisor jack.keenentgenipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Dave Moms ENI Drilling Supervisor 907 -670 -8623 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e 0errpetroleum.com 907-670-8607 907 - 229 -6100 Eni representatve IJack Potter ENI IDrilling HSE IJack.PotterI errpetroleum.com 907 -670 -8624 Eni representative IJoe Longo IENI I Dnlhng Engineer Ijoe.longo@avpetroleum,com 907670 -8623 907 - 947 -4323 l Eni represeMat,ve Greg Parker !ENI 'Expediter IGreg.Parkerc©enpetroleum.com 907- 980 -7545 -- - - as Type _ I - - - OD (in) - - -- - ID(in) - - --- ..__._ � Grade Top (ftK6) Bottom (ftK6► Run Dabs Last Casing seat .CASING - -- - 95/8 8681'L80 � - - - -- -09, 872706 /11/2010 -- — -_ -_ Last Leakoff Test _ :Depth (ft 8, g 27.0 TVD (itK8 8 34.99 Ve aPr OBM - - Fluid Dens BOlblgaq P (Surf) (psi) Eq. Mud Weight (Iblgal�Leak Off Pressure (psi) 13 98 I 2,7851 II it J 40* Eni E &P Division I Well Name: OPO4 -07 ENI Petroleum Daily Report I Well Code: 23893 J Field Name: Nikadchuq • CO. Inc. Date: 6/8/2010 - Report #: 26 IAPI /UWI: 50 -029- 23409 -00-00 1 ni n i_ page 1 of 1 [Wellbore name: OPO4 - 07 Well Header ;Permit/Concession N° Operator ENI Share ( %) Well Configuration type l 12081990 (ENI PETROLEUM 100.00 DIRECTIONAL .R otary Table Elevation (ft) [Ground Level (ft) Water Depth (ft) I RKB - Base Flange (ft) RKB - Tubing Spool (ft) , 53.20 1 12.20 1 0.00 I ' Rf Information 'Contractor -- - - - — - -- ----- - -.. -- Rig Name - -- Rig Type -- -- - -- NABORS ALASKA NABORS 245E LAND RIG ' Job Information Wellbore Job Phase Spud Date Target Depth (ftKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4 -07 DRILLING 5/192010 12,031.0 3,940.3 12,382.00 220.07 56.3 20.81 Daily Information Depth End (ftKB) Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather Wind 11,378.0 3,935.4 1,954.00 37.77 51.7 88.0 34.3 Clear, WC 33.6° 16° NNE @ 2 mph Daily summa operation - 24h Summary Drill ahead 8 -12 hole 10540 ft. POH, sidetrack well at 9944 ft. Drill ahead 9944 -10190 ft Operation at 07.00 Drill ahead 8 1/2 hole Depth @ 0400 10,372' MD 24h Forecast Drill ahead 8 1/2 hole towards TD Lithology Shows MAASP Pressure (psi) Mud Weight (1b/gal) 1 89.00 Time Log Cum Start End Dur Our ; T i m e Time I (hrs) (hrs) Phase O r. I Act. 1 Plan I Oper. Droller. I 00.00 ; 06.00 600 6 00 DRILL 10 3 P rDnIl ahead 8 -1/2 hole drctnl, 9670 - 10125 ft. WOB 8K, RPM 120, GPM 660, SPM 154, SPP 2840 Up 160, Dn 85, Rot 105, Tq on 8000, Tq off 7000 • SPR #1 240 / 310, #2 240 / 300, ' • ECDs - 10 4 to 10.7, Gas 30 units , Cuttings return normal quantity / quality. • ' ' Connections free, normal drag, no swab / gain / loss. 06'00 1030 4.50 1050 - -- -- -- - -_ - -- _ -- -- -- - -- DRILL fE � 3 , P .Drill ahead 8-1/2 hole drool, 10125 ft. - 10540 ft j ! 'WOB 8K, RPM 120, GPM 660, SPM 154, SPP 2840 [ 1 I Up 160, Dn 85, Rot 105, Tq on 8000, Tq off 7000 'SPR #1 240 / 310, #2 240 / 300, ADT 7.08 hrs, AST 0 hrs ECDs -10.4 to 10.7, Gas 120 units Cuttings ream normal quantity / quality. Connections free, normal drag, no swab / gain / loss. 10:30 112:30 2.00 12.50 DRILL F _____ 7 P PJSM, arc / cond fluids for sidetrack. _ 12:30 -' 13:30 1.00 13.50' DRILL F I 4 P PJSM, flow check, POH to 9944 ft for sidetrack. Normal drag, no swab / gain / loss. [ 13.30 20:00 - 6.50' 20 00 DRILL F 119 IP IPJSM, Commence open hole lowside sidetrack at 9944 ft. j Work / slide, cut 30 ft trough. Verify in fact sidetracked with 15K on bit. Positive press differential on / off bottom. AST 6 I ' . hrs 20,00 100:00 4 00 24.00 DRILL E 3 P Drill ahead 8 -1/2 hole drctnl, 9974 ft. - 10190 ft WOB 5K, RPM 120, GPM 680, SPM 154, SPP 2840 Up 160, Dn 85, Rot 105, Tq on 8000, Tq off 7000 SPR #1240 / 310, #2 240 / 300, ADT 3 hrs, AST 0 hrs 1 ECDs -10.4 to 10.7, Gas 120 units Cuttings return normal quantity. / quality. [Connections free, normal drag, no swab / gain / loss. Daily Contacts Position Contact Name 1 Company - _ Title E-mail Office Mobile Eni representative 1 Jack Keener ENI Dnlling Supervisor jack.keener @enipetroleum com 907- 670 - 8623 907- 715 -6434 Eni representative I Dave Moms ENI !Drilling Supervisor 907 -670 -8623 !Eni representative (Tom Norvig [ENI !Rig Clerk AKRigClerks245e @enipetroleum com 907 - 670 -8607 1907- 229 -6100 [Eni representaive Jack Potter I ENI iDnlling HSE 1Jack Potter @enipetroleum.com 907 -670 -8624 I Eni representative Joe Longo IENI (D Engineer ;loe.longo @enipetroleum.com 907-670 -8623 907-947-4323 :Eni representative (Greg Parker - [ENI E Greg Packer @enpetroleum.com 907 - 980 -7545 La st Casin Ca s. Type OD (in) m) Grade Top (ftKB) I Bottom MKS) Run Date F seat - T 10 ( _ — t - - C I 95/81 868 � -0.9 8,727.06/1/2010 [ Last !Depth (RKB) Test TVD (ftKB) ! Fluid Type ifluid Density (lb /gal) P (Surf) (psi) 7Eq. Mud Weight (lb/gal) !Leak Off Pressure (psi) 8,727.0 3,834 99 • VersaPro OBM 8.80 � 1,032 0 I_ 13.98 1 _ 2,7851 I � I III _ill W ell Name: O -07 otabs* Eni E &P Division , Daily Report — - - -- _ -- - --- ---- -_ -- Well Code: 23893 ENI Petroleum 1 � Field Name: Nikaitchuq Co. Inc. i Date: 619/2010 - Report #: 27 API/UWI: 50-029- 23409 -00-00 page 1 of 1 Wellbore name: OPO4 -07 - Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53 20 12.20 0.00 —_ Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG _ Job Information Wellbore Job Phase 'Spud Date Target Depth (ftKB( 'Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4 -07 DRILLING 5/19/2010 12,031.0 1 3,9403 12,382.00 220.07 56.3 21.81 -- - - - - -- -- --- - -- – Daily Information 12, 14 End ( 0 3,935.5 ! 2,0g 01 'Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature (°F) Weather 7Wind Depth -6 0 Depth and (TVD) (... ;Depth Progress Hou (ft) 32.07 62.6 88.0 33.1 Clear, WC 26.1° 113° NNE ia 8.1 mph Dail summary operation 24h Summary Drill ahead 8-1/2 hole 10190 - 11378 ft. Operation at 07.00 Dnll ahead 8 1/2" hole towards TO Depth ( 0400 hours 11475' MD 24h Forecast Drill ahead 81/2 hole towards TD, wiper trip Lithology ?Shows MAASP Pressure (psi) Mud Weight (lblgal) 8 90 Time Lo — Cum Start En D Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00'00 i 06.00 I 6 00 6,00 DRILL E 3 P Drill ahead 8-1/2 hole dretn1, 10190 ft - 10400 ft WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 Up 163, Dn 85, Rot 105, Tq on 11000, Tq off 9000 SPR #1240/310, #2240/300, ECDs -10.4 to 10.7, Gas 60 units 'Cuttings return normal quantity / quality. Connections free, normal drag, no swab / gain / loss. 1 1 06:00 12 00 6.00 12.00 DRILL E 13 :P DnII ahead 8-1/2 hole dretnl, 10400 ft - 10808 ft • WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 Up 163, Dn 85, Rot 105, Tq on 11000, Tq off 9000 SPR #1 240 / 310, #2 240 / 300, ECDs -10.4 to 10.7, Gas 60 units Cuttings return normal quantity / quality. Connections free, normal drag, no swab/gain / loss. 12:00 118.00 6.00 18.00 DRILL E 3 P Drill ahead 8 -1/2 hole dretnl, 10808 ft - 11187 ft WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 Up 163, Dn 85, Rot 105, Tq on 11000, Tq off 9000 SPR #1 240 / 310, #2 240 / 300, ECDs -10.4 to 107, Gas 160 units Cuttings ratan normal quantity 1 quality. I Connections free, normal drag, no swab / gain / loss. 18:00 r 6.00 24 00 DRILL IE 3 P Drill ahead 8-1/2 hole dretnl, 11187 - 11378 ft. WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 'Up 168, Dn 83, Rot 108, Tq on 11000, Tq off 9000 SPR #1 260 / 300, #2 250 / 290, ADT 19.27 hrs, AST 0 hrs ,ECDs -10.4 to 10 7, Gas 80 units Cuttings return normal quantity / quality. L , 'Connections free, normal drag, no swab / gain / loss. Daily Contacts I - -- - - - -- - - -- — — Position L Contact Name .1 Company Title E-mall Office Mobile Em representative I Jack Keener :EN! Drilling Supervisor jack. keener@ernpetroleum com 907- 670 -8623 907- 715 -6434 'Ern representative Dave Moms I ENI I Dnlling Supervisor 907 -670 -8623 'Eni representative Tom Norvig ',ENI ,Rig Clerk AKRigCbrks245e @enipetroleum.com 907-670 -8607 907- 229 -6100 'Eni representalve ,Jack Potter IENI 'Drilling HSE !Jack Potter @errpetroleum.com 907 -670 -8624 I Eni representative 'Joe Longo I ENI DnlhngEngineer I loe.longo @enipelroleumcom '907-670- 8623 907- 947 -4323 'Em representative 'Greg Parke r , ENI ' Expediter jGreg.Parker @enpetroleum.com I 907- 980 -7545 Last Casing seat Cas Type OD (gin) F ID (in) - Grade L Top (RKB) Bottom (RKB) Run Date Test [Depth Last Leakoff `TVD r (ftK6) 9 [Fluid Type -- - -- 8.681:L80 Fluid Density Qblga - 0 9 8,727.0 6/1/2010 6/1/2010 Last ff ( - T- r q P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 8,7270 3,83499 IVersaPro OBM 880 1,032.0 1198 2,785.1 -- ' - - - • Eni E &P Division Well Name: 0PO4 -07 1 ENI Daily Report Well Code: 23893 • page 1 of 1 Field Name: Nikaitchuq Co. Inc. Date: 6/10/2010 - Report #: 28 API /UWI: 50-029 -23409 -00-00 " n 1 ,Wellbore name: OPO4 -07 J Well Header [Permit/Concession N° 'Operator 1 ENI Share ( %) Well Configuration type ;Rotary Elevation (ft) - ENI Ground Level R Water Depth (ft) RKB 100.00 ;DIRECTIONAL O O ept O KB Base Flange (ft) i RKB - Tubing Spool (ft) 53 20 12 20 0.00 Rig Information 'Contractor lRlg Name 'Rig Type I NABORS ALASKA I NABORS 245E ILAND RIG Job Information I Wellbore 1Job Phase [ Spud Date ( Target Depth (RKB) Target Depth (W... Depth Dr. (MD) (ft) 'Drilling Hours (hrs) Average ROP (Mr) ()FS (days) 10PO4 -07 IDRILLING 5/19 /2010 I 12,031.0 3,9403 I 12,38200 220.07 56.3 22.81 Daily Information _ ;Depth End (ftKB) Depth End (ND) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (R/ ri3OB Temperature (°F) Weather Wind 1— 12,144.0 3,935.5 0 00 88.0 37.0 Clear, WC 36.1° 163° SSE a 4 mph ' Daily summary operation 24h Summary Drill 11378 -12144 ft, POH for BHA Operation at 07.00 Tripping out of hole, Bit Depth a 0400 hours 5956.6' MD 24h Forecast POH, MU BHA, RIH, condition for liner run. Lithology (Shows MAASP Pressure (psi) Mud Weight (Ib /gal) 9.00 Time Log Cum — - Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. [00:00 06'00 6.00'[ 600IDRILL iE i3 !P !Drill ahead 8-1/2 hole dretnl,11378ft.- 11600 WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 Up 168, Dn 83, Rot 108, Tq on 11000, Tq of 9000 , SPR #1 260 / 300, #2 250 / 290, ADT hrs, AST 0 hrs ECDs -10 4 to 10.7, Gas 80 units ' [ Cuttings return normal quantity / quality 1 normal Connections free, noal drag, no swab / gain / loss. 06.00 t -- - .- I - - - - -- - �- -- - - --- -- 12 00 6.00r 12�00',DRILL E 3 P I ahead 8-1/2 hole drctnl, 11900- 12021 ft. WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 I Up 168, Dn 83, Rot 108, Tq on 11000, Tq off 9000 ' SPR #1 260 / 300, #2 250 / 290, ADT hrs, AST 0 hrs I ECDs -10 4 to 10 7, Gas 80 units Cuttings return normal quantity / quality. Connections free, normal drag, no swab / gain / loss 12 00 14:30 ' 2 50 14 50r ,D � ,P "Drill ahead 8 -1/2 hole drctnl, 12021 - 12144 ft / � -- RILL - -- E 3 Note final depth 12144 R as determined by Geologists ENI WOB 6K/15K, RPM 120, GPM 660, SPM 154, SPP 2930 'Up 168, Dn 83, Rot 108, Tq on 11000, Tq of 9000 SPR #1 260 / 300, #2 250 / 290, ADT 11.2 hrs, AST 0 hrs ECDs -10.4 to 10.7, Gas 129 units ave Cuttings return normal quantity / quality. Connections free, normal drag, no swab / gain / loss. 14:30 118:30 4 OCT' 18 50 DRILL E 7 P Circ / cond fluids for trip out hole. 635 GPM. Pump hi vis / wt sweep. Calculate fluid caliper as gauge hole. Continue circ shakers clean. No gain / loss. Cuttings retum normal quantity / quality. 18:30 23:30 __ 5.00 23 50 DRILL ,E 6 P PJSM, POH 5" DP for BHA / BOP test to csg shoe 8700 R. Normal drag. No swab / gain / loss. Wellbore exc condition. 2 - 23:30 ; 00:00_ 050 24.00iDRILL IE _ 7 P _ Ciro/ cond fluids, insure casing clean prior to trip out. Daily Contacts Position Contact Name Company Tide E-mail Mee Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener©enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Dave Moms ENI Drilling Supervisor 907 -670 -8623 Eni representative ,Tom Norvig ENI Rig Clerk AKRigClerks245eaenipetroleum.com 907-670 -8607 907 - 229 -6100 [ Eni representalve 1Jack Potter ENI Dulling HSE Jack.Potterieripetroleum.com 907 -670 -8624 , Eni representative ,Joe Longo ENI Drilling Engineer joe.longoaenipetroleum.com 907570 -8623 907 - 947 -4323 IEni representative (Greg Parker ENI !Expediter Greg.Parkerienipetroleum.com 907- 980 -7545 (Eni representative Michael Seward ENI jDdg. Fac. Adv. Michael.Sewardaenipetroleum com [ 907 -952 -7880 ' Last Casing seat Cas. Type OD (in) ID (In) 1 Grade Top (ftKB) Bottom (RKB) Run Date CASING 9 5/81 - - - -- 8.6811L80 .--- L-- __ - ___ -0.9 8,727.0 6/1/2010 - -- - 8,7270 1 - - -- - --- -- - -- - - -- - -- - -- -- - - -- �LastLeakoff Test Depth (ftKB) 'TVD (ftKB) [luid Type IFluid Density (Ib/gal) P (Surf) (psi) Eq. Mud Weight 11b/gal) Leak Off Pressure (psi) 3,834.99 I VersaPro OBM 8.80 1,0320 13.98 2,785.1 I j i I i 4111 • - - * iis Eni E &P Division Well Name: 0PO4 -07 _ 1 - - - -- - - _-- -___ -- Daily Report Well 23893 - - -- - -- I ENI Petroleum • CO. Inc. Field Name: Nikaitchuq Date: 6/1112010 - Report #: 29 API /UWI: 50-029- 23409 -00-00 page 1 of 1 Wellbore name: OPO4 -07 I Well Header _ Fermit/Concession N° !Operator 'ENI Share ( %) Well Configuration type 2081990 !ENI PETROLEUM l 100.00 DIRECTIONAL Rotary Table Elevation (ft) [,Ground Level (R) Water Depth (ft) RKB - Base Flange (ft) IRKS - Tubing Spool (ft) 53.20 _1 12 20 0.00 j Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore '!,Job Phase Spud Date '[Target Depth (ftKB) ;Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) r- Da'1 Information D RILLING 5/19/2010 12,031 0 3,940.3 12,382.00 220.07 56.3 23.81 D End (ftKB) Depth End (TVD) (... !Depth Progress (ft) Drilling Hours (hrs) ;Average ROP (ft/hr) POB Temperature ( °F) i Weather Wind 12,144 0 L 3,9355 1 0.00 J_ 89.0 34.5 j Overcast, WC 26.4° 5° N @ 11 0 mph ! Daily operation '24h Summary ICirc, POH, test BOP, RIH clean out BHA 1 Operation at 07.00 RIH with clean out BHA #7, Bit depth at 0350 7948.6' MD 24h Forecast 1 RIH clean out BHA, arc, POH for liner run Lithology Shows I MAASP Pressure (psi) ;Mud Weight ((lb /gal) - -i - - -- -- -- 9.00 Time Log Cum Start End Dur Dur I00 00 Time 01 30 , i Ili 1 50, �M; 50 DR E 7 Act. Plan Op Descr. P Circ / cond fluids, at csg shoe 870011 Note gelled like substance to shakers from csg. Continue arc shaker dean. No gain Opr. j /loss 1 : 01'30 1 0200 5 50' - � 4 �P PJSM, flow check, POH 5" DP 8700 to BHA at 625 _ - � 2 00� DRILL � E ft. i - -- - - - - - -- - -- --- - - - -- 7 00 DRILL rE 4 PJSM, handle BHA, stand back partial BHA m mast, lay do remainder to pipe shed. rV7.00 08.0 -- . -- --- + - - - - - - --- - � - - ,07.00 0800 � 1 00. B.00TDRILL � E 1 i P I Flow check, Clear rig floor all unneccessary equi - - -- -- ;08:00 � 10.00 2.00: 10.00�DRILL FE ;1 P PJSM, Pull wear nng, install test plug, RU for test BOPE. 5.5 DRILL - AO? 10:00 15'30 5.501 15.50'. DRILL E 12 P ,PJSM, commence test ROPE, all related eauio 250 / 3500 osi Annular 75n / 2500 nai Pgrform time / / test at accumulator. Check bottle press. All tests successful. No failures, no re- tests. Witness waived Mr Jeff Jones AOGCC j this date 10 15:30 16:00 0 50 16.00 DRILL E 1 , P Pull lest plug, set wear ring RD all test equip. /lf 16.00 118:00 2.00 18.00 DRILL E 25 P PJSM, slip / cut dog line. 111-1 18:00 18:30 0.50 18.50 DRILL E 25 P Service rig 18:30 19:30 1 00 19.50 DRILL E 4 P PJSM, MU BHA #8 with hole opener. Flow check, RIH same. 19:30 23:30 4.00 23.50 DRILL E 4 P Flow check, follow BHA with 5" DP 6074 ft. Up 125K, Dn 88K. Data sheet with all parameters being recorded at specified intervals. 23:30 00:00 0.50 24.00 DRILL E 25 TRO4 PJSM, repair / replace swivel packing at top drive. Daily Contacts Position Contact Name I Company Title [ E-mail Office _ Mobile Eni representative Scott Beauchamp !ENI Drilling Supervisor Scott Beauchamp ©enipetroleum.com 907 - 670 - 8623 907- 841 -8759 Eni representative [Dave Moms ENI Dolling Supervisor 907 -670 -8623 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @enipetroleum.com 907 -670 -8607 907 - 229 -6100 Eni representalve !Jack Potter ENI Dolling HSE Jack.Potter @errpetroleum.com 907-670-8624 Eni representative !Joe Longo ENI Drilling Engineer joe.longo@enipetroleum.com 907.670 -8623 907 - 947 -4323 Eni representative Greg Parker ENI Expediter Greg Parker @enpetroleum.com 907 -980 -7545 Eni representative Michael Seward ENI _ 'DrIg.Fac.Adv. jMichael .Seward @enipetroleum.com 907 - 952 -78E0 Last Casing seat Cas. Type - OD (in) ID (In) I Grade Top (ftKB) Bottom (ftKt3) Run Date 9 5/8 ,CASING 8681;L80 -0.9 8,727.06/1/2010 !Last Leakoff !Depth (ftKB) TVD - Test (ftKB) !Fluid ,Flu -- _ -- _ .9- -- `- id - Type - - - -- Fluid Density (lb/gal) P (Surf) (psi) - Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) 8,727.0 3,834 99 ' VersaPro OBM 8.80 1,032.0 I 13.98 2,785.1 _ I 1 Ii ° • Eni E &P Division Well Name: 0PO4 -07 1 Daily Report ENI Petroleum Well Code: 23893 • Inc. Field Name: Nikaitchuq Date: 6/12/2010 - Report #: 30 API /UWI: 50-029 - 23409 -00-00 - Co. j page lofl Wellbore name: 0PO4 - 07 [Well Header Permit/ConcessionN° ' Operator ENI Share (%) Well Configuration type 12081990 , ENI PETROLEUM - 10000 DIRECTIONAL ry Elevation (ft) (ft) - � (ft) __ ota Table Elevation ft 'Ground Level R Water Depth ft RKB -Base Flange (ft) RKB - Tubing Spool (ft) 1 53 20 1220 _ _ 0 00 R g Inform ation Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore !Job Phase (Spud Date ! Target Depth (ftKB) (Target Depth (TV... (Depth Dr. (MD) (ft) Drilling Hours (hrs) !Average ROP (ft/hr) DFS (days) ' 0PO4 -07 ; DRILLING L 5/19/2010 j 12,031.0 ! 3,940.3 I 12382.00 220.07 1 — 56.3 24.81 Daily Information ' Depth End (RKB) 'Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) 'Average ROP (ft/hr) POB Temperature ( °F) Weather Wind 12,144.0 1 3,935.5 0.00 — 890 34.5 Cloudy, Fog, WC @ 11.3 mph 26.4° Daily summary operation 24h Summary RIH cleanout assy, displace well with 9.9 ppg brine POH for liner run. !Operation at 07.00 Operation @ 0400: Pulling out of hole. Depth 2675' MD 1 24h Forecast POH run 5 -1/2 slotted liner , r- . Lrthology _ -- I Shows - - -- MAASP Pressure (psi) Mud Weight (lb/gal) I - - - - -- - - - -- I _ 9.00 Time Log Cum Start End Dur Dur Tone lime (hrs) (W) Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50, DRILL E 25 U ;Cont replace wash packing at top drive. 02:30 04'30 2 00 4.501DRILL E 4 P :PJSM, flow check, resume RIH 5 " DP to tag bridge at 8840 ft. I Data sheet with all parameters being recorded at specified intervals. 1 5 12'00 13:30 1.50 13 5 04:30 112.00 7.50 12.00t DRILL E DRILL - ?E 128 P Wash ream various intervals tight / bridged hole from 8840 ft. 8824 - 9424, 9424 - 10240, 10240 - TD at 12144 ft. Up 118K, Dn 80K, Rot 118K, Gpm 460, SPP 1300, rpm 120 Tq 8 - 10K No gain / loss. 1 13.30 ± 14.00 _ ! 0.50 14 0;DRILL IE i 7 P ;Ciro I cond fluids. CBU X 2, GPM 585, SPP 2300 psi. Shakers clean. 1 !P PJSM, flow check, POH wiper trip to 11530, RIH to TD at 12144 ft. Wellbore exc cond. lE 1400 !1530 r 1.50 1550]DRILL jE 17 P Circ /condfluids 115 119.00 - 7 3 .50 19 00DRILL 'E " P 'PJSM, commence displace wellbore with 30 bbls LVT, 60 bbls Hi Vis brine as spacer, follow with 1300 bbls 9.9 ppg lubncated brine 5 bpm at 200 psi No gain / losses DRILL E 1 4 P - PJSM. flow check, Drop rabbit pipe drift, POI-15" DP to 7320 ft. Begin losses at 10500 ft 2 bph, ending with 18 bph at 7320 ft. Continued hole fill, at all times hole full. Data sheet with all parameters being recorded at specified intervals.(5 19 00 00.00 - 5.00 I 24 00 sfds open hole, 10 stds cased hole) Daily Contacts Position Contact Name 1 Company Title E-mail Office Mobile Eni representative Scott Beauchamp ;ENI Drilling Supervisor Scott.Beaucham - - - - - -- - - -- -- -- -_- — p @enipetroleum com 907- 670 -8623 907- 841 -8759 - - g sor Eni representative Dave Moms ' ENI Drilling Supervisor 907 -670 -8623 Eni representative ;Tom Norvig ENI Rig Clerk AKRigClarks245e @ertpetroleum.com 907 -670 -8607 907 - 229 -6100 Eni representaive (Jack Potter ENI Drilling HSE Jack.Potter @errpetroleum.com 907-670 -8624 Eni representative (Joe Longo ENI Drilling Engineer joe.longo@enipetroleum.com 907-670 -8623 907- 947 -4323 Ent representative 'Greg Parker ENI Expediter Greg Parker @enpetroleum,com 907 -980 -7545 Eni representative Michael Seward ENI Ddg. Fac. Adv. Michael.Seward @enipetroleum.com 907- 952 -7880 Last Casing seat Cas, Type OD (In) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 95/8 8.681 L80 -0.9 8,727.06/1/2010 Last Leako ff Test Depth (RKB) ITVD (RKB) Fluid Type Fluid Density (1b/gall jP (Surf) (psi) Eq. Mud Weight (1b/gal) Leak Off Pressure (psi) 8,727.0 1 3,834.99 VersaPro OBM 8.80 I 1,032.0 13.98 I 2,785.1 ! I - •. - , . III .V1441 Eni E &P Division Well Name: 0PO4 -07 1 CO. Inc. Daily Report ENI Petroleum Well Code: 23893 • Field Name: Nikaitchuq Date: 6/13/2010 - Report #: 31 API /UWI: 50-029- 23409 -00-00 en page 1 of 1 Wellbore name: OPO4 -07 ( Well Header Permit/Concession N° Operator ENI Share (k) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 0.00 Rig Information _._ Contractor Rig Name Rig Type 1 NABORS ALASKA NABORS 245 E LAND RIG -- -- -- -- - - - -- - Job Information Wellbore 'Job Phase Spud Date (Target Depth (ftKB) Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) ' DFS (days) 0PO4 -07 !DRILLING 5/19/2010 { 12,031.0 1 3,940.3 12,382.00 220.07 56.3 25.81 Daily Information _ Depth End (ftKB) (Depth End (TVD) (... Depth Progress (ft) (Drilling Hours (hrs) 'Average ROP (ft/hr) POB Temperature (°F) Weather (Wind 12,144.0 ' 3,9355 0.00 i 89.0 28.6 Clear, Patchy Fog, 1° N (2 6.1 mph WC 22 1° Daily summary operation 24h Summary POH 5" laying dn / standing back DP. Rig repel RIH 5-1/2 liner _ Operation at 07.00 !Operation at 0400, RIH 5 -1/2 liner Depth 2 0353 3595' MD 124h Forecast Run / suspend 5-1/2 liner in 9 -5/8 csg Lithology 'Shows _ - - MAASP Pressure (psi) Mud Weight (Ib /gal) 9.90 -- ----- - - - --- - -- -- -- Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. i Act. Plan °per, Descr. 100:00 00:30 050 0.50 DRILL E '25 P Service rig. ---- 1 - --- 100:30 07.00 6.50 j 7.00 DRILL E 4 P 'PJSM, flow check, static losses 25 bph. Continued hole fill. POH 5' DP to 7400 ft standing back in mast. Lay dn excess DP3550 -329ft. I 1 Data sheet with all parameters being recorded at specified intervals.(5 stds open hole, 10 stds cased hole) 07:00 09:00 2.00 9.00 DRILL E 4 'P Handle BHA #7, lay dn all components to pipe rack, load out unneeded items. 09:00 10:30 1.50 10.50 DRILL E 1 1P PJSM (Rig up / run 5-1/2 liner), place liner run equip to rig floor, RU same. 10:30 111:30 1.00 11.50 DRILL E 25 TR99 Troubleshoot / repair pipe skate "ramp kickers" 11'30 12:30 1.00 12.50 DRILL E 4 P PJSM, RIH 2jts 5-1/2 liner, Pipe skate malfunction. 12'30 '22:30 10.00 22.50 DRILL E 25 TR99 PJSM, flow check, continued 23 bph losses. Repair pipe skate. Sheared bolts. 22:30 00:00 1 50 24.00 DRILL E 4 P PJSM, flow check, losses 8 bph. Resume RIH 5-1/2, SL -80, 17 #, DWC slotted liner to 800 ft. 1 Daily Contacts _ Position 1 Contact Name Company Title E-mail Office Mobile ;Eni representative Dave Moms ENI Dulling Supervisor 907- 670 -8623 ;Eni representative 'Greg Parker ENI Expediter Greg Parker@enipetroleum.com 907-980-7545 IEni representatve !Jack Potter ENI !Dulling HSE Jack.Potter(enpetroleum.com 907 -670 -8624 Eni representative 'Joe Longo ENI IDnIling Engineer joe.longo2empetroleum.com 907 -670 -8623 907-947-4323 Em representative Michael Seward ENI IDrIg. Fac. Adv. , Michael.Seward @ enipetroleum.com 907 - 952 -7880 IEni representative Scott Beauchamp ENI !Drilling Supervisor ( Scott.Beauchamp(c�enpetroleum.com 907 -670 -8623 907 - 841 -8759 Eni representative "Tom Norvig IENI !Rig Clerk IAKRigClerks245e2eripetroleum.com 907-670-8607 907 - 229 -6100 Last Casing seat Cas. Type 1 „ OD (In) ID (In) 1 Grade 1 Top (ftKB) Bottom (ftKB) Run Date !LINER 51/2 4.892 IL-80 1 8,517.8 12,142.0 6/132010 Last Leakoff Test _ 8 ,727 0 3,834.99 Fluid T ye l (Surf) (psi) Eq. Mud Weight (lb/gal) e ( Fuid Density (lb/gal) P Sur) ) E. u Weigt b /al) Lak Off Pressure (psi) ' , 8.80 1,0320 Depth (ftKB) TVD (ftKB) Fluid Type � '- - `- -- - - - - -- - ` 1398 2,785.1 - - - - - -- --- I I I 1 I 1 • 11111 110 IF* Eni E&P Division ENI Petroleum Daily Report [Well Name: 0PO4-07 Well Code: 23893 Field Name: Nikaitchuq 1 50-029-23409-00-00 API/U Co. Inc. Date: 6114/2010 • - Report #: 32 API/UWI: 50 e rme , ___, L Wellbore name: OPO4-07 page 1 of 1 Well Header rPermit/Concession N° TOperator I ENI Share (%) Well Configuration type 12081990 :ENI PETROLEUM ,=.1 100.00 DIRECTIONAL [Rotary Table Elevation (ft) [ lGround Level (ft) I Water Depth (ft) I RKB - Base Flange (ft) IRKS - Tubing Spool (ft) L 53.20 12.20 0 00 I ' 1 . [Rig Information Contractor ;Rig Name Rig Type !NABORS ALASKA 1 NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (ftKB) Target Depth [TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) 0PO4-07 DRILLING 5/19/2010 12,031.0 3,940.3 12,382.00 220.07 56.3 26.81 Daily Information Depth End (ftKB) Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (Mr) POB Temperature (°F) Weather Wind 1 12,144.0 3,935.5 0.00 84.0 29.8 Cloudy, Fog, WC 24° NNE I 22.6 - 161° mph Daily summary operation 24h Summary RIH 5-1/2 liner, set pkr, test packer seal. POH laying dn 5" DP, lay dn liner running tools Operation at 07.00 Running in Hole with 4 1/2" ESP assembly. 24h Forecast I RU and Run 4-1/2 ESP assy jLithology 1 Shows MAASP Pressure (psi) Mud Weight (lb/gal) : L 9.90 1 Time Log r 1 Cum Start End Dur Dur Time Time (hrs) WO Phase Opr. Act. Plan Oper. Descr. ,00 00 , 04 I 4.001 4.00 DRILL E 4 P Continue RIH 5-1/2 liner to hanger. MU liner hgr, mix / pour hgr pac seal. Set up 30 min. [04.00 1 r08.00 t 4.001 8.00 DRILL E 7 P PJSM, flow check, 8 bbp losses, follow liner hgr with 5" DP to 9-5/8 csg shoe depth. 0800 11 0830 I: 0 850 DRILL E 7 f p Stop at 9-5/8" csg. shoe a18727' and circulate one DP capacity volume at 5 bpm with 370 psi. PU-143k, SO-88k, , 1 , 1Rot-105k, Rpm-30, Tq-6300 0830 11 12:00 t 3 501 12.001DRILL E 14 'F. 1PJSM, flow check. 8 bpm losses, Cont. run in hole with slotted liner assy. To 12100' Pu-170k, So-65k, Rot-105 Tag 1 I bottom at 12144' and pick up to Up wt. @170k + 2 ft. (g12142' . . . Circulate DP capacity 900 stks at 5 bpm w/425 psi. . . 1200 13'30 1 1 501 1350 DRILL lE :19 IP . Drop ball & pump down at 4 bpm w/295 psi, slowing pump to 2 bpm w/98 psi. 1 1 I land-out ball in seat & PT up to 3000 psi & hold for 10 minutes, PT up to 4000 psi I ' , . , and slack off to 80k, bleed off psi to zero, slack off to 75k, pick up to 110k & stop. I , 'Close annular preventer & PT backside packer to 1500 psi & hold for 5 minutes, 1 . OK, bleed off same (Chart record setting SLZXP Hanger/Packer & Testing same). 1 Pick up to 150k & release from hanger- ok 20k loss of liner wt L/D 2 Jts DP. 1 , I 1 1 1 ' Final depths = Guide shoe at 12142 ft, Top liner hgr = 8518 ft , I 1330 11430 I 1 00:1 14.50 DRILL E 1 1P 1 Circ 1.5 Full circulation at 7 bpm w/260 psi. Flow check- Static. i 14:30 :23:30 i ' 9.001 23 50 DRILL E 4 i iP PJSM, flow check, POH laying dn 5" DP. 267 jts total. 23:30 10000 - I 0.5(511 24.00 DRILL E 5 1P Flow check, make service breaks on liner run tool, lay dn same. Daily Contacts r Position I Contact Name Company Title E-mail Office Mobile _ ' Eni representative Dave Moms ENI DnIling Supervisor 907-670-8623 1 Eni representative Greg Parker ENI Expediter Greg Parker@enipetroleum.com 907-980-7545 Eni representalve Jack Potter ENI Drilling HSE Jack.Potterfgenipetroleurn,com 907-670-8624 Eni representative Joe Longo ENI Drilling Engineer joelongo@anipetroleum.com 907-670-8623 907-947-4323 Eni representative Michael Seward ENI Drlg. Fac. Adv. Michael.Seward@enipetroleum.com 907-952-7880 Eni representative Scott Beauchamp ENI Dnlling Supervisor ScottBeauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Torn Norvig ,ENI Rig Clerk AKRigClerks245e(genipetroleum.com 907-670-8607 907-229-6100 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 5 1/2 4 892 L-80 8,517.8 12,142.0 6/13/2010 Last Leakoff Test Depth (ftKB) 1 TVD (ftKB) Fluid Type !Fluid Density (lb/gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 8,727D 3,834.99 VersaPro OBM 8 80 1,032 0 13 98 2,785.1 ..L_ .L — VIIIIS Eni E &P Division Well Name: 0PO4 -07 ENI Petroleum Daily Report Well Code: 23893 . Field Name: Nikaitchuq U CO. Inc. Date: 6(1512010 - Report #: 1 API/BIM: 50 -029- 23409 -00-00 page 1 of 1 Wellbore name: OPO4 -07 Well Header _ Permit/Concession N° Operator ENI Share ( %) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) ?Titer Depth (ft) I RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 ! 0.00 Ri Information - --- - - - - -- - - -- -- — - -- - - - - -- Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG - — -- -- - --- i W� Information ob Phase !Spud Date Target Depth (ftKB) ITarget Depth (TV... ,Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) OPO4 -07 1COMPLETION 1 6/13/2010 12,031.0 3,940.3 L 3.00 Daily Information , Depth End (RKB) ,Depth (TVD En) (. Drilling Hours (hrs) .Average ROP (ft/hr) fPOB Temperature ( °F) ;Weather Wind - _ - i D Progress (ft) '; 82.0 31.6 Cloudy, WC 18.7° 14° NNE a 21 9 mph !Daily summ ary operation l _ 24h Summary Clear floor, RU /RIH ESP BHA pump assy. Operation at 07.00 RIH 4 -1/2 ESP Assy 24h Forecast RIH 4 -1/2 ESP Assy Lithology - -- - _ -- _ -- - -- _ -- Shows --- - - - - -- _- - - -- - -- - - -- - - - -- IMAASP Pressure (psi) ] Mud Weight (lb /gal) Time Log I Cum Start End Dur Dur Time Time (hrs) (hrs) phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 DRILL K 1 P Clear floor all liner run equip, prepare floor for completion. 01:00 01:30 0 50 1.50 DRILL K 5 P Drain BOP stack, pull wear nng. 01:30 02:00 0.50 2.00 DRILL K 1 P PJSM, all personnel!, topic - rig up / run ESP completion. _ 02:00 06.00 4.00 6.00 DRILL K 20 P Hang Centrilift sheaves in mast. RU Centrilift equip. RU handling equip. Lay out all ESP equip in pipe shed Inspect and fit test. .06:00 10:00 4 00 i 10.00 DRILL K 1 5 P Pick up and make up Mtr.centralizer, gauge housing, motor, upper 8 lower 1 I tandem seal assemblies, TTC x-over w /screen intake, x -over & pup jt. FIII with oil I 1 to TTC intake until void full & running out vent holes, as per procedue. Set in mousehole and break off TTC, set TTC in hole & make up Jt #1 Mu pump assy : l and set in tubing jt 1000 1)3 — 00 3.00 13.00 DRILL �K �5 P ,R /u Hal. Slickline 8 deploy pump assy w /GS tool into tubing, set down & release I 1 !from pump assy, POOH w /sliddine, redress GS tool and make up tbg. Pack-off I l assy, run into tbg Jar down on the GS tool to insert pack-off stinger into receptide 1 ;shear off by jarring down, pick up to confine released, set back down and hit jar 5 more times -OK, POOH w /GS tool. Make up test tool & run Into tbg. pack-off, shear off of test tool & POOH w /slickline, rig up & test to 1000/psi for 15 min -OK 1 Run in tbg w/Redressed tool and Latch test tool,POOH w /slickline & make up tbg stop tool, run in tbg. Jar down & release from tbg. Stop, POOH w /slickine, R/D 1 Halliburton & release slicldme unit. f -- •3:00 ' 16:00 3 00 16 00 DRILL K 15 I,P Make up TTC to top of seal assy & motor asst' (cross -over coupling free) connect ! I 11/4" TEC line, 1/4" cap tube, clamps, MLE cable & megger test same -OK, MU ' discharge pressure sub w /pups, currently connecting 1/4" TEC line to discharge ! sub- WORKING ON STEP #14 OF COMPLETION PROCEDURE. X18:00 - - - 1 - -- - - -- - -- - 20 30 I 4.50 20 50'1 DRILL K S P 1Continue with splice MLE I test procedure MU Swagelok crossover 1/4 to 3/8 ".cap tube Test connectrtons and clamp same RIH 4 -12 tbg to GLM. Carrico 4 -1/2 x 1" Mod KBMG, STS -1 shear valve installed. MU / torque up and clamp at I , .connections above / below GLM 20:30 700.00 3.50 1 24.00 1 K 14 P !PJSM, flow check (8 bpm losses), Follow ESP / GLM asst' with 4-1/2 tbg to 1540 ft, megging elect at 1000 ft intervals !Clamping intervals as specified In run program Daily Contacts Position Contact Name 1 Company Title -- -- E-mail - - - -- Office Mobile ,Em representative „Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative [ Alvin Criswell ENI Expediter Alvin.Cnswell(genipetroleum.com 907- 980 -7545 , Eni representatve !Jack Potter ENI ,Drilling HSE ;Jack Potterlerrpetroleum.com 907-670 -8624 Eni representative !ScottBeaucharrp 'ENI !DrillingSuperNsor ' Scott .Beauchamp @enipetroleum.com X907 -670 -8623 907- 841 -8759 Ens representative J Tom Norvig ENI .Rig Clerk .AKRigClerks245eIenipetroleum.com 1907-670 -8607 907 - 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade _ Top (ftKB) Bottom (ftKB) Run Date LINER 1 5 4.892 L -80 8,517.8 12,142.0 6/132010 _ Last LeakoffTest Depth (ftKB) TVD (RKB) Fluid Type !Fluid Density (Ib /gal) P (Surf) (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 8,727.0 3,834.99 VersaPro OBM I 8.80 1,032.0 13.98 2,785.1 III I Eni E &P Division Well Name: 0PO4 -07 Daily Report W ENI Petroleum y p rweo coati: 23893 • CO. nC. IFieldName: Nikartchuq D ate: 6/16/2010 - Report #: 2 API/UWI: 50 -029- 234 00- 00 _____ n Wellbore name: OPO4 -07 pag /oft Well Header Permit/Concession N° fOperator ENI Share (h) Well Configuration type 2081990 _ PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) !Ground Level (ft) [Water Depth (ft) I RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.20 ! 0.00 Rig Information Fontractor Rig Name Rig Type ! NABORS ALASKA NABORS 245 E LAND RIG Job Information rWellbore Job Phase Spud Date Target Depth (RKB) Target Depth (TV... Depth Dr. (MD) (ft) Drilling Hours (hrs) Average ROP (R/hr) DFS (days) ! OPO4 -07 COMPLETION 6/13/2010 12,031.0 3,940.3 4.00 Daily Information Depth End (ftKB) Depth End (TVD) (... Depth Progress (ft) Drilling Hours (hrs) Average ROP (ft/hr) POB Temperature ( °F) Weather Wind 82.0 32.4 Overcast, WC 20.5° 5° N © 19.6 mph Daily summaryoperation 24h Summary RIH 4-1/2 ESP completion, ND BOPE, NU prod tree. Operation at 07.00 Pulling two way check 24h Forecast Nipple up prod tree, test, freeze protect well. Lithology _ - -- - ----- - - - - -- - - - -- Thows -- - MAASP Pressure (psi) Mud Weight (lb /gal) ' 9.90 Time Log Cum Start End Dur Dur Time Time (hrs) ihrs) Phase Opr. Act. Plan Oper. Descr. 00:00 14:00 14 00. 14.00 DRILL lK ! P CONT RIH W/4 1/5 TBG 2500 TQ W/ESP & CONTROL LINE F/1580' INSTALLING CANNON CLAMPS, EVERY OTHER IJT, RECORDING DWN -WTS, CONDUCTIVITY TESTS EVERY 1000' T/7400. Cont. run 4 1/2" L -80 IBTM #12.6 ppf tubing to 7741' . Install x -over, run 2 jts VIT, make up land 1t & hanger, orient hanger. 14 :00 16'00 2,00! 16,00f0RILL K 5 , P /Install penetrator, make final splice on MLE cable, install chemical line through hanger (install check valve on chemical line / lust below hanger). Centnift perform well -hft, continuity, megger / insulation tests from top of penetrator- OK. Final SO Wt =70k / PU Wt =108k Land tubing hanger & R.I.L D.S. BTM, OF MTR. CENTRALIZER SET a 7865.56 FT. TOTAL CLAMPS & BANDS INSTALLED !MOTOR CLAMPS: 2 1 IPUMP CLAMPS' 6 1 412" FLAT CHANNEL CLAMPS 5 1 , CHRISTOLIZERS: 3 I ', , �4 12" CANNON CHANNEL CLAMPS: 106 41/2 -51/2 CLAMPS. 1 512" CHANNEL CLAMPS. 3 'BANDS 4 I 16:00 1 17:00 1.00 17.00 DRILL K 12 P TEST UPPER AND LOWER HANGER SEALS T/ 5M 10 MIN EACH. SET TWC. 17.00 118 :00 1.00 18.00 DRILL K 5 P PJSM, RD remainining ESP equip and spooling unit. 18:00 21:30 3.50 21.50 DRILL K 5 P PJSM, nipple do BOPE. _ 21:30 00:00 2.50, 24.00 DRILL K 5 P PJSM, Install production tree. Daily Contacts Position Contact Name Company 1 Title E-mail Office Mobile Eni representative Dave Moms y ENI ;Drilling Supervisor 907 -670 -8623 Eni representative Alvin Caswell ENI !Expediter iAlvin.Cnswellkenipetroleum com 907 - 980 -7545 Eni representaive 'Jack Potter ENI 1 Drilling HSE �Jack.Potter @errpetroleum.com 907 -670 -8624 Eni representative Scott Beauchamp !ENI Dulling Supervisor �Scott.Beauchamp@eripetroleum com 1907 -670 -8623 907- 841 -8759 Eni representative /Tom Norvig !ENI /Rig Clerk IAKRigClerks245e @errpetroleum com 1907-670 -8607 907 - 229 -6100 Last Casing seat Cas. 7 __ OD (in) . ID (in) Grade Top (ftKB) Bottom (RKB) Run Date - -- i 80 LINER 1 1 512; 4.892iL - - -80 8,5178 12,142.06/132010 Last Off Test Depth (ftKB) ITVD (ftKB) Fluid Type Fluid Density (Ib/gal) P (Surf) (psi) Eq. Mud Weight (Ib /gal) Leak Off Pressure (psi) 8,7270 1 3,83499 VersaPro OBM 8.80 I 1,032.0 13.98 2,785.1 it — 4D___ Vf#11 Eni E&P Division Well Name: OPO4-07 ENI Petroleum Daily Report Weil Code: 23893 Field Name: Nlkaitchuq • Co. Inc. Date: 6117/2010 - Report #: 3 APIIUWI: 50-029-23409-00-00 ena page 1 of 1 Wellbore name: OPO4-07 — .: . ..... Well Header Permit/Concession N° Operator ENI Share (%) Well Configuration type 2081990 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) TWater Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 , 12.20 1 0.00 , Rig Information Contractor Rig Name IRIg Type NABORS ALASKA NABORS 245 E LAND RIG !Job Information IWellbore — I-lob Phase I Spud Date Target Depth (ftKB) I Depth (TV... [depth Dr. (MD) (ft) [Drilling Hours (hrs) Average ROP (ft/hr) DFS (days) I OPO4-07 I COMPLETION ! 6/13/2010 12,031.0 . 1 . 3,940.3 __ 1 5.00 Daily Information IDepth End (ftKB) IDepth End (TVD) (... [Depth Progress (ft) [Drilling Hours (hrs) [Average ROP (ft/hr) IPOB I Temperature (°F) Weather 'Wind 82.0 33 6 Overcast, WC 22.3° 15° N el 22.1 mph I Daq summary operation 24h Summary NU prod tree, test, freeze protect well, prep for move RELEASE NABORS 245 THIS DATE AT 0800 HRS Operation at 07.00 Prepare Nabors 245 for ng move. 24h Forecast Prepare Nabors 245 for rig move Lithology [Shows MAASP Pressure (psi) Mud Weight (lb/gal) 9.90 Time Log Cum Start End Dur Dur Time Time (hrs) (tws) Phase Opr. Act. Plan Oper. Descr. 00:00 08:00 8.00 8 00 DRILL K 12 P Complete prod tree installation, test primary / secondary seals, Test tree and all components 5000 psi 10 min. Test ' , I successful. No re-tests Rig up lubricator, pull TWC. Plumb lines for displace tbg and tbg x 9-5/8 annulus to diesel. Rig up . I , lines & LRS pump down Tubing and shear-out disc in GLM (22164' 01 800 psi, line up on I.A. and LRS pump diesel down 1 IA taking retums up tbg at 2 bpm w/550 psi holding back pressure with choke. Final pump rate at 2 bpm w/700 psi good diesel returns back,shut down pump. Tbg psi (2125 / IA psi @200 Lubricate in BPV and secure tree I I RELEASE NABORS RIG 245 THIS DATE AT 0800 AM 1 1 ' Daily Contacts i 1 Position I Contact Name Company Title E-mail Office Mobile ,Eni representative :Dave Monis ENI Drilling Supervisor 907-670-8623 !Eni representative I !Alvin Cnswell ENI Expediter AlvinCriswell@enipetroleum.com 907-980-7545 ,Eni representaive !Jack Potter ENI Drilling HSE Jack Potter@enipetroleum.com 907-670-8624 IEni representative !Scott Beaucharrp ENI Drilling Supervisor Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 lEni representative ITom Non/1g ENI Rig Clerk AKRigCkarks245e(2enipetroleum.com 907-670-8607 907-229-6100 Eni representative !Michael Seward EM Drig. Fac. Adv. Michael.Seward@enipetroleum.com 907-952-7880 - Last Casing seat Cas. Type OD (In) ID (in) Grade i Top (ftKB) Bottom (ftKB) Run Date !LINER I 5 1/2 4,892 L-80 I 8,517.8 12,142.0 6/13/2010 I Last Leakoff Test ;Depth (ftKB) ITVD (ftKB) !Fluid Type . Fluid Density (1b/gal) P (Surf) (psi) I Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 8,727 0 , 3,834.99 i VersaPro OBM , 8.80 1,032.0 _1_ 13.98 2,785.1 , , I I 1 1 Schlumberger v OPO4 -07 Final Field Surveys ( lfli II (Def Survey) Report Date: June 12, 2010 - 01:46 AM Survey / DLS Computation: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 0.460 ° (True North) Field: Nikaitchuq Vertical Section Origin: 0.000 ft, 0.000 ft Structure / Slot: Oliktok Point / OPO4 TVD Reference Datum: Rotary Table Well: OPO4 -P07 TVD Reference Elevation: 53.360 ft above MSL Borehole: OPO4-07 Seabed / Ground Elevation: 12.200 ft above MSL UWI / API#: Borehole- 3118549 / 500292340970 Magnetic Declination: 21.706 ° Survey Name: OPO4-07 Field Total Field Strength: 57672.151 nT Survey Date: May 18, 2010 Magnetic Dip Angle: 80.954 ° Tort / AHD / DDI 1 ERD Ratio: 205.666 ° / 10437.031 ft / 6.819 / 2.639 Declination Date: May 18, 2010 Grid Coordinate System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Declination Model: BGGM 2009 Location Lat / Long: N 70° 30' 39.94568 ", W 149° 51' 46.87747" North Reference: True North Location Grid N/E Y /X: N 6036569.440 ftUS, E 516739.270 ftUS Grid Correction: 0.000 ° • Grid Convergence Angle: 0.12913048 ° Total Corr Mag North ->True North: 21.706 ° Grid Scale Factor: 0.99990032 Local Coord Referenced To: Well Head Comments MD Intl Azim True TVD VSEC NS EW DLS Northing Easting Latitude Longitude (ft) (1 (1 (ft) (ft) (N /S ft) (E/W ft) ( ° /100ft) (ftUS) (ftUS) (N /S ° "') (E/W ° "') Tie-In 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 N/A 6036569.44 516739.27 N 70 30 39.95 W 149 51 46.88 41.16 0.10 237.68 41.16 -0.02 S 0.02 W 0.03 0.24 6036569.42 516739.24 N 70 30 39.95 W 149 51 46.88 89.00 0.21 237.68 89.00 -0.09 S 0.09 W 0.14 0.23 6036569.35 516739.13 N 70 30 39.94 W 149 51 46.88 1 80.00 0.45 187.94 180.00 -0.53 S 0.53 W 0.33 0.39 6036568.91 516738.94 N 70 30 39.94 W 149 51 46.89 273.00 0.04 277.10 273.00 -0.89 S 0.89 W 0.41 0.49 6036568.55 516738.86 N 70 30 39.94 W 149 51 46.89 366.00 0.97 11.85 365.99 -0.12 S 0.11 W 0.28 1.05 6036569.32 516738.99 N 70 30 39.94 W 149 51 46.89 398.00 1.01 9.74 397.99 0.43 N 0.43 W 0.18 0.17 6036569.87 516739.09 N 70 30 39.95 W 149 51 46.88 427.00 0.99 7.45 426.98 0.93 N 0.93 W 0.10 0.15 6036570.37 516739.16 N 70 30 39.95 W 149 51 46.88 457.00 1.16 8.64 456.98 1.49 N 1.49 W 0.02 0.57 6036570.93 516739.24 N 70 30 39.96 W 149 51 46.88 490.00 1.58 5.36 489.97 2.27 N 2.27 E 0.07 1.29 6036571.71 516739.33 N 70 30 39.97 W 149 51 46.88 520.00 222 0.03 519.95 3.26 N 3.26 E 0.11 2.21 6036572.70 516739.37 N 70 30 39.98 W 149 51 46.87 549.00 3.17 0.14 548.92 4.63 N 4.63 E 0.11 3.28 6036574.07 516739.37 N 70 30 39.99 W 149 51 46.87 581.00 5.06 358.82 580.84 6.92 N 6.92 E 0.08 5.91 6036576.36 516739.34 N 70 30 40.01 W 149 51 46.88 614.00 6.88 358.64 613.66 10.35 N 10.35 E 0.01 5.52 6036579.79 516739.25 N 70 30 40.05 W 149 51 46.88 645.00 7.37 8.54 644.42 14.18 N 14.18 E 0.26 4.26 6036583.61 516739.49 N 70 30 40.09 W 149 51 46.87 676.00 8.04 8.85 675.14 18.29 N 18.28 E 0.89 2.17 6036587.72 516740.11 N 70 30 40.13 W 149 51 46.85 708.00 9.13 12.28 706.78 22.99 N 22.98 E 1.77 3.76 6036592.42 516740.99 N 70 30 40.17 W 149 51 46.83 740.00 10.52 12.76 738.31 28.33 N 28.31 E 2.95 4.35 6036597.75 516742.16 N 70 30 40.22 W 149 51 46.79 774.00 11.91 11.81 771.66 34.80 N 34.77 E 4.36 4.12 6036604.21 516743.55 N 70 30 40.29 W 149 51 46.75 802.00 13.12 6.32 798.99 40.80 N 40.75 E 5.30 6.06 6036610.20 516744.48 N 70 30 40.35 W 149 51 46.72 837.00 14.31 4.57 833.00 49.06 N 49.01 E 6.08 3.60 6036618.46 516745.24 N 70 30 40.43 W 149 51 46.70 876.37 16.43 359.72 870.96 59.48 N 59.43 E 6.44 6.29 6036628.88 516745.58 N 70 30 40.53 W 149 51 46.69 971.30 19.15 0.50 961.34 88.48 N 88.43 E 6.51 2.88 6036657.88 516745.58 N 70 30 40.82 W 149 51 46.69 1068.36 21.72 3.90 1052.29 122.34 N 122.28 E 7.87 2.92 6036691.72 516746.87 N 70 30 41.15 W 149 51 46.65 1163.43 25.97 5.25 1139.22 160.66 N 160.58 E 10.98 4.51 6036730.02 516749.88 N 70 30 41.52 W 149 51 46.55 1258.49 31.60 5.67 1222.50 206.24 N 206.12 E 15.34 5.93 6036775.57 516754.15 N 70 30 41.97 W 149 51 46.43 1355.80 36.79 2.61 1302.97 260.79 N 260.64 E 19.19 5.62 6036830.10 516757.87 N 70 30 42.51 W 149 51 46.31 1452.15 37.04 1.76 1380.00 318.63 N 318.47 E 21.40 0.59 6036887.92 516759.95 N 70 30 43.08 W 149 51 46.25 1543.39 38.38 0.66 1452.18 374.43 N 374.26 E 22.57 1.64 6036943.71 516760.99 N 70 30 43.63 W 149 51 46.21 1642.39 34.98 0.64 1531.57 433.56 N 433.39 E 23.24 3.43 6037002.83 516761.53 N 70 30 44.21 W 149 51 46.19 1736.46 35.24 359.46 1608.52 487.66 N 487.49 E 23.28 0.77 6037056.93 516761.45 N 70 30 44.74 W 149 51 46.19 1833.68 39.07 358.22 1686.00 546.34 N 546.18 E 22.07 4.01 6037115.61 516760.11 N 70 30 45.32 W 149 51 46.23 1927.22 38.11 356.90 1759.11 604.61 N 604.47 E 19.59 1.35 6037173.89 516757.50 N 70 30 45.89 W 149 51 46.30 2022.85 44.18 357.66 1831.09 667.40 N 667.29 E 16.63 6.37 6037236.70 516754.40 N 70 30 46.51 W 149 51 46.39 2120.78 47.37 359.88 1899.39 737.53 N 737.43 E 15.16 3.64 6037306.83 516752.77 N 70 30 4720 W 149 51 46.43 2216.70 50.30 359.96 1962.52 809.73 N 809.64 E 15.06 3.06 6037379.03 516752.51 N 70 30 47.91 W 149 51 46.43 2308.38 54.27 357.84 2018.60 882.21 N 882.13 E 13.64 4.70 6037451.50 516750.92 N 70 30 48.62 W 149 51 46.48 Dolling Office 2009 1 726.0 Nikartchoq\Oliktok Point\0PO4- P07\0PO4-07\0PO4-07 Field 6/122010 5 11 AM Page 1 of 3 Comments MD Ind Azim True TVD VSEC NS EW DLS Northing Easting Latitude Longitude (ft) O ( ° l (ft) (ft) (N /S ft) (E/W ft) ( °/100ft) (ftUS) (ftUS) (N /S ° "') (ENV ° "') 2382.52 57.83 357.72 2059.99 943.63 N 943.57 E 11.25 4.80 6037512.94 516748.39 N 70 30 49.23 W 149 51 46.55 BHA#5 12 1/4" 2528.21 61.66 358.51 2133.39 1069.35 N 1069.32 E 7.13 2.67 6037638.67 516743.99 N 70 30 50.46 W 149 51 46.67 2622.74 65.14 0.34 2175.71 1153.84 N 1153.83 E 6.30 4.07 6037723.16 516742.97 N 70 30 51.29 W 149 51 46.69 2719.63 67.82 1.70 2214.37 1242.66 N 1242.64 E 7.90 3.05 6037811.97 516744.36 N 70 30 52.17 W 149 51 46.64 2813.90 69.72 2.47 2248.51 1330.50 N 1330.45 E 11.10 2.15 6037899.78 516747.37 N 70 30 53.03 W 149 51 46.55 2909.23 72.16 2.41 2279.64 1420.54 N 1420.47 E 14.93 2.56 6037989.79 516751.00 N 70 30 53.92 W 149 51 46.44 3005.13 73.42 2.67 2308.01 1512.08 N 1511.98 E 18.99 1.34 6038081.31 516754.85 N 70 30 54.82 W 149 51 46.32 3100.64 73.36 2.39 2335.31 1603.55 N 1603.42 E 23.03 0.29 6038172.74 516758.69 N 70 30 55.71 W 149 51 46.20 3194.60 73.47 1.75 2362.13 1693.56 N 1693.41 E 26.28 0.66 6038262.73 516761.74 N 70 30 56.60 W 149 51 46.10 3290.73 73.98 1.88 2389.07 1785.82 N 1785.64 E 29.21 0.55 6038354.96 516764.45 N 70 30 57.51 W 149 51 46.02 3386.26 73.82 0.58 2415.57 1877.59 N 1877.40 E 31.18 1.32 6038446.71 516766.21 N 70 30 58.41 W 149 51 45.96 3483.18 74.24 0.34 2442.23 1970.77 N 1970.57 E 31.93 0.49 6038539.88 516766.75 N 70 30 59.33 W 149 51 45.94 3578.86 73.99 359.45 2468.42 2062.79 N 2062.60 E 31.76 0.93 6038631.90 516766.38 N 70 31 0.23 W 149 51 45.94 3674.36 73.67 358.89 2495.02 2154.49 N 2154.31 E 30.43 0.66 6038723.59 516764.84 N 70 31 1.13 W 149 51 45.98 3769.55 73.85 358.01 2521.64 2245.82 N 2245.67 E 27.96 0.91 6038814.94 516762.16 N 70 31 2.03 W 149 51 46.05 3865.91 73.62 357.62 2548.63 2338.22 N 2338.10 E 24.43 0.46 6038907.36 516758.43 N 70 31 2.94 W 149 51 46.16 3960.99 73.67 358.75 2575.40 2429.38 N 2429.29 E 21.54 1.14 6038998.52 516755.33 N 70 31 3.84 W 149 51 46.24 4057.46 73.37 358.74 2602.77 2521.85 N 2521.77 E 19.51 0.31 6039090.99 516753.10 N 70 31 4.75 W 149 51 46.30 4152.89 73.73 0.45 2629.79 2613.36 N 2613.29 E 18.87 1.76 6039182.50 516752.25 N 70 31 5.65 W 149 51 46.32 4249.85 73.63 1.98 2657.04 2706.40 N 2706.32 E 20.84 1.52 6039275.53 516754.01 N 70 31 6.56 W 149 51 46.26 4345.19 73.59 2.62 2683.94 2797.82 N 2797.71 E 24.51 0.65 6039366.92 516757.47 N 70 31 7.46 W 149 51 46.16 4441.13 73.72 2.24 2710.94 2889.83 N 2889.69 E 28.42 0.40 6039458.89 516761.17 N 70 31 8.36 W 149 51 46.04 4537.14 73.50 2.17 2738.04 2981.89 N 2981.73 E 31.96 0.24 6039550.93 516764.51 N 70 31 9.27 W 149 51 45.94 4631.36 73.64 2.22 2764.69 3072.22 N 3072.04 E 35.42 0.16 6039641.24 516767.76 N 70 31 10.16 W 149 51 45.83 4726.76 73.53 3.42 2791.65 3163.65 N 3163.44 E 39.92 1.21 6039732.64 516772.06 N 70 31 11.06 W 149 51 45.70 4821.71 73.78 4.72 2818.37 3254.58 N 3254.32 E 46.39 1.34 6039823.52 516778.32 N 70 31 11.95 W 149 51 45.51 4917.79 73.96 5.39 2845.06 3346.58 N 3346.25 E 54.52 0.70 6039915.47 516786.25 N 70 31 12.86 W 149 51 45.27 5014.22 73.83 4.90 2871.81 3438.92 N 3438.53 E 62.83 0.51 6040007.75 516794.35 N 70 31 13.76 W 149 51 45.03 5110.69 74.15 3.88 2898.42 3531.43 N 3530.98 E 69.93 1.07 6040100.21 516801.23 N 70 31 14.67 W 149 51 44.82 5205.71 73.90 3.54 2924.57 3622.63 N 3622.14 E 75.84 0.43 6040191.37 516806.94 N 70 31 15.57 W 149 51 44.64 5301.83 73.79 2.83 2951.31 3714.85 N 3714.32 E 80.97 0.72 6040283.56 516811.86 N 70 31 16.47 W 149 51 44.49 5397.94 73.27 2.64 2978.56 3806.95 N 3806.38 E 85.37 0.57 6040375.62 516816.05 N 70 31 17.38 W 149 51 44.36 5493.28 7326 2.63 3006.01 3898.18 N 3897.59 E 89.56 0.01 6040466.82 516820.04 N 70 31 18.28 W 149 51 44.24 5591.21 73.62 2.61 3033.93 3991.98 N 3991.36 E 93.85 0.37 6040560.59 516824.12 N 70 31 19.20 W 149 51 44.11 5686.63 73.15 2.69 306121 4083.35 N 4082.70 E 98.08 0.50 6040651.93 516828.14 N 70 31 20.10 W 149 51 43.99 5782.60 73.55 3.05 3088.71 4175.22 N 4174.53 E 102.69 0.55 6040743.76 516832.54 N 70 31 21.00 W 149 51 43.85 5878.19 73.42 3.34 3115.88 4266.76 N 4266.03 E 107.79 0.32 6040835.27 516837.44 N 70 31 21.90 W 149 51 43.70 5973.03 73.48 3.33 3142.90 4357.55 N 4356.79 E 113.08 0.06 6040926.03 516842.52 N 70 31 22.79 W 149 51 43.54 6069.78 73.46 3.31 3170.42 4450.19 N 4449.38 E 118.45 0.03 6041018.63 516847.69 N 70 31 23.70 W 149 51 43.39 6165.67 73.21 3.85 3197.92 4541.92 N 4541.07 E 124.19 0.60 6041110.31 516853.21 N 70 31 24.61 W 149 51 43.22 6260.09 73.36 3.99 3225.08 4632.18 N 4631.28 E 130.37 0.21 6041200.54 516859.19 N 70 31 25.49 W 149 51 43.03 6356.37 73.70 3.27 3252.38 4724.37 N 4723.43 E 136.22 0.80 6041292.68 516864.83 N 70 31 26.40 W 149 51 42.86 6452.07 71.49 5.89 3281.01 4815.44 N 4814.44 E 143.50 3.49 6041383.70 516871.90 N 70 31 27.29 W 149 51 42.65 6547.50 69.35 6.96 3312.98 4904.86 N 4903.78 E 153.55 2.48 6041473.06 516881.75 N 70 31 28.17 W 149 51 42.35 6645.59 72.45 5.90 3345.08 4997.03 N 4995.88 E 163.92 3.32 6041565.17 516891.92 N 70 31 29.08 W 149 51 42.05 6740.71 74.52 6.18 3372.12 5087.79 N 5086.56 E 173.52 2.19 6041655.86 516901.31 N 70 31 29.97 W 149 51 41.76 6835.97 74.27 5.88 3397.74 5179.11 N 5177.80 E 183.16 0.40 6041747.11 516910.74 N 70 31 30.87 W 149 51 41.48 • 6931.70 73.46 4.42 3424.35 5270.75 N 5269.39 E 191.41 1.69 6041838.71 516918.79 N 70 31 31.77 W 149 51 41.24 7024.91 73.55 3.69 3450.81 5359.95 N 5358.54 E 197.73 0.76 6041927.86 516924.91 N 70 31 32.65 W 149 51 41.05 7121.31 73.61 1.78 3478.06 5452.34 N 5450.89 E 202.14 1.90 6042020.22 516929.11 N 70 31 33.55 W 149 51 40.92 7218.28 73.18 2.75 3505.78 5545.22 N 5543.75 E 205.82 1.06 6042113.07 516932.57 N 70 31 34.47 W 149 51 40.81 7313.21 74.19 3.18 3532.44 5636.24 N 5634.73 E 210.53 1.15 6042204.06 516937.08 N 70 31 35.36 W 149 51 40.67 7408.43 74.31 0.86 3558.29 5727.84 N 5726.31 E 213.76 2.35 6042295.64 516940.10 N 70 31 36.26 W 149 51 40.58 7504.59 74.32 359.22 3584.29 5820.41 N 5818.89 E 213.82 1.64 6042388.20 516939.96 N 70 31 37.17 W 149 51 40.57 7600.69 74.42 358.34 3610.18 5912.92 N 5911.41 E 211.85 0.89 6042480.71 516937.78 N 70 31 38.08 W 149 51 40.63 7695.92 74.49 356.71 3635.71 6004.54 N 6003.07 E 207.89 1.65 6042572.35 516933.61 N 70 31 38.98 W 149 51 40.75 7792.22 74.81 356.04 3661.20 6097.17 N 6095.75 E 202.02 0.75 6042665.01 516927.53 N 70 31 39.90 W 149 51 40.92 7888.48 75.49 356.15 3685.87 6189.95 N 6188.57 E 195.68 0.72 6042757.81 516920.99 N 70 31 40.81 W 149 51 41.11 7981.95 74.31 356.57 3710.22 6279.96 N 6278.63 E 189.95 1.33 6042847.85 516915.05 N 70 31 41.69 W 149 51 41.28 8079.31 76.86 355.74 3734.45 6373.98 N 6372.71 E 183.63 2.75 6042941.90 516908.52 N 70 31 42.62 W 149 51 41.46 8175.30 78.60 356.83 3754.85 6467.52 N 6466.30 E 177.55 2.13 6043035.47 516902.23 N 70 31 43.54 W 149 51 41.64 8270.62 81.30 358.44 3771.49 6561.25 N 6560.07 E 173.68 3.28 6043129.22 516898.15 N 70 31 44.46 W 149 51 41.76 8366.69 82.53 357.83 3785.00 6656.29 N 6655.13 E 170.59 1.43 6043224.26 516894.84 N 70 31 45.40 W 149 51 41.85 8462.44 82.01 358.04 3797.88 6751.07 N 6749.95 E 167.17 0.58 6043319.06 516891.21 N 70 31 46.33 W 149 51 41.95 8558.12 81.43 357.96 3811.66 6845.67 N 6844.57 E 163.87 0.61 6043413.67 516887.69 N 70 31 47.26 W 149 51 42.05 Drilling Office 2009.1.726.0 Nikartchug101iktok Poin6OPO4- P071OPO4-071OPO407 Field 6112/2010 5 11 AM Page 2 of 3 Comments MD Inc! Azim True TVD VSEC NS EW DLS Northing Easting Latitude Longitude (ft) (°) r) (ft) (ft) (N /S ft) (ENV ft) ( °I100ft) (ftUS) (ftUS) (NIS ° "') (EIW ° "') 8654.72 81.68 357.57 3825.84 6941.11 N 6940.05 E 160.14 0.48 6043509.13 516883.75 N 70 31 48.20 W 149 51 42.16 8686.40 82.88 358.11 3830.10 6972.47 N 6971.42 E 158.96 4.15 6043540.49 516882.50 N 70 31 48.51 W 149 51 42.19 8736.74 83.36 359.18 3836.13 7022.42 N 7021.38 E 157.77 2.32 6043590.45 516881.21 N 70 31 49.00 W 149 51 42.23 BHA 6 (8 1/2 ") 8828.76 83.65 359.19 3846.54 7113.83 N 7112.80 E 156.47 0.32 6043681.86 516879.70 N 70 31 49.90 W 149 51 42.26 8923.62 84.45 0.01 3856.37 7208.17 N 7207.15 E 155.82 1.20 6043776.19 516878.83 N 70 31 50.83 W 149 51 42.28 9019.29 88.12 359.44 3862.57 7303.61 N 7302.60 E 155.36 3.88 6043871.63 516878.15 N 70 31 51.76 W 149 51 42.30 9112.76 90.38 35928 3863.79 7397.05 N 7396.05 E 154.31 2.42 6043965.07 516876.90 N 70 31 52.68 W 149 51 42.33 9210.88 89.52 357.35 3863.88 7495.10 N 7494.12 E 151.43 2.15 6044063.12 516873.79 N 70 31 53.65 W 149 51 42.41 9306.82 89.24 357.95 3864.92 7590.92 N 7589.98 E 147.49 0.69 6044158.96 516869.64 N 70 31 54.59 W 149 51 42.53 9402.49 89.90 358.48 3865.63 7686.51 N 7685.60 E 144.51 0.88 6044254.56 516866.45 N 70 31 55.53 W 149 51 42.62 9498.41 90.10 357.79 3865.63 7782.35 N 7781.46 E 141.39 0.75 6044350.41 516863.11 N 70 31 56.47 W 149 51 42.71 9594.44 89.47 357.34 3865.99 7878.26 N 7877.41 E 137.31 0.81 6044446.33 516858.82 N 70 31 57.42 W 149 51 42.83 9689.09 88.89 357.90 3867.35 7972.78 N 7971.96 E 133.38 0.85 6044540.87 516854.67 N 70 31 58.35 W 149 51 42.94 9785.47 88.43 356.69 3869.60 8068.98 N 8068.21 E 128.84 1.34 6044637.10 516849.91 N 70 31 59.29 W 149 51 43.08 9880.19 88.34 355.13 3872.27 8163.36 N 8162.65 E 122.08 1.65 6044731.51 516842.95 N 70 32 0.22 W 149 51 43.28 9976.98 88.51 354.68 3874.93 8259.66 N 8259.02 E 113.49 0.50 6044827.85 516834.14 N 70 32 1.17 W 149 51 43.53 10072.57 87.22 353.54 3878.49 8354.60 N 8354.03 E 103.69 1.80 6044922.84 516824.12 N 70 32 2.10 W 149 51 43.82 10167.62 87.02 353.68 3883.27 8448.85 N 8448.37 E 93.12 0.26 6045017.14 516813.34 N 70 32 3.03 W 149 51 44.13 10259.96 87.19 355.46 3887.93 8540.58 N 8540.18 E 84.40 1.93 6045108.92 516804.41 N 70 32 3.94 W 149 51 44.39 10359.04 87.62 355.83 3892.42 8639.21 N 8638.87 E 76.88 0.57 6045207.58 516796.67 N 70 32 4.91 W 149 51 44.61 10454.32 87.74 355.71 3896.28 8734.09 N 8733.81 E 69.86 0.18 6045302.50 516789.44 N 70 32 5.84 W 149 51 44.82 10550.49 88.51 354.67 3899.42 8829.80 N 8829.59 E 61.80 1.35 6045398.25 516781.16 N 70 32 6.78 W 149 51 45.05 10645.92 90.07 355.62 3900.61 8924.81 N 8924.67 E 53.72 1.91 6045493.30 516772.88 N 70 32 7.72 W 149 51 45.29 10742.59 87.85 357.21 3902.36 9021.22 N 9021.12 E 47.68 2.82 6045589.73 516766.62 N 70 32 8.67 W 149 51 45.47 10838.23 87.11 357.19 3906.57 9116.61 N 9116.56 E 43.01 0.77 6045685.14 516761.73 N 70 32 9.60 W 149 51 45.61 10934.21 86.59 358.96 3911.84 9212.36 N 9212.33 E 39.79 1.92 6045780.90 516758.30 N 70 32 10.55 W 149 51 45.70 11029.84 86.13 0.98 3917.91 9307.78 N 9307.76 E 39.74 2.16 6045876.32 516758.03 N 70 32 11.48 W 149 51 45.71 11125.25 87.48 3.83 3923.23 9402.98 N 9402.93 E 43.74 3.30 6045971.49 516761.82 N 70 32 12.42 W 149 51 45.59 11220.91 87.91 5.58 3927.08 9498.29 N 9498.19 E 51.58 1.88 6046066.75 516769.44 N 70 32 13.36 W 149 51 45.36 11316.27 87.16 6.36 3931.18 9593.12 N 9592.94 E 61.49 1.13 6046161.52 516779.14 N 70 32 14.29 W 149 51 45.06 11411.51 84.59 4.45 3938.03 9687.75 N 9687.50 E 70.44 3.36 6046256.09 516787.87 N 70 32 1522 W 149 51 44.80 11506.14 84.56 2.85 3946.98 9781.81 N 9781.51 E 76.44 1.68 6046350.10 516793.66 N 70 32 16.14 W 149 51 44.62 11603.03 87.79 3.73 3953.44 9878.35 N 9878.01 E 81.98 3.45 6046446.61 516798.99 N 70 32 17.09 W 149 51 44.46 11698.05 91.50 5.04 3954.03 9973.13 N 9972.73 E 89.25 4.14 6046541.33 516806.04 N 70 32 18.02 W 149 51 44.24 11792.93 92.34 3.33 3950.85 10067.75 N 10067.30 E 96.17 2.01 6046635.91 516812.74 N 70 32 18.95 W 149 51 44.04 11887.18 92.05 0.89 3947.24 10161.88 N 10161.41 E 99.64 2.61 6046730.02 516816.00 N 70 32 19.88 W 149 51 43.94 11986.89 92.65 0.10 3943.15 10261.51 N 10261.03 E 100.50 0.99 6046829.63 516816.63 N 70 32 20.86 W 149 51 43.91 12081.01 92.85 359.62 3938.64 10355.52 N 10355.04 E 100.27 0.55 6046923.63 516816.19 N 70 32 21.78 W 149 51 43.92 Projection to TD 12144.00 92.85 359.62 3935.50 10418.42 N 10417.96 E 99.85 0.00 6046986.53 516815.63 N 70 32 22.40 W 149 51 43.93 Survey Type: Def Survey Survey Error Model: ISCWSA Rev 0 *** 3-D 95.000% Confidence 2.7955 sigma Survey Program: MD From MD To EOU Freq (ft) Survey Tool Type Borehole I Survey (ft) (ft) 0.000 41.160 Act Stns SLB_NSG +SSHOT -Depth Only OPO4-07 / OPO4-07 Field 41.160 837.000 Act Stns SLB_NSG +SSHOT OPO4 -07 / OPO4-07 Field 837.000 12081.010 Act Stns SLB_MWD +GMAG OPO4 -07 / OPO4-07 Field 12081.010 12144.000 Act Stns SLB BLIND OPO4-07 / OPO4-07 Field Dolling Office 2009.1.726 0 Nikadchuq\Okktok PainlWPO4- P07\0PO4-07\OPO4 -07 Field 6/12/2010 5 11 AM Page 3 of 3 Welibore J o D ate 0PO4 -07 + I COMPLETION, 6/15/2010 " <now> Well tyr ftKB (MD) ftKB (TVD) Inc! Schematic - Actual Frm Frog -1 32 32 0.1 _ , 35 35 0.1 I 37 37 0.1 41 41 0.1 120 120 0.3 ab- 125 125 0.3 720 719 9.7 - c v_a 7?n S sV 7 8 __ 1,273 1,235 32.4 , _ .- .V9-011, 2,158 1,924 48.5 1 ,901 2,171 1.933 48.9 Ugnu Top 2,331 2,031 55.4 9 -- (UG4), 2,335 2,034 55.6 2,331 2,419 2,078 58.8 13 i 2,421 2,079 58.8 UG -2 Coal i Par! 3,773 2,523 73.8 1 - L Ugnu, 6,339 3,247 73.6 1rktirsirlar N Rand Fa' ,11 7,475 3,576 74.3 Sand e 7,583 3,605 74.4 Top 7,662 3,627 74.5 1 7,583 7,675 3,630 74.5 1 7 0 1 ir ,737 3,646 74.6 N Sand Bottom, 7,757 3,652 74.7 7,741 7,765 3,654 74.7 7,814 3,667 75.0 0 fir 0 7,826 3,670 75.1 7,844 3,674 75.2 7,862 3,679 75.3 0 0 7,865 3,680 75.3 OA Sand Top 8,518 3,806 81.7 . Iii 8,451 8,604 3,818 81.5 8,645 3,824 81.7 AO rA OA 8,714 3,833 83.1 8,727 3,835 83.3 t � 8,922 3,856 64.4 1 f I rj 9,707 3,868 88.8 j 10,487 3,897 88.0 i 11,316 3,931 67.2 j 1 2,140 3,936 92.9 j Li 12,144 � __......._.. • • Scblumberger Drillin.g & Measurements MWD /LWD Log Product Delivery Customer ENI US Operating Co. Inc. Alaska Dispatched To: Christine Mahnken Well No 0 P0.4- 07/0PO4 -07PB1 Date Dispatched: 2- Jul -10 Installation /Rig Nabors 245E Dispatched By: Paul Wyman No Of Prints No of CDs Data 1 OPO4 -07 - Logs: 1 2 in MD 1 2inTVD 1 OPO4 -07PB1 - Logs: 1 2 in MD 1 2 in TVD RE-0E1\1ED jut 0 6.2010 Arecno Please sign and return one copy to: Received By: D&M, 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 ���rmanC�slb.com Paul Wyman Fax: 907-561-8317 LWD Log Delivery V2.1, 03 -06 -06 • • [E DT ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co Inc. 3800 Centerpoint Dr., Ste 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Nikaitchuq Undefined Oil Pool, OPO4 -07 ENI US Operating Co Inc. Permit No: 208 -199 (Re- Issue) Surface Location: 3216' FSL, 1541' FEL, S5, T13N, R9E, UM Bottomhole Location: 3002' FSL, 1426' FEL, S29, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. This permit supersedes the permit previously issued to you on December 19, 2008. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. di< Chair DATED this ) ` day of April, 2010 cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via - email) STATE OF ALASKA ,K, ars 5 &i• c RECEW ALACA OIL AND GAS CONSERVATION COMMWON PERMIT TO DRILL APR 1 4 2010 20 AAC 25.005 la. Type of Work: lb. Proposed Well Class: Development - Oil - 0 • Service - Winj El Single Single Zone ❑ 1iS Drill El • Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ftcharaWdrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket is Single Well ❑ 11. Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 OPO4 -07 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 3800 Centerpoint Drive Suite 300, Anchorage 99503 MD: 11975' , TVD: 3940' ' Nikaitchuq . 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 3216' FSL, 1541' FEL, S5 T13N R9E UM • ADL 355024, 373301, 390616 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4216' FSL, 1371' FEL, S32 T14N R9E UM ADL 417493 5/10/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3002' FSL, 1426' FEL, S29 T14N R9E UM 1280 4708' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: "5: )2'ket 15. Distance to Nearest Well Open Surface: x- 516739 • y- 6036569 , Zone- 4 GL Elevation above MSL: p c 12 feet to Same P 2277 East 0P03 -P05 !�` o =r.� / 'isJ 0 to t '' ; -0`f . 16. Deviated wells: Kickoff depth: 300 feet • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) 4 /.) Maximum Hole Angle: 90° degrees Downhole: 1658 psig . Surface: 1255 psig . 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 84 36 36 120 120 pre - installed 16" 13 -3/8" 68 L -80 BTC 2618 35 35 2653 • 2072 502 sx 10.7# ASL, 220 sx 12.0# Deeperete 12.25" 9 -5/8" 47 L -80 BTCM 8455 33 33 8488'- 3812 426 sx 12.5# Deeperete 8.5" 5.5" 17 L -80 DWC 3687 8288 3790 11975 3940 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface _ Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat El BOP Sketch El Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch El Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907 - 865 -3321 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature I (v/vU r Phone Date Oi 10 Commission Use Only Permit to Drill ...,,,+�1� 'll�� • API Number: `°ermit App va See cover letter for other Number: L� (� I 50 -o -- �46`j -dC Sate: ; 1 01 O 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: ,(L 356 /S4 i3Or 7 .j T Samples req'd: Yes E No Mud log req'd: Yes ❑ No p' H measures: Yes L _, No 2 Directional svy req'd: Yes Q No ❑ 42 sod. r •s.. Av, rt. La.f.". Te51 yc t ti -rte � rf . - i 5(, e les {' .1",..„ 4 ✓� _4.7 01 Less •c iere0a� / 6 a en; s s :ac., a _ APPROVED BY THE COMMISSION /+ DATE: • AII l IPPI P"• , COMMISSIONER y• IC, •Io A 5f is.(n ORIGINAL .6 ' '' * 4‘ , 1 /f s' a Form 10 - 401 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate =1 • • Enil tiroIIeum REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 REVISION - Application for Permit to Drill Document Producer Well OPO4 -07 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AA C 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005 (c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005 (c)(9) 6 10. Seismic Analysis 6 Requirements of 20 AA C 25.005 (c)(10) 6 11. Seabed Condition Analysis 6 0PO4 -P07 PERMIT Document doc Page 1 of 7 Printed: 12- Apr -10 . riot • • • Enli REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 Requirements of 20 AAC 25.005 (c)(11) 6 12. Evidence of Bonding 6 Requirements of 20 AAC 25.005 (c)(12) 6 13. Proposed Drilling Program 6 Requirements of 20 AAC 25.005 (c)(13) 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005 (c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 BOP and Diverter Configuration 7 Attachment 4 Cement Loads and CemCADE Summary 7 Attachment 5 Well Schematic 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. REVISED Well Name: OPO4 -07 The well for which this REVISION Application is submitted requests to change the name to OPO4 -07. The original application referred to the well as OPO4 -P07. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applicat /on for a Perm /t 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 3216' FSL, 1541' FEL, S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2' AMSL Northings 6,036,569 Eastings: 516,739' Pad Elevation 12' AMSL OPO4 -P07 PERMIT Document.doc Page 2 of 7 Printed: 12- Apr -10 • t; • Enhl tIrII REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 Location at Top of Productive Interval 4216' FSL, 1371' FEL, S32 T14N R9E UM ( "OA" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8,399' Northings: 6,042,849' Eastings: 516,875' Total Vertical Depth, RKB: 3,803' Total Vertical Depth, SS :: 3,750' Location at Total Depth 3002' FSL, 1426' FEL, S29 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 11,975' Northings: 6,046,914' Eastings: 516,799' Total Vertica/ Depth, RKB: 3,940' Total Vertical Depth, SS: 3,887' Please see Attachment 7: Surface Platt and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AA C 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10 -401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed we //bore, including all adjacent wel /bores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (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 0.44 psi /ft, or 8.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the OA sand formation is 1,255 psi: OPO4 -P07 PERMIT Document.doc Page 3 of 7 Printed: 12- Apr -10 1 • n II �I111 1 REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 MPSP = (3,803 ft TVD)(0.44 - 0.11 psi /ft) = 1,255 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 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) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X -65 Welded 120 0 / 0 1207 120' Cemented to surface Cemented to Surface with 502 sx 10.7# ASLite Lead Yield 4.33 cu. Ft./ sk, 13 -3/8 16 68 L -80 BTC 2653' 0 / 0 2653' / 2072' 220 sx 12.0# DeepCRETE Tail Yield 1.60 cu. ft./ sk Cement Top planned @ 6920' MD / 3420' TVD Cemented w/ 9 -5/8 12 -1/4 47 L -80 BTCM 8488' 0 / 0 8488' / 3812' 426 sx 12.5# DeepCRETE Yield 1.52 cu. ft./ sk 8 -1/2" OA 5 -1/2 Sand 17 L -80 DWC 3687' 8288' / 3793' 119757 3940' Slotted Liner - no cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fol lowing items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); OPO4 -P07 PERMIT Document.doc Page 4 of 7 Printed: 12- Apr -10 • Viget Enil . tr ll uin • REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 Please see Attachment 3: BOP and Diverter Configuration A 21 -1/4 ", 2000 psi diverter with a 16" diameter diverter line and valve will be the diverter system used for drilling the surface hole. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling flu /d system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy (CP) 30 55 15 20 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 (LSND) Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 13- 3 /8 "Csg Shoe to 9- 5 /8 "Csg Point Value Value Density (ppg) 9.0 — 9.3 Density (ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity (CP) 45 - 60 (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 - 18 (lb /100 sf) (CP) HTHP Fluid loss Yield Point 18-24 (m1/30 min @ <5.0 (Ib /1 00 sf) 200psi & 100 °F API Filtrate Oil / Water Ratio 75 / 25 (cc / 30 min)) 4 - 6 Electrical >600 Chlorides (mg /1) <500 Stability pH 9.0 — 10.0 MBT <18.0 n with appropriate re Drilling fluid practices will be in accordance t regulations stated in 20 AAC 25.033. g OPO4 -P07 PERMIT Document.doc Page 5 of 7 Printed: 12- Apr -10 • • ent Enii • 1 r tirIIeurn REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25033(0; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom- founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding }have been met; Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. Install 21 -1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3. Run and cement 13 -3/8 ", 68 #, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. Remove diverter system, install and test wellhead to 5000 PSI. 5. Nipple up 13 -5/8" 5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12 -1/4" bit and 8" directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 0PO4 -P07 PERMIT Document.doc Page 6 of 7 Printed: 12- Apr -10 VI Ilk • • • Ern tiroII 11I1 REVISED Application for Permit to Drill Well OPO4 -07 Saved: 12- Apr -10 9. Directionally drill to 9 -5/8" casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Run and cement 9 -5/8 ", 47# L80, BTC Mod casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 11. Install 9 -5/8" packoff and test to 5000 psi. 12. Flush 13 -3/8" x 9 -5/8" annulus with water, followed by diesel freeze protect. 13. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 14. PU 8 -1/2" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 15. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. 16. Directionally drill 8 -1/2" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 17. PU and run 5 -1/2" slotted liner to TD. 18. Land liner, set liner hanger with 200' Liner lap inside the 9 -5/8" intermediate casing. POOH laying down DP as required. 19. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 20. Nipple down BOP, nipple up tree and test. Pull BPV. 21. Freeze protect well with diesel by pumping into 4 -1/2" x 9 -5/8" annulus, taking returns from tubing. 22. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt OPO4 -P07 PERMIT Document.doc Page 7 of 7 Printed: 12- Apr -10 Eni Petroleum Schlumberger OPO4 -07 (P9) Proposal Report Date: 31- Mar -10 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 0.460° Field: Nikaitchuq - Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Oliktok Point / OPO4 St Ud TVD Reference Datum: Rotary Table Well: OPO4 -07 s! b;' TVD Reference Elevation: 53.20 ft relative to MSL . Borehole: OPO4 -07 Fe Sea Bed / G r ound Level Elevation: 12.20 ft relative to MSL UWI /API#: 500292340900 Magnetic Declination: 21.703° Survey Name / Date: OPO4 -07 (P9) / March 31, 2010 Total Field Strength: 57672.339 nT Tort / AHD / DDI / ERD ratio: 112.810° / 10348.50 ft / 6.550 / 2.626 Magnetic Dip: 80.954° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: 20- May -10 • Location Lat/Long: N 70.51109602, W 149.86302152 Magnetic Declination Model: BGGM 2009 Location Grid N/E YIX: N 6036569.440 ftUS, E 516739.270 ftUS North Reference: True North Grid Convergence Angle: +0.12913048° Total Corr Mag North -> True North: +21.703° Grid Scale Factor: 0.99990032 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag / Gray Directional Zone Of Zone Of Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Depth True Section True North True North Tool Face Difficulty Exclusion Exclusion (ft ) I (deft) (deg) I (ft) (ft) I (ft) (ft) (ft) ( (deg) I (deg/100ft) Index (deg) Alert (ftUS) (ftUS) RTE 0.00 0.00 359.71 -53.20 0.00 0.00 0.00 0.00 - -- 0.00 0.00 9.04 Alert 6036569.44 516739.27 WRP 41.00 0.00 359.71 -12.20 41.00 0.00 0.00 0.00 - -- 0.00 0.00 9.04 Alert 6036569.44 516739.27 KOP Bld 1.5/100 300.00 0.00 359.71 246.80 300.00 0.00 0.00 0.00 359.71M 0.00 0.00 9.04 Alert 6036569.44 516739.27 Bld 3.5/100 400.00 1.50 359.71 346.79 399.99 1.31 1.31 -0.01 359.71M 1.50 0.29 7.67 Alert 6036570.75 516739.26 500.00 5.00 359.71 446.61 499.81 6.98 6.98 -0.04 HS 3.50 1.54 4.78 Fail 6036576.42 516739.22 600.00 8.50 359.71 545.90 599.10 18.73 18.73 -0.09 HS 3.50 2.20 3.37 Fail 6036588.17 516739.13 700.00 12.00 359.71 644.29 697.49 36.52 36.52 -0.18 HS 3.50 2.64 4.93 Fail 6036605.96 516739.00 Gyro Point 800.00 15.50 359.71 741.41 794.61 60.28 60.28 -0.31 HS 3.50 2.97 7.86 Alert 6036629.72 516738.83 900.00 19.00 359.71 836.90 890.10 89.93 89.93 -0.46 HS 3.50 3.24 11.12 6036659.36 516738.61 1000.00 22.50 359.71 930.40 983.60 125.35 125.36 -0.63 HS 3.50 3.46 14.49 6036694.78 516738.35 SV3 1037.64 23.82 359.71 965.00 1018.20 140.15 140.16 -0.71 HS 3.50 3.53 15.77 6036709.58 516738.24 • 1100.00 26.00 359.71 1021.56 1074.76 166.41 166.42 -0.84 HS 3.50 3.65 17.91 6036735.84 516738.05 1200.00 29.50 359.71 1110.04 1163.24 212.96 212.98 -1.08 HS 3.50 3.81 21.36 6036782.39 516737.71 SV2 1269.75 31.94 359.71 1170.00 1223.20 248.59 248.60 -1.26 HS 3.50 3.92 23.77 6036818.01 516737.45 1300.00 33.00 359.71 1195.52 1248.72 264.83 264.84 -1.34 HS 3.50 3.96 24.82 6036834.25 516737.33 1400.00 36.50 359.71 1277.67 1330.87 321.81 321.83 -1.63 HS 3.50 4.09 28.29 6036891.24 516736.92 Cry 2/100 1489.33 39.63 359.71 1348.00 1401.20 376.88 376.90 -1.91 HS 3.50 4.20 31.39 6036946.30 516736.51 1500.00 39.84 359.71 1356.20 1409.40 383.69 383.72 -1.94 HS 2.00 4.21 31.60 6036953.12 516736.46 1600.00 41.84 359.71 1431.85 1485.05 449.08 449.11 -2.27 HS 2.00 4.31 33.59 6037018.50 516735.98 1700.00 43.84 359.71 1505.18 1558.38 517.07 517.10 -2.62 HS 2.00 4.39 35.58 6037086.48 516735.49 1800.00 45.84 359.71 1576.08 1629.28 587.57 587.61 -2.97 HS 2.00 4.47 37.57 6037156.98 516734.97 WellDesign Ver SP 2.1 Bld( users) OPO4 \0PO4- 07\0PO4- 07\OPO4 -07 (P9) Generated 3/31/2010 11:42 AM Page 1 of 3 Measured Azimuth Vertical NS EW Mag / Gray Directional Zone 0f Zone Of Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Depth True Section True North True North Tool Face Difficulty Exclusion Exclusion P Y _ (ft) (deg) (deg) (ft ) (ft) (ft) (ft) (ft) (deg) (deg/100ft ) Index (deg) Alert (ftUS) (ftUS) 1900.00 47.84 359.71 1644.48 1697.68 660.50 660.55 -3.34 HS 2.00 4.55 39.56 6037229.92 516734.44 SV1 1942.85 48.70 359.71 1673.00 1726.20 692.48 692.53 -3.51 HS 2.00 4.58 40.42 6037261.89 516734.20 2000.00 49.84 359.71 1710.29 1763.49 735.78 735.83 -3.72 HS 2.00 4.62 41.55 6037305.19 516733.89 Base Perm 2022.91 50.30 359.71 1725.00 1778.20 753.35 753.40 -3.81 HS 2.00 4.63 42.01 6037322.76 516733. Cry 4/100 2059.20 51.02 359.71 1748.00 1801.20 781.41 781.47 -3.96 5.45R 2.00 4.66 42.73 6037350.82 516733.55 2100.00 52.65 359.90 1773.21 1826.41 813.49 813.55 -4.06 5.33R 4.00 4.69 44.34 6037382.89 516733.37 2200.00 56.63 0.35 1831.07 1884.27 895.02 895.08 -3.87 5.07R 4.00 4.77 48.28 6037464.42 516733.38 2300.00 60.62 0.75 1883.12 1936.32 980.38 980.44 -3.05 4.86R 4.00 4.85 52.23 6037549.77 516734.02 2400.00 64.60 1.13 1929.12 1982.32 1069.15 1069.20 -1.58 4.69R 4.00 4.92 56.19 6037638.52 516735.28 Top Ugnu (UG4) 2489.60 68.18 1.44 1965.00 2018.20 1151.23 1151.27 0.27 4.56R 4.00 4.99 59.73 6037720.59 516736.94 2500.00 68.59 1.48 1968.83 2022.03 1160.90 1160.93 0.51 4.55R 4.00 4.99 60.14 6037730.25 516737.17 End Cry 2574.40 71.56 1.73 1994.18 2047.38 1230.82 1230.84 2.47 - -- 4.00 5.04 63.09 6037800.16 516738.97 13 -3/8" Csg 2652.84 71.56 1.73 2019.00 2072.20 1305.22 1305.22 4.72 - -- 0.00 5.08 63.09 6037874.54 516741.05 UG -2 Coal Bed 4173.28 71.56 1.73 2500.00 2553.20 2747.22 2746.92 48.23 -- 0.00 5.51 63.09 6039316.18 516781.31 L Ugnu 6446.04 71.56 1.73 3219.00 3272.20 4902.72 4901.97 113.28 - -- 0.00 5.84 63.10 6041471.15 516841.49 Schrader Bluff 7116.17 71.56 1.73 3431.00 3484.20 5538.28 5537.39 132.46 - -- 0.00 5.91 63.10 6042106.55 516859.24 Cry 4/100 7604.17 71.56 1.73 3585.38 3638.58 6001.09 6000.11 146.43 18.33L 0.00 5.95 63.10 6042569.25 516872.16 Top N Sand 7618.99 72.12 1.53 3590.00 3643.20 6015.18 6014.19 146.83 18.27L 4.00 5.96 63.67 6042583.34 516872.53 End Cry 7694.74 75.00 0.55 3611.44 3664.64 6087.82 6086.82 148.15 - -- 4.00 5.98 66.60 6042655.96 516873.68 Base N Sand 7778.06 75.00 0.55 3633.00 3686.20 6168.29 6167.30 148.92 - -- 0.00 5.99 66.60 6042736.43 516874.27 Tgt 1 Heel / Cry 2/100 7894.74 75.00 0.55 3663.20 3716.40 6281.00 6280.00 150.00 HS 0.00 6.00 66.60 6042849.12 516875.10 7900.00 75.11 0.55 3664.56 3717.76 6286.08 6285.08 150.05 HS 2.00 6.00 66.71 6042854.20 516875.14 8000.00 77.11 0.55 3688.57 3741.77 6383.15 6382.14 150.98 HS 2.00 6.02 68.71 6042951.26 516875.85 Fault 11 8063.24 78.37 0.55 3702.00 3755.20 6444.95 6443.94 151.57 HS 2.00 6.04 69.97 6043013.05 516876.31 8100.00 79.11 0.55 3709.18 3762.38 6481.00 6479.99 151.92 HS 2.00 6.04 70.70 6043049.09 516876.57 8200.00 81.11 0.55 3726.36 3779.56 6579.51 6578.49 152.87 HS 2.00 6.07 72.70 6043147.59 516877.29 8300.00 83.11 0.55 3740.10 3793.30 6678.55 6677.53 153.82 HS 2.00 6.09 74.70 6043246.62 516878.02 End Cry 8394.74 85.00 0.55 3749.91 3803.11 6772.78 6771.76 154.72 - -- 2.00 6.11 76.59 6043340.84 516878.71 9 -5/8" Csg 8395.85 85.00 0.55 3750.01 3803.21 6773.88 6772.86 154.73 - -- 0.00 6.11 76.59 6043341.94 516878.72 40 Cry 4/100 8414.74 85.00 0.55 3751.66 3804.86 6792.70 6791.68 154.91 141.28L 0.00 6.11 76.59 6043360.76 516878.86 End Cry 8488.22 82.71 358.70 3759.52 3812.72 6865.75 6864.73 154.43 - -- 4.00 6.13 74.41 6043433.80 516878.22 Cry 4/100 8785.51 82.71 358.70 3797.25 3850.45 7160.50 7159.54 147.73 16.87L 0.00 6.16 74.41 6043728.57 516870.85 8800.00 83.26 358.53 3799.02 3852.22 7174.87 7173.91 147.38 16.85L 4.00 6.16 74.98 6043742.94 516870.47 OP 07 Tgt 1 8845.33 85.00 358.00 3803.65 3856.85 7219.92 7218.98 146.01 20.63R 4.00 6.18 76.74 6043788.00 516869.00 8900.00 87.05 358.77 3807.44 3860.64 7274.42 7273.50 144.48 20.57R 4.00 6.19 78.74 6043842.50 516867.34 End Cry 8909.81 87.41 358.91 3807.92 3861.12 7284.22 7283.30 144.28 - -- 4.00 6.19 79.10 6043852.30 516867.12 Cry 4/100 9257.62 87.41 358.91 3823.60 3876.80 7631.54 7630.68 137.67 176.34R 0.00 6.23 79.10 6044199.64 516859.73 OP 07 Tgt 2 9293.05 86.00 359.00 3825.64 3878.84 7666.90 7666.05 137.02 135.69L 4.00 6.24 77.68 6044235.00 516859.00 End Cm 9298.65 85.84 358.84 3826.04 3879.24 7672.49 7671.63 136.91 - -- 4.00 6.24 77.53 6044240.58 516858.88 WellDesign Ver SP 2.1 Bld( users) OPO4 \OPO4- 07\0PO4- 07\0PO4 -07 (P9) Generated 3/31/2010 11:42 AM Page 2 of 3 7 Measured Azimuth Vertical NS EW Mag I Gray Directional Zone 0f Zone Of Comments Inclination True Section TVD Tw Section True North True North Tool Face DLS Difficulty Exclusion Exclusion Northing Easting Depth (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) I (deg) I (deg/100ft ) Index (deg) Alert (ftUS) (ftUS) Cry 4/100 9711.36 85.84 358.84 3855.98 3909.18 8083.94 8083.17 128.60 0.83R 0.00 6.28 77.53 6044652.06 516849.65 OP 07 Tgt 3 9740.37 87.00 358.86 3857.79 3910.99 8112.88 8112.12 128.02 0.36L 4.00 6.29 78.69 6044681.00 516849.00 End Cry 9793.48 89.12 358.85 3859.59 3912.79 8165.95 8165.19 126.96 - -- 4.00 6.30 80.81 6044734.07 516847.82 Cry 4/100 10184.47 89.12 358.85 3865.56 3918.76 8556.73 8556.05 119.09 173.92R 0.00 6.34 80.81 6045124.87 516839.07 OP 07 Tgt 4 10187.60 89.00 358.86 3865.61 3918.81 8559.86 8559.18 119.03 170.41L 4.00 6.34 80.68 6045128.00 516839.00 End Cry 10190.17 88.90 358.84 3865.66 3918.86 8562.43 8561.75 118.98 - -- 4.00 6.34 80.58 6045130.57 516838.94 Cry 4/100 10606.27 88.90 358.84 3873.66 3926.86 8978.28 8977.69 110.58 2.97R 0.00 6.38 80.59 6045546.44 516829.61 OP 07 Tgt 5 10633.84 90.00 358.90 3873.92 3927.12 9005.84 9005.25 110.03 1.04L 4.00 6.38 81.68 6045574.00 516829.00 10700.00 92.65 358.85 3872.39 3925.59 9071.96 9071.38 108.74 1.04L 4.00 6.40 84.33 6045640.12 516827.55 End Cry 10715.88 93.28 358.84 3871.57 3924.77 9087.80 9087.23 108.42 - -- 4.00 6.41 84.96 6045655.96 516827.20 Cry 4/100 10999.53 93.28 358.84 3855.34 3908.54 9370.88 9370.35 102.69 179.66R 0.00 6.43 84.96 6045939.05 516820.83 11000.00 93.26 358.84 3855.31 3908.51 9371.35 9370.83 102.68 179.66R 4.00 6.43 84.94 6045939.52 516820.82 OP 07 Tgt 6 11081.55 90.00 358.86 3852.99 3906.19 9452.82 9452.32 101.04 178.85R 4.00 6.45 81.68 6046021.00 516819.00 11100.00 89.26 358.87 3853.11 3906.31 9471.27 9470.76 100.68 178.85R 4.00 6.46 80.95 6046039.44 516818.59 End Cry 11122.52 88.36 358.89 3853.58 3906.78 9493.78 9493.28 100.24 - -- 4.00 6.46 80.05 6046061.95 516818.10 Cry 4/100 11481.22 88.36 358.89 3863.83 3917.03 9852.19 9851.76 93.31 28.59L 0.00 6.49 80.05 6046420.38 516810.37 11500.00 89.02 358.53 3864.26 3917.46 9870.96 9870.53 92.89 28.58L 4.00 6.50 80.73 6046439.15 516809.91 OP 07 Tgt 7 11527.87 90.00 358.00 3864.50 3917.70 9898.80 9898.38 92.05 163.67R 4.00 6.50 81.74 6046467.00 516809.00 11600.00 87.23 358.81 3866.24 3919.44 9970.86 9970.46 90.04 163.65R 4.00 6.52 78.92 6046539.06 516806.83 End Cry 11610.83 86.82 358.93 3866.80 3920.00 9981.67 9981.27 89.83 - -- 4.00 6.52 78.50 6046549.88 516806.59 TD 11975.64 86.82 358.93 3887.07 • 3940.27 10345.78 10345.45 83.05 - -- 0.00 6.55 78.50 6046914.00 516799.00 Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From (ft ) MD To ( ft 1 EOU Freq Survey Tool Type Borehole -> Survey 0.00 41.00 1/100.00 SLB_NSG +SSHOT -Depth Only OPO4 -P07 -> OPO4 -P07 (P9) 41.00 800.00 1/100.00 SLB_NSG +SSHOT OPO4 -P07 -> OPO4 -P07 (P9) 800.00 2652.84 1/100.00 SLB_MWD +GMAG^^1 OPO4 -P07 -> OPO4 -P07 (P9) 2652.84 8395.85 1/100.00 SLB_MWD +GMAG^ ^2 OPO4 -P07 -> OPO4 -P07 (P9) IIIII 8395.85 11975.64 1/100.00 SLB +GMAG^ ^3 OPO4 -P07 -> OPO4 -P07 (P9) Legal Description: - Northing (Y) IftUSI Easting (X) IftUSI Surface : 3216 FSL 1541 FEL S5 T13N R9E UM • 6036569.44 516739.27 Tgt Heel : 4216 FSL 1371 FEL S32 T14N R9E UM 6042849.12 516875.10 TD / BHL : 3002 FSL 1426 FEL S29 T14N R9E UM 6046914.00 516799.00 WellDesign Ver SP 2.1 Bld( users) OPO4 \OPO4- 07\OPO4- 07\0PO4 -07 (P9) Generated 3/31/2010 11:42 AM Page 3 of 3 1 _ , VA+ Eni m�nnw w-emmoneuwww ~~°°=I°°M°°~°~ g°°~ ~~ FIELD | FIELD | STRUCTURE �� PO4-07 (P9) � Nikaitchuq i Oliktok Point ����, ~ 50 955 �~ ���, �����"� �� ���� �~�° �= .�~~"=".�== "~°~ "'°~ `` ~°`^` �' °=~�= Casting 516739 27°= Scale Fact ""9990°'° = =~-- `~°~ 0 1200 2400 3600 4800 6000 7200 8400 9600 �� �� 0 mo 0 xvpvm,.w,00 13Idsnw Gyro Point —— m � 1200 --------�--------�-----------------'--------'--------'^--------�------- __^ _ __ 0 ** _ ��� �� � __^_____�~~~~__~~,,~~�__^___~~,~~~___'==~_'^--__--_'�_____'�'�_+----_---��--_---� 1200 c. W _____ � End Celt -------- ---------- � -- --- ---�i���' � ������ �--- ----------------------------------- ^--------- ---------------- z.'--- 1:„2.' .nu II cu as u40o • 2400 m --~--------�------- ..� � ----------'---'---'---'---'- o , ��� w,w� ,n ��� �_____________---_—___—_--- ..� ___—C��1� � Fault 11 o rv � __ — ___ — _' -----------�------------------------------- -�` �` -- �ar� 3600 � —� — ���� ' , -:haat-== End Cry � (P9) ��uw '� End u, ~~���� TO Om End Cry �,�,w �n"iv, 4 I Cry 4/100 mppmv,o 0 1200 2400 3600 4800 6000 7200 8400 9600 S I Ent Petroleum Schlumberger WELL FIELD STRUCTURE OPO4 -07 (P9) I Nikaitchuq Oliktok Point Magnetic Parameters Surface Location NN1327 Rlxeaa Slate Planes, Zone 04, US Feet Mia I0neous Motley. BGGM 2009 Dip. 80955° Date. June 30. 2010 Le N70 30 39 946 NoMYng 603656944MJS Grid Cony. 40.12913046° 510 ()Pod TVD Rat Rotary Table (53.2011 above MSL) Mag 0ec'. 421650° FS'. 57676.1 nT Lon. W1495146677 Easing'. 51673927 MSS Scale Fart: 09999003163 Plan OPO4 -07 (PS) Sloy Date'. -3000 -1500 0 1500 3000 5N1 Lease Line (616) 2 10500 a0 10500 •PO4 -07 (P9) End Cry .N OP P07 Tgt 7 Cry 4/100 S'A End Cry OP P07 Tgt 6 Cry 4/100 End Cry 9000 "OP P07 Tilt 5 9000 Cry 4/100 Cry 41100 OP P07 Tgt 4 End Cry End Cry OP P07 Tgt 3 Cry 4/100 End Cry 7500 OP PO i eo 7500 End Cry OP P07 Tgt 1 End Cry Cry Cry 4/100 9 -5/8" Csg A A End Cry A Fault 11 Z Tgt 1 11••I I Cry 2/100 6000 End Cry 6000 Cry 4/100 C 11 0) U I 4500 4 500 C V V V 3000 3000 NI Lease Lirie (615) 1 5N1 Lease Line (616) 2 1500 1 1500 EndC r Cry 41100 Cry 21100 Gyro Point 0 4{IdJ 01100 0 RTE KOP Bid 1.5/100 -3000 -1500 0 1500 3000 «< W Scale = 1(in):1500(ft) E »> • • S chlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OPO4 -07 Oriented EOU Dimension Field Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule Date: June 30, 2010 used: Minor Risk - Separation Factor North j 350 0 10 340 150 20 330 140 30 � 130 ••�. 320 01 120 40 ��. 1 10 310 40 100 . N 50 • 300 ` mi . ,, 90 il ivat 80 60 , �• iii • f i 70 AlY�� 290 • . 60 ��� � 70 �� *410 �•`� 5 V 4I ti i' ♦ �• 40 r 1 . � � 80 280 - . • . 30 0 ,A�— o iiig k. - �• o 90 ■ 11111 270' ���C/ r,;, :r �� , ' 141 i 0 ' , 260 iiI �. , 1t E lI1 : • ' - ' , 0:∎ /, �1 vn t4. . � , ` 100 4> 250 T. " � � r ao 4 k• � ` � o o, ® 110 ! . , 4,�,'. ,:• \ � o v Oliktok Point -1A -106 (P3) 240 : i.11`4 1 ��. kw.- �� ��!$k , � , � ° ,, 0 s 230. ) / 1 o � ■ 1 03- P05P62 210 ` ® �'OA6t -104 (P1) 20i 04 (P2b) .... 160 190 180 170 Well Ticks Type: MD on OPO4 -P07 (P9) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH = 50.00 ft 0 0 S chlumberger _ TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OPO4 -07 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule 1 Date: June 30, 2010 used: Minor Risk - Separation — "owI Factor North 350 0 10 340 30 20 33 30 320 - - --° 5 40 310 '� ` 50 300 60 „oil, „ 1 1 a `_ �liktok Point -1A -106 (P3) 290 � , �' 70 . ._ Olikt.k Point 1 -: ` 100,114 280 ' 5 _. iiim \� g 270 ���® 90 i ! 260 / � 014 \ "4 \ \ °' 100 a ll ;mkt g( 250 "� / 1 S °° 110 )k,1‘ 120 A Willi IW 240 1 4IN �,� 230 opp* OP03- P05PB2 0130 22M 140 Pir 210 4 150 • - I . • 200 " - OP05 (P3) 190 180 170 Well Ticks Type: MD on OPO4 -P07 (P9) Calculation Method: Nomral Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH = 10.00 ft Dr 'in! Hazards Sumlary 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 Ri sk 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 Drilling Hazards Summary.doc 12/10/2008 4:04:00 PM ( HYDRIL GK 13 -5/8 ANNULAR BOP " 5K PSI 4' -6V LATCHED HEAD 5K FLANGE CONNECTION I 54 -1/2" LENGTH J • -OM - 4" 10-= 4" 10,0001 WP CAMERON TYPE F" HYDRIL 13 -5/8" 5K PSI GATE VALVE MPL DOUBLE GATE 13' - 4�" I 3' - �" 4" 10,000 WP STUDDED CONNECTION 4" 10,000# WP HCR VALVE /8ENGH CAMERON HCR VALVE _41 - &.."- ■ DRILLING 42 -7" L SPOOL T 4" CHOKE LINE /11 + 11. \ C i a - 3" KILL LINE 2' -2" 13- 5/8 " -5K PSI FLANGED � I ■11 III �I 4 " -10K PSI FLANGED OUTLETS 4 " "- 26" EST. LENGTH 4" 10,0001 WP I -- � CAMERON TYPE r HYDRIL 13 -5/8" 5k PSI GATE VALVE I - _ __4_ MPL SINGLE GATE � _ - i 3'-04" FLANGED CONNECTION 36 -1/4" LENGTH • NABORS ALASKA RIG 245E 13-5/8" 5K Ai i USX ITATAVAME BOP STACK CONFIGURATION 0 25150 Ab1W UM9�M19191iyq A�AI -9n W/03 -169 9W- ""Cr NABORS ALASKA RIG 145E j mu BLOW-OUT PREVENTER 13 -5/8' SK STUDDED STACK CONFIGURATION MEN 13W O8 A dA A ISSUED J OE NSfOW - JOE /RIVED JOE ALSTOI W. A 9c9 11 i r Nr DEICRP11011 WYE 8/A 99[ 2OOS OK 215E_0001 -5K ' 1 of 1 I C ON NEC TOR 1 CELLAR 1' J I li" 1 f • 1 �!!� �� __ — WELL I HYDRIL G K 13 -5/8 ANNULAR BOP " 5K PSI — I I f I up 4' -61" LATCHED HEAD L' 5K FIANCE CONNECTION ; O I 1 I r 54 -1/2" LENGTH _ = 1 OM - - MO= c4* 11 r H1DRN. 13 -5/8" 5K PSI - CITE VALVE AFL DOUBLE G4TE 'T7ZIIII:;:' • ppp/ STUDDED CONNECTION CR ; CAMERON N VALVE _41 - - _ RON MR VAN LEN E 42 -7/8" GTH i '.:;:11 1 1::: 1 11 • • ;; • FrcR 1 I. 4• max LNJE I • I ` III \ 1 •� II 3' tali 1.11E IE DRIWNG SPOOL + 11 allb. �II _ - — - — 2' -Y 13 - 5/8" -5K PSI FLANGED 1 ∎1I � ilr III III 4 " -10K FLANGED OUTLETS 4'x3 4" 10.000/ we 1 1 I 1 HYDRIL 13 -5/8" 5k PSI ESIIMAIID CANYON + - J' -d• MPL SINGLE CATS 9• -0" LENGTH 041E VALVE � FLANGED CONNECIKOJ IVERIER LAVE - 1 36 -1/4" LENGTH is" D 13.5/8" 5K BOP STACK CONFIGURATION DIVERTER LINE ROUTING NABORS ALASKA RIG 245E ENI NIKAITCHUO PROJECT 21 -I/4" 2000 / WP SNAPPER 2. 000/ STU TOP BY 4' -4 /z" 21 -1/4" 2.000/ FLANGED BOTTOM • H2S TRIMMED ANNULAR OIERIER SYSTEM Z 3/18• �∎ SURFACE DIVERTER 16" -1501 FLG PIPING CONFIGURATION 2'-0 ` — IiII PLAN VIEW 1 111� 2• � 0• 24" DIA R WO= Iii .VOND 11.K°° �� `-16" KNIFE GATE A Nabors Akan 2 0 KM H ACTUATOR •r°mod•"+ r o M' '1vi1io 99503-2630 2' -0" P°°""T NN3ORS AIASIGI RIG 245E MU BOP STACK MID DIVERTER CONRGURAIVON - EM NIKAICHUO PROJECT SURFACE DIVERTER CONFIGURATION EWEN IN CISME WI 'PRIM BY iv. 9JULY08 A .14 JA ISSUED JOE ALSTON JOE A STON JOE ALSTON A "m It IP V 6QOP101 WEE 24 ' 1 N/A ONE JULY 20os 245E.0301 -w( IICHUO of 1 Nabors Alaska Drilling Rig - 245E Material List Item Description 1 -15 4- 1/16" 10M Cameron Manual Gate Valve 16 2- 1/16" 10M Cameron Manual Gate Valve A,B 4- 1/16" 10M Cameron H2 Manual Choke C 3-1/16 10M Shaffer Hydraulic Choke • . ' i ft- -- ow To Gas s►r. _` -1 -c ' 9 1 - 4 Bus © \ �q /0 , ) � `6 o till pill ( 0 I Of dor . m 1 To Sha 0 / � l ; OA �':. r Nit ' ' 'v. , . © Fro .w= '�� y BOPS `. _ op; . Legend QL White Handle Valves • aD Normally Open To Reserve `` ED Red Handle Valves Normally Closed - 'GODS Date: 6 -1 -01 Rev. 1 1 • Schlumberger C emCAD E * well cementing recommendation for 9 -5/8" Intermediate Casing Operator : Eni Petroleum Well : OPO4407 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr. Jason Brink Location : Nabors 245E Proposal No. : Draftv4 Service Point : Prudhoe Bay, Alaska Date Prepared : 4 -9 -2010 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 - 1700 E -Mail Address : tstafford©slb.com 4 04 Ilk* t� tx G 9 �UATE • Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger • • Client : Eni Petroleum Well : OPO4.07 SdIkerger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing la) Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8488.0 ft BHST : 85 degF Bit Size : 12 1/4 in (x 1000) psi OE1 20. in o- @ 120ft _ - - O Frac 2.5 • • • • • Pore Permafrost jam 0D 13.4 in r @26531t Shale OD 9.62 in S hale[ @ 8488ft Y o — o - o _ LC 03408 ft Shale y1 O O - Well Lithology Formation Press. Page 2 0PO4- P07.cfw , 04 -09 -2010: LoadCase 9 -5/8 Intermediate Casing la): Version wcs- cem453_10 i • • Client : Eni Petroleum Well : 0PO4 407 StiliNkrier String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Previous String MD OD Weight ID (ft) (in) (lb /ft) (in) 2653.0 13 3/8 68.0 12.415 Landing Collar MD : 8408.0 ft Casing /liner Shoe MD : 8488.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb /ft) (in) (psi) (psi) 8488.0 9 5/8 40.0 47.0 8.681 L -80 4760 6870 BTCM Page 3 0PO4 -P07 cfw, 04 -09 -2010 , LoadCase 9-5/8 Intermediate Casing (a) , Version wcs- cem453_10 le • i Client : Eni Petroleum Well : 0PO4 -107 String : 9-5/8 District : Prudhoe Bay, I r er S g /8 , Alaska Y Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Mean OH Diameter : 12.250 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 12.823 in Total OH Volume : 932.0 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 4.012 deg /100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 359.7 0.000 41.0 41.0 0.0 359.7 0.000 100.0 100.0 0.0 359.7 0.000 200.0 200.0 0.0 359.7 0.000 300.0 300.0 0.0 359.7 0.000 400.0 400.0 1.5 359.7 1.500 500.0 499.8 5.0 359.7 3.500 600.0 599.1 8.5 359.7 3.500 700.0 697.5 12.0 359.7 3.500 800.0 794.6 15.5 359.7 3.500 900.0 890.1 19.0 359.7 3.500 1000.0 983.6 22.5 359.7 3.500 1037.6 1018.2 23.8 359.7 3.507 1100.0 1074.8 26.0 359.7 3.496 1200.0 1163.2 29.5 359.7 3.500 1269.8 1223.2 31.9 359.7 3.498 1300.0 1248.7 33.0 359.7 3.504 1400.0 1330.9 36.5 359.7 3.500 1489.3 1401.2 39.6 359.7 3.504 1500.0 1409.4 39.8 359.7 1.968 1600.0 1485.1 41.8 359.7 2.000 1700.0 1558.4 43.8 359.7 2.000 1800.0 1629.3 45.8 359.7 2.000 1900.0 1697.7 47.8 359.7 2.000 1942.8 1726.2 48.7 359.7 2.007 2000.0 1763.5 49.8 359.7 1.995 2022.9 1778.2 50.3 359.7 2.008 2059.2 1801.2 51.0 359.7 1.984 2100.0 1826.4 52.7 359.9 4.012 2200.0 1884.3 56.6 0.3 3.997 2300.0 1936.3 60.6 0.8 4.005 2400.0 1982.3 64.6 1.1 3.994 2489.6 2018.2 68.2 1.4 4.008 2500.0 2022.0 68.6 1.5 3.959 2574.4 2047.4 71.6 1.7 4.004 2600.0 2055.5 71.6 1.7 0.000 2652.8 2072.2 71.6 1.7 0.000 2700.0 2087.1 71.6 1.7 0.000 2800.0 2118.7 71.6 1.7 0.000 2900.0 2150.4 71.6 1.7 0.000 3000.0 2182.0 71.6 1.7 0.000 3100.0 2213.6 71.6 1.7 0.000 3200.0 2245.3 71.6 1.7 0.000 3300.0 2276.9 71.6 1.7 0.000 3400.0 2308.5 71.6 1.7 0.000 3500.0 2340.2 71.6 1.7 0.000 3600.0 2371.8 71.6 1.7 0.000 3700.0 2403.4 71.6 1.7 0.000 Page 4 0PO4 -P07 cfw, 04 -09 -2010 , LoadCase 9-5/8 Intermediate Casing (al : Version wcscem453_10 0 0 Client : Eni Petroleum Well : OPO4 -P07 S I I ie1 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 3800.0 2435.1 71.6 1.7 0.000 3900.0 2466.7 71.6 1.7 0.000 4000.0 2498.3 71.6 1.7 0.000 4100.0 2529.9 71.6 1.7 0.000 4173.3 2553.1 71.6 1.7 0.000 4200.0 2561.6 71.6 1.7 0.000 4300.0 2593.2 71.6 1.7 0.000 4400.0 2624.8 71.6 1.7 0.000 4500.0 2656.5 71.6 1.7 0.000 4600.0 2688.1 71.6 1.7 0.000 4700.0 2719.7 71.6 1.7 0.000 4800.0 2751.4 71.6 1.7 0.000 4900.0 2783.0 71.6 1.7 0.000 5000.0 2814.6 71.6 1.7 0.000 5100.0 2846.3 71.6 1.7 0.000 5200.0 2877.9 71.6 1.7 0.000 5300.0 2909.5 71.6 1.7 0.000 5400.0 2941.2 71.6 1.7 0.000 5500.0 2972.8 71.6 1.7 0.000 5600.0 3004.4 71.6 1.7 0.000 5700.0 3036.0 71.6 1.7 0.000 5800.0 3067.7 71.6 1.7 0.000 5900.0 3099.3 71.6 1.7 0.000 6000.0 3130.9 71.6 1.7 0.000 6100.0 3162.6 71.6 1.7 0.000 6200.0 3194.2 71.6 1.7 0.000 6300.0 3225.8 71.6 1.7 0.000 6400.0 3257.5 71.6 1.7 0.000 6446.0 3272.0 71.6 1.7 0.000 6500.0 3289.1 71.6 1.7 0.000 6600.0 3320.7 71.6 1.7 0.000 6700.0 3352.4 71.6 1.7 0.000 6800.0 3384.0 71.6 1.7 0.000 6900.0 3415.6 71.6 1.7 0.000 7000.0 3447.2 71.6 1.7 0.000 7100.0 3478.9 71.6 1.7 0.000 7116.2 3484.0 71.6 1.7 0.000 7200.0 3510.5 71.6 1.7 0.000 7300.0 3542.1 71.6 1.7 0.000 7400.0 3573.8 71.6 1.7 0.000 7500.0 3605.4 71.6 1.7 0.000 7600.0 3637.0 71.6 1.7 0.000 7604.2 3638.4 71.6 1.7 0.000 7619.0 3643.0 72.1 1.5 3.990 7694.7 3664.4 75.0 0.6 3.999 7700.0 3665.8 75.0 0.6 0.000 7778.1 3686.0 75.0 0.6 0.000 7800.0 3691.7 75.0 0.6 0.000 7894.7 3716.2 75.0 0.6 0.000 7900.0 3717.5 75.1 0.6 2.092 8000.0 3741.5 77.1 0.6 2.000 8063.2 3755.0 78.4 0.6 1.992 8100.0 3762.1 79.1 0.6 2.013 8200.0 3779.3 81.1 0.6 2.000 8300.0 3793.0 83.1 0.6 2.000 8394.7 3802.9 85.0 0.6 1.995 8395.8 3803.0 85.0 0.6 0.000 Page 5 OPO4- P07 .cfw, 04 -09 -2010 , LoadCase 9-5/8 Intermediate Casing (a) , Version wcs- cem453_10 • 0 Client : Eni Petroleum Well : OPO4 -P07 SIrger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 8488.0 3811.0 85.0 0.6 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 120.0 11.50 8.30 Permafrost Sandstone 2025.0 12.00 8.30 Permafrost Sandstone 2860.0 12.00 8.30 Shale 6014.0 12.00 8.30 Shale 8113.0 12.00 8.30 Shale 8488.0 12.00 8.30 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (deg F) (degF /100ft) 0.0 0.0 20 0.0 2025.0 1779.5 32 0.7 2653.0 2141.3 50 1.4 8488.0 3880.1 85 1.7 I Page 6 0PO4- 807.cfw, 04 -09 -2010 , LoadCase 9 -5/8 Intermediate Casing (a) , Version wcs-cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 Schlumhcrgcr String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) ft degF (x 1000) ft 0 1 60 90 0 7 5 5.0 7.5 Geoth.Profile Hori. Depart. 1 _ \ 77 t co — O - N.. N o O o - M 4 li ti o — N \ C 7 � CO — O a CI O — 0-,_ Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 6,920' Original fluid Mud 9.60 lb/gal Pv : 28.000 cP Ty : 19.00 Ibf /100ft2 Displacement Volume 615.5 bbl Total Volume 800.7 bbl TOC 6920.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 1003.9 5916.1 12.50 Pv:36.000 cP Ty:25.00 Ibf /100ft2 DeepCRETE 115.2 1568.0 6920.0 12.50 k:2.77E- 2Ibf.s ^n /ft2 n:0.604 Ty:16.24 Ibf/100ft2 Mud 615.5 0.0 9.60 Pv:28.000 cP Ty:19.00 Ibf /100ft2 Page 7 OPO4- P07.cfw; 04 -09 -2010 ; LoadCase 9-5/8 Intermediate Casing (a), Version wcs- cem453_10 Client : Eni Petroleum Well : 0PO4 -P07 Schi boiler String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Static Security Checks : Frac 267 psi at 2653.0 ft Pore 145 psi at 2653.0 ft Collapse 4466 psi at 8408.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 73 ton ft (x 1000) psi 0 2.5 — Hydrostatic: — Frac Pore o — ' G .. 67— Fluid Sequence Static Well Security Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH 11 5.0 70.0 14.0 70.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4 -Drop Bottom Plug DeepCRETE 5.0 115.2 23.0 115.2 80 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 615.5 72.4 615.5 80 19 -Start Displacement Total 01:59 800.7 bbl hr:mn End Job: Bump Top Plug, Bleed -off PSI, Check floats Dynamic Security Checks : Frac 18 psi at 8488.0 ft Pore 145 psi at 2653.0 ft Collapse 4466 psi at 8408.0 ft Burst 6330 psi at 0.0 ft Page 8 0PO4- P07.cfw ; 04 -09 -2010 , LoadCase 9 -5/8 Intermediate Casing (al ; Version wcs- cem453_10 0 0 Client : Eni Petroleum Well : OPO4 -P07 Schlumhcrgcr String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) Temperature Results BHCT 83 degF Simulated Max HCT 85 degF Simulated BHCT 64 degF Max HCT Depth 8488.0 ft CT at TOC 64 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 77 degF Bottom Hole _ (degF) (degF) 85 degF I ° o —Cale. WHP _ — Calo. Pump Press. 0) Q. oI 0 20 40 60 80 100 120 140 Time (mire) _ Fluids at 8488 ft S° —Acquired 0 Out g —Acquired Q In - —Q Out m Q In co _________I o 1 L o 0 20 40 60 80 100 120 140 Time (min) Page 9 0PO4- P07.cfw; 04 -09 -2010; LoadCase 9-5/8 Intermediate Casing (a): Version wcs- cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 Schliohrger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 lntermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 9 -5/8" Intermediate Casing District : Prudhoe Bay, Alaska Country : USA P = u? Depth = 8488 ft I Depth - 265 ft ,-- 1 - Frac N - Frac P Pore - Pore ' o Hydrostatic o - Hydrostatic -- N namc i uynamc I in in. 1 O O l it at ro i - V I v 25 `a -0 in 3 m - - o W Vf u , rnO I N O > do ad • € / c c .N c c O Qu7 — 4 c pj 8 O o of of N I m , 0 I N O O g 0 50 100 150 0 50 100 150 ! Time (min) Time (min) 0 a S Total Depth = 8488.0 ft Top of Cement = 6920.0 ft 0 *Mark of Schlumberger 'i uIPr Page 10 0PO4- P07.cfw ; 04 -09 -2010 ; LoadCase 9-5/8 Intermediate Casing (a); Version wcs- cern453_10 • 0 Client : Eni Petroleum Well : OPO4 -P07 SI1 ier String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) Section 4: centralizer placement Top of centralization :2500.0 ft Bottom Cent. MD :8468.0 ft Casing Shoe :8488.0 ft NB of Cent. Used :42 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 2648.0 3 1/1 NW -TR -9 5/8 -6 -TR 3B W090 0.0 2628.8 6928.0 0 0/0 0.0 2648.0 8488.0 39 1/1 NW -TR -9 5/8 -6 -TR 3B W090 0.0 6947.2 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW -TR -9 5/8 -6 -TR W090 9 5/8 12.850 11.591 No Hannover 12.250 51.71 2852.83 3B (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Fommation :0.25 Total Drag Force :35 ton Hook Toad Down Stroke :75 ton Hook load Up Stroke :145 ton Page 11 0PO4 -P07 cfw; 04 -09 -2010, LoadCase 9-5/8 Intermediate Casing (a) ; Version wcs- cem453_10 • Client : Eni Petroleum Well : 0PO4 -P07 Sc Irger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) ft _ 0 I , 0 60 80 100 — Between Cent. +Lt Cent. i o M o m a, — Pipe Standoff Page 12 OPO4- P07 .cfw; 04 -09 -2010; LoadCase 9-5/8 Intermediate Casing (a) ; Version wcs-cem453_10 • 4 Client : Eni Petroleum Well : 0PO4 -P07 SGirger String : 9-5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 9 -5/8" Intermediate Casing District : Prudhoe Bay, Alaska Country : USA ft ton 0 0 25 50 75 100 125 150 — Hooldoad Up — — Hooldoad Dow n I - - - - Weight 1 — — Rag Force 1 \ 1 \ c 1 c 1 \ \ 1 1 1 II I v I > t \ i r \ ti I O 0- 8 \ co 1 1 w \ ch v \ 1 • \ o O N O cm p 4 O ? Running Forces Z" O a Friction Factor = 0.25 Total Depth = 8488.0 ft Top of Cement = 6920.0 ft 0 *Mark of Schlumberger kkhimberger Page 13 0PO4- 907.cfw ; 04 -09 -2010 ; LoadCase 9 -5/8 Intermediate Casing lal ; Version wcs-cem453_10 i • 0 Client : Eni Petroleum Well : 0PO4 -P07 Schlulnberger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) Section 5: WELLCLEAN II Simulator ft % 2 1 75 100 Std Betw. Cent. - - - -- Cement Coverage 0 0 o m 0 0 o to - ..5 0 0 0 Cement Coverage Risk Mud on the Wall Fluids Concentrations g z6 z 7000 - - 7000 7000 7000 - 7200 . ' -7200 7200 7200 - 7400 -7400 7400 7400 7600 -7500 - Z- 7600 -- - '" 7600 ti- s s s n 7800 7800 n 7600 76n0 n • RI 5000 8000 8000 -8000 8200 8300 8200 7 -8200 8400 8400 B400- -8400 • • 3 ° a • P 915 i T i 2 Mud Eall High I♦ Low r DeepCRETE I I Medium I I None IT MUDPUSH II Page 14 OPO4-P07.cfw : 04-09-2010 , LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem453_10 I Client : Eni Petroleum Well : OPO4 -P07 Schlumhcrgcr String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb /gal Rheo. Model : BINGHAM Pv : 28.000 cP At temp. : 80 degF Ty : 19.00 lbf/100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type : WBM Job volume : 615.5 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 96.0 Water : 0.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 12.50 lb /gal Rheo. Model : BINGHAM Pv : 36.000 cP At temp. : 80 degF Ty : 25.00 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 70.0 bbl DeepCRETE DESIGN Fluid No: 7 Density : 12.50 lb /gal Rheo. Model : HERSCHEL_B. k : 2.77E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.604 Ty : 16.24Ibf/100ft2 Gel Strength : (lbf/100ft2) DESIGN BLEND SLURRY Name : 12.5 ppg Lit Mix Fluid : 4.956 gal /sk Job volume : 115.2 bbl Dry Density : 117.67 lb/ft3 Yield : 1.52 ft3 /sk Quantity : 426.30 sk Sack Weight : 100 lb Solid Fraction : 56.3 BASE FLUID Type : Fresh water Density : 8.32 lb /gal Base Fluid : 4.850 gal /sk Additives Code Conc. Function D167 0.350 %BWOC Fluid loss D046 0.200 %BWOC Antifoam D153 0.150 %BWOC Antisettling D185 0.053 gal /sk blend Dispers. LT D186 0.053 gal /sk blend Accelerator Page 15 OPO4- P07.cfw ; 04 -09 -2010 ; LoadCase 9-5/8 Intermediate Casing (a) ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 Stillohrier String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Sect 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH 11 5.0 70.0 14.0 70.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4 -Drop Bottom Plug DeepCRETE 5.0 115.2 23.0 115.2 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 615.5 72.4 615.5 19 -Start Displacement Total Pumping Time : 01:59 hr:mn End Job: Bump Top Plug, Bleed -off PSI, Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 108 bbl MIXING PREPARATION MUDPUSH II Volume : 70.0 bbl Density : 12.50 Ib /gal Code Quantity Design Fresh water 58.786 bbl D046 41.085 Ib 0.200 %BWOW D182 352.719 Ib 6.000 lb/bbl of base fluid D031 15813.851 Ib 225.91 Ib/bbl of spacer DeepCRETE Volume : 115.2 bbl Density : 12.50 Ib /gal Yield : 1.52 ft3 /sk Dry Phase Liquid Phase Blend : (Ib) Design Mix Water 50.3 bbl 10.0 bbl LAS Design 12.5 ppg Lit 42629.625 lb Fresh water 49.224 bbl 9.786 bbl D167 95.813 lb 0.350 %BWOC D185 22.675 gal 4.508 gal 0.053 gal /sk blend D046 54.750 Ib 0.200 %BWOC D186 22.675 gal 4.508 gal 0.053 gal /sk blend D153 41.063 Ib 0.150 %BWOC Page 16 0PO4- P07.ctw ; 04 -09 -2010 , LoadCase 9 -5/8 Intermediate Casing (a): Version wcs- cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 SI IYI String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Page 17 0PO4- P07.cfw ; 04 -09 -2010 ; LoadCase 9 -5/8 Intermediate Casing (a) ; Version wcs- cem453_10 • ! Client : Eni Petroleum Well : OPO4 -P07 SGkIrger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 9 -5/8" Intermediate Casing District : Prudhoe Bay, Alaska Country : USA Annulus ID : 9.625 in - OD : 12.250 in O • — MUDPUSHII — Mud O i O O _ W O O n O 0 — a u Eh a 3 ■ > m co a r c O • o ra U m U N u_ .... - O m d, 01 d O __ U v 0 q I I I I I I I I I 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 't Flow Rate (bbl /min) 0 a n ■ Mud Bingham Ri = 28.000 cP Ty = 19.00 Ibf /100ft2 0 II I MUDPUSH II Bingham R/ = 36.000 cP Ty = 25.00 Ibf /100ft2 ■ DeepCRErE Herschel : k = 2.77E-2 Ibf.s ^n /ft2 n = 0.604 Ty = 16.24 Ibf /100ft2 *Mark of Schlumberger Stklumberpr Page 18 0PO4- P07.cfw ; 04 -09 -2010 ; LoadCase 9-5/0 Intermediate Casing (a) ; Version wcs- cem453_t0 • • Client : Eni Petroleum Well : 0PO4 -P07 Seillikergell String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Page 19 OPO4 -P07 cfw; 04 -09 -2010 , LoadCase 9 -5/8 Intermediate Casing (a) , Version wcs- cem453_10 • • Schlumberger C emCADE * well cementing recommendation for 13.375 ' Surface Casing Operator : Eni Petroleum Well : 0PO4407 (P9) Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : North Slope - Alaska Proposal No. : Draft v3 Service Point : Prudhoe Bay, Alaska Date Prepared : 4 -9 -2010 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford©slb.com s 0.14 ftlikA %„,.,. V L q � � ATE 4/* Disclaimer Notice. This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services Freedom from infringement of patents of Schlumberger or others is not to be inferred. * Mark of Schlumberger • • Client : Eni Petroleum Well : OPO4 -$07 SAM boiler String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2653.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi 0D20.in 0 1r' 1.0 1.5 .=.- ,, ® 16Oft - • Frac Pore � _ L — 4-- - OD 13.4 in C— @2653ft ▪ Permafrost 1 • o o _ LC 0573 ft ▪ . fy \ • • : : .' :, i • ., I og • . • . • . • . • . • ° _�_i i 0 0 c,- Well Lithology Formation Press. Page 2 OPO4- P07,cfw, 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0PO4 -P07 Srilmihrier String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib /ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2573.0 ft Casing /liner Shoe MD : 2653.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib /ft) (in) (psi) (psi) 2653.0 13 3/8 40.0 68.0 12.415 L -80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 120.9 % Mean OH Equivalent Diameter: 18.688 in Total OH Volume : 845.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) ( %) (in) 2023.0 16.000 150.0 19.279 2653.0 16.000 35.0 16.822 Page 3 0PO4 -P07 cfw ; 04 -09 -2010 , LoadCase Surface Casing ; Version wcs- cem453_10 Client : Eni Petroleum Well : 0PO4 -P07 S I 1 ie1 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 72 deg Max. DLS : 4.012 deg /100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 359.7 0.000 41.0 41.0 0.0 359.7 0.000 100.0 100.0 0.0 359.7 0.000 200.0 200.0 0.0 359.7 0.000 300.0 300.0 0.0 359.7 0.000 400.0 400.0 1.5 359.7 1.500 500.0 499.8 5.0 359.7 3.500 600.0 599.1 8.5 359.7 3.500 700.0 697.5 12.0 359.7 3.500 800.0 794.6 15.5 359.7 3.500 900.0 890.1 19.0 359.7 3.500 1000.0 983.6 22.5 359.7 3.500 1037.6 1018.2 23.8 359.7 3.507 1100.0 1074.8 26.0 359.7 3.496 1200.0 1163.2 29.5 359.7 3.500 1269.8 1223.2 31.9 359.7 3.498 1300.0 1248.7 33.0 359.7 3.504 1400.0 1330.9 36.5 359.7 3.500 1489.3 1401.2 39.6 359.7 3.504 1500.0 1409.4 39.8 359.7 1.968 1600.0 1485.1 41.8 359.7 2.000 1700.0 1558.4 43.8 359.7 2.000 1800.0 1629.3 45.8 359.7 2.000 1900.0 1697.7 47.8 359.7 2.000 1942.8 1726.2 48.7 359.7 2.007 2000.0 1763.5 49.8 359.7 1.995 2022.9 1778.2 50.3 359.7 2.008 2059.2 1801.2 51.0 359.7 1.984 2100.0 1826.4 52.7 359.9 4.012 2200.0 1884.3 56.6 0.3 3.997 2300.0 1936.3 60.6 0.8 4.005 2400.0 1982.3 64.6 1.1 3.994 2489.6 2018.2 68.2 1.4 4.008 2500.0 2022.0 68.6 1.5 3.959 2574.4 2047.4 71.6 1.7 4.004 2600.0 2055.5 71.6 1.7 0.000 2653.0 2072.2 71.6 1.7 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 120.0 11.00 8.43 Permafrost Sandstone 2025.0 12.00 8.43 Permafrost Sandstone 2616.0 13.00 9.20 Sandstone 2653.0 13.00 9.20 Sandstone Page 4 OPO4- P07 .cfw , 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs -cem453_10 • Client : Eni Petroleum Well : OPO4 -P07 SChiumberger String : 13.375 District : Prudhoe Bay, Alaska 11 Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 2023.0 1778.3 32 0.7 2653.0 2072.2 50 1.4 ft degF (x 1000) ft c._ 0 1 40 60 1 1^ 1• 0.9 1.2 1.5 Geath.Profile — Hari. Depart. 1111111 - ° .um _.0 i i 1lIUMI UIl•IwIIIIMMIIIIffMI ° - - h MUUMUU UN ° _ ° - NH. imm 0 ° 1 ` ' i iiil■ii Cas�ai■ \ , --h os II in . .,_ s " �.=C \ ■ :o_:■ .� �::: ■ um . ° CA _ _ J_ NI 1• _ ; CD C-J Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.60 lb/gal Pv : 12.000 cP Ty : 7.00 Ibf /100ft2 Displacement Volume 385.3 bbl Total Volume 934.5 bbl TOC 0.0 ft Page 5 OPO4- P07 .cfw ; 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 Schiuberr String 13.375 District Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.50 Pv:16.000 cP Ty:12.00 lbf/100ft2 Lead Slurry 386.7 2153.0 0.0 10.70 k:4.06E -2 Ibf.s ^n /ft2 n:0.345 Ty:0.03 lbf/100ft2 12.0 ppg 62.5 500.0 2153.0 12.00 k:7.50E -2 lbf.s ^n /ft2 n:0.372 Ty:4.15 lbf/100ft2 DeepCRETE Mud 385.3 0.0 9.60 Pv:12.000 cP Ty:7.00 lbf/100ft2 Static Security Checks : Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2067 psi at 2573.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 51 ton ft (x 1000) psi o _ . 0 0 1.5 r Hydrostatic — Fran Pore 0 0 0 0 0 O — L J I O O Fluid Sequence Static Well Security Page 6 OPO4- P07.cfw ; 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • 0 Client : Eni Petroleum Well : 0PO4 -P07 S I IE String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 13.375 "' Surface Casing District : Prudhoe Bay, Alaska Country : USA Depth = 160 ft Depth = 2653 ft Lc? 1 — Frac ! - Frac . - - Fbre ■. 6 - Hydrostatic 0 ' - Hydrostatic I o - Dynanic ch 1 - vynanc i N Lo in r O CV - 5 1 f6 0 D) 7 N - E m 3 y 1 N O 2 LO r > C C o ' o 8 of i o q o 0 o Lo 1 s N g o o 0 50 100 150 200 0 50 100 150 200 a Time (min) lime (min) O CI. o Total Depth = 2653.0 ft Top of Cement = 0.0 ft *Mark of Schlumberger 'ierP• Page 7 OPO4 -P07 cfw ; 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • i Client : Eni Petroleum Well : 0PO4 -P07 SIrier String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 100.0 25.0 100.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4 -Drop Bottom Plug Lead Slurry 5.0 386.7 77.3 386.7 80 13 -Start Mixing Lead Slurry 12.0 ppg 5.0 62.5 12.5 62.5 80 16 -Start Mixing Tail Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 385.3 45.3 385.3 80 19 -Start Displacement Total 02:50 934.5 bbl hr:mn End Job: Bump Top Plug, Bleed - off PSI, Check floats Dynamic Security Checks : Frac 3 psi at 160.0 ft Pore 10 psi at 160.0 ft Collapse 2067 psi at 2573.0 ft Burst 4844 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 70 degF Simulated BHCT 70 degF Max HCT Depth 2653.0 ft CT at TOC 59 degF Max HCT Time 02:50:10 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement I (degF) I (degF) 1 20 degF Bottom Hole (degF) (degF) 50 degF Page 8 0PO4- P07.cfw ; 04 -09 -2010 ; LoadCase Surface Casing , Version wcs- cem453_10 • 0 Client : Eni Petroleum Well : OPO4 -P07 Sehlumberger String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing o -- —kin Calc. WHP / C Pump Press. cv I I // 0 30 60 90 1 1 180 Time (min) Fluids at 2653 ft .--..= ._ Acquired 0 —Qq dU Out i E,_., w ___1 l -•- - - -r 1 ( Ti t O L: 0 30 60 90 120 150 180 Time (miry) Section 4: centralizer placement Top of centralization :80.0 ft Bottom Cent. MD :2596.0 ft Casing Shoe :2653.0 ft NB of Cent. Used :13 NB of Floating Cent. :13 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 136.0 1 1/1 NW -TR -13 3/8 -8 -TR 3 W304 55.4 116.0 2136.0 0 0/0 0.0 2133.3 2616.0 12 1/1 NW -TR -13 3/8 -8 -TR 3 W304 66.4 2616.0 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 -TR -13 3/8 -8 -TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Formation :0.25 Total Drag Force :3 ton Hook Toad Down Stroke :90 ton Hook Toad Up Stroke :97 ton Page 9 0PO4-P07.cfw ; 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 Sehill Mager String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing ft o- 0 1 '0 60 80 100 — Between Cent. +At Cent. �- 0 0 o — M — Pipe Standoff Page 10 OPO4- 907 .cfw ; 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0PO4 -P07 SIhrger String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 13.375 ' Surface Casing District : Prudhoe Bay, Alaska Country : USA ton ft 0 10 20 30 40 50 60 70 80 90 100 O — V I I t I Hooldoad Up — — Hooldoad Dow n Weight — — Drag Force \. \. 0 1 �. 8- 1 E \. o I \ 1 5 O I y I 0 1 \\ J \ S O < O o O 3 M — r Running Forces Friction Factor = 0.25 Total Depth = 2653.0 ft Top of Cement = 0.0 ft 'Mark of Schlumberger Schlingierpr Page 11 0PO4-P07.cfw ; 04 -09 -2010: LoadCase Surface Casing ; Version wcs-cem453_10 • • Client : Eni Petroleum Well : 0PO4 -P07 Schlemberger String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN 11 Simulator ft 0/ o _ 0 1 A 0 60 80 100 Std Betw. Cent. - Cement Coverage 0 0 o - 0 0 o - f 1 C. 0 C. Cement Coverage Risk Mud on the Wall Fluids Concentrations 0 5 2 3 0 z 0 01 ' 0 . 500- i -500 500 - - 500 - 1 t 1000- -1006 ri ,- 1000- -1006 c d 1500 - -150 a c 1 S00 1500 0 c o 2000- -2000 2000- 2006 2900 :506 2500- -2500 I I a o €, D o 3 z x Mil Mud High ® Low Q 12.0 ppg DeepCRETE = Medium 7 None 1 1 Lead Slurry I 1 MUDPUSH II Page 12 OPO4 -P07 cfw : 04 -09 -2010: LoadCase Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OPO4 -P07 Schlumberger String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb/gal Rheo. Model : BINGHAM Pv : 12.000 cP At temp. : 80 degF Ty : 7.00 Ibf /100ft2 Gel Strength : (Ibf /100ft2) MUD Mud Type : WBM Job volume : 385.3 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 96.0 % Water : 0.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 lb/gal Rheo. Model : BINGHAM Pv : 16.000 cP At temp. : 80 degF Ty : 12.00 Ibf /100ft2 Gel Strength : (Ibf /100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 4.06E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.345 Ty : 0.03Ibf /100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : B809 Mix Fluid : 19.043 gal /sk Job volume : 386.7 bbl Dry Density : 105.47 Ib /ft3 Yield : 4.33 ft3 /sk Quantity : 501.63 sk Sack Weight : 188 lb Solid Fraction : 41.2 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 19.043 gal /sk Page 13 OPO4- P07 .cfw : 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0PO4 -P07 Schlumbcrgcr String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing 12.0 ppg DeepCRETE DESIGN Fluid No: 5 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k : 7.50E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.372 Ty : 4.15Ibf/100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid : 5.163 gal /sk Job volume : 62.5 bbl Dry Density : 110.20 lb/ft3 Yield : 1.60 ft3 /sk Quantity : 219.78 sk Sack Weight : 100 lb Solid Fraction : 56.8 % BASE FLUID Type : Fresh water Density : 8.32 lb /gal Base Fluid : 4.943 gal /sk Additives Code Conc. Function D047 0.020 gal /sk blend Antifoam D185 0.050 gal /sk blend Dispers. LT D186 0.150 gal /sk blend Accelerator Sect 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 100.0 25.0 100.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4 -Drop Bottom Plug Lead Slurry 5.0 386.7 77.3 386.7 13 -Start Mixing Lead Slurry 12.0 ppg 5.0 62.5 12.5 62.5 16 -Start Mixing Tail Slurry DeepCRETE Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 385.3 45.3 385.3 19 -Start Displacement Total Pumping Time : 02:50 hr:mn End Job: Bump Top Plug, Bleed -off PSI, Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 343 bbl Page 14 OPO4- P07.cfw; 04 -09 -2010 ; LoadCase Surface Casing ; Version wcscem453_10 Client : Eni Petroleum Well : OPO4 -P07 Scillolierger String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing MIXING PREPARATION MUDPUSH 11 Volume : 100.0 bbl Density : 10.50 Ib /gal Code Quantity Design Fresh water 91.096 bbl D182 546.575 Ib 6.000 Ib/bbl of base fluid D031 11720.791 Ib 117.21 lb/bbl of spacer Lead Slurry Volume : 384.3 bbl Density : 10.70 Ib /gal Yield : 4.33 ft3 /sk Dry Phase Liquid Phase Blend : 93716 Ib Design Mix Water 226.0 bbl 10.0 bbl LAS Design B809 93716.484 Ib Fresh water 226.017 bbl 10.001 bbl 12.0 ppg DeepCRETE Volume : 62.5 bbl Density : 12.00 Ib /gal Yield : 1.60 ft3 /sk Dry Phase Liquid Phase Blend : 21978 Ib Design Mix Water 27.0 bbl 10.0 bbl LAS Design 12.0 PPG Lit 21977.973 Ib Fresh water 25.867 bbl 9.575 bbl D047 4.396 gal 1.627 gal 0.020 gal /sk blend D185 10.989 gal 4.068 gal 0.050 gal /sk blend D186 32.967 gal 12.203 gal 0.150 gal /sk blend Page 15 0PO4- P07.cfw, 04 -09 -2010 , LoadCase Surface Casing ; Version wcs- cem453_10 ! • Client : Eni Petroleum Well : OPO4 -P07 Sekkihrier String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 13.375 ' Surface Casing District : Prudhoe Bay, Alaska Country : USA Annulus ID : 13.375 in - OD : 16.000 in MUDPUSHII - Mud - Tail Slurry 0 Lead Slurry co o 'N M N � a ■ co — N m fl F C O N :r u_ m N U co o q a 0 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 a_ Flow Rate (bbl /min) 0 ■ Mud Bingham: PV = 12.000 cP Ty = 7.00Ibf /100ft2 MUDPUSH II Bingham: P/ = 16.000 cP Ty = 12.00Ibf /100ft2 3 Lead Slurry Herschel : k = 4.06E-2 Ibf.s ^n/ft2 n = 0.345 Ty = 0.03 lbf/100ft2 ■ Tail Slurry Bingham P/ = 81.518 cP Ty = 10.51 Ibf /100ft2 *Mark of Schlumberger Ii pr Page 16 0PO4- P07.cfw : 04 -09 -2010 ; LoadCase Surface Casing ; Version wcs- cem453_10 • • _ - iii Emil Petroleum OPO4 -07 (P9) Nikaitchuq Field enn North Slope - Alaska DIR / LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD • SIZE SPECS INFO Cement to Surface 20 " Hole Angle X -65 0 20" Conductor Shoe 160' 160' N/A Welded / Driven N/A GR / Res Surface Csq Dir /PWD 13 -3 / 8 " 68 Ibs /ft Wellbore Stability Mud Motor L -80, BTC 8.8-9.7 ppg Lost Circulation Hole Cleaning Casing Sections KOP:300' Casing Wear DLS: 1.5 -3.5 deg /100' Hole Angle 70 13 - 3/8" Casing Point 2,653' 2,072' j% 16" 50 F WBM GR / RES Neutron / Density / PWD Inter Cas ino Wellbore Stability 9 -5/8" Lost Circulation Rotary Steerable 47 Ibs /ft 9.0 -9.2 ppg Hole Cleaning L -80, BTC -M Torque & Drag Casing Sections Sail Angles: Casing Wear 70 degrees TOC @ BHA Expense 6920''• 1 — Pick -up Top of Sand MD r tip •::: 4'it tiff 111.0 HI. TOL 8,288 iiiiii. :5 Hole Angle >L ∎1 ■4 87 9 - 5/8" Casing Point 8,488' 3,812' 12 - 1/4" 8 F LSND GR / RES Neutron / Density / PWD Wellbore Stability Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5 -1/2" Torque & Drag 17 Ibs /ft 9.0 -9.2 ppg Casing Sections Rotary Steerable L -80, IBT -M Casing Wear (Geo- Steering) BHA Expense 5 - 1/2" Slotted Liner Hole Angle 89 Proposed TD 11,975' 3,940' 8 -1/2" 85° F MOBM • Formation Integrity And Leak Off Test Procedure Drilling Operations 1. After cementing casing and nippling up BOP Equipment, RIH to top of cement and pressure test the h test pressure specified in the well plan (usually 2500 - 3000 for 30 minutes and casing tot e to p p p ( y psi) record on a chart (AOGCC required casing integrity test). The slowest possible pump rate is preferred to allow detection of leaks. Pump rates of 1/4 to 1 BPM are typical; however, adjust the pump rate to match the test pump capability to maintain a constant pump rate. Record pressures approximately every 1/4 bbl on the Pressure Integrity Test (PIT) Form (you can locate on the drilling N drive). Plot the casing pressure test (volume versus pressure), and indicate how long the pressure is held on the casing. Verify that the test data forms a straight line and there is no air entrained in the mud, or leaks in the system. Repeat the casing pressure test if needed, especially if a straight line cannot be established at the higher test pressures. 2. Drill 20' to 50' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good downhole pressure test). Pick up into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill string at a rate approximating that used to test the casing in Step No. 1. Lower pump rates are preferred in order to minimize friction pressures losses (especially with long strings of small drillpipe) which are ignored in the calculations; however, adjust the pump rate to match the test pump capability and maintain a constant pump rate. Pump rates between 1/4 and 1 -1/2 BPM are typical, with higher rates applicable to tests conducted with large intervals of open hole. 6. On the PIT Form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure. Record pressures approximately every 1/4 bbl pumped. The data points should initially form a straight line with a similar slope to the casing integrity test as the system compressibility's are similar. Eventually, the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate and the data points will deviate from the straight line. The first, sustained occurrence of this departure is the leak -of point (see Figure 1). Pump an additional 3 bbls after the suspected leak -off point is reached to assure continued decreasing slope on the pressure versus volume plot. If a straight line cannot be established during initial pumping (suggesting a surface leak or air in the system) or a clear leak -off point is not indicated, consider re- running the test. Be sure to bleed all pressure off the system prior to re- running the test. A slightly higher pump rate may be considered if a clear departure is not indicated on the pressure versus volume plot. Small filtration fluid losses can cause a slope change, especially at slow pump rates, and confuse the identification of a more definitive leak off point. Note: If the maximum EMW specified in the wellplan is reached without indication of leak -off, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a leak off test (LOT) 7. Shut down when the leak -off point is observed and 3 bbls of mud have been pumped into the formation. Record the instantaneous shut -in pressure (ISIP). With the pump shut down, monitor and record a 15 second and 30 second shut -in pressure and the shut -in pressures for a minimum of 10 minutes (at 30 second intervals) or until the shut -in pressure stabilizes. Plot the information and record the LOT point or FIT point on the PIT Form. Bleed the pressure off and record the fluid volume recovered if possible. If in doubt of the leak off point, contact the Drilling Superintendent to discuss and evaluate the test. Upon completion of the test, forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the proper Agencies. • • NOTE: Pumping to the leak -off point plus 3 bbls is less critical for casing shoes other than surface casing, but it is important to pump enough to ensure a good LOT and not a spurious departure. 8. Corrective measures will be performed if the open hole pressure integrity fails to meet predetermined standards. The Drilling Supt. is to be notified immediately of any LOT or FIT that results in less than adequate formation integrity as defined in the Well Plan. Do not drill ahead until the inadequate formation integrity is addressed. TiP LOT F 4, 1 , . J ,O Maximum Pressure A � F ` 1 1 . — e ��e — J ° co As oi c ; fi r 0 er, F ormation Ta Breakdown En Pressure Anticipated Pressure A Ira a) I A Fracture P-1 Leak Off Point r V o ' Propagation ,� % . Pressure Shut Fracture o . c inglii Closure I ' . --- In ❑ ❑ ❑ Pressure Instants ous ❑ ■ ❑ ❑ ❑ . ❑ ❑ ❑ ❑ r Pressure Volume and Shut -in Time • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/06 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK 1.1 Point MODULE DOCK R \ OPP `� THIS P P s SURVEY ..\ lor U2 9 ' am DEW u S. Q SITE STP • � — I DU , POiNI MODULES ; . NOC STAGING AREA•, T13N, R9E ' DS -30 q\ 1 SCALE: ollt 1" = 150' \--1, / 45,30 19 % � , ""gb1Y 2 . ,2.� S TP PAD \ VICINITY MAP q o \ '\ SCALE: 1" = 1 Mile o o >7% \ 'O �r'o \ � r a 0 o 00 � . \\\\\ o°o "?..0 � s \-, o \ O Z o 0 ..o >�sc� s 1 \ ( _----2? -....., O \ 00 \ 7- •• .... / ) OLIKTOK \ 0 POINT PAD `\ \ \ l tA \ / \ SEE SHEET 3 FOR NOTES / \ / U Existing Conductor - /` LOUNSBURY & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS lb AREA: MODULE: UNIT: - EnO Petroleum OLIKTOK POINT WELL CONDUCTOR I� ASBUILT LOCATIONS CADD FILE NO. I DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80 —d1 1 OF 3 I 2 0 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4 -24 2 12/23/0€ JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP -I1 6,036,332.70 1,656,791.89 70° 30' 39.015" 149° 51' 57.587" 2,052 1,519 12.1 4.0 OP -12 6,036,328.85 1,656,784.83 70° 30' 38.977" 149° 51' 57.795" 2,056 1,526 12.2 4.0 0P03 -P05 6,036,325.10 1,656,777.76 70° 30' 38.940" 149° 51' 58.004" 2,059 1,533 12.2 4.0 0PO4 -P07 6,036,321.43 1,656,770.69 70° 30' 38.904" 149° 51' 58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70° 30' 38.868" 149° 51' 58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70° 30' 38.831" 149° 51' 58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70° 30' 38.757" 149° 51' 59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70° 30' 38.720" 149° 51' 59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70° 30' 38.683" 149° 51' 59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70° 30' 38.647" 149° 51' 59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70° 30' 38.610" 149° 51' 59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70° 30' 38.573" 149° 52' 00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70° 30' 38.463" 149° 52' 00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70° 30' 38.426" 149° 52' 00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70° 30' 38.389" 149° 52' 01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70° 30' 38.353" 149° 52' 01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70° 30' 38.316" 149° 52' 01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70° 30' 38.279" 149° 52' 01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70° 30' 38.205" 149° 52' 02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70° 30' 38.168" 149° 52' 02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70° 30' 38.132" 149° 52' 02.586" 2,141 1,889 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70° 30' 38.095" 149° 52' 02.793" 2,145 1,696 12.2 _ 1.7 OP23 6,036,235.05 1,656,608.27 70° 30' 38.058" 149° 52' 03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70° 30' 38.022" 149° 52' 03.209" 2,153 1,710 12.2 1.3 I D ISPOSAL WELLS i 1 1 . i I , AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. ^Ir' ')I' NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. 0P25 6,036,004.35 1,656,510.91 70° 30' 35.791" 149° 52' 05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70° 30' 35.867" 149° 52' 05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. 0" SO IVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: ,, E Petit eu� WELL CONDUCTOR D IM . ASBUILT LOCATIONS CADD FILE NO. I DRAWING N0 PART: REV: LK680D1 10/9/08 NSK 6.80 -d1 I 2 OF 3 I 2 s REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4 -24 2 12/23/ JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L -2539 FOR NAD27 INFORMATION. - - • "C-, . 9.t SURVEYOR'S CERTIFICATE •' ,.4# 1 HEREBY CERTIFY THAT l AM PROPERLY g h ,/ %21- � / REGISTERED AND LICENSED TO PRACTICE i7 .. �. 0 LAND SURVEYING IN THE STATE OF 0 .•• f K^ : J. RO OKUS �I ALASKA AND THAT THIS PLAT REPRESENTS ♦ �� : ,r A SURVEY DONE BY ME OR UNDER MY � ��' ':, Ls 803 •: DIRECT SUPERVISION AND THAT AT ALL S' + p'•••,tz,,. •s ,Fir► .', ' p ue DIMENSIONS AND OF DECEMBER 23, 2008. +i 4 1 \��t� •• CORRECT AS 0 LOUNSBURY & ASSOCIATES, INC. SU ENGINEERS PLANNERS z AREA: MODULE: UNIT: Eni . E�O Petroleum WELLCONDUCTOR D ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 I NSK 6.80 -di 3 OF 3 I 2 • • RECEIVED • i x APR J4MO II�II iIr ��euI" moll&G. Mellow 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Maurizio Grandi Phone (907) 865 -3320 Email: Maurizio.Grandi@enipetroleum.com April 12, 2010 Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue, Suite 100 Anchorage, Alaska 99501 RE: REVISED Application for Permit to Drill Producer OPO4 -07 Dear Commissioners, This application is a revision. Please refer to permit #208 -199 which was approved 12/19/08. Please note that the well name has been revised. ENI US Operating Co. Inc. hereby applies for a REVISION to Permit to Drill #208 -199 for the onshore production well OPO4 -07. The well will be drilled and completed using Nabors rig 245E. The planned spud date for OPO4 -07 is May 10, 2010. Eni US Operating Co. Inc. would like the AOGCC to consider implementing a fourteen (14) day BOP — testing schedule at this time. OPO4- 07will be the fourth (4 well drilled by Eni and the sixth (6 well drilled at Oliktok Point. To date, four (4) wells have been drilled at Oliktok Point without any well control incidents. Please find attached for the review of the Commission forms 10 -401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Jason Brink at 907 - 865 -3321. Sincerely, ! Maurizio Gr. di Well Operation Project Manager AOGCC OPO4-P07: Check Coordinate Conversion 18 December 2008 INPUT OUTPUT Geographic, NAD83 State Plane, NAD27 5004 - Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. Op04 -P07 Slot Location 1/1 Latitude: 70 30 38.904 Northing/Y: 6036569.418 Longitude: 149 51 58.212 Easting/X: 516739.277 Convergence: 0 07 44.86992 Scale Factor: 0.999900318 Datum Shift (m.): Delta Lat. = 32.276, Delta Lon = - 117.283 Remark: AOGCC SFD 12/18/2008 Corpscon v6.0.1, U.S. Army Corps of Engineers Nikaitchuq OPO4 -P07 PTD 208 -199 Surface Location • • . 7,4 -, • ,fi t ADL 355024 (Offshore) ADL 373301 1 (Onshore) ., 4, .r' ,r M Y * ' t' ` OPO4 -P07 Surface Location or f . �'' r 70 30 38.904, -149 51 58 -212 . , ` +. 4 6 ec • ,,,, - i,„ ADL 355024 ,. (Offshore) . , i ' ir „ r it , Ccpyrq: Protected , i 0 '" DO NOT SCAN IN1 ' ,,Y �. r . . . 4 * , 4 ,, .t. a r -) $ L ; ERFICHE , , Amin t 333 It Image 0 2008 Dig b e 7,30!40.43 +N. '14951'50 02 W *ley 5 tt a Eye alt 1146 It 081218_ MAP_ 2081990_ Nikaitchuq _OPO4- P07_Surface_Location SFD 12/18/2008 Nikaitchuq OPO4 -P07 PTD 208 -199 Surface Location • • 1 http : / /landrecords.alaska.gov /gis/ raster /dnr /plats /Irdpp1U014N0091. 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BASE M% z i x x x x x w I, x,xxxxxxxx ;xxxx x / 1 _ . 59 1 SA i � x x. f .. x x x x x x x x x r, x' x x ' x - , :r x> x x x x v x - , - 'V Se x u • 'St ,.. .. ,. . x x x • , x x 0 0 x x x ` > x 01LIRRISONX. < :1 x r x . x x x x x �� x x x x r x, x x O ° 0 0 0 " 0 0 x x x x x x< x x, x x, x x x x C- x x x x x x x x x x x x x x. w x x - x .. x x x x x x x a> x x x x_ x_ x x x x x x > OLIKTOK POINT . H x0000 x 0 ` X • z z x x x x x x x x x x x x x x. A x x w �Y R : x x a y xj x x x x r r ,.,e r � OBGLEASE x • x x x x x x x x x x x xx x x x . ...2,. 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I I R \_1 0 r • 70% - Sign- - - T ----- PROTRACTION MGR. 1.0-1, APPROVED 111/1074, ^ MS AZT a n.N6t0:1219 A[GRmn iif o s) GSQ A.FxORD ItAi. ]RACY R. /).45iD ACRQ: WTMNIlr I e TRA[TR 14JW./l A0000 rat naw vu e v e ; ACCEPTED 0.1119. - An nS9 , corn ..19.1 " %; ' 6215 An r:RV RxEn Ironlss. USS mxQ A GIAxi AFFECTS. DISPOSAL ,. URA W' rTATY .., ,. _ DOCUMENTS MP w C.f. w xaxAL w TxM verge., Am. wow karma. Darter -� u. SOMA M M USE ILL ArReca All MOT LANDS R R, -� wrtx `; 12ixf SO-91- SIM PEN A.M. A.M. A GM WYMM2II ., % %i 1. \1 .... - -- - rii " m A msw, AS l UAMSTED anvixa %{R G.1 I IA . ,o-m -6912 MN uss SITS ACCENTED ammo, iy { :! :' , vr ; as C.S i; : : , oz IND TOGAS. APIAWAI. CO. WC A. CAS ONLY t '% " : % 1 % j : ti ,: "it,, ■ (' :21 ✓ / f l -' _ f y h '. . II . „e�, 0" .-- ' •' ..,41!...',-:::::: / Jf I I . I arrcvrton STATUS PLAT USERS: ON „� 7.0 Au n..ro Po f' J I.1 ,. L f I 'l) W/ES cT.WE FlM AC'11UTAa ]'HAl' E1[IFnTI LxTC• APIACPM Tnx:ARH►e :'r 26.25. 19.351n 4 081218_ MAP_ 2081990_ Nikaitchuq _OPO4- P07_Surface_Location SFD 12/18/2008 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO 2 — • 0PO4-P07 (surface TD) 6000000 • I i 7 AEO 1 4./ 5950000 - , - L- 1 1 * 900000 40 CFR 147'102 (b)(3) • :5. 5850000 400000 500000 600000 700000 800000 rage 1 oI I • • c� Maunder, Thomas E (DOA) From: Brink Jason [jason.brink @enipetroleum.com] Sent: Wednesday, March 04, 2009 8:52 AM To: Maunder, Thomas E (DOA); Gennings Tom; Grandi Maurizio; Longo Joseph; Province Robert Cc: Roby, David S (DOA); Davies, Stephen F (DOA); Brink Jason Subject: ENI Operations: Requires Immediate Action for change of Operator Importance: High Tom 1. The disposal well has been perforated. I am working the 10 -407 and you will have the details on this well by early next week. The EPA witnessed the entire operation and verbally approved the well. We are currently completing their lengthy completion report summary and will submit to them next week. All operations were witnessed and performed successfully. ENI expects no difficulties having this disposal well approved by the EPA. 2. I suspected you would ask about a change of Operator. We submitted this request to our Land department on January 27th, 2009 (your initial request) and were told that ENI filed a change of operator notice about one year ago or so. Our Land department will follow up on this immediately. � Jason Brink SvS :9-0)— Q \Cc\ Drilling Engineer (� ENI Alaska a Office: 907 -865 -3321 t. —0\ \ " L\L\ - 0 a Cell: 907 - 947 -3790 From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] �� Sent: Wednesday, March 04, 2009 8:20 AM k . \ , _ _ To: Brink Jason; Gennings Tom; Grandi Maurizio c Cc: Roby, David S (DOA); Davies, Stephen F (DOA) it'\O � c Q s - \So -o-''c Subject: RE: ENI Operations Thanks much Jason. Some additional questions ... 1. Has the disposal well been perforated and all the EPA verifications performed? 2. Regarding the Kerr -McGee wells, our records still show KM as the operator. It is probably appropriate to file a change of operator notice for those wells. Call or message with any questions. Tom Maunder, PE AOGCC From: Brink Jason [ mailto :jason.brink ©enipetroleum.com] Sent: Tuesday, March 03, 2009 5:30 PM To: Maunder, Thomas E (DOA); Gennings Tom; Grandi Maurizio Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI Operations Tom, Answers to your questions: 1. Nabors 245 is currently being cold stacked as we speak. Completion of the cold stack procedure will be next week. 3/4/2009 Page 2 of B� • • 2. (permit 1) OP03 -P05 is completed and shut -in with BPV installed and VR plugs installed in the annular valves. This producer will be put on production as production facilities are commissioned in late 2010. (permit 2) OP26 -DSPO2 is completed and shut -in with BPV installed. I am currently writing the completion 10 -407 summary for the AOGCC. This disposal well could be utilized for disposal this year. ENI is currently decisioning whether or not to commission grind and injection facilities this year or in 2010. (permit 3) OPO4 -P07 will not be drilled this year but will be drilled in the first quarter of 2010. 3. (permit request 4) Please continue to process this application. ENI plans to drill this water source well in the first quarter of 2010. 4. ENI wishes to not rename the two Oliktok Point wells drilled by Kerr - McGee. Please let me know if you have further questions. Jason Brink Drilling Engineer ENI Alaska Office: 907- 865 -3321 Cell: 907- 947 -3790 From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] Sent: Tuesday, March 03, 2009 11:35 AM To: Gennings Tom; Brink Jason Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: ENI Operations Tom and Jason, Sorry that the current economic climate has so drastically affected your operations. I have a couple of questions 1. When will rig operations be halted? 2. You have received permits for 3 new wells. What will the status of these wells be at the completion of rig operations? 3. We have received an application for a 4th well, do you desire the Commission to continue processing it? 4. In an earlier email I asked if it was intended to rename the two Oliktok Point wells drilled by Kerr - McGee. I received an acknowledgement of that question; however no decision has been communicated to me. I would appreciate hearing of the decision. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in 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. 3/4/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME A / f c Ic_er () 1 (' t� —115 (; G7%c PTD# 2-CE / V Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: A / / 71- POOL: A 1' li ! C ` Circle 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(D, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 -‘ °7 Field & Pool NIKAITCHUQ, UNDEFINED OIL - 561100 Well Name: NIKAITCHUQ O -0 Program DEV Well bore seg PTD#: 2081990 Company ENI PETROLEUM — — Initial Class /Type DEV / 1 -OIL GeoArea 890 Unit 11400 On /Off Shore On Annular Disposal Administration 11 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 373301, wellbore will pass thru ADL 355024, top prod interval & TD in ADL 39.0616_ 13 Unique well name and number Yes 4 Well located in a defined pool No NIKAITCHUQ, UNDEFINED OIL - 561100, governed by statewide regulations 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes Nearest well will be the proposed Nikaitchuq OP08 -PO4, which, when drilled, will lie about 1450' to the west. 7 Sufficient acreage available in drilling unit Yes Only well in SE 1/4 of Section 29. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes ENI has a 100% working interest ownership in lease ADL 390616 10 Operator has appropriate bond in force Yes RLB0008627 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait Yes SFD 4/15/2010 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 117 Nonconven. gas conforms to AS31.05.030(j.1 A) (j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs Yes All aquifers exempted 40 CFR 147.102 (b)(3). 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons No Slotted liner completion planned. 1 23 Casing designs adequate for C, T, B & permafrost Yes (BHL at heel was moved >500') 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 1 25 If a re-drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Traveling cylinder path calculated. Gyros possible in surface hole. 27 If diverter required, does it meet regulations Yes Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 8.5 EMW. MW planned up to 9.5 ppg. Appr GLS 4/16/2010 29 BOPEs, do they meet regulation Yes (7 day BOP test cycle unless approved by Commission) 1 130 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 1255 psi. 3500 psi BOP testplanned. 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S is not known in SB. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected based in offset drilling Geology 1 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.5 ppg EMW; will be drilled using 8.8 to 9.5 ppg mud 37 Seismic analysis of shallow gas zones NA Hydrates may be encountered; mitigation measures discussed in drilling hazards summary Appr Date SFD 4/15/2010 38 Seabed condition survey (if off-shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering ' Re -issue due to bottom hole change. Well name also changed from OPO4 -P07 to OPO4 -07. Date: Date Dat • Commissioner: Commissioner: 4-14 -/ DTS 6JKN \\ �� SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co Inc. 3800 Centerpoint Dr. Ste 300 Anchorage AK 99503 Re: Nikaitchuq Field, Nikaitchuq Undefined Oil Pool, OPO4 -P07 ENI US Operating Co Inc. Permit No: 208 -199 Surface Location: 3217 FSL, 1541' FEL, S5, T13N, R9E, UM Bottomhole Location: 3189' FSL, 2124' FEL, S29, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this/ day of December, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • 0 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 0' l t 20 AAC 25.005 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil Q 1 c. Specify if well is proposed for: Drill Q Re -drill Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple ZonC Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: I_ I Blanket ❑ Single Well 11. Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 OPO4 -P07 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 3800 Centerpoint Drive Suite 300, Anchorage 99503 MD: 12225' , TVD: 3936' ' Nikaitchuq 4a. Location of Well (Governmental Section): 7. Property D� { . * Surface: 3217' FSL, � ' FEL, S5 T13N R9E UM • 04 AD( 355024 390616' Top of Productive Horizon: 154/ l 1. *f 4g•nb 8. Land Use Permit: 13. Approximate Spud Date: 4623' FNL, 1645' FEL, S32 T14N R9E UM ADL 417493 1/15/2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4568' to South Line 3189' FSL, 2124' FEL, S29 T14N R9E UM 1,280' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 516739 y- 6036569 Zone- 4 (Height above GL): 12' MSL & 52' RKB Well within Pool: 2568' East to OP03 -P05 16. Deviated wells: Kickoff depth: 300 ' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° deg Downhole: 1658 psig . Surface: 1240 psig • 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X -65 Welded 124 36 36 160 160 pre - installed 16" 13 -3/8" 68 L -80 BTC 2825 35 35 2860 " 2152 • 716 sx 10.7# ASL, 220 sx 12.0# Deeperete 12.25" 9 -5/8" 47 L -80 BTCM 8244 33 33 8277 , 3850 • 367 sx 12.5# Deeperete 8.5" 5.5" 17 L -80 DWC 4148 8077 3837 12225 - 3936 • Slottled liner in open hole 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketct❑ Drilling Program Time v. Depth ❑t Shallow Hazard Analysis Q Property Plat Q Diverter SketctJ Seabed Repor❑ Drilling Fluid Prog i 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jason Brink @ 907 - 865 -3321 Printed Name Maurizio Grandi \ Title Well Operation Project Manager Signature /t . / - Phone y,) 7 f( , s - 3 j) )Date to , ( 1 S ! 0 e r 1 JV "l Commission Use Only Permit to Drill � API Number: Permit Approval See cover letter / Number: [:.3 -� -/� 50- pZ_- 2,,„,3V6?- I Date: 1 , 1 1, cg for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produc coalbed methane, gas hydrates, or gas contained in shales: El � Samples req'd: Yes Li No Z Mud log req'd: Yes ❑ Nog . . C1 y � u + Other: q_ �' H2S measures: Yes ❑ No Directional svy req Yes No 350 r A r .t� - k c �� i'' S ∎ \ y.'% 4 •- •-■1 Cq ∎41 ,A 0 <5 / / 7 / / APPROVED BY THE COMMISSION / D ATE: , COMMISSIONER ` r r� € t :b /z• 0 P. °a Form 10 -401 Revised 12/2005 ' L i ! 1 E \ IA 1 Submit in Du /4C* • • Erg Enii 'l c jt�ro IIauIm 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Maurizio Grandi Phone (907) 865 -3320 Email: Maurizio .Grandi @enipetroleum.com December 10, 2008 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill Producer OPO4 -P07 Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Permit to Drill for the onshore production well OPO4 -P07. • The well will be drilled and completed using Nabors rig 245E. The planned spud date for OPO4 -P07 is January 15, 2009. Please find attached for the review of the Commission forms 10 -401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Jason Brink at 907 - 865 -3321 or Joseph Longo at 907 - 865 -3323. Sincerely, Maurizio Grandi Well Operation Project Manager iroot E inl • Appin for Permit to Drill, Well OPO4 -P07 . C iroO iuiI Revision No.O ( Saved: 16-Dec-08 Eni Application for Permit to Drill Document Producer Well OPO4 -P07 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (0 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005 (c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 Surface Hole Mud Program (extended bentonite) 4 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10. Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005 (c)(11) 5 12. Evidence of Bonding 5 Requirements of 20 AAC 25.005 (c)(12) 5 OPO4 -P07 PERMIT Document.doc Page 1 of 7 Printed: 16- Dec -08 AppIi n for Permit to Drill, Well OPO4 -P07 Revision No.0 En Saved: 16- Dec -08 ed 13. Proposed Drilling Program 6 Requirements of 20 AAC 25.005 (c)(13) 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AA C 25.005 (c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 BOP and Diverter Configuration 7 Attachment 4 Cement Loads and CemCADE Summary 7 Attachment 5 Well Schematic 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 1. Well Name Requirements of 20 AAC 25.005 (1) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25040(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. The well for which this Application is submitted will be designated as OPO4 -P07. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; ��\ .1 ) Location at Surface 3217' FSL, 1 ' FEL, S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 52' AMSL • Northings 6,036,569: Eastings: 516,739' • Pad Elevation 12' AMSL • Location at Top of Productive Interval 4623' FNL, 1645' FEL, S32 T14N R9E UM ( "OA" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7,732' Northings: 6,043,255' Eastings: 516,599' Total Vertical Depth, RKB: 3,757' Total Vertical Depth, 55: 3,708' Location at Total Depth 3189' FSL, 2124' FEL, S29 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12,202' Northings: 6,047,100' Eastings: 516,100' Total Vertical Depth, RKB: 3,936' Total Vertical Depth, 55: _ 3,884' Please see Attachment 7: Surface Platt OPO4 -P07 PERMIT Document. doc Page 2 of 7 Printed: 16- Dec -08 P/S Applifn for Permit to Drill, Well OPO4 -P07 Eni JL �,. • a tIr O Ilea Saved: 16- Dec -08 Ertl and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated, the application for a Permit to Drill (Form 10 -401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those we /is, to the extent that those names are known or discoverable in pub /ic records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 MC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app //cation: (4) information on dri /ling hazards, including (A) the maximum downho/e 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 0.44 psi /ft, or 8.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the OA sand formation is 1,240 psi: MPSP = (3,757 ft TVD)(0.44 - 0.11 psi /ft) = 1,240 psi . (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. • and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ /cation 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 /ntegrity tests, as required under 20 AAC 25.030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure OPO4 -P07 PERMIT Document. doc Page 3 of 7 Printed: 16- Dec -08 rAk AppI n for Permit to Drill, Well OPO4 -P07 � Revision No.0 E iniu 16) E Ir s 11 c LUII 11 Saved: 16-Dec-08 Erd 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 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) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X -65 Welded 120 40 / 40 1607 160' Cemented to surface Cemented to Surface with 716 sx 10.7# ASLite Lead Yield 4.33 cu. Ft./ sk, 13 -3/8 16 68 L -80 BTC 2860' 0 / 0 2860' / 2152' 220 sx 12.0# DeepCRETE Tail Yield 1.60 cu. ft./ sk Cement Top planned @ 6400' MD / 3313' TVD Cemented w/ 9 -5/8 12 -1/4 47 L -80 BTCM 8277' 0 / 0 8277' / 3850' 367 sx 12.5# DeepCRETE Yield 2.25 cu. ft./ sk 8 -1/2" OA 5 -1/2 Sand 17 L -80 DWC 3749' 8076' / 3835' 12225'/ 3936' Slotted Liner - no cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration A 21 -1/4 ", 2000 psi diverter with a 16" diameter diverter line and valve will be the diverter system used for drilling the surface hole. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 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) OPO4 -P07 PERMIT Document.doc Page 4 of 7 Printed: 16- Dec -08 AppliS for Permit to Drill, Well OPO4 -P07 Revision No.O lEni r �i t - �,� � �� Saved: 16- Dec -08 -J Yield Point 50 70 30 50 (Ib /100 sf) 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 (LSND) Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 13 -3/8" Csg Shoe to 9 -5/8" Csg Point Value Value Density (ppg) 9.0 — 9.3 ' Density (ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity 45 - 60 (CP) (seconds) Yield Point 15 - 20 Plastic Viscostiy (lb /100 sf) 12 - 18 (CP) HTHP Fluid loss Yield Point (m1/30 min @ <5.0 (lb /100 sf) 18 -24 200psi & 100 °F API Filtrate Oil / Water Ratio 75 / 25 (cc /30 min)) 4 - 6 Electrical Stability >600 Chlorides (mg /I) <500 pH 9.0 — 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(0; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom- founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bondingjhave been met; OPO4 -P07 PERMIT Document.doc Page 5 of 7 Printed: 16- Dec -08 1111 r* Appli n for Permit to Drill, Well OPO4 -P07 L II 111 Revision No.0 1 Saved: 16-Dec-08 Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. Install 21 -1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point at +/- 2860 MD / 2152' TVD as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3. Run and cement 13 -3/8 ", 68 #, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 4. Remove diverter system, install and test wellhead to 5000 PSI. 5. Nipple up 13 -5/8" 5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12 -1/4" bit and 8" directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. • 9. Directionally drill to 9 -5/8" casing point at 8277' MD / 3850' TVD. Pull out of hole backreaming to the surface casing shoe. 10. Run and cement 9 -5/8 ", 47# L80, BTC Mod casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 11. Install 9 -5/8" packoff and test to 5000 psi. 12. Flush 13 -3/8" x 9 -5/8" annulus with water, followed by diesel. 13. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 14. PU 8 -1/2" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 15. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. 16. Directionally drill 8 -1/2" hole to TD at +/- 12225' MD / 3936' TVD as per directional plan. Pull out of hole backreaming to the surface casing shoe. 17. PU and run 5 -1/2" slotted liner to TD. 18. Land liner, set liner hanger with 200' Liner lap inside the 9 -5/8" intermediate casing. POOH laying down DP as required. 19. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 20. Nipple down BOP, nipple up tree and test. Pull BPV. 21. Freeze protect well with diesel by pumping into 4 -1/2" x 9 -5/8" annulus, taking returns from tubing. 22. Set BPV and move rig off. 23. Rig up wire line unit. Pull BPV. 24. Set shear -out valve in mandrel. Use ESP to clean up well. 25. Place well on production. OPO4 -P07 PERMIT Document.doc Page 6 of 7 Printed: 16- Dec -08 r i.t • Applii n for Permit to Drill, Well OPO4 -P07 EiniH t Ileum Saved: 16- Dec -08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt OPO4 -P07 PERMIT Document.doc Page 7 of 7 Printed: 16- Dec -08 r . Eni Petroleum _ $cblumberger OPO4 P07 (P5) Proposal Report Date: December 1, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 356.650° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Oliktok Point / OPO4 •' sWdy TVD Reference Datum: Rotary Table Well: OPO4 -P07 TVD Reference Elevation: 52.00 ft relative to MSL Borehole: OPO4 -P07 Feas'bM Sea Bed I Ground Level Elevation: 12.00 ft relative to MSL UWI /API #: 50029 Magnetic Declination: 22.364° Survey Name I Date: OPO4-P07 (P5) / February 15, 2009 Total Field Strength: 57675.294 nT Tort / AHD 1 DDI I ERD ratio: 104.459° / 10577.67 ft / 6.536 / 2.687 Magnetic Dip: 80.931° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 15, 2009 • Location Lat/Long: N 70.51109600, W 149.86302154 Magnetic Declination Model: BGGM 2008 Location Grid WE YIX: N 6036569.433 ftUS, E 516739.268 ftUS North Reference: True North Grid Convergence Angle: +0.12913046° Total Corr Mag North -> True North: +22.364° Grid Scale Factor: 0.99990032 Local Coordinates Referenced To: Well Head Measured Vertical Mag 1 Gray Directional Comments Inclination Azimuth Sub -Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (ft) (ft) (ft ) (ft) (deg) (degl100ft ) Index (ftUS) (SUS) RTE 0.00 0.00 359.71 -52.00 0.00 0.00 0.00 0.00 - -- 0.00 0.00 6036569.43 516739.27 N 70.51109600 W 149.86302154 WRP 41.00 0.00 359.71 -11.00 41.00 0.00 0.00 0.00 -- 0.00 0.00 6036569.43 516739.27 N 70.51109600 W 149.86302154 KOP Bld 1.5/100 300.00 , 0.00 359.71 248.00 300.00 0.00 0.00 0.00 359.71M 0.00 0.00 6036569.43 516739.27 N 70.51109600 W 149.86302154 Bld 3.5/100 400.00 1.50 359.71 347.99 399.99 1.31 1.31 -0.01 359.71M 1.50 0.29 6036570.74 516739.26 N 70.51109958 W 149.86302159 500.00 5.00 359.71 447.81 499.81 6.97 6.98 -0.04 HS 3.50 1.54 6036576.41 516739.22 N 70.51111507 W 149.86302183 600.00 8.50 359.71 547.10 599.10 18.70 18.73 -0.09 HS 3.50 2.20 6036588.16 516739.13 N 70.51114717 W 149 700.00 12.00 359.71 645.49 697.49 36.47 36.52 -0.18 HS 3.50 2.64 6036605.95 516739.00 N 70.51119577 W 149.86302305 Gyro Point 800.00 15.50 359.71 742.61 794.61 60.20 60.28 -0.31 HS 3.50 2.97 6036629.71 516738.83 N 70.51126069 W 149.86302404 1 900.00 19.00 359.71 838.10 890.10 89.81 89.93 -0.46 HS 3.50 3.24 6036659.36 516738.61 N 70.51134169 W 149.86302526 1000.00 22.50 359.71 931.60 983.60 125.18 125.36 -0.63 HS 3.50 3.46 6036694.78 516738.35 N 70.51143846 W 149.86302673 1100.00 26.00 359.71 1022.76 1074.76 166.19 166.42 -0.84 HS 3.50 3.65 6036735.84 516738.05 N 70.51155065 W 149.8630284 1200.00 29.50 359.71 1111.24 1163.24 212.67 212.98 -1.08 HS 3.50 3.81 6036782.38 516737.71 N 70.51167782 W 149.8630303 1300.00 33.00 359.71 1196.72 1248.72 264.47 264.84 -1.34 HS 3.50 3.96 6036834.25 516737.33 N 70.51181952 W 149.86303251 1400.00 36.50 359.71 1278.87 1330.87 321.38 321.83 -1.63 HS 3.50 4.09 6036891.23 516736.91 N 70.51197521 W 149.86303487 Cry 2/100 1487.78 39.57 359.71 1348.00 1400.00 375.38 375.91 -1.90 HS 3.50 4.20 6036945.30 516736.52 N 70.51212294 W 149.86303711 1500.00 39.82 359.71 1357.41 1409.41 383.18 383.72 -1.94 HS 2.00 4.21 6036953.11 516736.46 N 70.51214427 W 149.86303743 1600.00 41.82 359.71 1433.08 1485.08 448.44 449.08 -2.27 HS 2.00 4.31 6037018.46 516735.98 N 70.51232282 W 149.86304014 1700.00 43.82 359.71 1506.43 1558.43 516.31 517.04 -2.62 HS 2.00 4.39 6037086.41 516735.49 N 70.51250848 W 149.86304295 1800.00 45.82 359.71 1577.37 1629.37 586.69 587.52 -2.97 HS 2.00 4.47 6037156.88 516734.97 N 70.51270102 W 149.86304587 1900.00 47.82 359.71 1645.80 1697.80 659.50 660.43 -3.34 HS 2.00 4.55 6037229.79 516734.44 N 70.51290021 W 149.86304889 2000.00 49.82 359.71 1711.64 1763.64 734.65 735.69 -3.72 HS 2.00 4.62 6037305.04 516733.89 N 70.51310580 W 149.86305201 Cry 3.5/100 2057.03 50.96 359.71 1748.00 1800.00 778.52 779.62 -3.95 2.78L 2.00 4.66 6037348.96 516733.56 N 70.51322581 W 149.86305383 WellDesign Ver SP 2.1 Bld( doc4ox_100) OPO4 \OPO4- P07\OPO4- P07 \OPO4 -P07 (P5) Generated 12/1/2008 12:39 PM Page 1 of 3 Measured Vertical Mag I Gray I Directional Comments Inclination Azimuth Sub -Sea TV TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deq) (deg) (ft) 1 (ft) (ft) (ft ) (ft) (deg) (degl100ft ) Index (ftUS) (ftUS) 2100.00 52.46 359.62 1774.63 1826.63 812.20 813.34 -4.14 2.72L 3.50 4.69 6037382.68 516733.29 N 70.51331794 W 149.86305545 2200.00 55.96 359.42 1833.10 1885.10 893.20 894.44 -4.83 2.60L 3.50 4.77 6037463.77 516732.42 N 70.51353949 W 149.86306106 2300.00 59.45 359.23 1886.52 1938.52 977.62 978.95 -5.83 2.50L 3.50 4.84 6037548.27 516731.24 N 70.51377037 W 149.86306922 2400.00 62.95 359.06 1934.69 1986.69 1065.16 1066.56 -7.13 2.42L 3.50 4.91 6037635.87 516729.73 N 70.51400970 W 149.86307990 2500.00 66.45 358.90 1977.42 2029.42 1155.47 1156.94 -8.74 2.35L 3.50 4.98 6037726.23 516727.92 N 70.51425660 W 149.86309307 2600.00 69.94 358.75 2014.56 2066.56 1248.24 1249.75 -10.65 2.29L 3.50 5.04 6037819.03 516725.81 N 70.51451014 W 149.86310866 End Cry 2625.95 70.85 358.71 2023.27 2075.27 1272.67 1274.19 -11.19 - -- 3.50 5.06 6037843.47 516725.21 N 70.51457691 W 149.86311310 13 -3/8 "Csg 2859.89 70.85 358.71 2100.01 2152.01 1493.52 1495.13 -16.17 -- 0.00 5.15 6038064.37 516719.73 N 70.51518048 W 149.86315383 Cry 4/100 7783.19 70.85 358.71 3715.01 3767.01 6141.39 6144.83 - 120.90 5.24R 0.00 5.95 6042713.35 516604.54 N 70.52788279 W 149.86401154 7800.00 71.52 358.77 3720.43 3772.43 6157.29 6160.74 - 121.24 5.22R 4.00 5.96 6042729.25 516604.15 N 70.52792624 W 149.864014 7900.00 75.50 359.15 3748.80 3800.80 6253.08 6256.59 - 122.98 5.11R 4.00 5.99 6042825.09 516602.20 N 70.52818810 W 149.86402 8000.00 79.49 359.51 3770.45 3822.45 6350.58 6354.19 - 124.12 5.03R 4.00 6.02 6042922.68 516600.85 N 70.52845473 W 149.864037 8100.00 83.47 359.86 3785.26 3837.26 6449.32 6453.07 - 124.65 4.98R 4.00 6.06 6043021.54 516600.09 N 70.52872484 W 149.86404236 End Cry 8176.46 86.52 0.13 3791.93 3843.93 6525.35 6529.22 - 124.66 - -- 4.00 6.08 6043097.70 516599.91 N 70.52893290 W 149.86404240 O -P7 Heel 8276.46 86.52 0.13 3798.00 3850.00 6624.98 6629.04 - 124.43 - -- 0.00 6.09 6043197.50 516599.91 N 70.52920558 W 149.86404056 9 -5/8" Csg 8276.62 86.52 0.13 3798.01 3850.01 6625.15 6629.20 - 124.43 - 0.00 6.09 6043197.67 516599.91 N 70.52920603 W 149.86404055 8276.71 86.52 0.13 3798.02 3850.02 6625.23 6629.29 - 124.43 165.85L 0.00 6.09 6043197.75 516599.91 N 70.52920626 W 149.86404055 8276.94 86.52 0.13 3798.03 3850.03 6625.46 6629.51 - 124.43 - -- 2.00 6.09 6043197.98 516599.91 N 70.52920688 W 149.86404055 Cry 2/100 8810.38 86.52 0.13 3830.45 3882.45 7156.93 7161.97 - 123.23 HS 0.00 6.15 6043730.38 516599.91 N 70.53066146 W 149.86403081 P07 Tgt 1 8884.59 88.00 0.13 3834.00 3886.00 7230.92 7236.10 - 123.06 HS 2.00 6.16 6043804.50 516599.91 N 70.53086398 W 149.86402945 8900.00 88.31 0.13 3834.50 3886.50 7246.29 7251.50 - 123.03 HS 2.00 6.17 6043819.90 516599.91 N 70.53090604 W 149.86402916 End Cry 8954.88 89.41 0.13 3835.59 3887.59 7301.06 7306.36 - 122.90 - -- 2.00 6.18 6043874.76 516599.91 N 70.53105592 W 149.86402814 Cry 2/100 9177.46 89.41 0.13 3837.90 3889.90 7523.22 7528.93 - 122.39 42.80L 0.00 6.20 6044097.30 516599.92 N 70.53166395 W 149.86402396 P07 Tgt 2 9188.66 89.57 359.98 3838.00 3890.00 7534.40 7540.13 - 122.38 43.79L 2.00 6.20 6044108.50 516599.91 N 70.53169454 W 149.86402388 End Cry 9199.63 89.73 359.83 3838.07 3890.07 7545.35 7551.10 - 122.40 - -- 2.00 6.21 6044119.48 516599.87 N 70.53172453 W 149.86402403 Cry 4/100 9345.90 89.73 359.83 3838.76 3890.76 7691.39 7697.37 - 122.84 94.23L 0.00 6.22 6044265.72 516599.10 N 70.53212410 W 149.86402764 9400.00 89.57 357.67 3839.09 3891.09 7745.45 7751.45 - 124.02 94.21L 4.00 6.24 6044319.80 516597.80 N 70.53227185 W 149.86403732 P07 Tgt 3 9491.99 89.30 354.00 3840.00 3892.00 7837.41 7843.18 - 130.70 93.25L 4.00 6.26 6044411.50 516590.91 N 70.53252243 W 149.86409205 9500.00 89.28 353.68 3840.10 3892.10 7845.41 7851.14 - 131.56 93.24L 4.00 6.27 6044419.46 516590.03 N 70.53254418 W 149.8640990 9600.00 89.06 349.69 3841.55 3893.55 7945.01 7950.06 - 146.02 93.19L 4.00 6.29 6044518.34 516575.35 N 70.53281441 W 149.8642175 End Cry 9625.56 89.00 348.67 3841.98 3893.98 7970.34 7975.16 - 150.82 - -- 4.00 6.30 6044543.42 516570.50 N 70.53288298 W 149.86425686 Cry 4 /100 9777.11 89.00 348.67 3844.62 3896.62 8120.40 8123.73 - 180.60 123.98R 0.00 6.31 6044691.91 516540.38 N 70.53328886 W 149.86450084 PO7 Tgt 4 9795.04 88.60 349.26 3845.00 3897.00 8138.17 8141.33 - 184.03 122.50R 4.00 6.32 6044709.50 516536.91 N 70.53333693 W 149.86452896 9800.00 88.49 349.43 3845.13 3897.13 8143.09 8146.20 - 184.95 122.50R 4.00 6.32 6044714.37 516535.98 N 70.53335023 W 149.86453646 End Cry 9809.87 88.28 349.76 3845.40 3897.40 8152.88 8155.90 - 186.73 - -- 4.00 6.32 6044724.07 516534.18 N 70.53337674 W 149.86455106 Cry 2/100 10665.48 88.28 349.76 3871.06 3923.06 9001.93 8997.51 - 338.76 1.37R 0.00 6.40 6045565.24 516380.27 N 70.53567586 W 149.86579667 10700.00 88.97 349.78 3871.89 3923.89 9036.19 9031.47 - 344.89 1.37R 2.00 6.41 6045599.18 516374.06 N 70.53576864 W 149.86584691 P07 Tgt 5 10706.42 89.10 349.78 3872.00 3924.00 9042.56 9037.79 - 346.03 1.54R 2.00 6.41 6045605.50 516372.91 N 70.53578591 W 149.86585624 End Cry 10743.24 89.84 349.80 3872.34 3924.34 9079.12 9074.02 - 352.55 - -- 2.00 6.41 6045641.71 516366.30 N 70.53588489 W 149.86590972 Cry 2/100 11302.50 89.84 349.80 3873.94 3925.94 9634.38 9624.44 - 451.59 175.21L 0.00 6.46 6046191.85 516266.04 N 70.53738852 W 149.86672133 WellDesign Ver SP 2.1 Bld( doc40x_100) OPO4 \OPO4- P07 \OPO4- P07 \OPO4 -P07 (P5) Generated 12/1/2008 12:39 PM Page 2 of 3 Measured Vertical Mag I Gray Directional Comments Inclination Azimuth Sub -Sea TV ND NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty P (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (deg/100ft ) Index (ftUS) (ftUS) P07 Tgt 6 11314.34 89.60 349.78 3874.00 3926.00 9646.14 9636.09 - 453.69 174.21L 2.00 6.46 6046203.50 516263.91 N 70.53742037 W 149.86673854 End Cry 11325.92 89.37 349.76 3874.10 3926.10 9657.63 9647.49 - 455.75 - -- 2.00 6.46 6046214.89 516261.83 N 70.53745150 W 149.86675539 TD / 7" Csg , 12225.37 89.37 349.76 3884.00 . 3936.00 10550.53 10532.55 - 615.69 - -- ' 0.00 6.54 6047099.50 516099.91 N 70.53986933 W 149.86806636 Survey Error Model: SLB ISCWSA version 24 *** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft) MD To (ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 40.00 1/100.00 SLB_NSG +SSHOT -Depth Only OPO4 -P07 -> OPO4 -P07 (P5) 40.00 800.00 1/100.00 SLB_NSG +SSHOT OPO4 -P07 -> OPO4 -P07 (P5) 800.00 2625.95 1/100.00 SLB_MWD +GMAG ^A1 OPO4 -P07 -> OPO4 -P07 (P5) 2625.95 8276.62 1/100.00 SLB_MWD +GMAG ^ 2 OPO4 -P07 -> OPO4 -P07 (P5) 8276.62 12225.37 1/100.00 SLB_MWD +GMAG ^ 3 OPO4 -P07 -> OPO4 -P07 (P5) Legal Description: Northing (Y) (ftUS] Easting (X) (ftUS] • Surface : 3216 FSL 1541 FEL S5 T13N R9E UM ' 6036569.43 • 516739.27 O -P7 Heel : 4565 FSL 1645 FEL S32 T14N R9E UM 6043197.50 516599.91 TD / BHL : 3189 FSL 2124 FEL S29 T14N R9E UM 6047099.50 516099.91 • WellDesign Ver SP 2.1 Bld( doc40x_100) OPO4 \0PO4- P07 \OPO4- P07 \OPO4 -P07 (P5) Generated 12/1/2008 12:39 PM Page 3 of 3 Eni Eni Petroleum Schlumberger WELL FIELD STRUCTURE OPO4 -P07 (P5) I Nikaitchuq Oliktok Point Magnet. Parameters Surface L0caSon NAD27 Ahska StMe Planes, Zone 04, US Feet Mlacersnoops Modal BGGM 2005 Dip: 80.931' Date: February 15, 2009 Lat N703039.946 Northing: 0436569.43060 G4 Cony: +0 12913046 5297 OPO4 ND Ref: Rotary Table (52000 above MSL) Meg Dec: 022.364' FS 57675.3 nT ton'. W1495146.678 Easting. 51673927 BUS Scale Fact. 09969003183 Pb,, : OPO4P07 (P5) Sryy Date: February 15, 2003 6400 7200 8000 8800 9600 10400 0 800 CD OPO4 -P07 (P5) CO Cry 4/100 End Cry C 0-P7 Heel P07 Tgt 2 End Cry R07 Tgt 4 R07 Tgt 5 h • RTE 93/8" Csg Cry 2/100 P07 T � Cm b /100 End Cry Cry 2/100 c:7 ry 2/10: End Cry — � End Cry , TD /'" Csg KOP Bid 1.5/100 II N Bld 3.5/100 03 4000 OPO4 -P07 (P5 4000 Cl) Cry 2/100 Cry 4/100 €nd Cry P07 Tgt 1 End Cry P07 Tgt 3 Gyro Point 800 6400 7200 8000 8800 9600 10400 Vertical Section (ft) Azim = 356.65 ° , Scale = 1(in):800(ft) Origin = 0 N / -S, 0 E / -V Cry 2/100 • 0 1600 "cw 3:5/1110 1600 0 co C End Cry 13 -3/8" Csg II N. co > 0 2400 2400 • F • 3200 3200 Cry 4800 End Cry 0 -P7 Heel 9-5/8" Csa unli OPO4 -P07 (P5) 4000 4000 0 800 1600 2400 3200 4000 4800 5600 6400 Vertical Section (ft) Azim = 356.65 ° , Scale = 1(in):800(ft) Origin = 0 N / -S, 0 E / -V • • Evil Petroleum Schlumberger WELL FIELD STRUCTURE OPO4 -P07 (P5) Nikaitchuq Oliktok Point Magnetic Parameters Surface Location NND27 Maske State Manes, Zone 04, US Feet MaceIlaneous Model. 00082008 Dip 80.931' Date: February 15. 2009 Lat N70 30 39 946 N4rtNg: 6036569.433US Grid Corm'. +0.12913045' Slot OPO4 NS Ref: Rotary Table (5263 R above MSL) Mag Dec: +22.364' F5: 576753 nT Lon W149 51 46678 Eastin9: 516739.27 SUS Scale Fact. 0.9999003183 Plan OPO4-P07(P5) Sr, Date: February 15.2009 -3000 -1500 0 1500 3000 10500 Pe4,1,0710s1 10500 TD /7 " Csg End Cry P07 Tgt 6 Cry 2/100 End Cry P07 Tgt 5 9000 9000 Cry 2/100 N End Cry d► i rk P07 Tgt 4 ' Cry 4/100 End Cry • P07 Tgt 3 . End Cry rvaloo Pp7.7st.2 7500 7500 End Cry Cry 2/100 PO7 Tgt 1 • Cry 2/100 9-5/8" Csg O -P7 Heel End Cry NI • A A Z Cry 4/100 6000 6000 0 0 c II 8 4500 4500 co V V V 3000 3000 1500 13 -3/8" Csg I Q 1500 End Cry Cry 3.5/100 Cry 2/100 0 Gyro-Point 0 Bld 3.5/100 KOP Bid 1.5/100 RTE -3000 -1500 0 1500 3000 «< W Scale = 1(in):1500(ft) E »> • • ANTICOLLISION SUMMARY REPORT Client: ENI Slot: OPO4 Field: Nikaitchuq Well: OPO4 -P07 Structure: Oliktok Point Borehole: OPO4 -P07 Subject Trajectory: OPO4 -P07 (P5) (PLAN) Rpt Date: December 01, 2008 Analysis Method: Normal Plane Depth Interval: Every 100.00ft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Mag Model: BGGM 2008 I Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct (ft)_ Dev. (ft) Fact. MD (ft) I TVD (ft) _ Alert I Minor I Major Oliktok Point I -1 (DEF SW) PASS I 24.751 21.801 74.85 99.00 99.00 MinPts 48.52 41.92 16.81 499.14 498.95 MinPt -O -SF 6319.4911 6166.8411 63.111 4957.84 2840.20 MinPts Oliktok Point 1 -1A -106 (P3) (DEF PLN) PASS 24.751 21.80 74.85 99.00 99.00 MinPts 48.52 41.92 16.81 499.14 498.95 MinPt -O -SF 1 6287.401 6117.73 56.39 6736.61 3423.70 MinPt -CtCt I 6301.081 6069.52 41.25 8917.96 3886.97 MinPt -CtCt 6303.7711 6061.25i1 39.38 9369.54 3890.89 MinPt -O -ADP 6840.19 6516.5711 31.9411 11818.97 3931.53 MinPt -O -S Oliktok Point 1 -2 (DEF SW PASS 1 5.76 10.24 6.59 349.03 349.02 MinPt -CtCt 16.91 9.711 4.59 499.01 498.82 5.00 Enter Alert 16.91 9.71 4.59 499.01 498.82 5.00 Exit Alert 1568.41 1516.051 47.101 2476.73 2019.97 MinPt -O -SF 4107.71 3985.07 1 51.261 4531.99 2700.51 MinPt -O -SF 6896.12 6657.691 43.831 7775.74 3764.56 MinPt -O -SF 7212.61 6963.301 43.821 8068.67 3833.36 MinPt -O -SF 7406.78 7149.871 43.651 8267.29 3849.44 MinPt -O -SF 7947.52 7632.201 38.101 10416.90 3915.61 MinPt -O -SF OP03- P05P61 current SURVEY PASS 7.96 5.04 19.33 98.80 98.80 MinPt-CtCt 8.19 3.91 4.80 298.80 298.80 5.00 Enter Alert 11.44 5.41 3.80 498.88 498.70 MinPt -O -SE 16.20 9.03 4.40 598.55 597.67 5.00 Exit Alert 1643.63 1486.9311 15.9611 2350.70 1963.62 MinPt-O-SF OP05-P06 (P3) (DEF PLN PASS 8.01 3.02 3.31 300.00 300.00 5.00 Enter Alert 8.47 2.421 2.531 399.88 399.87 MinPts 11.90 4.55 2.91 499.16 498.97 5.00 Exit Alert 1 5088.631 4917.26 45.18 6895.21 3475.72 MinPt -CtCt 5100.511 4866.67 33.05 9096.27 3889.06 MinPt -CtCt 5101.5711 4861.7011 32.22 9351.01 3890.79 MinPt -O -ADP 5134.32 4886.42 1 31.371 9482.34 3891.88 MinPt -O -SF 5613.52 5299.091 26.981 11787.78 3931.19 MinPt -O -SF OP06 -105 (P2) (DEF PL PASS 16.02 11.02 8.12 300.00 300.00 MinPt-CtCt 16.66 10.63 6.01 399.78 399.77 MinPt -O -ADP 23.94 15.06 5.041 597.80 596.93 MinPt -O -SF 3206.92 3125.201 60.681 3744.01 2442.03 MinPt -O -SF 1 3841.011 3672.04 34.59 7101.16 3543.28 MinPt -CtCt I 3850.391 3636.69 27.33 8621.04 3870.94 MinPt -CtCt 1 3850.391 3628.05 26.26 9126.41 3889.37 MinPt -CtCt 3851.9111 3624.3411 25.65 9362.21 3890.84 MinPt -O -ADP 3865.39 3634.141 25.331 9443.51 3891.47 MinPt -O -SF 3925.21 3689.831 25.271 9577.22 3893.18 MinPt -O -SF 4234.61 3958.44 1 23.201 11199.40 3925.65 MinPt -O -SF OP08 -104 (P3) (DEF PLN PASS 40.04 35.05 22.57 300.00 300.00 MinPt -CtCt 40.66 34.68 16.41 399.49 399.48 MinPt -O -ADP 64.24 52.731 10.28i1 788.98 783.98 MinPt -O -SF 1 1 1298.841 1113.69 10.65 7775.49 3764.48 MinPt-CtCt Version DO 4.0 (doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 12/1/2008 12:53 PM Page 1 of 3 • 0 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct ft Dev. (ft) Fact. MD (ft) I TVD (ft) Alert I Minor I Major MEM 1 091.80 9.46 8586.58 3868.85 MinPt -CtCt 1301.0311 1078.601 8.86 9332.56 3890.70 MinPt -O -ADP 1308.48 1083.07 IMIE 9443.59 3891.47 MinPt -O -SF 1446.30 1208.80 9.22 10122.34 3906.77 TD OP10 -107 (P2) (DEF PLN PASS 55.72 49.83 23.55 399.33 399.32 MinPt-CtCt 56.10 49.25 18.46 497.93 497.75 MinPt -O -ADP 99.23 74.06 6.40' 1286.70 1237.54 MinPt -O -SF 445.65 376.981 10.051 3404.33 2330.61 MinPt-O-SF 1172.52 949.851 7.971 8374.18 3855.94 MinPt -O -SF 11 1333.8611 1067.75 7.58 11791.27 3931.22 MinPt-CtCt 1337.4611 1064.6311 7.4111 12191.22 3935.62 MinPts OP11 -PO4 (P2) (DEF PLN PASS 64.08 59.08 37.01 300.00 300.00 MinPt -CtCt 64.54 58.63 27.27 399.23 399.22 MinPt -O -ADP 100.91 88.211 14.461 884.97 875.87 MinPt -O -SF 149.95 132.07 14.381 1166.87 1134.25 MinPt -O -SF 241.97 218.941 17.491 1815.72 1640.29 MinPt -O -SF 11 449.1111 348.08 6.80 6712.59 3415.82 MinPt -CtCt 454.9011 341.711 6.13 6796.87 3443.46 MinPt -O -ADP 494.65 359.50 5.57 6958.93 3496.63 MinPt -O -SF 1 1 2643.4211 2418.8211 17.841 9682.04 3894.97 MinPts OP12 -101 (P2) (DEF PL PASS 72.09 67.10 41.83 300.00 300.00 MinPt-CtCt 72.70 66.73 30.32 399.11 399.10 MinPt -O -ADP 107.18 96.34 18.841 785.24 780.37 MinPt -O -SF 216.35 197.671 19.821 1241.45 1199.06 MinPt -O -SF 542.80 502.451 21.411 2281.23 1928.89 MinPt -O -SF 2293.90 2136.601 22.201 6561.58 3366.28 MinPt -O -SF 5063.90 4789.83 27.96 11217.34 3925.70 TD OP13 -P01 (P2) (DEF PLN) PASS 88.101 83.111 51.45 300.00 300.00 MinPts 159.96 147.271 23.201 875.85 867.21 MinPt -O -SE 251.94 233.141 22.961 1143.23 1113.36 MinPt -O -SF 1030.13 983.071 34.591 2292.24 1934.57 MinPt -O -SF 3264.13 3140.731 40.471 4909.83 2824.45 MinPt -O -SF 5711.04 5488.751 38.961 8245.57 3848.12 MinPt -O -SF 6452.29 6210.691 40.461 9237.97 3890.25 MinPt -O -SF 7386.15 7077.321 36.151 12216.35 3935.90 MinPt -O -SF OP14-P02 (P2) (DEF PLN) PASS 96.111 91.11 56.26 300.00 300.00 MinPts 183.54 170.31 25.311 872.39 863.92 MinPt -O -SF 403.35 377.431 25.681 1288.05 1238.68 MinPt-O-SE 6056.64 5919.191 67.291 5153.72 2904.46 MinPt -O -SF 9116.94 8885.831 59.801 8263.80 3849.23 MinPt -O -SF 11 9823.2911 9548.4311 54.09 10947.22 3924.93 MinPts 10651.26 10342.4511 52.15i1 12200.76 3935.73 MinPt -O -SE OP15 -103 (P1) (DEF PL PASS 104.12 99.12 61.07 300.00 300.00 MinPt-CtCt 104.95 99.09 45.82 398.73 398.72 MinPt -O -ADP 195.39 182.95 29.101 867.53 859.29 MinPt -O -SF 433.13 409.671 30.821 1265.37 1219.48 MinPt -O -SF 7298.69 7169.95 86.691 4716.43 2761.01 MinPt -O -SF 11242.93 11002.891 70.981 8299.72 3851.41 MinPt -O -SE 12507.29 12191.151 59.801 12175.94 3935.46 MinPt -O -SF OP16 -P03 (P1) (DEF PLN) PASS I 112.131 107.13 I 65.89 300.00 300.00 MinPts 217.20 204.46 31.4611 864.04 855.97 MinPt-O-SE 13046.77 12802.811 81.031 8314.38 3852.30 MinPt-O-SE 12215.00 11959.831 72.501 9779.73 3896.67 MinPt -O -SF 14042.25 13726.391 67.201 12193.14 3935.65 MinPt -O -SF OP18 -108 (P1) (DEF PLN) PASS iiri 128.15 124.25 134.68 200.00 200.00 MinPt-CtCt 128.41 123.66 I 84.21 300.00 300.00 MinPt -O -ADP 255.51 242.28 35.361 856.80 849.07 MinPt -O -SF 14627.50 14381.431 90.071 8287.26 3850.66 MinPt -O -SF 14998.57 14746.071 89.981 8622.07 3871.00 MinPt -O -SF 15266.79 14961.661 75.661 11868.33 3932.07 MinPt-O-SE Version DO 4.0 ( doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 12/1/2008 12:53 PM Page 2 of 3 • • Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct (ft)_ Dev. (ft) Fact. MD (ft) I TVD (ft) Alert I Minor I Major OP19 -ENI #1 (P1) (DEF PLN PASS 143.85 138.86 85.03 300.00 300.00 MinPt -CtCt 144.45 138.49 61.59 398.27 398.26 MinPt -O -ADP 180.73 169.34 30.061 858.17 850.38 MinPt-O-SF 5252.51 5145.751 75.531 4884.47 2816.14 MinPt -O -SF 6968.59 6825.86 1 74.511 6078.41 3207.79 MinPt -O -SF OP20- ENI #9(P1)(DEF PL� PASS 151.78 146.79 89.79 300.00 300.00 MinPt-CtCt 152.38 146.42 65.04 398.18 398.17 MinPt -O -ADP 200.34 189.35 34.951 853.64 846.06 MinPt-O-SF 5901.09 5826.19 1 122.211 2742.87 2113.63 MinPt -O -SF 7673.08 7573.431 118.431 3228.25 2272.84 MinPt-O-SF OP21 -ENI #10 (P1) (DEF PLN PASS 160.18 155.19 94.77 300.00 300.00 MinPt-CtCt 160.75 155.16 76.84 398.03 398.02 MinPt -O -ADP 223.27 213.18 43.651 851.94 844.44 MinPt -O -SF 4065.49 4018.47 1 136.901 2613.58 2071.17 MinPt -O -SF 6749.82 6667.19 1 126.311 3427.31 2338.14 MinPt -O -SF OP22 -ENI #2 (P1) (DEF PLN PASS 168.19 163.20 99.58 300.00 300.00 MinPt-CtCt 168.79 162.83 72.14 397.98 397.97 MinPt -O -ADP 277.10 259.99 28.201 1309.42 1256.61 MinPt-O-SE 5861.35 5758.98 1 88.001 6286.61 3276.08 MinPt-O-SF OP23- ENI #4 (P1) (DEF PLN PASS 176.20 171.20 104.40 300.00 300.00 MinPt -CtCt 176.80 170.84 75.64 397.89 397.88 MinPt -O -ADP 267.15 254.451 38.911 948.89 936.09 MinPt -O -SF 374.45 357.171 37.741 1196.61 1160.29 MinPt -O -SF 921.29 891.86 j 51.181 1901.71 1698.94 MinPt -O -SF 5938.12 5783.36 1 58.481 5485.71 3013.36 MinPt -O -SF 7659.43 7464.70 1 59.751 6745.41 3426.58 MinPt -O -SE OP24 -ENI #12 (P1) (DEF PLN) PASS I 184.211 179.21 109.21 300.00 300.00 MinPts 277.95 266.44 45.881 853.52 845.94 MinPt -O -SF 4572.90 4509.261 112.131 2698.69 2099.13 MinPt -O -SF 6173.36 6085.31 1 108.191 3255.86 2281.90 MinPt -O -SF 7907.06 7792.131 105.461 3858.51 2479.59 MinPt -O -SF OP26- DSP02(P2)(DEF PLN) PASS 391.38 386.25 221.73 300.00 300.00 MinPt-CtCt 392.33 386.211 161.76 392.56 392.55 MinPt -O -ADP 693.48 647.53 23.861 2532.21 2042.01 MinPt-O-SE 3446.05 3341.98 50.86 6669.01 3401.52 TD Version DO 4.0 (doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 12/1/2008 12:53 PM Page 3 of 3 41 S chlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on Well: OPO4 -P07 Oriented EOU Dimension Field: Nikaitchuq .Ti Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Separation Factor Date: February 15, 2009 ■ North 350 0 10 340 65 20 330 ....0110 6 M.4. 30 320 ' 55 �_ 40 On _t 50 I ar . 310 45. irg � 50 40" I �f 35 A 4 60 • 290 4 „- . 5 7 _ 70 ''., 280 ; olbA 80 to 1 270 liP\ 9 Oliktok Point I -1 Oliktok Point I 260 l -°'° s , .., �� ° 9 � 69s ,� i1 �� 1 00 OP10 107 (P2 �, �♦'1 ; , . *OA c,) q `r o 250 1 > /. , o. is 110 1 -V i / o OP11 -PO4 (l7„ �/ �rn 120 i� 014 ggti 230 OP' 130 6g 3 0 ■ OP03- P05PB1 current 220 \ 140 2 150 OP05 -P06 (P3) OP08 -104 (P3) 20 160 190 18 19P06- I0"¢M Well Ticks Type: MD on OPO4 -P07 (P5) Calculation Method: Normal Plane Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH = 20.00 ft • Schiumberger g Cylinder r v l i n Plot TRAVELING CYLINDER PLOT a e Client: ENI NoGo Region EOU's based on Well: OPO4 -P07 Oriented EOU Dimension Field: Nikaitchuq N Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Separation Factor . Date: February 15, 2009 ■Nior I f North 350 0 10 340 20 330 30 _ 140 320 4 0 o illi 120 310 50 , ° ::- 1 1 1 11 I I 011111 i i ir liti * *4 . .4U 300 Ah. 110 m i if 290 � � � �� ° � � � ♦ ■ � � 70 ■ ,TO 0 :73 0 ,1** „a ll wAr "witti 280 P�. ` " "rtI l 16. • �•�r 80 op '� _ ._.. .. '� co • ate e Y e 'te ■. 270 / 1 / e 1 L _ " \ ■��. 90 260 \ �= * • `� i ��� y / ' ;111.. �a „<.o ` �' �° ® 100 ii cb � ���� i�' X 69 • 250 iy i . if ,s9 • o � ( • ^ 110 , �. -j�f , °° o� Oliktok Point I -1A -106 (P3) 240 " s.' ` �� � . w �� ® • 1 20 if 23 ` v e ,: At: ' A ill 16,10 Ai 130 le Amok \ 220\ , P05PB1 current O w 05 -P06 (P3) 210 6 -105 (P2) ,' 200 OP08 10 ,Bkr 190 180 170 Well Ticks Type: MD on OPO4 -P07 (P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH = 50.00 ft DriSng Hazards Sumi*ary 16" Open Hole / 13 -3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced • drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12 -1/4" Open Hole / 9 -5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of • Lecithin. Stuck Pipe Low Good hole cleaning, pre- treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. • Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8 -1/2" Open Hole / 5 -1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut -in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Drilling Hazards Summary .doc 12/10/2008 4:04:00 PM HYDRIL 13 -5/8" 5K PSI GK ANNULAR BOP 4' -51" LATCHED HEAD 5K FLANGE CONNECTION 1 54 -1/2" LENGTH • J L i 4 10,000# WP 1 i — - - — CAMERON TYPE F" i GATE VALVE HYDRIL 13 -5/8" 5K PSI 13' -4 " ' 1 C 3'—i" MPL DOUBLE GATE 1 1 4" 10,000# WP STUDDED CONNECTION 4" 10,000# WP 1 _ _ — CAMERON HCR VALVE 42 -7/8" LENGTH CAMERON HCR VALVE A ■ DRILLING SPOOL 4" CHOKE LINE ,,,41 + I� Cis 3" KILL LINE 2'-2" 13- 5/8 " -5K PSI FLANGED — �1 I/ Q/ 4"-10K PSI FLANGED OUTLETS 4 "x3 "- j �l 26" EST. LENGTH 4" 10,000# WP CAMERON TYPE "F" HYDRIL 13 -5/8" 5k PSI GATE VALVE 1 _ _ I _ _ 3 , MPL SINGLE GATE FLANGED CONNECTION 36 -1/4" LENGTH [J • NABORS ALASKA RIG 245E 13-5/8" 5K BOP STACK CONFIGURATION Nabors � ` k "' 252, A5039 tiro- 2525 o ksl 5 Y0 500 60Mf Mcnaaw. Abelw 05507 -2939 80] -2 5000 PROJECT NABORS ALASKA RIG 245E '" BLOW-OUT PREVENTER I3 -5/8' 5K STUDDED STACK CONFIGURATION 13A44R08 A Al JA ISSUED u9.w0 ST ALSrON °f � N Si0N BY 200 ALSTON A OPPROVW JOE art ,pa V. V. 85888505 9o4E N/A al9 WRCN 2008 ' 24500002 -5K 9 1 of I • • . I - ® 11:31 UP CLAMP � I 0) C ONNECTOR CELLAR � J , 1 _ - _!!� _ I _ — WELL I HYDGK RIL 13 -5/8ANNULAR BOP ' SK PSI cae U P LATCHED HEAD p O Ism— 5K FLANGE CONNECTION _ I / _ I 5 4 - 2 LENGTH � - - i _ E� - I I _ n •�.' • 4 ),_ EN I 4' 10.000/ WP CAMERON TYPE "F" HYDRIL 13-5/8'5K PSI 13' -41' J I C i . I GATE VALVE .Y MPL DOUBLE GATE illl qq 1 I I 4'10,000/ WP STUDDED CONNECTION �. l 4' 1N000 WP VALVE _ CAMERON HCR VALVE 42 - /B" LENGT CAMERON HCR � I I DN DRILLING SPOOL 4' CHOKE LINE • Ai + h _ Au `. - 3 ' KILL LIN 2' 2 . 13- 5/8' -5K PSI FLANGED / ■I II I 1 �- 4' -lOK PSI FLANGED OUTLETS //' 4"x.3"--r � 1 25' EST. LENGTH CAMERON TYPE F" I I T r HYDRIL 13 -5/8" 5k PSI 60'-o" ESTIMATED MPL SINGLE GATE LENGTH GATE VALVE - - - - J' - o • FLANGED CONNECTION 16" DIVERTER LINE I I 36 -1/4" LENGTH \` 13.5/8' 5K + BOP STACK CONFIGURATION DIVERTER LINE ROUTING NABORS ALASKA RIG 245E ENI NIKAITCHUO PROJECT I 21 -1/4" 2,000/ WP SHAFFER • 2,000/ STUDDED TOP BY 4' -4 I /2' I 21 -1/4" 2,000/ FLANGED BOTTOM H2S TRIMMED ANNULAR DIVERTER SYSTEM 3/15" SURFACE DIVERTER 16" -150, FIG PIPING CONFIGURATION ` � '�'f ' ' PLAN VIEW 1 2 _0. 24 DIA. nm s rerea OFSitl1 a wears mc ncrraoiwnoN oa use a 1 L6pN 6 P41Y1494 MY i MIIMiPoIIe N BY 1 10 ,0 5 51,0 �� `16" KNIFE GATE Alaska Nonce u""� 5= 00 Nabors 2525 C •2N Suite 500 W/ HYD. ACTUATOR AOi wTT zs�� 95,03 2 ._ 0 . P0.°1E0f NABORS ALASKA RIG 245E MU BOP STACK AND DIVERTER CONFIGURATION ENI NIKAICHUO PROJECT SURFACE DIVERTER CONFIGURATION 9JULY00 A JA JA ISSUED °"" ALSON PALSTON 'fie' JOE ALSTON e" A nrt M. D . NT. 005 snu N/A "° JULY 2008 2e5LO3OI- NIKAITCHUO 9 1 of 1 . . Nabors 1 .. . P - I, _ • Rig- Material List Item Description 1-15 4-1/16" 10M Cameron Manual Gate Valve 16 2-1/16" 10M Cameron Manual Gate Valve A,B 4-1/16" 10M Cameron H2 Manual Choke C 3-1/16" 10M Shaffer Hydraulic Choke • ,.. . . ,. .... , _.,.... ,,, ......,,,... _ _ , ... . .. . ... .. . .. 4011 : . AIN i To Gas '.i --- - 0 . ...xi i . ■ V ..., .. - .,.. 1 „ , i / r . 4D Alik ......--___, OF:a . , c) 4 • 411 Ilk . L If , A 4'! coo li 1._.,. - 41111., --- - -,-4 t • it . ei 0 ( lki7 II ----411111111N 0 ---- 11,/ i.- ' If.. Fr . BOP s s - ,;;.. . . ,.. . . Legend dig ■-- - (11C, White Handle Valves eserve Pit ,. _...... , 'cID Normally Open ...- Ade ,.... ' To R Red Handle Valves e ..., Normally Closed ; , ; s -::- al • Date: 6-1-01 Rev. 1 .., .......,„ „.., „.....,,,,,, . „ ....„... . ....,....: -..- . . .,,„„...... , .. ......... ... . . ...„, . -. - - . - - . - - - - - • • Schlumberger C emCADE * well cementing recommendation for 13.375 "" Surface Casing Operator : Eni Petroleum Well : OPO4 -P07 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : North Slope - Alaska Proposal No. : Draft v1 Service Point : Prudhoe Bay, Alaska Date Prepared : 12 -10 -2008 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford@slb.com 4 � \GN d C7 q4 U Rit Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger i • Client : Petroleum Well Schlemberger Well OP 04-P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2860.0 ft BHST : 50 degF Bit Size : 16 in (x 1000) psi N •••••• "". 0 I 1.0 1 .5 PO re FI3C . Permafrost ti o _ N ..... 5i • _ 4 Well Lithology Formation Press. Page 2 op04- po7.cfw; 12 -10 -2008 ; LoadCase Surface Casing ; Version wcs- cem452_07 • S Client : Eni Petroleum S Ism rger Well OPO4 -P07 String : 13375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib /ft) (in) 120.0 20 169.0 18.376 Landing Collar MD : 2780.0 ft Casing /liner Shoe MD : 2860.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2860.0 13 3/8 40.0 68.0 12.415 L -80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 184.5 % Mean OH Equivalent Diameter: 19.956 in Total OH Volume : 1060.0 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) ( %) (in) 2025.0 16.000 250.0 21.184 2860.0 16.000 35.0 16.822 Page 3 op04- po7.c1w; 12 -10 -2008, LoadCase Surface Casing; Version wcs- cem452_07 0 0 Client : Eni Petroleum S Iikrger Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 71 deg Max. DLS : 3.510 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 359.7 0.000 41.0 41.0 0.0 359.7 0.000 100.0 100.0 0.0 359.7 0.000 200.0 200.0 0.0 359.7 0.000 300.0 300.0 0.0 359.7 0.000 400.0 400.0 1.5 359.7 1.500 500.0 499.8 5.0 359.7 3.500 600.0 599.1 8.5 359.7 3.500 700.0 697.5 12.0 359.7 3.500 800.0 794.6 15.5 359.7 3.500 900.0 890.1 19.0 359.7 3.500 1000.0 983.6 22.5 359.7 3.500 1100.0 1074.8 26.0 359.7 3.500 1200.0 1163.2 29.5 359.7 3.500 1300.0 1248.7 33.0 359.7 3.500 1400.0 1330.9 36.5 359.7 3.500 1487.8 1400.0 39.6 359.7 3.497 1500.0 1409.4 39.8 359.7 2.046 1600.0 1485.1 41.8 359.7 2.000 1700.0 1558.4 43.8 359.7 2.000 1800.0 1629.4 45.8 359.7 2.000 1900.0 1697.8 47.8 359.7 2.000 2000.0 1763.6 49.8 359.7 2.000 2057.0 1800.0 51.0 359.7 1.999 2100.0 1826.6 52.5 359.6 3.495 2200.0 1885.1 56.0 359.4 3.504 2300.0 1938.5 59.5 359.2 3.494 2400.0 1986.7 63.0 359.1 3.503 2500.0 2029.4 66.4 358.9 3.503 2600.0 2066.5 69.9 358.8 3.493 2625.9 2075.2 70.8 358.7 3.510 2700.0 2099.5 70.8 358.7 0.000 2800.0 2132.3 70.8 358.7 0.000 2860.0 2152.0 70.8 358.7 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 120.0 11.00 8.43 Permafrost Sandstone 1800.0 12.00 8.43 Permafrost Sandstone 2436.6 13.00 9.20 Sandstone 2860.0 13.00 9.20 Sandstone Page 4 op04- po7.cfw: 12 -10 -2008 , LoadCase Surface Casing , Version wcs- cem452_07 • • Client : Eni Petroleum Schlobergcr Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 1800.0 1629.4 32 0.7 2436.5 2002.9 48 1.4 2436.6 2002.9 48 1.4 2860.0 2152.0 50 1.4 ft degF (x 1000) ft 0 1 40 60 I ' A 1.8 1.2 1.6 — Geoth.Profile — Hori. Depart. ts! co O co o o - cti p o (0 m _ Q _ CV CN o Cy - Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.60 lb/gal Pv : 12.000 cP Ty : 7.00 Ibf /100ft2 Displacement Volume 416.2 bbl Total Volume 1130.6 bbl TOC 0.O ft Page 5 op04- po7.cfw; 12 -10 -2008: LoadCase Surface Casing ; Version wcs- cem452_07 • • Client : Petroleum Schlumhurger Well OP 04-P07 P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.50 Pv:16.000 cP Ty:12.00 Ibf/100ft2 Lead Slurry 551.8 2360.0 0.0 10.70 Pv:18.127 cP Ty:16.55 Ibf /100ft2 12.0 ppg 62.5 500.0 2360.0 12.00 k:7.50E -2 Ibf.s ^n /ft2 n:0.372 Ty:4.15 Ibf /100ft2 DeepCRETE Mud 416.2 0.0 9.60 Pv:12.000 cP Ty:7.00 Ibf /100ft2 Static Security Checks : Frac 2 psi at 120.0 ft Pore 14 psi at 120.0 ft Collapse 2062 psi at 2780.0 ft Burst 5020 psi at 0.0 ft Csq.Pump out 53 ton ft (X 1000) psi < > 0 0 1.5 — Hydrostatic — Frac • — Pore – O _ Fluid Sequence Static Well Security Page 6 op04- po7.cfw ; 12 -10 -2008 ; LoadCase Surface Casing ; Version wcs- cem452_07 II . • Client : Eni Petroleum S Ia rger Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 100.0 25.0 100.0 80 7 -Start Pumping Spacer Lead Slurry 5.0 551.8 110.4 551.8 80 13 -Start Mixing Lead Slurry 12.0 ppg 5.0 62.5 12.5 62.5 80 16 -Start Mixing Tail Slurry DeepCRETE Mud 8.5 416.2 49.0 416.2 80 19 -Start Displacement Total 03:16 1130.6 bbl hr:mn End Job: Bump Top Plug, Bleed -off PSI, Check floats Dynamic Security Checks : Frac 0 psi at 120.0 ft Pore 7 psi at 120.0 ft Collapse 2062 psi at 2780.0 ft Burst 4835 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 2860.0 ft CT at TOC 60 degF Max HCT Time 03:16:50 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 50 degF Page 7 op04-po7.cfw ; 12-10-2008 , LoadCase Surface Casing; Version wcs- cem452_07 • • Client : Petroleum Well S�reukrger Well OP 04-P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing — Calc. WHP - Calc. Pump Press. Q 2 , L 0 30 60 90 120 150 180 210 Time (min) .te Fluids at 2860 ft a, — — Acquired Q Out "— g — Acquired Q In s —Q Out 0 In LT_ co asfD 0 0 30 60 90 120 150 180 210 Time (min) Page 8 op04- po7.cfw; 12 -10 -2008; LoadCase Surface Casing; Version wcs -cem452_07 • • Went : ell 0P 0 4- P07 Petroleum ScIiberger Well OP4 -P String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 13.375 ' Surface Casing District : Prudhoe Bay, Alaska Country : USA Depth = 120 ft _ Depth = 2860 ft 7 - Frar _. M - Frac - Pore - Pore co _ - Hydrostatic 0 - Hydrostatic O — Dynamic t.,j - uynamc ci l _ co r cnco- N N0 E = = r C m Q Q _ / 1 O v / o- I / 4 O U ---/ 1 J kr>_ m d co 0 250 6' 0 250 V Time (min) Time (min) o Total Depth = 2860.0 ft Top of Cement = 0.0 ft *Mark of Schlumberger gcMu pr Page 9 op04- po7.cfw ; 12 -10 -2008 ; LoadCase Surface Casing ; Version wcs- cern452_07 • Client : Petroleum Well Schlumberger Well OP 04-P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :110.0 ft Bottom Cent. MD :2850.0 ft Casing Shoe :2860.0 ft NB of Cent. Used :38 NB of Floating Cent. :38 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 2380.0 14 1/4 NW -TR -13 3/8 -8 -TR 3 W304 0.0 2345.6 2860.0 24 2/1 NW -TR -13 3/8 -8 -TR 3 W304 84.6 2860.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW -TR -13 3/8 -8 -TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft * 0 1 A0 60 80 100 to — Between Cent. I +Pt Cent. + ++ + + ° + + o + o ' - Pipe Standoff Page 10 op04- po7.cfw; 12 -10 -2008; LoadCase Surface Casing; Version wcs- cern452_07 • • Client : Eni Petroleum Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing rr CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 13.375 ' Surface Casing District : Prudhoe Bay, Alaska Country : USA ton ft 0 10 20 30 40 50 60 70 80 90 100 — Hookioad Up — — Hooldoad Dow n - - - - Weight — — Drag Force 1 \. \. _ 1 • \ \•. 1 \ \ 1 \ \ ° \ n 0 0 1 \ o - \ I U t U d p O - Running Forces Friction Factor = 0.3 Total Depth = 2860.0 ft Top of Cement = 0.0 ft *Mark of Schlumberger Page 11 op04- po7.cfw; 12 -10 -2008; LoadCase Surface Casing ; Version wcs- cem452_07 • Client : Petroleum Schl bergcr Well OP 04-P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II Simulator ft 0 9n 0 60 90 100 -- Std Betw. Cent. — Cement Coverage O O cv - Cement Coverage Fluids Concentrations Risk Mud on the Wall z z 01 I 0 0 is WO- -500 500 500 1000 1000 1W0- — -1000 . t f a 0 1500- 1500 a t 1500 1500 2000- 2000 2000 2000 2500 2500 2500 2500 a x MI Mud IN High Ell Low ▪ 12.0 ppg DeepCRETE IN Medium ME None • Lead Slurry ▪ MUDPUSHII Page 12 op04- po7.cfw; 12 -10 -2008 ; LoadCase Surface Casing : Version wcs- cem452_07 • Client : Eni Petroleum S Iin rgar Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb/gal Rheo. Model : BINGHAM P : 12.000 cP At temp. : 80 degF Ty : 7.00 Ibf /100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type : WBM Job volume : 416.2 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 96.0 % Water : 0.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 lb/gal Rheo. Model : BINGHAM Pv : 16.000 cP At temp. : 80 degF Ty : 12.00 Ibf /100ft2 Gel Strength : (Ibf /100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : BINGHAM Pv : 18.127 cP At temp. : 80 degF Ty : 16.55 Ibf /100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : B809 Mix Fluid : 19.043 gal /sk Job volume : 551.8 bbl Dry Density : 105.47 Ib /ft3 Yield : 4.33 ft3 /sk Quantity : 715.83 sk Sack Weight : 188 lb Solid Fraction : 41.2 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 19.043 gal /sk Page 13 op04- po7.cfw; 12 -10 -2008; LoadCase Surface Casing ; Version wcs- cem452_07 • • Client : Eni Petroleum S Iin rger Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing 12.0 ppg DeepCRETE DESIGN Fluid No: 5 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k : 7.50E -2 Ibf.s "n /ft2 At temp. : 80 degF n : 0.372 Ty :4.15 Ibf/100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid : 5.163 gal /sk Job volume : 62.5 bbl Dry Density : 110.20 Ib /ft3 Yield : 1.60 ft3 /sk Quantity : 219.78 sk Sack Weight : 100 lb Solid Fraction : 56.8 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 4.943 gal /sk Additives Code Conc. Function D047 0.020 gal /sk blend Antifoam D185 0.050 gal /sk blend Dispers. LT D186 0.150 gal /sk blend Accelerator I I Sect 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 100.0 25.0 100.0 7 -Start Pumping Spacer Lead Slurry 5.0 551.8 110.4 551.8 13 -Start Mixing Lead Slurry 12.0 ppg 5.0 62.5 12.5 62.5 16 -Start Mixing Tail Slurry DeepCRETE Mud 8.5 416.2 49.0 416.2 19 -Start Displacement Total Pumping Time : 03:16 hr:mn Page 14 op04- po7.cfw; 12 -10 -2008, LoadCase Surface Casing Version wcs- cem452_07 . • Client : Eni Petroleum 5cI� berger Well OPO4 -P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing End Job: Bump Top Plug, Bleed -off PSI, Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 398 bbl MIXING PREPARATION MUDPUSH 11 Volume : 100.0 bbl Density : 10.50 Ib /gal Code Quantity Design Fresh water 91.096 bbl D182 546.575 Ib 6.000 Ib /bbl of base fluid D031 11720.791 Ib 117.21 Ib /bbl of spacer Lead Slurry Volume : 551.8 bbl Density : 10.70 Ib /gal Yield : 4.33 ft3 /sk Dry Phase Liquid Phase Blend : 115666 Ib Design Mix Water 279.0 bbl 10.0 bbl LAS Design 12.0 ppg DeepCRETE Volume : 62.5 bbl Density : 12.00 Ib /gal Yield : 1.60 ft3 /sk Dry Phase Liquid Phase Blend : 23952 Ib Design Mix Water 29.4 bbl 10.0 bbl LAS Design 0.020 gal /sk blend 0.050 gal /sk blend 0.150 gal /sk blend Page 15 op04- po7.cfw; 12 -10 -2008; LoadCase Surface Casing , Version wcs- cem452_07 Client : Eni Petroleum SelIoberger Well OPO4 P07 String : 13.375 District : Prudhoe Bay, Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well : OPO4 -P07 Stang : 13.375 "' Surface Casing District : Prudhoe Bay, Alaska Country : USA Annulus ID : 13.375 in - OD : 16.000 in — Tail Slurry - Lead Slurry - MUDPUSITY - Mud CNI FA (0 co N N � to .... : o : 6o646872768o848892 Flow Rate (bbVmin) ■ Mud Bingham: PJ = 12.000 cP Ty = 7.00 lbf /100ft2 ■ MUDPUSH II Bingham RI = 16.000 cP Ty = 12.00 Ibf /100ft2 ® Lead Slurry Bingham: PV = 18.127 cP Ty = 16.55 Ibf /100ft2 ■ Tail Slurry Bingham: P✓ = 81.518 cP Ty = 10.51 Ibf /100ft2 *Mark of Schlumberger Sc Iu pr Page 16 op04- po7.clw; 12 -10 -2008; LoadCase Surface Casing ; Version wcs- cem452_07 • Schlumberger Cem CAD E * well cementing recommendation for 9 -5/8" Intermediate Casing Operator : Eni Petroleum Well : OPO4 -P07 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr. Jason Brink Location : North Slope - Alaska Proposal No. : Draftvl Service Point : Prudhoe Bay, Alaska Date Prepared : 12 -10 -2008 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford @slb.com 5 �G Disclaimer Notice. This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. } Mark of Schlumberger • Client : Petroleum Schlumberger Well OP 04-P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8277.0 ft BHST : 92 degF Bit Size : 12 1/4 in ft (x 1000) psi - — 0 1 2 3 Frac I - - Pore - Permafrost • 1111111 ZEIE • it • • G — I G CO Shale rn _ Well Lithology Formation Press. Page 2 op04- po7.cfw; 12 -10 -2008; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • • Client : Em Petroleum S ��mkrger Well OPO4 -P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Previous String MD OD Weight ID (ft) (in) (Ib /ft) (in) 2860.0 13 3/8 68.0 12.415 Landing Collar MD : 8197.0 ft Casing /liner Shoe MD : 8277.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb /ft) (in) (psi) (psi) 8277.0 9 5/8 40.0 47.0 8.681 L -80 4760 6870 BTCM Mean OH Diameter : 12.250 in Mean Annular Excess : 35.0 % Mean OH Equivalent Diameter: 13.045 in Total OH Volume : 895.4 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 4.005 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 5900.0 3149.3 70.8 358.7 0.000 6000.0 3182.1 70.8 358.7 0.000 6100.0 3214.9 70.8 358.7 0.000 6200.0 3247.7 70.8 358.7 0.000 6300.0 3280.5 70.8 358.7 0.000 6400.0 3313.3 70.8 358.7 0.000 6500.0 3346.1 70.8 358.7 0.000 6600.0 3378.9 70.8 358.7 0.000 6700.0 3411.7 70.8 358.7 0.000 6800.0 3444.5 70.8 358.7 0.000 6900.0 3477.3 70.8 358.7 0.000 7000.0 3510.1 70.8 358.7 0.000 7100.0 3542.9 70.8 358.7 0.000 7200.0 3575.7 70.8 358.7 0.000 7300.0 3608.5 70.8 358.7 0.000 7400.0 3641.3 70.8 358.7 0.000 7500.0 3674.1 70.8 358.7 0.000 7600.0 3706.9 70.8 358.7 0.000 7700.0 3739.7 70.8 358.7 0.000 7783.2 3767.0 70.8 358.7 0.000 7800.0 3772.5 71.5 358.8 4.000 7900.0 3800.8 75.5 359.1 3.997 8000.0 3822.5 79.5 359.5 4.005 8100.0 3837.3 83.5 359.9 3.995 8176.5 3844.0 86.5 0.1 4.004 8200.0 3845.4 86.5 0.1 0.000 8276.5 3850.0 86.5 0.1 0.000 8277.0 3850.1 86.5 0.1 0.000 Page 3 op04- po7.cfw; 12 -10 -2008; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 I i 0 • Client : Petroleum Shc� berier Well OP 04-P07 P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 120.0 11.50 8.30 Permafrost Sandstone 2025.0 12.00 8.30 Permafrost Sandstone 2860.0 12.00 8.30 Shale 6014.0 12.00 8.30 Shale 8277.0 12.00 8.30 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 2025.0 1779.7 32 0.7 2436.0 2002.6 56 1.8 6013.9 3186.6 77 1.8 6014.0 3186.7 77 1.8 8277.0 4009.7 92 1.8 Page 4 op04- po7.clw ; 12 -10 -2008 ; LoadCase 9 -5/8 Intermediate Casing (al ; Version wcs- cem452_07 . • Client : Eni Petroleum Well OPO4 -P07 Schlu lberger String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) ft degF (x 1000) ft 0 'I 100 n ' 5.0 7.5 Geoth.Protile - Hon. Depart. I I _ �� u�� al 1 IIIIIIIIIIIIIII 11111111.11110111111111111111111 a _ t co L o y 111 a o 11111111111111 ,, , \II\ i=i CA X CV a _ �l _ \\ co a a a — a Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 4900' Original fluid Mud 9.60 lb/gal Pv : 28.000 cP Tv : 19.00 Ibf /100ft2 Displacement Volume 600.1 bbl Total Volume 847.3 bbl TOC 6400.0 ft Page 5 op04- po7.cfw, 12 -10 -2008: LoadCase 9 -5/8 Intermediate Casing (a): Version wcs- cem452_07 • Went : ell 0P 0 4- P07 Petroleum SekIWnkrgnr Well OP4 -P String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH 11 100.0 1327.9 5072.1 11.00 PV:36.000 cP Ty:25.00 Ibf /100ft2 DeepCRETE 147.2 1877.0 6400.0 12.50 Pv:94.000 cP Ty:38.00 lbf/100ft2 Mud 600.1 0.0 9.60 Pv:28.000 cP Ty:19.00 Ibf /100ft2 Static Security Checks : Frac 268 psi at 2860.0 ft Pore 145 psi at 2860.0 ft Collapse 4438 psi at 8197.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 73 ton ft (x 1000) psi 0 3 , — Hydrostatic — Frac —Pore o � o I o M ▪ – co O – Fluid Sequence Static Well Security Page 6 op04- po7.cfw; 12 -10 -2008 ; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 0 0 Client : Eni Petroleum S Iinherger Well OPO4 -P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4 -Drop Bottom Plug DeepCRETE 5.0 147.2 29.4 147.2 80 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 600.1 70.6 600.1 80 19 -Start Displacement Total 02:10 847.3 bbl hr:mn End Job: Bump Top Plug, Bleed -off PSI, Check floats Dynamic Security Checks : Frac 19 psi at 8277.0 ft Pore 145 psi at 2860.0 ft Collapse 4438 psi at 8197.0 ft Burst 6323 psi at 0.0 ft Temperature Results BHCT 86 degF Simulated Max HCT 92 degF Simulated BHCT 69 degF Max HCT Depth 8277.0 ft CT at TOC 69 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 80 degF Bottom Hole (degF) (degF) 92 degF Page 7 op04- po7.cfw; 12 -10 -2008 , LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • • Client : Petroleum geil�m�rger Well OP 04-P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) —Cale. WHP — Cale. Pump Press. a ( o 0 20 40 60 80 100 120 140 Time (min) Fluids at 8277 ft ° ' — Acquired 0 Out — Ccquired 0 In —O Out In sa ' � I o LL0 = 0 I 0 20 40 60 80 100 120 140 Time (min) Page 8 op04- po7.cfw; 12 -10 -2008; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • • Went : ell 0P 0 4- P07 Petroleum ScImierger Well OP4 -P String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 9-5/8" Intermediate Casing District : Prudhoe Bay, Alaska Country : USA Depth = 2860 ft Depth = 8277 ft — Prat _. ' MIEriffli■ - Fbre . -Pore - Hydrostatic O - Hydrostatic O uynamc N Dynanic c‘i (.1? O_ _ r N o� 0 N co \ 9 0) O) N '§' • d I J v O • • N N C V) O N , O d O (I O c C C Q ci Q O - 0) O 6 • 0 - ( ' 1 W 0) 1 _ O U GD • O d `� 0 50 100 150 0 50 100 150 Time (min) Time (min) Total Depth = 8277.0 ft Top of Cement = 6400.0 ft *Mark of Schlumberger 1 Page 9 op04- po7.c1w; 12 -10 -2008; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • Client : Eni Petroleum S Iwihrger Well OPO4 -P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) Section 4: centralizer placement Top of centralization :2700.0 ft Bottom Cent. MD :8257.0 ft Casing Shoe :8277.0 ft NB of Cent. Used :50 NB of Floating Cent. :47 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 2837.0 3 1/1 NW -TR -9 5/8 -6 -TR 3B W090 0.0 2819.1 6397.0 0 0/0 0.0 2837.0 8277.0 47 1/1 NW -TR -9 5/8 -6 -TR 3B W090 0.0 6414.9 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 -TR -9 5/8 -6 -TR W090 9 5/8 12.850 11.591 No Hannover 12.250 51.71 2852.83 3B (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Running Force Calculations: Travelling Block Weight :20 ton Friction Factor Centralizer /Formation :0.3 Total Drag Force :33 ton Hook load Down Stroke :64 ton Hook load Up Stroke :131 ton Page 10 op04- po7.clw; 12 -10 -2008, LoadCase 9 -5/8 Intermediate Casing (a) ; Version wcs- cem452_07 • • Client : Eni Petroleum Well S�I��rg�r Well OP 04 -P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 9-5/8" Intermediate Casing District : Prudhoe Bay, Alaska Country : USA ton 0 20 40 60 80 100 120 140 Hookload Up — — Hookload Down - • • - Weight — — Drag Force V S. 1 \ \ . \ ° o - \ C) \ \ v 1 \ • \ • .5 I \ \ • \ 1 m 0 0 5 • - \ \ 1 \ I U I I O 8 O d O Running Forces Friction Factor = 0.3 Total Depth = 8277.0 ft Top of Cement = 6400.0 ft *Mark of Schlumberger Sdharger Page 11 op04- po7.cfw; 12 -10 -2008; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • Client : Eni Petroleum Well SchI Berger Well 01 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) ft 0 9n0 60 80 100 t.. Between Cent. -_ _ -__ ___ _ } + +Ft Cent. 0 o +- o tYa o 0 Pipe Standoff Page 12 op04- po7.cfw; 12 -10 -2008; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • • Client : Eni Petroleum SiIuiiberger Well OP 04 -P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Section 5: WELLCLEAN II Simulator ft °lo 0 I 4 0 60 80 100 — Std Betw. Cent. — Cement Coverage o m 0 rn— Cement Coverage Fluids Concentrations Risk Mud on the Wall g z ° 5000 -- 5000 5000 5000 9900 5500 5500 5500 8000 I 8000 F 8000 6000 6500 6500 s 6500 6500 • n a 7000 7000 ° ° 7000 7000 7500 7500 7500 7500 8000 8000 8000 8000 • - G o Z ▪ Mud MI High Low ▪ DeepCRETE NM Medium MIN None ▪ MUDPUSHII Page 13 op04- po7.cfw : 12 -10 -2008: LoadCase 9 -5/8 Intermediate Casing (a), Version wcs- cem452_07 • • Client : Eni Petroleum Si elm r� r Well OPO4 -P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb/gal Rheo. Model : BINGHAM Pv : 28.000 cP At temp. : 80 degF T : 19.00 Ibf /100ft2 Gel Strength : (Ibf /100ft2) MUD Mud Type : WBM Job volume : 600.1 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 96.0 Water : 0.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 11.00 lb/gal Rheo. Model : BINGHAM Pv : 36.000 cP At temp. : 80 degF Ty : 25.00 Ibf /100ft2 Gel Strength : (Ibf /100ft2) Job volume : 100.0 bbl DeepCRETE DESIGN Fluid No: 7 Density : 12.50 lb/gal Rheo. Model : BINGHAM Pv : 94.000 cP At temp. : (degF) Ty : 38.00 Ibf /100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : DeepCRETE Mix Fluid : 7.906 gal /sk Job volume : 147.2 bbl Dry Density : 199.77 Ib /ft3 Yield : 2.25 ft3 /sk Quantity : 367.22 sk Sack Weight : 94 lb Solid Fraction : 53.0 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 7.806 gal /sk Additives Code Conc. Function D167 0.350 %BWOC Fluid loss D046 0.200 %BWOC Antifoam D153 0.150 %BWOC Antisettling D185 0.050 gal /sk blend Dispers. LT D186 0.050 gal /sk blend Accelerator Page 14 op04- po7.cfw; 12 -10 -2008 , LoadCase 9 -5/8 Intermediate Casing (a), Version wcs- cem452_07 • • Client : Petroleum S l�mkrier Well OP 04-P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9 -5/8 Intermediate Casing (a) Sect 7: operator summary Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 5.0 100.0 20.0 100.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4 -Drop Bottom Plug DeepCRETE 5.0 147.2 29.4 147.2 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 600.1 70.6 600.1 19 -Start Displacement Total Pumping Time : 02:10 hr:mn End Job: Bump Top Plug, Bleed -off PSI, Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 216 bbl MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density : 11.00 lb/gal Code Quantity Design Fresh water 90.365 bbl D031 14622.682 lb 146.23 lb/bbl of spacer DeepCRETE Volume : 147.2 bbl Density : 12.50 lb/gal Yield : 2.25 ft3 /sk Page 15 op04- po7.cfw ; 12 -10 -2008 , LoadCase 9 -5/8 Intermediate Casing (a) ; Version wcs- cem452_07 • • Client : Eni Petroleum SdIinkrger Well OPO4 P07 String : 9 -5/8 District : Prudhoe Bay, Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing (a) CemCADE Client : Eni Petroleum Well : OPO4 -P07 String : 9-5/8" Intermediate Casing District : Prudhoe Bay, Alaska Country : USA Annulus ID : 9.625 in - OD : 12.250 in 0 - MUDPUSH II - Mud - DeepCRETE O o O O co N o. V N O cn r— c o o � U O U 1 I 1 I I I f 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bbVmin) ■ Mud Bingham Pd = 28.000 cP Ty = 19.00 Ibf /100ft2 ■ MUDPUSH H Bingham: Pd = 36.000 cP Ty = 25.00 Ibf /100ft2 ■ DeepCRETE Bingham: PV = 94.000 cP Ty = 38.001bf /100ft2 `Mark of Schlumberger $cilupr Page 16 op04- po7.cfw; 12 -10 -2008 ; LoadCase 9 -5/8 Intermediate Casing (a); Version wcs- cem452_07 • Fnl Petroleum Oliktok Point OPO4- Nikaitchuq Field Eni P07 North Slope - Alaska DIR / LWD FORM DEPTH HOLE CASING MUD INFO M MD TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle X -65 0° 20" Conductor Shoe 160' 160' N/A Welded / Driven N/A GR / Res . Surface Csq Dir / PWD 13 -3/8" 68 Ibs /ft Wellbore Stability Mud Motor L-80, BTC 8.8 -9.7 ppg Lost Circulation Hole Cleaning Casing Sections KOP:300' Casing Wear DLS: 1.5 -3.5 deg /100' Hole Angle 70 13 -3/8" Casing Point 2,860' 2,152' 16" 50 F WBM GR /RES Neutron / Density / PWC Inter. Casing Wellbore Stability 9 -5/8" Lost Circulation Rotary Steerable 47 Ibs /ft 9.3 -11.5 ppg Hole Cleaning L -80, BTC -M Torque & Drag Casing Sections Sail Angles: Casing Wear 70 degrees BHA Expense Pick -up Top of Sand • gen TOL 8,077' Hole Angle ��� ►�� 87 9 -5/8" Casing Point 8,277' 3,850' • 12 -1/4" 85° F LSND GR /RES Neutron / Density / PWC Wellbore Stability Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5 -1/2" Torque & Drag 17 Ibs /ft 9.3 -11.5 ppg Casing Sections Rotary Steerable L -80, IBT -M Casing Wear (Geo- Steering) BHA Expense 5 -1/2" Slotted Liner Hole Angle 89 Proposed TD 12,225' 3,936' 8 -1/2" 85" F MOBM . • Formation Integrity And Leak Off Test Procedure Drilling Operations 1. After cementing casing and nippling up BOP Equipment, RIH to top of cement and pressure test the casing to the test pressure specified in the well plan (usually 2500 - 3000 psi) for 30 minutes and record on a chart (AOGCC required casing integrity test). The slowest possible pump rate is preferred to allow detection of leaks. Pump rates of 1/4 to 1 BPM are typical; however, adjust the pump rate to match the test pump capability to maintain a constant pump rate. Record pressures approximately every 1/4 bbl on the Pressure Integrity Test (PIT) Form (you can locate on the drilling N drive). Plot the casing pressure test (volume versus pressure), and indicate how long the pressure is held on the casing. Verify that the test data forms a straight line and there is no air entrained in the mud, or leaks in the system. Repeat the casing pressure test if needed, especially if a straight line cannot be established at the higher test pressures. 2. Drill 20' to 50' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good downhole pressure test). Pick up into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill string at a rate approximating that used to test the casing in Step No. 1. Lower pump rates are preferred in order to minimize friction pressures losses (especially with long strings of small drillpipe) which are ignored in the calculations; however, adjust the pump rate to match the test pump capability and maintain a constant pump rate. Pump rates between 1/4 and 1 -1/2 BPM are typical, with higher rates applicable to tests conducted with large intervals of open hole. 6. On the PIT Form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure. Record pressures approximately every 1/4 bbl pumped. The data points should initially form a straight line with a similar slope to the casing integrity test as the system compressibility's are similar. Eventually, the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate and the data points will deviate from the straight line. The first, sustained occurrence of this departure is the leak -of point (see Figure 1). Pump an additional 3 bbls after the suspected leak -off point is reached to assure continued decreasing slope on the pressure versus volume plot. If a straight line cannot be established during initial pumping (suggesting a surface leak or air in the system) or a clear leak -off point is not indicated, consider re- running the test. Be sure to bleed all pressure off the system prior to re- running the test. A slightly higher pump rate may be considered if a clear departure is not indicated on the pressure versus volume plot. Small filtration fluid losses can cause a slope change, especially at slow pump rates, and confuse the identification of a more defmitive leak off point. Note: If the maximum EMW specified in the wellplan is reached without indication of leak -off, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a leak off test (LOT) 7. Shut down when the leak -off point is observed and 3 bbls of mud have been pumped into the formation. Record the instantaneous shut -in pressure (ISIP). With the pump shut down, monitor and record a 15 second and 30 second shut -in pressure and the shut -in pressures for a minimum of 10 minutes (at 30 second intervals) or until the shut -in pressure stabilizes. Plot the information and record the LOT point or FIT point on the PIT Form. Bleed the pressure off and record the fluid volume recovered if possible. If in doubt of the leak off point, contact the Drilling Superintendent to discuss and evaluate the test. Upon completion of the test, forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the proper Agencies. 0 i NOTE: Pumping to the leak -off point plus 3 bbls is less critical for casing shoes other than surface casing, but it is important to pump enough to ensure a good LOT and not a spurious departure. 8. Corrective measures will be performed if the open hole pressure integrity fails to meet predetermined standards. The Drilling Supt. is to be notified immediately of any LOT or FIT that results in less than adequate formation integrity as defined in the Well Plan. Do not drill ahead until the inadequate formation integrity is addressed. Ideal LOT J A Maxim m Pressur- r FAIN IIIIM i� Forma on mil rom -�� Breakd • wn A - . • - - . cn cn ��� -1 li0OW " cu _WAII-.M a Leak Off Point o FA Pro agation , A , ' Pre sure t In ' o • ' • o 0 o Fracture „�° . Closure !SIP ° ❑ ❑ Pressure For Instantan ° II ❑ ❑ o ❑ ❑ ❑ ❑ ❑ Shut to Pressure Volume and Shut -in Time • • ' REV I DATE BY CK APP DESCRIP11ON REV DATE 8Y CK APP DESCRIPTION 10/30/08 JFC XXX Added Wells Slot 4 -12 2 12/08/08 JFC BGM Added Wells Slot 13 -18 Oliktok OLIKTOK Point INTAKE DOCK �\ � o OPP � , THIS l MODULE f it SURVEY _O TANK �ti°�' � ,,:=1,-, DS -3R �: 1 0 DEW LINE IN S I 0 SITE STP YANK OLIKTOK Po1rJT STAGING AREA°. MODULES I T13N, R9E D -30 18 �] . 1 �� � 15 SCALE. ` � 1" = 150' DS -30 A ,_2,}2 - 1 0 2 \ \ SIP PAD \ \ VICINITY MAP o \ SCALE: 1 = 1 Mile 0 --O \ 00'° -°C) 0 -o y \ 0 O 0 0, 0 v0 \\\..\4\v\ o \ oo� o -°o°,, \ .p � o eo o o � �n �/ cs OLIKTOK \ POINT PAD \ . \ \ 0 1 ) '11., \ \ / \ \ SEE SHEET 2 FOR NOTES / \ • Existing Conductor / �� / LOTTNI SIBURY �/ n1s ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS / AREA: MODULE: UNIT: I O WELL O CO D ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80 —di 1 OF 3 2 • REV I DATE BY — CK 1 APP DESCRIPTION REV DATE BY CK APP DESCRIP110N 1 10/30/08 JFC XXX Added Wells Slot 4 -12 2 12/00/00 JFC BGM Added Wells Slot 13 -18 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN Well Ak State Plane Sec Line No. 'YS 'X' Latitude(N) Longitude(W) P•NOffs E.L. PA 0.G. O V. OP -11 6,036,332.70 1,656,791.89 70' 30' 39.015" 149° 51 57.587" 2,052' 1,519' 12.1' 4.0' OP -12 6,036,328.85 1.656,784.83 70' 30' 38.977" 149' 51 57.795" 2,056' 1,526' 12.2' 4.0' 0P03 —P05 6,036,325.10 1,656,777.76 70° 30' 38.940" 149° 51' 58.004" 2,059' 1,533 12.2' 4.0' 0PO4 —P07 6,036,321.43 1,656,770.69 70° 30' 38.904" 149° 51' 58.212" 2,063' 1,541'. 12.2' OP05 6,036,317.71 1,656,763.67 70° 30' 38.868" 149° 51 58.419" 2,067' 1,548' 12.2' 3.5' OP06 6,036,313.96 1,656,756.55 70° 30' 38.831" 149° 51' 58.629" 2,070' 1,555' 12.2' 3.9' OP07 6,036,306.41 1,656,742.45 70' 30' 38.757" 149' 51' 59.045" 2,078' 1,569' 12.2' 3.8' OP08 6,036,302.66 1,656,735.36 70° 30' 38.720" 149° 51' 59.254" 2,082' 1,576' 12.2' 3.8' OP09 6,036,298.90 1,656,728.32 70° 30' 38.683" 149° 51' 59.462" 2,085' 1,583' 12.2' 3.9' OP10 6,036,295.16 1,656,721.26 70° 30' 38.647" 149° 51' 59.670" 2,089' 1,590' 12.2' 3.9' OP11 6,036,291.38 1,656,714.21 70° 30' 38.610" 149° 51' 59.878" 2,093' 1,597' 12.2' 3.8' OP12 6,036,287.63 1,656,707.14 70' 30' 38.573" 149° 52' 00.087" 2,097' 1,604' 12.2' 3.9' OP13 6,036,276.37 1,656,685.97 70° 30' 38.463" 149' 52' 00.711" 2,108' 1,626' 12.2 3.9 OP14 6,036,272.66 1,656,678.89 70' 30' 38.426" 149° 52 00.920" 2,112' 1,633 12.2' 3.9' OP15 6,036,268.88 1,656,671.79 70' 30' 38.389" 149' 52' 01.129" 2,115' 1,640' 12.2' 3.9' 0P16 6,036,265.11 1,656,664.75 70° 30' 38.352" 149° 52 01.337" 2,119' 1,647' 12.2' 3.9' OP17 6,036,261.36 1,656 ,657.70 70° 30' 38.316" 149' 52' 01.545" 2,123' 1,654' 12.2' 3.9' OP18 6,036,257.62 1,656,650.62 70° 30' 38.279" 149° 52' 01.753" 2,127' 1,661 12.2' 3.9' n/AD 83 D rZ , /s.4% Bold Indicates Conductor Asbuilt this survey. LOU .N S]EIUFY "s� AssucIAIl`ES, IfNc. S URVEYfIRS ENGINEERS PIANNERS AREA: MODULE: UNIT: En OLIKTOK POINT PAD 't WELL CONDUCTOR ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80 —d1 PART: REV: 2 OF 3 2 • REV DATE BY CK APP . DESCRIPTION REV DATE BY CK APP DESCRIPTION NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN PROPOSED DISPOSAL WELLS Well Ak State Plane Sec Line PAD 0.G. No. 'Y' 'X' Latitude(N) Longitude(W) Offset F.N.L. F.E.L. ELEV. ELEV. 0-01 6,036,004.35 1,656,510.87 70° 30' 35.791" 149° 52' 05.887" 2,380' 1,802' 12.0' 3.2' OP -26 6,036,013. ?? 1,656,529. ?? 70' 30' 35. ? ? ?" 149' 52' 05. ? ? ?" ? ?? ? ?? 12.0' 3.2' SURVEYOR'S CER TI EI CA TE ®P • • •.... .. '� ..S �® / HEREBY CERTIFY THAT / AM PROPERLY , ■I '• �® REGISTERED AND LICENSED TO PRAC77CE ® 4 t h A 0 LAND SURVEYING IN THE STATE OF 0 ALASKA AND 77-IAT THIS PLAT REPRESENTS 0 a 0 •; ,1 A SURVEY DONE BY ME OR UNDER MY 0 ALAN J. ROOKUS ,o DIRECT SUPERVISION AND THAT ALL 104 LS - 8035 . ;' Q ,` �� DIMENSIONS AND OTHER DETAILS ARE ®, �f'F •'•• • ° °° S CORRECT AS OF MONTH X, XXXX. ® 4N It," i VaS®® ®\\\:4:4•416" ' ]l.(JNIEJTJR sio S E� mw. SIDRVEYORS ENGINEERS PLANNERS lb AREA: MODULE: UNIT: OLIKTOK POINT PAD lika WELL CONDUCTOR A SBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80 —d1 3 OF 3 1 . . TRANSMITTAL LETTER CHECKLIST WELL NAME OP / 7 " 7 PTD# Z / /Development Service Exploratory Stratigraphic Test Non-Conventional Well _ ` / FIELD: / , Y/ kG-1 ��G�- POOL: /Y �'�C �I"C ad ee'�K i' J (J . rl Circle 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 perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool NIKAITCHUQ, UNDEFINED OIL - 561100 Well Name: NIKAITCHUQ OPO4 -P07 Program DEV Well bore seg ❑ PTD#: 2081990 Company ENI PETROLEUM Initial Class/Type DEV / PEND GeoArea 890 Unit 11400 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 373301, wellbore will pass thru AOL 355024, top prod interval & TD in AOL 390616 3 Unique well_ name and number Yes 4 WeII located in a defined pool No NIKAITCHUQ, UNDEFINED OIL - 561100, governed by statewide regulations 5 WeII located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes Nearest well will be Nikaitchuq OP03 -P05, which will lie about 1/2 mile to the east 7 Sufficient acreage ayailable in_drilling unit Yes Only well within Sections 32 and 29 8 lf_deviated, is wellbore plat included Yes 9 Operator only affected party Yes ENI has a 100% working interest ownership in lease ADL 390616 10 Operator has_appropriate bond in force Yes RLB0008627 11 Perrnitcan be issued without conservation ord er Yes Appr Date 12 Permit can be issued without adrninistrativ_e_approvai Yes SFD 12/19/2008 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and_strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells_within 1 /4_mite area of review identified (For service well only) NA 16 Pre - produced injector, duration of pre production less than 3 months (For service well only) NA 17 Nonconven, gas conforms to AS31,05,0306,1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface_casing_ protects all_known USDWS Yes All aquifers exempted 40 CFR 147.102 (b)(3). 20 CMTvol adequate to circulate_on conductor & surf csg Yes 21 CMT v_ol adequate_ to lie- inlong string to surf csg No 22 CMT_will cover all known productive horizons No Slotted liner completion planned. 23 Casing designs adequate for C, T, B _& permaf Yes 24 Adequate tankage_or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste_to approved disposal well(s), 25 If_a_ re-drill has_a 10 -403 for abandonment been approved NA 26 Adequate wellbore separationproposed Yes Proximity analysis performed. Traveling cylinder path calculated. Gyros possible in surface hole. 27 if diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid_ program schematic & equip list adequate Yes Maximum expected formation pressure 8.5 EMW. MW planned up to 9.5 ppg. TEM 12/19/2008 29 BOPEs,_do they meet regulation Yes 30 BOPE_press rating appropriate; test to_(put psig in comments) Yes MASP calculated at 1240 psi. 3500_ psi BOP testplanned, • 31 Choke manifold complies w /API_ RP -53 (May 8 4) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H28 gas probable No H2S is not known in SB. Rig has sensor and alarms. 34 Nlechanical_condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen_ sulfide measures Yes None expected based in offset drilling Geology 36 Data_presented on potential overpressure zones Yes Expected reservoirpressure is 8.5 ppg EMW; wilt be drilled using 8.8 to 9.5 ppg mud Appr Date 37 Seismic analysisof shallow gas zones NA Hydrates_may_be encountered;_ mitigation measures discussed in drilling hazards section SFD 12/19/2008 38 Seabed condition survey (if off-shore) NA 39 Contact name /phone for weekiy_progress reports [exploratory only] NA Geologic - Engineering Public Commissioner: Date: Commissioner: Date p. ner Date 111111 /0 /i • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • c�� Potirolloiuim FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OPO4 -07 and PB1 OLIKTOK POINT, ALASKA r • 1 s„, I' ' KKK z .++Y' , . y Provided by: CANRIG Approved by: Andrew Buchanan Compiled by: John Lundy Dan Grunwald Emil Opitz Distribution: June 21, 2010 Date: June 10, 2010 • C)\°\ �� Nikaitchuq OPO4 -07 eni • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 3 2 WELL DETAILS 4 2.1 Well Summary 4 2.2 Hole Data 4 3 GEOLOGICAL INFORMATION 5 3.1 Hole Information 5 3.2 Daily Activity Summary 6 3.3 Target and Reference Well Correlation Points 9 3.4 Lithostratigraphy 10 3.5 Mudlog Summary 11 3.6 Connection Gases 31 3.7 Trip (Wiper) Gases 31 3.8 Sampling Program / Sample Dispatch 32 3.9 Approved Sample Plan OPO4 -07 33 • 4 PRESSURE / FORMATION STRENGTH DATA 34 4.1 Pore Pressure Gradient Evaluation 35 4.2 Quantitative Methods 35 5 DRILLING DATA 36 5.1 Survey Data 36 5.2 Bit Record 41 5.3 Mud Record 42 6 DAILY REPORTS 45 Enclosures 2 "/100' Formation Log (MD /TVD) 2 "/100' LWD Combo Log (MD/TVD) 2 "/100' Gas Ratio Log (MD /TVD) 5 "/100' Formation Log (MDTVD) (3400' to 4500' ; 11,500' to TD) 2 "/100' Drilling Dynamics Log (MD &TVD) Show Reports Final Data CD • CANRIG Nikaitchuq OPO4 -07 eni • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Downtime Parameter Equipment Type / Position Comments (hours) Casing Pressure Cable to 1502 transducer for BOP 0 tests only. Computer — Drill Floor Monitor Azonix Y IP conflicts Computer — Pit Monitor Azonix 0 Computer for Company Man, Rigwatch Remote (HP Compaq) 0 camp Computer for Company Man/ Rigwatch Remote (HP Compaq) 48 Replace receiver Toolpusher, office (wireless) antenna Computer for Mud Engineer Rigwatch Remote (HP Compaq) 0 Computer for Toolpusher Rigwatch Remote (HP Compaq) 0 Computers for Mudloggers (3) Data editing, Rigwatch Master, and 0 Rigwatch Remote (all HP Compaq) • QGM Agitator Ditch gas (Mounted in possum belly) Clean /repair /adjust Flame Ionization Detector (FID) Total 2 Gas and Chromatography. gas trap Hook Load / Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes /Minute and Pump Output 0 Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain /Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 24 C/O Transducer Pump stroke counters (2) 2 proximity sensors 0 Rate of penetration Crown Fast Sheave proximity 0 sensors RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to Rigwatch Master 0 Computer • CANRIG 2 III' Nikaitchuq OPO4 -07 eni • 1.2 Crew Unit Type : Arctic Unit Number : ML014 Years Days Mudloggers , *2 Sample Catchers Years Days Technician Days John Lundy 18 23 Steve Franzen 2 15 Allen Williams 2 Dan Grunwald 2 21 Omar Hinostroza 2 12 Howard Lamp 3 Emil Opitz 2 6 Shaun Terhune 1 15 Zach Beekman 2 1 Zach Beekman 2 8 *1 Years experience as Mudlogger *2 Days at wellsite between spud and completion at a total depth of 12,144 feet. Two loggers remained at the rig until completion. • • II, CANRIG 3 Nikaitchuq OPO4 -07 eni r 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OPO4 -07 PB1 API Index #: 50- 029 - 23409 -70 -00 Well: Nikaitchuq OPO4 -07 API Index #: 50- 029 - 23409 -00 -00 Field: Nikaitchuq Surface Co- Ordinates: Lat. 70.51109737 Long. - 149.86302079 Borough: North Slope Primary Targets: Schrader Bluff; OA Sand State: Alaska Primary Target Depth: 12031'MD/ -3834' TVDSS Rig Name / Type: Nabors 245E /Arctic Triple TD Depth: 12144'MD/- 3882.3' TVDSS Spud Date: May 19, 2010 Ground Elevation: 12.2 FT MSL TD Date: June 10, 2010 RT Elevation: 53.36' MSL @ RKB Days Drilling: 25 TD Formation: Schrader Bluff OA Sand Classification: Producer • 2.2 Hole Data The Borehole extends from the surface to a TD at 12,144'MD/3935.50'TVD and has three sections designated by hole diameter: the 16" Surface Borehole; the 12 %" Intermediate Borehole; and the 8'/" Production Lateral Borehole (Lateral Borehole). The well was designed as a production well. FIT Maximum Hole Section TD Mud Shoe Depth LOT Depth Dev. Casing/ Formatio Weight (inc) Liner MD TVD n (ppg) MD TVD (ft) (ft) (ft) (ft) Conductor 120 120 Recent 8.7- 0 20" casing 120 120 N/A 16" Surface Borehole 2455 2099.2 Ugnu 9.45 57.68 13/6" casing 2421 2080.7 12.4 Schrader 12 %" 8750 3838.0 Bluff 9.25 82.88 9%" casing 8727 3835.15 14 Schrader 8'/" 12144 3935.5 Bluff 8.9 92.85 7" Liner 12,142' 3.935' N/A • CANRIG 4 Nikaitchuq OPO4 -07 eni • 3 GEOLOGICAL INFORMATION 3.1 Hole Information Additional Comments: The well was spudded on the 19th of May 2010, entering a pre set conductor pipe at a depth of 120', and 16" hole was drilled to a depth of 2455'. During the drilling of the surface hole there was one trip for bit and to change out MWD /directional tools at 881' MD. 13 3/8" surface casing was set at 2420'. The float equipment and shoe were drilled out and new hole was drilled to 2475'. A Leak Off Test (LOT) was performed to 12.4 ppg The intermediate section was drilled with a hole diameter of 12.25" to 8750'. Fluid losses were encountered during the drilling of the intermediate hole section. On May 28, 2010, beginning at 6441'MD, soft sands were encountered and the well began taking 20 -40 bbl /hr losses. At 6486' MD, the losses increased to approximately 75 bbl /hr. A 35 bbl LCM pill was pumped at that point, and drilling continued with 25 bbl /hr losses to 7150' MD. From 7700' MD to intermediate casing point at 8750' MD, losses continued at a rate of 11 bbl /hr. 9 5/8" Casing was run into the hole without difficulty and set at 8727'. After drilling out to 8797' a Leak Off Test (LOT) was performed to 1032 psi /14 ppg equivalent mud weight. The hole was completed drilling 8.5" hole to a depth of 12144'MD. For additional detail, see daily summary below. • I I • CANRIG 5 Nikaitchuq OPO4 -07 eni • 3.2 Daily Activity Summary 5/18/2010; Rig Up Canrig; Pre -spud prep on rig 5/19/2010; Pick up BHA #1. Performed shallow gas evacuation drill. Pre -spud meeting held after drill. Wash down /clean out conductor to 110', and drill to 175'. TOH and rack back 2 stds. PJSM for continuing to P/U BHA #1. R/U Gyro survey. Drill to 227', then circulate to clean clay out of flow line. Drill from 227' to 566'. POOH and UD bit. Could not build angle, dialing up mud motor. 5/20/2010; Drilling /Sliding from 566'. Ream and wash 8 degree dogleg from 626' to 645'. Continue drilling /sliding to 849', taking gyro surveys every 30'. Slide from 849' to 881'. Circulate and condition, pump sweep and follow with 2.5 bottoms up. POOH, rack back drill string and check bit gauge and grade. R/D Eline, gyro data. P/U smart tools. Service top drive, C/O gear oil in top drive. RIH to 575'. Shim from top drive guide pads dropped approx 20' to rig floor (shim 2 "x5 "x1 /8 "; WT= 8oz.). Clear rig floor and assess situation. Plan for replacement of shim. Check torque on all bolts and install keeper wires. Inspect the rest of top drive rail from floor to crown. Resume RIH from 575' to 854. 5/21/2010; Slide ahead from 881', reaming 6+ degree doglegs. Wait on weather @ 1030hrs; potential ice buildups falling on rig floor. Continue drilling ahead @ 1200hrs from 1452' to 2193'. 5/22/2010; Drill ahead from 2193 ft to 2455 ft; circulate bottoms -up x4; back ream hole from 2455 ft to 1525 ft; trip in hole to 2000 ft; back ream hole from 2000 ft to 481 ft - heavy returns; trip in hole from 481 ft to 2385 ft, pump high viscosity sweep and circulate bottoms -up x3.5; trip out of hole to BHA - no tight spots; lay down BHA. 5/23/2010; Resume laying down BHA; pick up and rig up casing tools; run13 3/8" casing to 2379 ft, filling • while running in and topping off every 10 joints; circulate bottoms up; rig up cement lines and equipment, circulate and condition mud; pressure test cement lines, displace cement, bump plug, and land casing @ 2420 ft; blow down cement lines nad rig down cementing equipment; flush BOP stack and nipple down diverter in preparation for BOP testing. 5/24/2010; Finish nippling down diverter; install and pressure test well head; install annular valve and riser; remove diverter line and nipple up BOP stack; install choke, kill line, bell nipple, and flow line; slip and cut drilling line; pick up test joint, set test plug, and test BOP's; miscellaneous mudlogging activity — recalibrate gas detection equipment and service gas trap. 5/25/2010; Test BOP's - upper IBOP failed; replace upper IBOP valve in top drive; re -test upper IBOP successfully; rig down test equipment, install wear bushing, and lay down test joint; clear ice from derrick; pick up BHA, load nuclear source; pick up 12 joints drill pipe; circulate mud and shallow test MWD toolstring; trip in hole and tag cement at 2326'; circulate bottoms -up; pressure test casing; drill out cement to 2455'. 5/26/2010; Drill ahead from 2455 ft to 2475 ft; circulate bottoms -up to swap out spud mud with LSND mud; perform leak -off test to 12.4 ppg eq. mud weight; circulate and condition mud; drill ahead from 2475 ft to 3645 ft; circulate bottoms -up; drill ahead from 3645 ft to 4220 ft, pumping sweep at 3741 ft. 5/27/2010; Drill ahead from 6655 ft to 7149 ft; pump LCM pill and circulate bottoms -up twice due to losses of 25 bbl /hr; drill ahead from 7149 ft to 7284 ft; service top drive; drill ahead from 7284 ft to 7734 ft; miscellaneous mudlogging activity - calibrate gas detection equipment. 5/28/2010; Drill ahead from 5605 ft to 6441 ft - losing 20 -40 bbl /hr at 6441 ft; pull back 1 stand, circulate bottoms -up 2x, reducing ECD to 9.69 ppg with estimated losses of 20 -25 bbl /hr; drill ahead from 6441 ft to 6486 ft - losing 75 bbl /hr at 6486 ft; pump 35 bbl LCM pill; POOH to 6124 ft, circulate and condition mud for 1 hr; run in hole to 6420 ft, wash down to 6486 ft; drill ahead from 6486 ft to 6655 ft. • CANRIG 6 Nikaitchuq OPO4 -07 eni • 5/29/2010; Drill ahead from 4220 ft to 5605ft; miscellaneous mudlogging activity - primary gas trap fails at approximately 04:00, switch to secondary gas trap, replace motor in primary gas trap and reinstall same, service and test gas trap repeatedly as gas levels are extremely low, hoist replacement hydrogen cylinder to top of rig and swap out empty hydrogen cylinders. 5/30/2010; Pump 10.5 ppg sweep with hole lubricant (vegetable shortening /lard); drill ahead from 7734 ft to 8510 ft, losses of 137 bbls on day tour and 122 bbls on night tour ( -11 bbl /hr average). 5/31/2010; Drill ahead from 8510 ft to 8750 ft; begin to circulate high viscosity sweep; power outage on rig - operations stalled for 1.5 hours; resume pumping sweep and monitor well - no losses; trip out of hole from 8750 ft to 7500 ft; back ream from 7500 ft to surface casing shoe at 2420 ft - 6 bbl loss ; circulate bottoms up at shoe; service top drive and crown; trip in hole from 2420 ft to 4507 ft, and fill pipe. 6/01/2010; Rig down BOP testing equipment and lay down test joint; rig up to run 9 5/8" casing; run in hole with 9 5/8" casing to 8750 ft, circulating bottoms -up at 2405 ft, 4400 ft, 6460 ft, 8000 ft, and 8750 ft; pick up landing joint. 6/02/2010; Rig down BOP testing equipment and lay down test joint; rig up to run 9 5/8" casing; run in hole with 9 5/8" casing to 8750 ft, circulating bottoms -up at 2405 ft, 4400 ft, 6460 ft, 8000 ft, and 8750 ft; pick up landing joint. 6/03/2010; Circulate bottoms up following casing run - 32u trip gas; rig clown Frank's casing tool; rig up cement lines and cement head; circulate bottoms -up to condition mud for cement job; pressure test cement lines; pump cement job and bump plug; rig down cement head and flush BOP stack; lay down landing joint and casing elevators; install and pressure test wellhead; change out upper rams; test BOP's; pull test plug, set wear ring, lay down test joint, blow down lines; trip in hole in preparation for laying down worn drill pipe. • 6/04/2010; Continue to trip in hole with drill pipe to 3814 ft in order to lay down worn joints; clean out mud pits and take on oil -based mud; slip and cut drilling line; service drawworks and crown; lay down worn drill pipe, vacuuming oil -based mud out of each; clear ice from derrick; trip in hole with drill pipe to 4950 ft in order to lay down worn joints; lay down drill pipe, vacuuming oil -based mud out of each. 6/05/2010; Pick up new drill pipe and run in hole to 3250 ft; circulate and condition mud, clean drill pipe; trip out of hole, rack back 34 stands; service iron roughneck and drawworks, clean drill floor, and strap new drill pipe in pipe shed; pick up new drill pipe and run in hole to 8200 ft; circulate and condition mud, clean drill pipe; miscellaneous mudlogging activity - calibrate gas detection equipment. 6/06/2010; Trip new drill pipe out of hole and rack back; pick up 8 joints heavyweight drill pipe and jars and run in hole with same; trip heavyweight drill pipe out of hole and rack back; pick up BHA and trip in hole to 1000 ft; circulate and condition mud, and shallow test MWD tools; trip in hole to 8500 ft, filling pipe every 20 stands; circulate bottoms -up 2x to clean hole; pressure test casing /shoe to 3000 psi; wash down to float tag at 8644 ft; drill out float and cement, tag shoe at 8728 ft; drill ahead to 8758 ft; circulate and condition mud while attempting to downlink to rotary steerable tools. 6/07/2010; Drill ahead from 8758 ft to 8797 ft; circulate bottoms -up; perform formation integrity test to 1032 psi /14 ppg equivalent mud weight; blow down kill line and rig down testing equipment; drill ahead from 8797 ft to 9670 ft. 6/08/2010; Drill ahead from 9670 ft to 10,540 ft, reaming each stand; circulate bottoms -up, and continue to circulate until hole is clean; trip out of hole from 10,540 ft to 9944 ft, stand back 6 stands of drill pipe, and prepare directional drilling and rig monitoring systems for sidetrack; kick off open hole sidetrack from 9544 ft; drill ahead to 10190 ft; miscellaneous mudlogging activity — recalibrate gas detection equipment. 6/09/2010; Drill ahead from 10,190 ft to 11378 ft, reaming each stand. • CANRKG 7 Nikaitchuq OPO4 -07 eni • 6/10/2010; Drill ahead from 11378 ft to 12144 ft, reaming each stand; circulate bottoms -up; pump high viscosity sweep until cuttings are clean (7800 strokes); pump weighted sweep until cuttings are clean (7800 strokes); pull out of hole from 12144 ft to 8700 ft; circulate bottoms -up at shoe; miscellaneous mudlogging activity - calibrate gas detection equipment. 6/11/2010; Continue to circulate at the intermediate casing shoe, pump dry job; blow down top drive; monitor hole for 10 minutes - hole static; pull out of hole from 8700 ft to 625 ft; lay down BHA; clear and clean drill floor; rig up BOP testing equipment; remove wear bushing and install test plug; test BOP's; lay down test tool, pull test plug, and install wear ring; lay down test joint, blow down choke manifold; slip and cut drilling line; service top drive and blocks; pick up BHA; trip in hole with hole opener BHA to 6074 ft; change out swivel packing. 6/12/2010; Service the top drive with grease then test. Trip in the hole. From 6050', fill every 20 joints to proper displacement down to 8840'. Ream and wash the hole. Run in hole with no pumps and no rotation from 9424' to 10240'. Reaming and washing through several tight spots from 10240' to 12144. Circulate and condition the hole. Circulate 2 bottoms up. Trip out of hole then flow check the well at 11530. Run in hole to bottom and circulate and condition 1 bottoms up. Displace to completion fluid (Brine). Trip out of hole and flow check. No flow. Pull out of hole. 6/13/2010; Pull out of hole. Lay down BHA. Service rig. Run in hole with completion liner. • CANRIG 8 9 *s Nikaitchuq OPO4 -07 eni • 3.3 Target and Reference Well Correlation Points Surface OPO4 -07 Prognosis P03- P03PB1 OP -11 1 OP- 12 -PB01 OP26 -DSPO2 MD TVDSS TVDSS TVDSS TVDSS TVDSS SV-4 720 -664 -657.7 -659.1 SV -3 978 -910 -907.6 -902.8 SV -2 1273 -1173 - 1174.0 - 1169.0 - 1163.2 SV -1 1901 -1969 - 1671.1 - 1671.2 - 1647.0 - 1648.1 Permafrost Base 1973 -1725 - 1722.1 - 1726.8 - 1724.3 Ugnu Top (UG4) 2331 -1978 - 1984.8 - 1984.8 - 1931.5 - 1957.2 13 3/8 SCP 2401 -2019 UG -2 Coal Marker 3774 -2470 - 2512.7 - 2488.2 - 2422.0 - 2428.2 L Ugnu 6220 -3173 - 3140.3 - 3274.3 - 3060.0 - 3122.5 Schrader Bluff 7220 -3460 - 3387.3 - 3511.3 - 3341.9 - 3325.0 • N Sand Top 7475 -3533 Fault 11 7557 -3357 N Sand Top 7582 -3564 - 3470.7 - 3596.2 - 3386.4 - 3382.6 N Sand Bottom 7742 -3609 - 3523.5 - 3640.5 - 3424.4 - 3423.3 OA Sand Top 8451 -3750 - 3789.6 - 3518.2 - 3536.4 9 7/8" ICP 8750 Total Depth 12144 Final Top Picks: LWD tops and bases refer to provisional picks by the wellsite geologist. • CANRIG 9 Sl Nikaitchuq OPO4 -07 em • 3.4 Lithostratigraphv ENI PROGNOSED LWD PICK FORMATION MD TVDITVDSS MD TVD/TVDSS (ft) (ft) (ft) (ft) SV-4 720 714/ - 664 Above LWD Start SV -3 978 1062/ -910 975 965.4/ -912.0 SV -2 1273 1225/ - 1173 1266 1228.4/- 1175.0 SV -1 1901 2021/ 1833 1685.4/- 1632.0 Permafrost Base 1973 1977/ - 1725 1932.7 1763.4/- 1710.0 Ugnu Top (UG4) 2331 2030/ - 1978 2313 2021.4/- 1968.0 13'/8" Surface Casing Point 2401 2071/ -2019 2420.9 2080.1/- 2026.8 TD 16" Hole Section 2401 2072.4/- 2019.0 2455.0 2097.6/- 2044.2/ UG -2 Coal Marker 3774 2622/ -2470 3788.0 2527.1/- 2473.7 • L Ugnu 6220 3225/ -3173 6355.0 3252.0/- 3198.6 Schrader Bluff 7220 3512-3460 7286.0 3525.0/- 3471.6 N Sand Top 7475 3585 -3533 7543 3594.8/- 3541.4 Fault 11 7557 3409/ -3357 7684 3646.6/- 3593.2 N Sand Top 7582 3616/ -3564 7816.0 3667.4/- 3614.0 N Sand Bottom 7742 3661/-3609 8006.0 3716.3/- 3662.9 Fault #3 8226 3775.0/- 3721.7 Not Present OA Sand Top 8451 3802/ -3750 8702 3832.5/- 3779.2 9%" Int. Casing Point 8750 3802/ -3750 Total Depth 12144 3939/ -3887 • CANRIG 10 Clk Nikaitchuq OPO4 -07 ern • 3.5 Mudloq Summary The Permafrost section of the OPO4 -07 consists of moderate beds of sand, conglomerate and claystone with thinner clay interbeds, particularly near the surface. This material is almost entirely included in the permafrost section, contained no hydrocarbon shows. Quaternary Deposits / Sagavanirktok — Surface to 2313.2' MD /- 1968.0' TVDSS Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 1050 8.3 169.1 252 0 28.7 This interval extends from surface down to the top of the Ugnu at 2313.2' MD and is comprised of a thick sequence of sands, conglomerates and claystones with occasional thin to massive siltstone and poorly developed coals and carbonaceous remains. Sand dominates the upper part of the section with claystone becoming predominant with depth Discrete fragments of sandstone were rarely observed, samples were typified by loose sand and conglomeritic pebble fragments with irregular globular clay masses. Clay masses commonly contained trace to abundant sand mechanically worked into the clay by drilling, circulation and shaker action and had a surface coating of imbedded loose sand. Formation consists of moderate to thick beds with locally abundant thinner interbeds. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Claystone (1000 -1090) = olive gray to dark gray to medium gray in color; slightly to moderately adhesive; moderately cohesive; cuttings come over shakers as clumpy; dull earthy luster; silty gritty texture turns to clayey smooth as depth increases; very slightly calcareous when exposed to hcl. • Sand (1000 -1060) = translucent to dark gray to dusky yellowish brown; upper very fine to lower medium predominantly; fair to well sorted; subangular to subrounded angularity; moderate to high sphericity; >5% pyrite noticed throughout samples; <5% bluish green to green glauconite in samples. Claystone (1090 -1150) = medium gray to dark gray in color throughout; very slightly adhesive when prodded; slightly cohesive; cuttings are very clumpy; pasty consistency is noticed throughout samples; dull earthy luster; silty to clayey to some gritty interbeds texturally throughout the clumps; sands account for the grittiness noticed in cuttings from reworking due to drilling. Claystone (1150 -1210) = dark gray to grayish black; color has been steadily becoming darker as depth increases; very slightly adhesive; slightly cohesive; cuttings are globular and clumpy; dull earthy luster in cuttings; silty and gritty to clayey texture throughout cuttings; grittiness due to reworked sand grains. Claystone (1210 -1330) = medium dark to medium gray; soft to slightly firm; clayey to silty texture; dull earthy luster; globular irregular cuttings habit; surface of clay masses coated with mechanically imbedded loose sand; slightly to moderately cohesive; slightly to moderately adhesive; locally very silty; trace to non calcareous. Sand (1330 -1420) = light to medium light gray; soft to dis- aggregated; moderately well to well sorted; friable; fine upper to medium lower and fine lower grain; angular to sub - angular and occasionally sub spheroidal; dominantly clear to translucent white quartz; trace dark mafic mineral /lithics; trace brown, orange and blue gray grains trace glauconite; occasional trace pyrite; interbedded with thin to moderate claystone; trace calcareous; no oil indicators Conglomeratic Sand /Conglomerate (1350 -1440) = light to medium dark gray; moderately hard to dis- aggregated; medium lower to medium upper and fine upper sand with trace to abundant coarse and small pebbles /pebble fragments; sand is predominantly clear to translucent white with trace to common dark mafic mineral /lithic grains; coarser material is dominated by dark gray to black chert/lithics with trace translucent white quartz pebble fragments; occasional trace pyrite in quartz pebble fragments; trace clastic coal • 11 CANRIG 11 Nikaitchuq OPO4 -07 eni • fragments; finer material is angular to sub - angular and sub - spheroidal as seen above; pebbles are moderately rounded; trace fine pyrite nodules in medium gray pebbles and larger pyrite nodules in loose sand; generally matrix supported in silty /sandy clay; grain supported in part; no oil indicators; trace to non calcareous. Claystone (1420 -1510) = medium dark to medium gray; soft to slightly firm; clayey to silty texture; dull earthy luster; globular irregular cuttings habit; surface of clay masses coated with mechanically imbedded loose sand; slightly to moderately cohesive; slightly to moderately adhesive; locally very silty to sandy; occurs as moderate beds and also as interbeds in the associated sand /conglomerate; no oil indicators; non to trace calcareous. Sand /Conglomeratic Sand (1540 -1600) = medium to medium light gray; moderately sorted; fine upper to fine lower in the upper portion coarsening with depth becoming medium lower to fine upper and medium upper; trace coarse and occasional small pebbles /fragments generally matrix supported in fluffy hydrophilic light to very light gray silty clay; upper sand is principally clear to translucent white quartz; grades to medium gray and brownish gray lithics with abundant clear and trans - lucent quartz; trace black and dark gray mafic mineral /lithics; trace pyrite in pebbles and as loose nodules in sand; trace to common coal fines; trace glauconite; no oil indicators; very slight trace calcareous. Sand /Conglomeratic Sand (1600 -1750) = medium gray with a slight brownish secondary hue; soft to dis- aggregated; friable; moderately sorted; medium lower to medium upper and fine upper grain; about evenly divided between clear to translucent white quartz and light to medium gray and brownish gray lithics; trace to common dark gray to black mafic mineral /lithics and coal fines; common to abundant very fine crystalline pyrite in larger grains and scattered pebble fragments; common medium grain size pyrite nodules; trace glauconite; trace partially de- composed wood; trace brick red, brown and orange lithics appears to be primarily matrix supported in light to very light gray silty hydro philic clay; expansive; easily lost in sample preparation; no visible pitting or overgrowth on sand; pitting and chatter visible on pebbles; no oil indicators; non to trace calcareous. Sand /Conglomeratic Sand (1750 -1810) = translucent to medium gray to dusky yellowish brown throughout; 411 upper very fine to lower medium sized grains; well sorted grains with subangular to subrounded angularity; high sphericity; some slight pitting visible under high magnification; medium sized pyrite grains are found throughout samples, generally <5 %; bluish green to light green glauconite throughout samples, <5 %; conglomerate consists of pea sized pebbles varying in different darker hues of gray generally, some dusky yellowish brown to dark brown; pebble surfaces varied from very smooth to moderately pitted. Claystone (1780 -1840) = medium gray to dark gray; sample consistency is curdy, similar to cottage cheese; dull earthy luster; texture is highly variable from silty to very gritty to granular containing small pebble sized grains; the reworking of the clay from drilling has included the sand and pebble grains into the clay cuttings; moderately adhesive; slightly to moderately cohesive; no to slight reaction to hcl. Sand (1810 -1960) = translucent to medium gray to dusky yellowish brown grains; upper very fine to lower medium grain size; well sorted throughout sample interval; subangular to subrounded; high to moderate sphericity; no visible abrasion or other surface features on grains when viewed under high magnification; fine to medium sized pyrite grains throughout interval, <5 %; bluish green to translucent green glauconite throughout interval. Claystone (1900 -1990) = medium dark gray to medium gray to some dark gray cuttings; cuttings are clumpy reworked globular masses; dull earthy luster; silty gritty to silty clayey to some granular textured cuttings. variance due to reworking of clay from drilling; slightly to moderately adhesive; slightly cohesive; no visible reaction to hcl. BASE OF THE PERMAFROST: 1932.7' MD/ - 1710.0' TVDSS Sand /Sandstone (1960 -2080) = translucent to medium dark gray to some dark brown grains; upper very fine to lower medium grain size; well sorted; subangular to subrounded with high to moderate sphericity; very fine to medium sized pyrite grains, <5 %; light green to bluish green glauconite, <5 %; trace amounts of shell • CANRIG 12 Nikaitchuq OPO4 -07 • fragments; sandstone cuttings slightly calcareous; some sandstone cuttings have pyrite growths on /within them. Claystone (1990 -2140) = medium gray to dark gray; clumpy globular masses change to a pasty and mushy consistency as depth increases; dull earthy luster; silty clayey to silty gritty texture; slightly adhesive; slightly cohesive; no visible reaction to hcl. Sand (2080 -2200) = translucent to dark gray to dusky yellowish brown; upper very fine to lower medium; very well to well sorting through sample interval; subangular to sub - rounded with high to moderate sphericity; pyrite throughout interval both as homogeneous grains and within some quartz grains' crystalline structure; bluish green to light green glauconite throughout, <5% light green to bluish green glauconite throughout sample interval. Sand (2200 -2320) = translucent to dusky yellowish brown to medium gray; black lithic grains abundant giving salt and pepper appearance; upper very fine to lower medium grain size throughout sample interval; well sorted; subangular to subrounded; high sphericity; fine to medium pyrite grains, <5 %; light green to bluish green glauconite throughout sample interval. Coal (2230 -2280) = very poorly developed coal accompanied by carbonaceous shale; coal is brittle and tough to crumbly; irregular hackly fracture; tabular to wedge like; dull to resinous luster; carbonaceous shale is dusky yellowish brown to dusky brown; very mushy to crumbly; looses form when prodded; some cuttings show grading from carbonaceous shale to poorly developed lignite coal. Claystone (2260 -2380) = medium gray to olive black to dark gray; clumpy pasty consistency in globular masses; dull earthy luster throughout; silty to gritty texture depending on amount of reworking with sand due to drilling; moderately to very adhesive; slightly to moderately cohesive. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 1296 25 5220 1370 30 6578 1395 23 5007 1508 44 8953 1526 118 23796 1584 84 19252 1649 118 23681 1778 90 17959 1886 248 49633 2024 103 20846 2073 73 15785 Ugnu: 2313.2' MD/ - 1968.0' TVDSS to 7286' MD /- 3471.6' TVDSS Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 956 2.1 159.9 136 tr 14.8 The Ugnu formation consists of two units, upper and lower Ugnu. The upper portion of the formation is essentially similar in nature and appearance to the overlying material. However, the sands are generally finer grain and exhibit slightly greater wear through transport/erosion. The section consists primarily of thickly bedded sand /sandstone occasionally grading to sandstone conglomerate and conglomerate. Moderate to thin claystone and siltstone interbeds occur throughout. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. • CANRIG 13 en' Nikaitchuq OPO4 -07 • Sand (2320 -2450) = translucent to medium gray to dusky brown; upper very fine to lower medium grain size; well sorted with high to moderate sphericity; subangular to subrounded; medium to fine sized pyrite grains throughout, <5 %; few light green to greenish blue glauconite grains. Sand (2455 -2560) = samples consist of a slurry of medium gray, well sorted loose sand; the sand is primarily lower medium- to upper fine- grained, with a full range from upper medium- to lower fine- grained; grains mostly consist of transparent to translucent quartz that is very light gray to colorless, along with scattered light orange grains; the remainder of the sand consist of dark brown and dark gray to black siliceous lithics and some blue green glauconitic lithics; quartz grains are angular to subangular and display moderate to poor sphericity, while the lithics are mostly subrounded with moderate to good sphericity; samples are non - calcareous. Sand (2560 -2680) = light to medium light gray; moderately to locally well sorted; friable; soft to dis- aggregated; medium lower to fine upper and very fine upper grading to medium upper and very coarse with depth; angular to sub - angular; abundant visible crystal facets; slightly smokey to translucent white and clear quartz predominate; abundant light gray lithic /mineral grains; trace to abundant dark mafic mineral /lithics and coal fines; trace brick red jasper, yellow, greenish gray, orange and bluish gray grains; scattered phlogopite mica; moderately thick vertically sorted beds; occasional thin lignitic sub - bituminous coal interbeds; material appears to be primarily grain supported with some locally clay matrix supported; slightly calcareous; no oil indicators. Sand (2680 -2770) = light to medium light gray with a slight bluish secondary hue; soft to dis- aggregated; friable; moderately well sorted; medium lower to fine and very fine upper; trace medium upper and coarse; angular to sub - angular and occasionally sub spheroidal; slight smokey to translucent white and clear quartz predominate; trace brick red jasper; trace yellow, bronze, brown, bluish gray and green lithic /mineral grains; trace to common dark gray to black mafic mineral /lithics; scattered phlogopite series mica in thin books; primarily clay matrix supported through this interval; some local grain support; moderately thick beds with occasional thin lignitic sub - bituminous coal interbeds; slightly calcareous, principally from scattered off white calcite fracture fill. Sand (2770 -2920) = light to medium light gray with a slight bluish secondary hue; soft to dis- aggregated; friable; moderately well sorted; medium lower to medium upper and fine upper; trace coarse lower; angular to sub - angular; slightly smokey to translucent white and clear quartz predominate; trace to common dark gray to black mafic mineral/ lithics; trace yellow, green, bronze and bluish gray lithic /mineral grains; occasional thin phlogopite books; trace muscovite mica; sample recovered as loose sand with variable amounts of soft brown to brownish gray clay matrix masses; indicates primary grain support with local zones of hydrophilic clay matrix; occurs as moderate beds with occasional thin lignitic sub - bituminous coal interbeds; some clay masses appear to be slightly oil stained and display a very slight dull yellow fluorescence; no odor; no cut; very slightly calcareous, primarily from point source calcite. Coal /Carbonaceous shale (2950 -3010) = dark brownish gray to dark brown; firm to very firm; splintery irregular fragments; hackly; silty to clayey in part; commonly brown stained on fractures and partings; thinly bedded; interbedded with lignitic brown silty sandstone; no features of well developed coal in the thicker beds but some of the thinner material interbedded in the previous sand section displayed partial sub - vitreous luster. Sand /Conglomeratic Sand (3010 -3100) = light to medium light gray; soft to dis- aggregated; friable; moderately well to poorly sorted; fine upper to medium lower in the upper portion of the zone; becomes medium upper to coarse upper and very coarse with trace to common fine at 3070 sample; angular to sub- angular; occasional sub - spheroidal lithic /chert grains; primarily translucent smokey and white quartz with common dark gray to black mafic mineral /lithics above 3070'; larger grain material below 3070' is dominated by clear and translucent white quartz with some smokey quartz grains; varicolored grains have become rare; trace brown, orange and bluish gray grains; common glauconite; trace pyrite; material appears to be matrix supported in the finer fraction, grain supported in the larger grain material; matrix is a very light brownish gray to light brown clay; lignitic in part; very slightly calcareous, primarily from trace calcite; no oil indicators. • AMG 14 Nikaitchuq OPO4 -07 eni • Sand /Conglomeratic Sand (3100 -3220) = light gray with a slight greenish to brownish secondary hue; soft to dis- aggregated; friable; medium upper to coarse lower and occasionally very coarse; angular to sub - angular; trace small subrounded pebbles /very coarse sand; common crystal facets on quartz grains; predominantly clear to translucent white and smokey quartz; common to abundant light to medium light gray lithics; common dark gray to black mafic mineral /lithics; common to abundant glauconite; trace orange and red jasper; trace brown, yellow and bluish gray lithic /mineral grains; trace pyrite as masses and inclusions in quartz; commonly grain supported; occasional partially indurated fragments are moderately calcareous; interbedded with soft clayey siltstone; siltstone is hydrophilic and recovered fragments are moderately to very sandy; no oil indicators. Siltstone /Claystone (3190 -3340) = light brownish gray; soft to very soft; dull earthy to gritty luster; silty to sandy texture; non cohesive; non adhesive; very hydrophilic; fluffy easily washes away in sample preparation slightly to very sandy; tends to contain fine to very fine grain quartz sand; flocculates immediately in hcl; no oil indicators; non to very slightly calcareous. Sand /Conglomeratic Sand (3220 -3400) = light gray with a slight greenish to brownish secondary hue; soft to dis- aggregated; friable; medium upper to coarse lower and occasionally very coarse; angular to sub - angular; trace small pebbles /pebble fragments; common crystal facets on quartz grains predominantly clear to translucent white and slightly smokey quartz; common to abundant light to medium light gray lithics; common dark gray to black mafic mineral /lithics; common to abundant glauconite; trace orange and red jasper; trace brown, yellow and bluish gray lithic /mineral grains; trace pyrite as masses and inclusions in quartz; commonly grain supported; occasional partially indurated fragments are moderately calcareous; interbedded with soft clayey siltstone; siltstone is hydrophilic and recovered fragments are moderately to very sandy; no oil indicators; Siltstone /Claystone (3340 -3490) = very light brown; soft to very soft; dull earthy to gritty luster; silty to sandy • texture; non cohesive; non adhesive; very hydrophilic; fluffy easily washes away in sample preparation slightly to very sandy; tends to contain fine to very fine grain quartz sand; flocculates rapidly in hcl; no oil indicators; very slightly to slightly calcareous. Sand /Conglomeratic Sand (3400 -3550) = light gray with a slight greenish to brownish secondary hue; soft to dis- aggregated; friable; medium upper to coarse lower and occasionally very coarse; angular to sub - angular; trace small pebbles /pebble fragments; common crystal facets on quartz grains predominantly clear to translucent white and slightly smokey quartz; common to abundant light to medium light gray lithics; common dark gray to black mafic mineral /lithics; common to abundant glauconite; trace orange and red jasper; trace brown, yellow and bluish gray lithic /mineral grains; trace pyrite as coarse grain size masses and inclusions; mixed grain and matrix support; some partially indurated fragments are moderately calcareous; interbedded with soft clayey siltstone no oil indicators; slightly calcareous. Sand /Conglomeratic Sand (3550 -3690) = light gray with a slight greenish to brownish secondary hue; soft to dis- aggregated; friable; medium upper to medium lower, coarse lower and fine upper; trace coarse upper; section gradually coarsens with depth; angular to sub - angular; trace sub spheroidal; samples are dominantly clear to trans - lucent white and slightly smoky quartz; common dark mafic mineral /lithics; common medium light to medium gray lithics; trace brown, bronze and blue gray lithics; trace light blue -green mineral; trace pyrite as coarse grain size masses and occasional fine crystal in quartz grains; apparently grain supported or dis - aggregated; rare indurated fragments are trace to very slightly calcareous; no oil indicators. Sand (3690 -3755) = samples consist of a light to medium brownish gray slurry of sand with lesser silt and minor clay; the sand is a well sorted, lower medium -to upper fine- grained quartz sand with minor gray siliceous lithics and blue green glauconite, trace black shale, and rare pyrite and calcite cement; the quartz is very light gray, translucent, and subrounded to subangular with good to moderate sphericity; grain surfaces are etched and pitted. Carbonaceous Shale (3755 -3830) = very dark brown to black shale; the shale is crumbly to brittle, and • CANRIG 15 1 Nikaitchuq OPO4 -07 en' cuttings are sub - blocky to somewhat tabular; planar fracture surfaces display a matte texture with a dull to slightly waxy luster; under the microscope, thin, fissile shale laminae are evident, interbedded with dark brown organic material that is partially oxidized to reddish brown or lighter shades of brown; rare black, blocky bits of low grade coal are scattered throughout the samples; interbedded with minor siltstone and lesser sand and claystone. Sand (3830 -3980) = samples consist of an olive gray slurry of disaggregated silty sand; the bulk samples exhibit poor cohesion and completely lack plasticity; the grains are moderately to well sorted, with a range of grain sizes from upper fine to lower very fine- grained, grading into silt; the sand is mostly comprised of translucent to transparent very light gray to pale yellow quartz with a few brown grains; the remainder of the sand consists of blue green glauconitic lithics and black siliceous lithics, the latter imparting a slight salt and pepper appearance to the sand under the microscope; grains are subangular to subrounded and display moderate sphericity overall; the surfaces of quartz grains show signs of both etching and polishing; traces of quartz, lithic, and chert chips and rare pebbles occur in the sample at 3970'; trace amounts of interbedded black shale are present in the base of the interval, samples are mildly calcareous; no stain, odor, cut, nor fluorescence are detectable. Sand (3980 -4045) = samples consist of an olive gray slurry of disaggregated sand and silt with slight amounts of interbedded fissile black shales; the sand is moderately to well sorted, with grain sizes ranging from upper fine- to lower very fine- grained sand that grades into silt; trace coarse grains are found in the lower half of this interval; the sand primarily consists of very light gray quartz with subordinate black lithics and minor blue green glauconite; grains are subangular with moderate sphericity on average. Siltstone (4045 -4090) = gray sandy siltstone with minor clay interbedded with sand; rare intact cuttings are crumbly, with a dull, earthy luster and a silty and gritty texture due to sand content; samples mostly consist of disaggregated sand and silt. Sand (4090 -4230) = samples consist of a pulverulent, brownish gray slurry of disaggregated sand and silt with traces of interbedded thin black shale; the sand is moderately to well sorted; grain sizes range from lower medium to lower very fine grained and appear to grade into silt -sized particles; coarse chips and pebbles are present at the top and base of this interval; the sand is primarily comprised of translucent to transparent very light gray to colorless to very pale yellow quartz with sparse brown grains; the remainder of the sand consists of silicic, black cryptocrystalline lithics and minor blue green glauconite; trace orange lithics and rare pyrite are also present; the quartz grains are subangular to subrounded, with moderate sphericity on average, while the lithics are more subrounded with good sphericity; the coarse grains consist of angular white chert or rounded black lithic pebbles; no stain, odor, cut nor fluorescence are detectable. Sand (4230 -4380) = samples consist of a dark olive gray slurry of loose sand with minor disaggregated silt and traces of interbedded black shale; the sand is well sorted and consists primarily of translucent to transparent very light gray to colorless to pale yellow quartz along with a small amount of brown grains; the remainder is composed of medium gray to black cryptocrystalline siliceous lithics and minor blue green glauconite; larger, medium- to very coarse - grained chips of quartz, chert, and gray lithics are conspicuous within the samples, along with a few intact gray lithic pebbles; the quartz sand is subangular to subrounded and exhibits moderate to poor sphericity, while the lithic sand is mostly subrounded and displays good sphericity; the surfaces of the quartz sand grains display impact abrasions as well as etching, and the coarse lithics are polished; samples are non calcareous, and no petroleum stain, odor, nor fluorescence are detectable. Sand (4380 -4530) = samples consist of a medium grayish brown slurry of loose sand with minor disaggregated silt; the sand is a well sorted sand that is mostly upper fine to upper very fine grained, with minor amounts of lower very fine grained sand grading into silt as well as trace to minor medium to coarse - grained chips and rare coarse pebbles; the sand is predominantly comprised of very light gray to colorless to pale yellow, translucent to transparent quartz, with the remainder consisting of gray to black, siliceous cryptocrystalline lithics and minor blue green glauconite; the quartz sand is subangular with moderate sphericity while the lithics are subrounded with good to moderate sphericity; quartz grain surfaces display both • 16 CANRIG Beni Nikaitchuq OPO4 -07 • impact abrasions and etching; rare pyrite can be found within the samples, as well as within the black lithics; the coarse chips and pebbles consist of white quartz, orange to yellow chert, and gray or black lithics; the chips are angular, while the pebbles are well rounded and often polished; no petroleum stain, odor nor fluorescence is detectable. Sand (4530 -4600) = samples consist of a medium olive gray slurry of loose sand and disaggregated silt; the sand mostly consists of translucent to transparent very light gray to colorless quartz, with subordinate black lithics that impart a salt and pepper appearance to the sand; the quartz is subangular to subrounded with moderate sphericity, and grain surfaces show signs of both impact abrasions and etching; the lithics are subrounded with good sphericity, as are minor grains of blue green glauconite; no stain, odor, cut nor fluorescence are detectable. Sand /Sandstone (4600 -4700) = light to medium light gray; hard to dis- aggregated sample recovered as loose sand with occasional hard well indurated calcareous sandstone; non friable; moderately to poorly sorted; medium upper to medium lower, coarse lower and fine grain; trace to common coarse upper and very coarse; scattered 3mm pebble /pebble fragments; angular to sub - angular and occasionally sub spheroidal; predominantly translucent white to slightly smokey and clear quartz; common to abundant light to medium gray lithics; trace to common dark gray to black mafic mineral /lithics; trace glauconite; trace yellow, brown, bronze and medium bluish gray lithics; trace pyrite as micro - crystalline masses; material appears well indurated; no visible porosity in scattered sandstone fragments; loose sand generated by very slow mechanical destruction of the rock; occasional thin claystone and siltstone interbeds; no oil indicators; note; adding resinex (looks like coal). Siltstone /Claystone (4760 -4900) = medium to medium light brownish gray; sample recovered as soft globular masses of partially hydrated clay /silt with common to abundant fine upper to fine lower angular quartz sand; very hydrophilic; easily lost in sample preparation surface of the masses imbedded with larger loose sand grains; non to slightly adhesive; non cohesive; fluffy flocculates quickly with hcl; acts as matrix material in adjacent sands; common to very abundant pyrite; occasional very thin coaly interbeds; non calcareous overall; 410 trace calcite; no oil indicators Sand /Sandstone (4810 -4930) = light to medium light gray with a slight greenish to brownish secondary hue; sample collected as loose dis- aggregated sand; occasional very silty /clayey sandstone masses similar to the above siltstone; moderately sorted; angular to sub - angular and occasionally sub spheroidal; trace larger grains display some stream erosion characteristics; principally translucent white to slightly smokey and clear quartz; trace dark mafic mineral /lithics; trace varicolored jasper; trace glauconite stain on quartz grains; trace orange, blue -gray and brown lithic /mineral grains; trace very thin coaly interbeds; sand appears to be in gradational contact with the associated silt/claystone; no oil indicators; very slightly calcareous. Sand /Sandstone (4930 -4990) = light to medium light gray with a slight greenish to brownish secondary hue; sample collected as loose dis- aggregated sand; occasional very silty /clayey sandstone masses similar to the above siltstone; sample generally retains some silt moderately sorted; angular to sub - angular and occasionally sub spheroidal; trace larger grains display some stream erosion characteristics; individual grains are primarily translucent white to slightly smokey and clear quartz; trace dark mafic mineral /lithics; trace glauconite stained quartz and occasional small glauconite grains; trace varicolored jasper, yellow, bronze, blue -gray, and brown mineral /lithics; common medium to medium light gray lithics; common crystalline facets mostly on clear quartz grains; trace very thin carbonaceous shale. Sand /Sandstone (5050 -5230) = samples consist of a slurry of loose sand that is olive brown when wet and light yellowish brown when dry; the sand is a moderately sorted quartz sand, with grain sizes ranging from lower medium to lower very fine- grained as well as some trace disaggregated silt and clay; the sand is mostly comprised of translucent to transparent very light gray to colorless to pale yellow quartz with scattered brown quartz; the remainder of the sand consists of dark gray and black cryptocrystalline, siliceous lithics and minor blur green glauconite; the former impart a salt and pepper appearance to the sand under the microscope; very rare pyrite and calcite can be found; the quartz grains are subangular to subrounded and exhibit moderate sphericity; etching and pitting are common on the surfaces of quartz grains, though some larger grains display • CANRIG 17 eni Nikaitchuq OPO4 -07 • signs of impact abrasion; the lithics are subrounded to subangular with good to moderate sphericity, though a few of the larger grains also show signs of impact abrasions; tiny, sparse clusters of weakly cemented sand are scattered throughout the samples; the cement is primarily siliceous, though very rare cuttings effervesce in acid; samples are otherwise largely non calcareous; no petroleum stain, odor, cut, nor fluorescence are detectable. Sand /Sandstone (5230 -5400) = samples consist of a slurry of loose sand with minor disaggregated, interbedded silt and black shale, as well as trace clay; the sand is a well sorted, fine to very fine- grained quartz sand; though the bulk of the sand is within lower fine to upper very fine- grained, the full range of grain sizes is from lower very fine- to lower medium - grained; sparse, coarse cherty chips and lithic pebbles are also contained in the samples, and trace pyrite and calcite be found as well; the sand mostly consists of translucent to transparent very light gray to colorless to pale yellow quartz, along with a few brown grains; minor amounts of medium to dark gray siliceous lithics and blue green glauconite make up the remainder of the sand; the quartz is subangular to subrounded, with moderate to good sphericity; quartz grain surfaces are etched and pitted; the lithics are subrounded with good sphericity; pyrite is also occasionally seen within the gray lithics; rare tiny clusters of poorly cemented sand can be found within the samples; the cement is mostly siliceous, but a few sandstone cuttings have calcite cement; samples are very slightly calcareous, particularly in silt -rich intervals; no petroleum stain, odor, cut, nor fluorescence are present. Sand /Sandstone (5400 -5580) = samples consist of a slurry of sand, minor disaggregated interbedded siltstone, and trace tiny bits of carbonaceous shale; bulk samples are olive gray when wet and light yellowish gray when dry; the sand is a well sorted quartz sand with lesser dark lithics; grains are mostly lower fine- to lower very fine- grained, with a slight amount of upper fine to lower medium - grained sand; under magnification the sand has a salt and pepper appearance; the quartz is translucent to transparent, very light gray to pale yellow with a few scattered brown grains; the lithics are comprised of dark gray to black, cryptocrystalline silicic grains and minor blue green glauconite; trace red orange lithics, pyrite, and rare calcite can also be found in the samples; rare, scattered, tiny cuttings of intact yet weakly cemented sandstone are contained in the • samples as well; many of the sandstone cuttings have silicic cement, while calcite cement effervesces in a small number; otherwise, the overall samples are only mildly calcareous except for thin slivers in the black shale; sandstone porosity appears to be minimal, perhaps only one to two percent; no petroleum odor is noticeable, and oil stain, cut, and fluorescence are absent. Claystone (5580 -5660) = samples consist of a pulverulent mass of dis- aggregated clay, sand and silt; bulk samples are brownish gray to olive gray and display moderate cohesion, yet only modest plasticity due to sand and silt content; the clay /silt/sand mixture is mushy and pasty, and disregarding the sand, there is a dull earthy texture and a smooth, clayey to silty texture to the mixture; the samples are mildly calcareous; no petroleum odor, stain, cut, or fluorescence are detectable. Sand /Sandstone (5670 -5880) = samples consist of a grayish brown slurry of loose sand with minor amounts of disaggregated interbedded siltstone and some pulverulent claystone at the top of this interval; the aggregate material displays poor cohesion and slight plasticity at the top of the interval where the clay occurs; the sand is a very well sorted quartz sand with subordinate dark lithics which gives it a salt and pepper appearance under the microscope; the bulk of the sand is lower fine- grained to upper very fine grained, with sparse upper fine- to lower medium - grained dark lithics; the quartz is a translucent very light gray to pale yellow with a few brown grains and sparse transparent colorless grains; the lithics mostly consist of black to dark grayish brown, cryptocrystalline, silicic grains with trace blue green glauconite and reddish orange lithics; rare pyrite and calcite are also contained in the samples; the quartz grains are subangular to angular and display moderate sphericity, while the lithics are subangular to subrounded, but with only moderate sphericity also; all grains display signs of impact abrasions, and some of the quartz grains are etched and pitted; rare intact cuttings of poorly cemented sandstone occur in the uppermost portion of this interval, and the cement is calcareous; samples are slightly calcareous overall, slightly more so toward the top of this interval; the sand from approximately 5800' to 5850' is extremely uniform and almost entirely upper very fine grained; no petroleum odor was detected, and no stain, fluorescence, or cut is visible. Sand (5900 -6000) = siltstone /claystone; very light to light brownish gray; soft; samples recovered as • CANRIG 18 eni Nikaitchuq OPO4 -07 • aggregations of loose silty sand and sand impregnated irregular silt/clay masses; slightly cohesive; non to slightly adhesive; hydrophilic /expansive; flocculates quickly with hcl; contains moderate amounts of very fine to fine grain quartz sand; surface of masses coated with adhering loose larger sand grains; no oil indicators; trace to slightly calcareous. Sand ( 6000 -6110) = light brownish gray; soft to dis- aggregated; friable in part; samples recovered as loose sand with trace to common hard calcareous sandstone flakes present in zones of slow drilling; medium lower to fine upper and medium upper grain; trace to locally common very fine grain; angular to sub - angular and sub - spheroidal and irregular shattered grains; individual grains are primarily translucent white to smokey quartz; common to abundant clear quartz; common to trace dark mafic mineral grains; trace brown, blue -gray and yellow mineral /lithics; trace to abundant glauconite; occasional trace micro - crystalline pyrite nodules; trace to common medium to light gray lithics yield a salt & pepper appearance appears to be primarily matrix supported in fine brownish silt/clay with interbedded zones of harder calcite cemented well indurated hard sandstone; occasional very thin coaly intervals; very slightly to moderately calcareous; no fluorescence or other oil indicators. Sand (6110 -6220) = light brownish gray; dis- aggregated; friable in part; samples recovered as loose sand with trace to scattered hard calcareous sandstone flakes present in zones of slow drilling; fine lower to fine upper and medium lower grain; trace to locally common very fine grain; angular to sub - angular and sub - spheroidal individual grains are primarily translucent white to slightly smokey translucent quartz; common to abundant clear quartz; common to trace dark mafic mineral grains; trace brown, blue -gray and yellow mineral /lithics; trace glauconite; trace to occasionally common micro - crystalline pyrite nodules; trace medium to light gray lithics; slight pepper in salt appearance; primarily grain supported with locally prevalent clay /ash support; occasional hard calcite cemented well indurated sandstone; very slightly to moderately calcareous; no fluorescence or other oil indicators. Sand /Sandstone /Conglomeratic Sand (6220 -6370) = light gray with a slight brownish secondary hue; dis - aggregated loose sand to hard calcareous sandstone; friable in part; moderately to well sorted; fine upper to fine lower, very fine upper and medium upper; scattered very coarse and pebble fragments; finer material occurs in the upper part of the zone; vertically sorted coarsening with depth; samples consist of loose sand with common to abundant thin flaky very fine grain hard calcareous sandstone; coarser material appears to be generally matrix supported in light brownish gray silt/claystone with some local grain support; matrix is hydrophilic and easily washes away in sample preparation; sand is angular to sub - angular grains predominate; trace sub - spheroidal and occasional stream eroded subrounded grains; predominantly translucent white quartz in the finer grain; coarser material has the same mineral distribution seen in previous samples; slightly to very slightly calcareous overall; 10% poorly developed coal in the 6340 sample; returns to the fine grain sand below 6340' sandstone is moderately calcareous; slight very dull yellow fluorescence at 6310' becoming general at 6340'; very slight clear yellow crush cut; very slight yellow residue fluorescence; no odor. LOWER UGNU at 6355.0' MD /- 3198.6' TVDSS Sand /Sandstone /Conglomeratic Sand (6370 -6650) = light gray with a slight brownish secondary hue grading to medium dark gray; dis- aggregated to hard; friable in part; poorly sorted sand evenly distributed from upper coarse to lower very fine grained with sparse very coarse chips; sand consists of approximately 60% dark lithics and 40% quartz; the sand has a salt and pepper appearance when viewed with the naked eye; the lithics are comprised of very dark brownish gray to dark gray and black, siliceous, cryptocrystalline grains, minor pale blue green glauconite and trace reddish orange lithics; the quartz is translucent and mostly very light gray to pale yellow to medium brown, with minor amounts of pale to medium orange quartz; quartz grains are angular to subangular with moderate sphericity on average, while the lithics are subangular to rounded with moderate to good sphericity; many of the coarse grains are chipped; otherwise, the surfaces of the coarse grains are polished; the remainder of the grains display signs of impact abrasions, and numerous quartz grains are etched and pitted; samples are mildly calcareous, particularly in the fine to very fine fraction of the sand, and rare intact cuttings of weakly lithified fine to very fine sandstone are bound by calcareous cement; trace pyrite can also be found in the samples; no petroleum odor is detectable, oil stain and cut are absent, and only • CANRIG 19 Nikaitchuq OPO4 -07 enI pinpoint calcite fluorescence in fine sand is visible. Sand (6650 -6805) = samples consist of a medium gray to brownish gray slurry of upper fine- to upper very fine- grained sand with trace disaggregated tiny flakes of interbedded, thin, black carbonaceous shales and scattered coarse pebbles; samples are light gray when dry, and bulk samples display virtually no cohesion; the sand is primarily composed of translucent to transparent very light gray to yellowish gray to colorless quartz with a few brown grains; roughly 10 percent of the sand is comprised of gray to black siliceous, cryptocrystalline lithics along with minor to trace amounts of light blue green glauconite and bright reddish orange lithics; rare pyrite and calcite can also be found within the samples; the quartz sand is subangular to angular and displays moderate sphericity on average; the dark lithics are subangular to subrounded and also exhibit moderate sphericity, although the glauconite and reddish orange lithics tend to be more subrounded and display good sphericity; samples are only mildly calcareous overall; no petroleum odor is detectable and oil stain and cut are absent; only sparse pinpoint calcite fluorescence is visible. Sand /Sandstone (6805 -6970) = samples consist of a medium gray to brownish gray slurry of very well sorted quartz sand with subordinate lithics; the sand is upper fine- grained to upper very fine- grained; the quartz is translucent to transparent very light gray to yellowish gray to colorless with minor scattered brown grains; the lithics consist of black to dark gray siliceous, cryptocrystalline grains with some very dark brown lithics, minor light blue green glauconitic grains, and rare but conspicuous bright reddish orange silicic lithics; minor to trace amounts of very fine, disaggregated flakes of carbonaceous shale are also scattered throughout the sand; the quartz is subangular to angular with moderate sphericity, while the dark lithics are subangular to subrounded with moderately but slightly better sphericity; the glauconite and reddish orange lithics are subrounded and display good sphericity; rare pyrite and calcite are also mixed in the sand; samples are only modestly calcareous, with some calcite adhering to shale; surfaces of quartz grains display some signs of etching; otherwise, all lithologies display some degree of impact abrasions; no petroleum odor is detectable, and neither stain nor cut are visible; trace pinpoint yellow fluorescence. • Sand /Conglomeratic Sand (6970 -7150) = medium light gray with a slight brownish secondary hue; samples recovered as dis- aggregated loose sand; friable in part; vertically sorted; medium lower to fine upper, medium upper and trace coarse in the top of the zone; grading to coarse upper to medium upper, coarse lower and medium lower with increasing depth; trace very coarse and small pebble fragments at 7090' sample; returns to finer grain sorting at 7150'; no discernable crystal overgrowth or pitting; angular to sub - angular throughout; occasional sub spheroidal grains and moderately rounded pebble fragments; primarily clear to translucent white quartz; trace to common dark mafic mineral /lithics; trace to common light to medium gray lithics; trace brown, orange and blue -gray lithic /mineral grains; scattered pyrite and coal fines; trace glauconite; apparent grain supported with occasional silt/clay matrix interbeds; 10% to 40% dull yellow fluorescence; trace dead oil in silt and slight oil stain on sand grains; slight cut to clear yellow improves with crush; slight muddy yellow residue cuts to clear yellow; 7120' has medium yellow white slow streaming cut with a good bright yellow residue ring; no odor noted; slightly calcareous. Sand /Conglomeratic Sand (7150 -7325) = medium gray with a slight brownish secondary hue; hard; sample recovered as loose dis- aggregated sand; medium lower to medium upper, fine upper and coarse lower in the upper part of the zone; coarsens with depth; trace very coarse and small pebble fragments in the basal portion; 30 to 40% dark lithic /mineral grains; balance is primarily clear to translucent quartz; trace to common brown and medium gray lithic /mineral fragments; trace glauconite; common to very abundant well indurated coarse grain sandstone with massive pyrite secondary cementation; no visible fragments showing matrix support; partial silica cementation; slightly to very slightly calcareous; 10% to 20% dull yellow fluorescence with a trace clear yellow cut and muddy yellow residue; 40% medium yellow fluorescence in 7240' sample moderate slow streaming cut to bright yellow and a slight yellow residue fluorescence; trace visible oil on some sand grains; no odor. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 2260 204 41558 2668 65 13032 • CANtIG 20 Silk Nikaitchuq OPO4 -07 eni • 2734 63 13798 2996 66 14786 3555 42 8849 3784 60 12515 3851 50 11263 3952 52 11490 4276 57 12989 4428 55 12681 6719 19 4159 tr 6734 15 3394 22 6884 10 2447 4 tr 13 6980 113 27190 13 6 Schrader Bluff: 7286' MD /- 3471.6' TVDSS to TD 8750' MD/ -3784' TVDSS Drill Rate (ft/hr Total Gas (units) Maximum Minimum Average Maximum Minimum Average 260.6 0.8 76.5 267 tr 30.8 The upper portion of the Schrader Bluff is a series of moderately thick sand beds separated by intervening siltstone interbeds. The lower part of the formation gradually becomes dominated by siltstone and claystone with minor sand interbeds. Some problems due to partial lost circulation and abrasion of the BHA and drill string were encountered while drilling to casing point at 8750'. This well encountered significant oil shows in the "N" and "OA" sands. The "N" sand was encountered twice due to displacement along Fault #11. The bottom (lateral) section of the hole was drilled with periscope steering in order to drill lateral production footage • in both the upper and lower lobes of the "OA" sand. Sand /Conglomeratic Sand (7150 -7325) = medium gray with a slight brownish secondary hue; hard; sample recovered as loose dis- aggregated sand; medium lower to medium upper, fine upper and coarse lower in the upper part of the zone; coarsens with depth; trace very coarse and small pebble fragments in the basal portion; 30 to 40% dark lithic /mineral grains; balance is primarily clear to translucent quartz; trace to common brown and medium gray lithic /mineral fragments; trace glauconite; common to very abundant well indurated coarse grain sandstone with massive pyrite secondary cementation; no visible fragments showing matrix support; partial silica cementation; slightly to very slightly calcareous; 10% to 20% dull yellow fluorescence with a trace clear yellow cut and muddy yellow residue; 40% medium yellow fluorescence in 7240' sample moderate slow streaming cut to bright yellow and a slight yellow residue fluorescence; trace visible oil on some sand grains; no odor. Sand /Conglomeratic Sand (7325 -7480) = medium gray with a slight brownish secondary hue; hard; sample recovered as loose dis- aggregated sand; coarse lower to medium upper and coarse upper gradually fining downward becoming fine lower to fine upper and very fine at 7380' sample; material then begins to coarsen downward; angular to sub - angular in the upper zone, subrounded to sub - angular and angular in the finer material; slight crystalline overgrowth residue; some frosting /pitting visible below 7360'; no matrix supported fragments noted; appears to be partially indurated in situ, dis- aggregated by bit action; about evenly divided between dark gray to black lithics and clear to translucent white quartz; common light gray lithics; trace andesite grains; trace to common pyrite; scattered glauconite; surviving well indurated fragments are in the fine to very grain range; trace oil saturated very fine grain sandstone; 10 to 30 % dull to medium yellow fluorescence; slight clear yellow to medium yellow cut; slight to moderate yellow residue fluorescence; slightly perceptible petroleum odor and trace light brown oil stain. TOP "N" SAND at 7543.4' MD /- 3541.4' TVDSS • CANRIG 21 Nikaitchuq OPO4 -07 QIH • Sand /Conglomeratic Sand (7480 -7730) = samples consist almost entirely of a dark brownish gray fluid mass of sand coming across the shakers; the sand is a poorly sorted sand comprised of roughly 60 percent lithics and 40 percent quartz; grain sizes range from lower coarse - grained to lower very fine grained, with some very coarse chips and pebbles as well; the lithics mostly consist of dark gray to black, hard, siliceous cryptocrystalline lithics with minor amounts of blue green glauconitic lithics; the quartz is mostly very light gray and translucent, with variable amounts of yellow and light brown grains; except for the glauconite, the lithics are more commonly coarse- to medium grained; the quartz is coarse to fine- grained with a little very fine grained quartz sand; minor very coarse chips of lithics and quartz are scattered throughout the samples; quartz grains are subangular with moderate sphericity on average; exclusive of chipping, the lithics are subrounded to rounded, yet exhibit only moderate sphericity as well; the sand is well sorted and medium to fine grained at 7500, 7550, and 7650 feet; in these finer- grained intervals, the sand is dominated by quartz with subordinate lithics, and rare intact cuttings of sandstone are bound by calcite cement; all grains display evidence of impact abrasions, and the surfaces of quartz grains are also etched; in the intervals of finer sand, gas levels are elevated, a slight petroliferous odor exists, dark brown stain is visible in roughly 10% of samples, and trace small tarry bits can be found within the sand; roughly 10% of these sands exhibit patchy bright yellow fluorescence, and a straw cut fluoresces bright white; a light amber residue fluoresces white as well. FAULT #11 at 7737' MD /- 3593.2' MD Siltstone (7730 -7750) = very light brown crumbly siltstone; planar fracture; flaky cuttings; earthy luster. TOP "N" SAND at 7816.0' MD / -- 3614.0' TVDSS Sand /Sandstone (7750 -7900) = medium gray with a slight brownish secondary hue; samples recovered as loose sand with moderate to scattered amounts of thin flaky hard fine to very fine grain sandstone; friable in part; moderately to locally well sorted; medium lower to fine upper, medium upper and very fine grain; trace coarse and very coarse; scattered 3mm pebble /pebble fragments; vertically sorted in moderate beds; about evenly divided between translucent white to clear and slightly smokey quartz and medium to light gray lithic /mineral grains; trace to common dark gray to black mafic mineral /lithics trace coal fines; trace orange jasper, brown and bluish gray lithics; scattered pyrite; trace plagioclase feldspar; no clay matrix noted; partially silica cemented; slightly to very slightly calcareous; 40 to 100% medium yellow fluorescence; fast streaming cut to yellow - white; moderate brown residue with muddy yellow fluorescence; slight oil odor; trace to common free oil; slight to moderate oil stain. Sand /Sandstone (7900 -8020) = medium gray with a slight to moderate brownish secondary hue; sample collected as loose sand with scattered hard well indurated fine to very fine grain sandstone; friable in part; medium upper to medium lower, fine upper, coarse lower and very fine grain; moderate beds; vertically sorted; angular to sub - angular to sub - rounded and occasionally slightly rounded; translucent white to slightly smokey and clear quartz predominate; 20 to 30% light to medium gray lithic /mineral grains; trace to common dark gray to black mafic mineral /lithics; trace orange jasper, trace brown mineral /lithics; locally common pyrite nodules; trace to common off white shell fragments; 60 to 90% dull golden yellow fluorescence; fast streaming cut to yellow - white; slight brownish residue fluoresces medium yellow; slight to locally moderate oil odor; trace to very abundant brown oil stain free oil on shaker at 8005'; very slightly to slightly calcareous. BOTTOM "N" SAND at 8005.0'6' MD /- 3662.9' TVDSS Sand /Sandstone (8020 -8150) = medium gray with a slight to moderate brownish secondary hue; sample collected as loose sand with trace hard well indurated fine to very fine grain sandstone; thin light brownish gray to gray siltstone interbeds grading to sandy siltstone; friable in part; medium lower to medium fine upper, medium and very fine grain moderate beds; vertically sorted; angular to sub - angular to sub - rounded; translucent white to slightly smokey and clear quartz predominate; 20 -30% light to medium gray lithic /mineral • CANRIG 22 eni Nikaitchuq OPO4 -07 grains; trace to common dark gray to black mafic mineral /lithics; trace orange jasper, trace brown mineral /lithics; trace pyrite; trace biotite mica trace to common off white to tan shell fragments; 20 to 70% dull golden yellow fluorescence probably due to contaminant oil in mud system; fluoresce and cut same as previous section. Sand /Sandstone (8150 -8260) = medium gray with a slight brownish secondary hue; sample collected as loose sand with trace fragments of fine to very fine sandstone; dis- aggregated; friable in part; interbedded with thin sandy silt- stone; angular to sub - angular; translucent white to clear quartz predominate 20 to 40% light to medium gray mineral/ lithics; trace dark mafic mineral /lithics; trace pyrite; trace biotite mica; common tan to off white shell fragments; partially matrix supported; grades to and interbedded with similar sandy siltstone; 50 -90% medium yellow -gold fluorescence; fast streaming cut to slightly milky yellow- white; slight brownish residue fluoresces medium yellow; slight oil odor; slight brown stain; slightly to very slightly calcareous. Sand /Sandstone (8260 - 8570) = samples consist of a slurry of disaggregated, well sorted quartz sand with scattered coarser chips and pebbles; the sand is mostly upper fine- to upper very fine grained with trace amounts of lower medium- and lower very fine grained sand; the bulk of the sand is composed of translucent, very light gray to pale yellowish gray quartz with sparse light brown grains; minor black to brownish black silicic, cryptocrystalline lithics comprise the remainder of the sand, along with trace light blue green glauconite; the lithics impart a salt and pepper appearance to the sand; the quartz is subangular to angular and display moderate sphericity on average, while the lithics are subangular to subrounded with good to moderate sphericity; the surfaces of quartz grains are etched and pitted; tiny, rare intact sandstone cuttings are cemented by silica in the uppermost portion of this interval, while the remainder is cemented by calcite; the sandstone is partially grain supported and has only a percent or two of visible porosity; extremely rare pyrite cement can be found; the chips and pebbles are upper medium to very coarse grained, but consist of dark lithics and quartz in opposite proportions; black siliceous lithics and medium to dark gray chert dominate the coarse grains, with lesser very light gray to light brown quartz comprising the remainder of the pebbles and pebble chips; the pebbles are commonly polished when not chipped; the samples at 8330 and 8360 feet contain minor yet conspicuous amounts of tabular to platy pinkish orange opaque calcite, and rare pieces of it have good shell riffles; the shells are accompanied by minor tabular cuttings of light brown siltstone; samples are moderately calcareous, particularly in fine fractions; a slightly perceptible petroliferous odor is detectable, and trace Tight brown oil stain is visible; samples exhibit 10 to 20 percent scattered dull yellow fluorescence, likely due in part to lubricating mud additive; a straw cut is extracted, exhibiting a streaming, moderate white fluorescence; a light amber residue fluoresces dull yellow. Sand /Sandstone (8600 -8750) = medium gray with a slight brownish secondary hue; samples collected as dis- aggregated loose sand with scattered very fine grain sandstone fragments and occasional small pyrite cemented medium grain sandstone; friable in part; medium lower to fine upper and medium upper ; trace coarse; scattered 3 to 4mm pebbles and pebble fragments; sub - angular to angular and sub - spheroidal; some coarse and pebble slightly to moderately rounded; individual grains about evenly divided between translucent white to clear quartz and medium to dark gray and black lithic /mineral grains; common to abundant dark gray to brownish gray chert; trace dark mafic mineral /lithics; trace glauconite stained quartz; common to abundant pyrite nodules; interbedded with thin sandy siltstone, carbonaceous shale and trace thin coals; above 8720' samples display 20 to 40% dull yellow fluorescence and other oil indicators seen above; may be due to oil contamination in the mud; 8750' sample shows 90% dull golden yellow fluorescence; moderate fast streaming yellow -white cut fluorescence; slight brownish residue ring cuts readily to yellow - white; slight oil odor; slight oil stain on 40% of sand grains; trace thin oil on partings in associated siltstone; very slightly calcareous. I I CANRIG 23 eni Nikaitchuq OPO4 -07 • PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 7405 26 7005 16 7488 34 5649 23 1 7560 41 8698 54 11 13 7 10 3 7676 83 16388 105 22 21 10 15 16 7812 57 11557 77 37 39 4 18 16 7848 164 33962 339 136 237 156 217 6 7868 215 43152 442 146 227 104 176 19 7895 129 25030 242 92 234 24 132 152 7950 160 35678 354 91 131 37 130 1 8006 267 54990 608 165 208 58 191 10 8065 47 9762 81 31 Tr 3 31 16 8167 232 49962 531 254 150 222 211 85 8250 56 11275 125 93 141 220 193 6 8460 57 13545 98 46 59 59 68 58 8600 38 8369 58 13 7 6 7 6 8748 135 58517 138 43 53 61 18 49 TOP "OA" SAND at 8706.0' MD/ - 3779.2' TVDSS Sand /Sandstone (8750 -8870) = well sorted upper fine- to upper very fine- grained loose quartz sand with scattered tabular brown siltstone; quartz is transparent to translucent very light gray; grains are subangular to angular with moderate sphericity and minor etching; trace pale green glauconite and reddish orange lithics; abundant powdered calcite mud additive; pervasive pale white calcite fluorescence; 5 to ll, 10 percent dull yellow fluorescence in siltstone; clear cut fluoresces milky white, likely due in part to oil - based mud. Siltstone (8870 -8950) = dark brown siltstone with minor interbedded very fine quartz sand; cuttings are crumbly, platy to tabular, with a dull, waxy luster and a smooth, silty texture; very calcareous, with some visible lighter brown microlaminae; trace pinkish orange shell material; petroleum odor and stain masked by oil -based mud; 30 to 70 percent patchy, dull white fluorescence; streaming amber cut fluoresces bright white; slight amber residue fluoresces bright white also. Siltstone (8950 -8990) = dark brown siltstone with fine- grained quartz sand; crumbly cuttings with platy habit blocky fracture, and silty texture; petroleum odor and stain masked by oil -based mud; 30 to 70 percent patchy, dull, white fluorescence; amber cut, bright white cut fluorescence; slight amber residue with white fluorescence. Sand /Sandstone (8990 -9040) = very light gray, transparent to translucent quartz, lower fine to upper fine, well sorted, very calcareous; minor to trace pale green glauconite; odor and stain masked by oil -based mud; even dull white fluorescence over entire sample. Sand /Sandstone (9040 -9110) = very Tight gray quartz, transparent to translucent; very well sorted, rounded to well rounded; upper fine to upper very fine to trace lower very fine; very calcareous; occasional small pyrite cemented fine grained sandstone; sandstones are dark brown, tabular; free oil coming across shakers; oil and stain masked by oil -based mud, 90 percent of sample fluoresces dull white, streaming amber cut fluoresces bright white. Sand /Sandstone (9110 -9150) = very light gray, lower fine grained to lower very fine; quartz grains are transparent to translucent; very well sorted dis- aggregated sand; well rounded; trace sandstone is gray to dark brown, firm to moderately hard; 100 percent of sample fluoresces dull white, cut fluoresces bright white. • CANRIG 24 eni Nikaitchuq OPO4 -07 Sand (9150 -9210) = light gray, very well sorted, well rounded, quartz grains are transparent to translucent, very fine to fine grained, dis- aggregated sand; trace pale green to green glauconite and dark lithics, very calcareous; sandstone found in trace amounts, moderately hard; trace oil in sample; 100 percent of sample fluoresces dull white, streaming amber cut fluoresces bright white; slight amber residue fluoresces white. Sand /Sandstone (9210 -9290) = sand is light gray, dis- aggregated, well rounded and well sorted, quartz is transparent to milky white, some etching; trace shell fragments and calcite, pale green glauconite; trace amounts of oil in sample; 100 percent of sample has dull white fluorescence, streaming amber cut fluoresces bright white. Siltstone (9260 -9280) = light gray, friable; effervesces under acid; micro laminae present; brittle; blocky; smooth to silty texture, dull luster. Sand (9290 -9450) = samples consist of a light gray to olive gray slurry of loose disaggregated sand; the sand is well sorted and primarily very-fine grained, with a fair amount of lower fine- grained sand; the bulk of the sand consists of translucent to transparent very light gray to colorless quartz, along with a small number of yellow grains; the remaining grains are comprised of minor to trace light green glauconite, dark brown to black lithics, and white calcite; grains are subrounded to subangular and exhibit moderate sphericity on average; quartz grain surfaces display signs of impact abrasions with some evident etching; rare but conspicuous pinkish orange shell fragments are scattered throughout the samples; bulk samples are very calcareous, likely due in part to calcite mud additive; extremely rare, tiny, intact sandstone cuttings are cemented by calcite; very rare light to medium brown oil stain can be found in samples; petroleum odor is masked by lingering oil -based mud; an even, dull white fluorescence is visible across the samples; a clear to pale straw cut gives off an immediate, dull white fluorescence; no cut residue; visible oil on shakers. • Sand /Sandstone (9450 -9630) = samples consist of a brownish gray slurry of loose, disaggregated sand; the sand is a well to very well sorted very fine grained quartz sand; fine- grained quartz is present in minor amounts and scattered very fine to medium - grained calcite is present as well; the quartz is translucent very light gray to yellowish gray, to transparent and colorless, along with a few brown grains; the remainder of the sand consists of minor to trace amounts of light blue green glauconitic lithics and dark brown to black silicic lithics; the black lithics are largely lowermost very fine- grained; the quartz is subangular to subrounded and displays moderate sphericity on average; the glauconite tends to be subrounded with moderate to good sphericity, while the black lithics are angular and at times tabular or even micaceous; quartz grain surfaces are slightly etched and pitted; very tiny, rare intact cuttings of sandstone are cemented by calcite; samples are very calcareous, though due in part to powdered calcite mud additive; an even, dull white fluorescence is exhibited over the entire samples, likely influenced by the oil -based mud; a light amber to clear cut displays an immediate dull white fluorescence; no cut residue. Sand /Sandstone (9630 -9800) = samples consist of a brownish gray to olive brown slurry of disaggregated loose sand; the sand is very well sorted, with grain sizes ranging from upper very fine - grained to lower very fine- grained; the bulk of the sand is composed of transparent to translucent very light gray to yellowish gray quartz, with minor blue green glauconitic lithics and dark brown to black siliceous lithics; minor to trace amounts of calcite is scattered throughout the samples, trace yellowish orange to reddish orange lithics are also present, and rare pyrite can be found in the samples as well; the sand is subangular to subrounded and displays moderate to good sphericity; some quartz grains show minor pitting; samples are very calcareous, though abundant calcite mud additive obscures material from the formation; trace oil stain occurs as rare blobs of sand bound by viscous oil; petroleum odor is masked by oil -based mud residue; dull, white fluorescence occurs evenly across entire samples; a pale straw to light amber cut is extracted, and it fluoresces dull white; no cut residue. Sand /Sandstone (9780 -9980) = samples consist of a dark brownish gray slurry of loose disaggregated sand with minor amounts of brown siltstone cuttings; the sand is very fine- grained and well sorted, with a • CANRIG 25 eni Nikaitchuq OPO4 -07 • small amount of lower fine- grained sand; the sand primarily consists of translucent to transparent very light gray to colorless quartz with minor lithics; the lithics consist of very fine- grained dark brown to black siliceous grains and blue green glauconite; the grains are subangular to subrounded, with moderate sphericity overall; quartz grains are etched and pitted; trace to minor calcite cleavage fragments are also contained in the samples; very rare, tiny, intact sandstone cuttings are poorly indurated and cemented by calcite; the samples are very calcareous overall, though powdered calcite is also being added to the mud system; like the sandstone, siltstone cuttings are particularly calcareous; the siltstone cuttings are crumbly to crunchy and tabular to sub blocky, with a dull, waxy luster and a smooth, silty texture, and microscopic laminae; the samples exhibit an even, dull white to very slightly yellow fluorescence, though the siltstone cuttings fluoresce bright white; a dark straw to amber cut is extracted, and the cut fluorescence is immediate and bright white. Sand /Sandstone (9980- 10110) = samples consist of a dark brown slurry of loose disaggregated sand and a slight amount of silt, along with scattered dark brown siltstone cuttings; the sand is mostly composed of translucent to transparent very light gray to colorless quartz with minor lithics; the sand is well sorted and very fine- grained, with scattered lower fine- grained sand; the lithics consist of blue green glauconite and lowermost very fine- grained black siliceous grains, some of which are platy or even micaceous; trace to minor calcite cleavage fragments are also mixed in with the quartz sand; grains are subangular to subrounded and display moderate sphericity; samples are very calcareous, likely due in part to calcite mud additive; an even, dull white fluorescence is displayed by the samples, though siltstone cuttings fluoresce bright white; a light amber cut is extracted, and the cut fluorescence is immediate and bright white; no cut residue; free oil on the shakers. Sand (10110- 10250) = very light gray to translucent to medium light gray grains; upper very fine to upper fine; very well sorted throughout sample interval; subangular to subrounded angularity; moderate to high sphericity; samples contain 5 -10% black lithic grains throughout; black lithics are very fine grained; contains approx 5% bluish green to Tight green glauconite grains; up to 20% shell fragments of dark • yellowish orange to moderate yellowish brown colors; some siltstone cuttings throughout sample interval; large amount of siltstone cuttings at 10250 interval; brownish black to olive black to black; soft to firmly friable and crumbly; tabular wedgelike cuttings habit; vitreous and greasy luster, but when cuttings are prodded and split interior luster is more dull waxy earthy; no visible structures within cuttings; even sample fluorescence of moderately bright yellow; bright cut fluorescence, white, and immediate; visible cut is light amber. Sand (10250- 10310) = translucent to very light gray to light gray; very noticeable color change from previous samples; upper very fine to upper fine sized grains with occasional medium and coarse grains throughout; fine grains are well sorted; subangular to subrounded with moderate sphericity; fine grained black lithics throughout samples, approx 10 %; bluish green to light green glauconite throughout samples, <5 %; shell fragments throughout samples, 5 -10 %; even sample fluorescence, moderately bright yellow; bright cut fluorescence, white, and immediate; visible cut is pale straw. Sand (10310- 10430) = translucent to medium gray to light gray quartz grains; overall color has darkened from previous interval; upper very fine to lower medium grain size; moderate sorting; subangular to subrounded angularity with moderate sphericity; fine grained black lithics throughout sample interval approx 5 -10 %; light green to bluish green glauconite grains, <5 %; even yellow sample fluorescence, moderately bright; bright slow streaming milky white cut fluorescence; dark straw visible cut. Siltstone (10400- 10490) = olive black to brownish black cuttings; firmly friable to moderately hard to friable; crunchy to crumbly tenacity; blocky fracture; tabular wedgelike cuttings habit; greasy vitreous cuttings luster, earthy dull and slightly waxy luster when cuttings are broken; gritty to silty texture; no visible structures in cuttings. Sand (10430- 10550) = translucent to medium gray to light gray; mostly upper very fine to upper fine with occasional medium sized grains throughout sample interval; well sorted; subangular to subrounded with • C1NRI] 26 Vis Nikaitchuq OPO4 -07 eni • moderate sphericity; fine grained black lithics throughout, approx 10 %; bluish green to light green glauconite throughout, approx 5 %; shell fragments throughout sample interval, 5 -10 %; shell fragments dark yellowish orange to dark yellowish brown; evenly distributed fluorescence, bright yellow, speckled appearance as if a sprinkling of powder on sample; bright milky white cut fluorescence; dark straw visible cut. PEAKS Depth TG C1 C2 C3 C4I C4N C51 C5N 8829 124 59720 183 28 34 28 10 7 8913 103 52933 188 29 31 28 13 14 9009 95 54662 128 33 21 23 11 9094 110 69128 245 37 29 27 15 9145 112 76499 273 49 53 48 26 9749 70 57910 245 49 39 40 29 18 9939 82 45450 189 37 36 35 28 16 10178 110 104706 437 100 116 94 66 26 10456 32 12430 69 23 44 39 32 15 OPO4 -07 ST1 (Open hole sidetrack) Sand /Sandstone (9980- 10035) = Ioose,well sorted, very fine, very Tight gray quartz sand with minor black lithic grains and blue green glauconite; grains are subangular; sample is calcareous; even, dull white fluorescence; pale straw cut fluoresces dull white. Siltstone (10035- 10065) = sub blocky, dense to brittle cuttings of olive brown siltstone; dull, waxy luster and smooth, silty texture; microscopic laminae; even white to yellow fluorescence. • Sand /Sandstone (10065- 10300) = samples consist of a brownish gray to olive brown slurry of loose sand containing scattered dark brown siltstone cuttings; the sand is a well sorted, very fine grained quartz sand with a small amount of intermixed fine- grained sand; the bulk of the sand consist of translucent, very light gray to slightly yellowish gray quartz to transparent, colorless quartz; the remainder of the sand is comprised of trace to minor lithics consisting of very dark brown to black siliceous grains and blue green glauconite; rare reddish orange lithics and calcite cleavage fragments are also found within the sand; the quartz and black lithics are subangular to angular and display moderate sphericity, while the lighter lithics are subrounded with good sphericity; quartz grain surfaces are partially etched and pitted; extremely rare, tiny, intact sandstone cuttings are poorly indurated and and cemented by calcite; bulk samples are very calcareous, due in part to calcite mud additive; a dull even fluorescence is presented across the entire samples, though siltstone cuttings fluoresce slightly brighter; a dark straw to amber cut is extracted, and the cut fluorescence is immediate and white to slightly yellow; a very light cut residue fluoresces dull white; abundant free oil is coming across the shakers, likely due in part to open hole above sidetrack; aside from the scent of the oil -based mud, a faint petroliferous odor is detectable and oil stain can be vaguely perceived in rare, very light brown, cohesive blobs of sand. Sand /Sandstone (10300 - 10430) = samples consist of an olive brown slurry of loose, disaggregated sand; the sand is well sorted and primarily very fine grained, with minor lower fine- grained sand; the bulk of the sand is composed of quartz; minor to trace amounts of lithics comprise the remainder of the sand; the quartz is translucent very light gray to slightly grayish yellow to transparent and colorless; black, lowermost very fine- grained lithics constitute much of the small remaining portion of the sand, along with trace blue green glauconite and calcite cleavage fragments; the quartz and black lithics are mostly subangular and display moderate sphericity on average; the glauconite is subrounded with good sphericity; very rare, intact bits of sandstone cuttings are poorly indurated and cemented by calcite; samples are very calcareous, though this is likely partly due to powdered calcite mud additive; samples exhibit an even, dull white to slightly yellow fluorescence; a pale straw cut is extracted, and the cut fluorescence is immediate and dull white also. • CANRIG 27 Ois Nikaitchuq OPO4 -07 eni • Sand (10430- 10520) = medium gray to translucent to Tight gray; upper very fine to upper fine; very well sorted; subangular to subrounded with moderate to high sphericity; fine grained black lithics throughout sample interval, approx 10 %; bluish green to light green fine grained glauconite throughout sample interval, approx 5 %; dark yellowish orange shell fragments, approx 5 %; even moderately bright yellow fluorescence throughout sample; dull immediate white cut fluorescence; dark straw visible cut. Sand (10520- 10610) = light gray to medium gray to translucent; upper very fine to very fine; very well sorted throughout sample interval; subangular to subrounded with moderate to high sphericity; approx 10% fine grained black lithics throughout sample interval; bluish green to light green fine grained glauconite, 5 %; no odor; even dull yellowish white fluorescence throughout; immediate moderately bright white cut fluorescence; dark straw visible cut. Sand (10610- 10700) = medium gray to olive gray to translucent; upper very fine to upper fine grain size; very well sorted throughout sample interval; subangular to subrounded; moderate sphericity; approx 10% fine to medium sized black lithic grains; some lithic grains are micaceous; approx 5% bluish green to light green fine grained glauconite throughout sample interval; dark yellowish orange to dark yellowish brown shell fragments, most abundant in 10610 -10640 interval; very slight odor; even moderately bright yellow fluorescence throughout samples; immediate dull white cut fluorescence; light amber visible cut; pale straw visible residual ring; faint yellow residual ring fluorescence; faint white residual fluorescence. Sand (10700- 10790) = olive gray to medium gray to medium dark gray with some translucent quartz grains; upper very fine to lower fine with few upper fine grains; very well sorted throughout sample interval; subangular to subrounded with moderate sphericity; approximately 10 -20% fine grained black lithics; approximately 5 -10% bluish green to brilliant green glauconite grains, predominately very fine grain size to few fine grain sizes, mostly subrounded with moderate to high sphericity; slight odor; even moderately bright yellowish white to white fluorescence; immediate dull white cut fluorescence; light amber • to amber visible cut; straw visible residual ring; dull yellow residual ring fluorescence; dull white residual fluorescence. Sand (10790- 10880) = olive gray to medium dark gray to medium gray with occasional translucent quartz grains; upper very fine to upper fine; very well sorted; subangular to subrounded with moderate sphericity; approx 10 -20% black lithics, fine grained; approx 5% bluish green to brilliant green very fine glauconite grains; slight to no odor; patchy to even moderately bright yellow to frosty white fluorescence; immediate dull white cut fluorescence; dark straw visible cut. Sandstone (10850- 10910) = olive black to olive gray to dark gray; upper very fine to upper fine; very well sorted; subangular to subrounded grains with moderate sphericity; sandstone cuttings are easily friable to firmly friable; sandstone is calcicly cemented and effervesces vigorously when exposed to HCL; some thin laminae noticed when cuttings viewed under low magnification; gritty to silty texture; crumbly when prodded; prodded cuttings show light brown oil staining inside when split open. Sand (10880- 11030) = olive gray to dark greenish gray to grayish black hues throughout sample interval; light gray and translucent quartz grains when viewed under higher magnification; upper very fine to upper fine with occasional lower very fine grains; very well sorted subangular grains with moderate sphericity; approx 10% fine grained black lithics; bluish green to brilliant green fine grained subrounded to subangular glauconite grains, approx 5 %; some pyrite noticed in samples, <1%; slight to no odor noticed above OBM; even moderately bright yellowish white to frosty white fluorescence; immediate dull white cut fluorescence; light amber visible cut. Sand (11030- 11150) = grayish black to olive gray to dark greenish gray hues throughout sample interval; medium light gray to translucent quartz grains when viewed under higher magnification; upper very fine to upper fine; very well sorted; subangular to subrounded with moderate sphericity; approximately 10% fine grained black lithics, some micaceous; bluish green to light green glauconite, typically very fine grain sizes and subrounded with high to moderate sphericity, <5 %; moderate odor; no visible stain on cleaned • CANRIG 28 Nikaitchuq OPO4 -07 eni • sample but oil sheen is at shakers; even moderately bright yellowish white fluorescence; immediate bright white cut fluorescence; dark brown to amber visible cut. Sand /Sandstone (11150- 11290) = samples consist of a slurry of disaggregated loose sand; the sand is very well sorted and mostly upper very fine- grained, with lesser lower very fine - grained material; the bulk of the sand is comprised of translucent very light gray to yellowish gray quartz; the remainder of the sand consists of minor, lowermost very fine grained black lithics; blue green glauconite and white calcite cleavage fragments are also present in trace amounts; the sand is subangular and displays moderate sphericity on average; some quartz grain surfaces are etched and pitted; samples are very calcareous, due in part to calcite mud additive; rare, Tight brown oil stain is visible, though petroliferous odor is masked by oil -based mud scent; an even, dull white to slightly yellow fluorescence is exhibited over the entire samples; an amber to brown cut is extracted, and the cut fluorescence is immediate and white; cut residue is minimal to absent; an oily layer skimmed off the top of the samples prior to sieving fluoresces moderate to bright white. Sand /Sandstone (11290- 11400) = samples consist of an olive brown slurry of well sorted, very fine grained loose sand; the sand is primarily composed of translucent very light gray to pale yellow quartz; minor very dark brown to black lithics and trace blue green glauconite makes up the rest of the sand; grains are mostly subangular, though glauconite tends to be subrounded; grain sphericity is moderate on average; samples are very calcareous, and tiny abraded flakes of calcite occur in the lower half of this interval; an even, dull white fluorescence is exhibited across entire samples; an amber to brown cut fluoresces milky white. Sand /Sandstone (11400- 11500) = samples consist of an olive brown slurry of loose, well sorted, upper very fine grained quartz sand with lesser lithics; the quartz is very light gray, and minor black lithics and trace blue green glauconite is the other constituents; grains are subangular on average; samples are very calcareous, and scattered sandstone cuttings are are cemented by calcite; the entire samples fluoresce a • dull white, and an amber cut fluoresces milky white. Siltstone (11470- 11500) = light brownish gray, crumbly, tabular to sub blocky cuttings with a dull, waxy luster and a smooth, silty texture; very calcareous and interbedded with calcite cemented sandstone at the bottom of the interval. Sand (11500- 11600) = light olive gray to brownish black to dark greenish gray hues throughout sample interval; individual quartz grains are also light gray to translucent; upper very fine to lower very fine to upper fine; very well sorted; subangular to subrounded with moderate sphericity; approximately 5 -10% very fine to fine grained black lithics; bluish green to brilliant green to translucent moderate green very fine to fine grained glauconite grains, subangular to subrounded with moderate to high sphericity, approximately 5 %; slight odor; even bright yellowish white to white fluorescence throughout; immediate moderately bright white cut fluorescence; light amber to amber visible cut. Sand /Sandstone (11600- 11690) = olive gray to olive black to grayish black hues; upper very fine to upper fine to lower very fine; very well sorted; subangular to subrounded with moderate sphericity; approx 10% very fine to fine grained black lithics; moderate green to bluish green to translucent brilliant green glauconite, very fine to fine grained, subrounded to subangular, approx 5 %; sandstone is calcareously cemented; easily friable to firmly friable with some cuttings being moderately hard; slight to moderate odor; even moderately bright yellowish white fluorescence; immediate dull white cut fluorescence; dark straw visible cut; straw residual ring; clear residue; yellowish white residual ring fluorescence; white residual fluorescence. Sand (11690- 11780) = olive black to olive gray to medium dark gray hues; upper very fine to upper fine to lower very fine; very well sorted; subangular to subrounded with moderate sphericity; approximately 10% very fine to fine grained black lithics throughout sample interval; <5% bluish green to brilliant green glauconite; fragrant odor; even moderately bright yellowish white fluorescence; immediate dull white cut fluorescence; straw visible cut; pale straw residual ring; clear residue; yellowish white residual ring CANRIG 29 CA Nikaitchuq OPO4 -07 eni fluorescence; white residual fluorescence. Sand (11780- 11870) = olive gray to olive black to medium dark gray; upper very fine to upper fine; very well sorted; subangular to subrounded with moderate sphericity; approx 10 -20% very fine to fine grained black lithics in sample interval; approx 5% moderate green to translucent brilliant green very fine to fine grained glauconite, subrounded to subangular with high to moderate sphericity; fragrant odor; even moderately bright yellowish white fluorescence; immediate dull white cut fluorescence; dark straw to light amber visible cut; pale straw residual ring; clear residue; light yellow residual ring fluorescence; white residue fluorescence. Sand (11870 - 11990) = olive gray to medium dark gray to olive black hues; upper very fine to upper fine; very well sorted; subangular to subrounded with moderate sphericity; 10 -20% fine to very fine grained black lithics throughout sample interval; approximately 5% bluish green to moderate green to some translucent brilliant green very fine to fine glauconite grains, subrounded to subangular with moderate sphericity; slight odor; even moderately bright yellowish white fluorescence; fast blooming dull white cut fluorescence; Tight amber to amber visible cut; straw residue; yellowish white residue fluorescence. Sand (11990- 12144) = olive gray to olive black to medium dark gray hues; upper very fine to upper fine; very well sorted; subangular to subrounded with moderate sphericity; approx 10% fine to very fine grained black lithics; <5% bluish green to translucent brilliant green to moderate green glauconite, very fine to fine grained, subangular to subrounded with moderate sphericity; slight odor; even dull yellowish white fluorescence throughout sample interval; immediate dull white cut fluorescence; straw to dark straw visible cut; pale straw residual ring; clear residue; dull yellow residual ring fluorescence; dull white residue fluorescence. Siltstone (11990- 12144) = brownish gray to olive black to brownish black hues throughout sample • interval; tough and crunchy to crumbly brittle tenacity; blocky fracture; tabular platy cuttings habit; waxy earthy to greasy luster; texture varies from silty clayey to very gritty silty sandstone; some very thin black laminations were noticed in occasional cuttings. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 10023 291 64916 465 166 217 109 200 172 10156 416 80104 329 68 65 74 51 32 10251 451 69404 300 79 66 71 37 30 10448 375 100142 418 102 106 110 81 41 10638 267 53618 216 64 61 64 49 31 10737 267 57275 248 72 80 84 60 38 10880 100 31715 145 44 57 56 39 25 I'I • CANRIG 30 II 1 eni Nikaitchuq OPO4 -07 • 3.6 Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 7667 8 9019 63 7854 34 9216 54 7954 15 10056 24 8242 6 10342 24 10776 5 11917 15 3.7 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 2455 1525 245 2455 481 111 8750 2455 8* 8750 0 32 12144 0 90 * secondary gas trap; primary gas trap down for repairs • 4110 CANRIG 31 ifi*s Nikaitchuq OPO4 -07 eni • 3.8 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to Unwashed Headspace Weatherford Laboratories Samples (Iso -Jars) with 30'/20' per 8845 Fallbrook Drive A bactericide, plan and 1000'- 12144' Houston, TX 77064 Set owner: ENI selected intervals Wet Paleontology Samples Fugro Data Solutions B (Whirl -Pak bags), 30'/20' 1000'- 12144' 3311 S. US Hwy 77 Set owner: ENI per plan Schulenburg, TX 78956 Washed- and -dried Fugro Data Solutions C Reference Samples, 30'/20' 1000' -8750' 3311 S. US Hwy 77 Set Owner: ENI per plan Schulenburg, TX 78956 Washed- and -dried AOGCC D Reference Samples, per plan 1000' -8750' 333 W. 7 Ave., Suite 100 Set Owner: State of Alaska Anchorage, AK 99501 Washed, Spin -dried Fugro Data Solutions 10 E Reference Samples (vials), 30'/20' 8750'- 12144' 3311 S. US Hwy 77 Set Owner: ENI per plan Schulenburg, TX 78956 Washed, Spin -dried AOGCC F Reference Samples (vials), per plan 8750'- 12144' 333 W. 7 Ave., Suite 100 Set Owner: State of Alaska Anchorage, AK 99501 1000' per Weatherford Laboratories G Gas Samples in Iso- Tubes, plan and 180'- 12144' 8845 Fallbrook Drive Set Owner: ENI selected Houston, TX 77064 intervals I • CANRIG 32 en' Nikaitchuq OPO4 -07 • 3.9 Approved Sample Plan OPO4 -07 Dry samples: 2 Sets every 30' from 1000' to TD. Note: increase to 20' intervals on shows and zones of interest ( "ZOI "). Wet Samples: 1 Set every 30' from 1000' to TD; Note: increase to 20' intervals on shows and zones of interest ( "ZOI "). Iso- Tubes: Every 1000' from shoe to TD. Note: increase to 30' intervals on shows and zones of interest ( "ZOI "). Canned Cuttings Samples: (In Iso -Jars) Every 1000' from shoe' to TD. Note: Increase to 30' interval in ZOI and shows. ZOI (Zones of Interest) In ZOI, sample frequency is increased as specified, beginning 100' above the listed "Top" and continuing to 30' past the predicted base of the ZOI. N Sand top (first); 7475'md/ -3533' tvdss Fault #11; 7559' md/ -3557' tvdss N Sand Top (second); 7582' md/ 3564' tvdss 40 N Sand bottom 7742' md/ -3609' tvdss Treat this as a continuous section. Take samples at 20' intervals on wet and dry samples and 30' intervals on Iso -Jars from 7360' to 8060' MD. Mudlogger will take Iso -Tubes on 30' Intervals from 7370' to 7800'. Lateral Section: Wet samples, washed, in whirl pack on 30' intervals. Washed, centrifuged and lightly dried samples, 2 sets, on 30' intervals Iso -Jars and Iso -Tubes on 500' intervals and peaks /zones of interest as identified by site Geo or Eni Operations Geologist. 110 CANRIG 33 • • • Nikaitchuq OPO4 -07 eni 4 PRESSURE / FORMATION STRENGTH DATA Connection gas peaks were rarely encountered and generally were not significantly large. The pore pressure gradient (PPG) is estimated to have varied from 9.6 in the TBA 15.5 in the Kuparuk. Problems with the well "breathing" ie: episodes of lost circulation and flow from the same intervals and at the same mud weights indicate down hole fracture /fault complications which make pore pressure evaluation difficult. 34 CANRIG • • Olt nfli Nikaitchuq OPO4 -07 4.1 Pore Pressure Gradient Evaluation Primary Secondary Interval Tops Pore Pressure (EMW) Formation Trend Lithology Lithology MD TVDSS Min Max Interval Trend Indicators Primary( %) Secondary( %) (ft) (ft) (ppg) (ppg) Quaternary/ Sltst/Cylst 40% Sand /Cong 60% 8.7 9.25 Up BG,CG Sagavanirktok Clyst/Sltst/Sh Ugnu Sand /Cong 60% 2039' - 1964.5' 9.2 9.35 Flat BG,CG,TG 40% Schrader Bluff Sand 60% Sltst 40% 3717' - 3300.4' 9.2 9.6 Up BG,CG NOTE: Clyst = Claystone /Clay, Sd = Sand, Cong = Conglomerate, Sltst = Siltstone, Sh = Shale, Sst = Sandstone, Ls = Limestone 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), lost circulation (LC), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by client, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6- ((.001 *TLGSU) +(0.05 *DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PPG range, when establishing trends, as with DXC data, with data points in shale intervals. 35 CANRIG eni Nikaitchuq OPO4 -07 • 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth (0) ( °) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 0 0 0 0 0 0 0 0 41.16 0.1 237.68 41.16 -0.02 -0.03 -0.02 0.24 89 0.21 237.68 89 -0.09 -0.14 -0.09 0.23 180 0.45 187.94 180 -0.53 -0.33 -0.53 0.39 273 0.04 277.1 273 -0.89 -0.41 -0.89 0.49 366 0.97 11.85 365.99 -0.11 -0.28 -0.12 1.05 398 1.01 9.74 397.99 0.43 -0.18 0.43 0.17 427 0.99 7.45 426.98 0.93 -0.1 0.93 0.15 459 1.16 8.64 458.98 1.52 -0.02 1.52 0.54 • 490 1.58 5.36 489.97 2.26 0.07 2.26 1.38 520 2.22 0.03 519.95 3.25 0.11 3.25 2.21 549 3.17 0.14 548.92 4.62 0.11 4.62 3.28 581 5.06 358.82 580.84 6.91 0.08 6.91 5.91 614 6.88 358.64 613.66 10.34 0 10.34 5.52 645 7.37 8.54 644.42 14.16 0.26 14.17 4.26 676 8.04 8.85 675.14 18.27 0.88 18.28 2.17 708 9.13 12.28 706.78 22.97 1.77 22.98 3.76 740 10.52 12.76 738.31 28.3 2.95 28.32 4.35 774 11.91 11.81 771.66 34.76 4.36 34.79 4.12 802 13.12 6.32 798.99 40.74 5.3 40.79 6.06 837 14.31 4.66 833 49 6.09 49.05 3.58 876.37 16.43 359.72 870.96 59.42 6.46 59.47 6.32 971.3 19.15 0.5 961.34 88.42 6.53 88.47 2.88 1068.36 21.72 3.9 1052.29 122.27 7.89 122.33 2.92 • CANRIG 36 eni tak Nikaitchuq OPO4 -07 0 Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth (0) ( °) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 1163.43 25.97 5.25 1139.22 160.56 10.99 160.65 4.51 1258.49 31.6 5.67 1222.5 206.11 15.36 206.23 5.93 1355.8 36.79 2.61 1302.97 260.63 19.21 260.78 5.62 1452.15 37.04 1.76 1380 318.46 21.41 318.62 0.59 1543.39 38.38 0.66 1452.18 374.25 22.58 374.42 1.64 1642.39 34.98 0.64 1531.57 433.37 23.25 433.55 3.43 1736.46 35.24 359.46 1608.52 487.48 23.3 487.65 0.77 1833.68 39.07 358.22 1686 546.17 22.08 546.33 4.01 1927.22 38.11 356.9 1759.11 604.46 19.61 604.6 1.35 2022.85 44.18 357.66 1831.09 667.28 16.65 667.39 6.37 2120.78 47.37 359.88 1899.39 737.42 15.18 737.52 3.64 2216.7 50.3 359.96 1962.52 809.62 15.08 809.72 3.06 2308.38 54.27 357.84 2018.6 882.11 13.65 882.2 4.7 • 2382.52 57.83 357.72 2060 943.56 11.27 943.62 4.8 2528.21 61.66 358.51 2133.39 1069.32 7.13 1069.34 2.67 2622.74 65.14 0.34 2175.71 1153.82 6.30 1153.83 4.07 2719.63 67.82 1.70 2214.38 1242.63 7.90 1242.66 3.05 2813.90 69.72 2.47 2248.51 1330.44 11.10 1330.49 2.15 2909.23 72.16 2.41 2279.64 1420.46 14.93 1420.53 2.56 3005.13 73.42 2.67 2308.01 1511.97 18.99 1512.08 1.34 3100.64 73.36 2.39 2335.31 1603.41 23.03 1603.54 0.29 3194.60 73.47 1.75 2362.13 1693.40 26.28 1693.56 0.66 3290.73 73.98 1.88 2389.07 1785.63 29.21 1785.81 0.55 3386.26 73.82 0.58 2415.57 1877.39 31.18 1877.58 1.32 3483.18 74.24 0.34 2442.23 1970.57 31.93 1970.76 0.49 3578.86 73.99 359.45 2468.42 2062.59 31.76 2062.78 0.93 3674.36 73.67 358.89 2495.02 2154.30 30.43 2154.48 0.66 3769.55 73.85 358.01 2521.64 2245.66 27.96 2245.81 0.91 Measured Incl. Azim. True Latitude Departure Vertical Dogleg S CANRIG 37 1 t IA Nikaitchuq OPO4 -07 eni • Depth ( °) ( °) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 3865.91 73.62 357.62 2548.63 2338.10 24.43 2338.22 0.46 3960.99 73.67 358.75 2575.40 2429.28 21.54 2429.38 1.14 4057.46 73.37 358.74 2602.77 2521.77 19.51 2521.84 0.31 4152.89 73.73 0.45 2629.79 2613.28 18.87 2613.35 1.76 4249.85 73.63 1.98 2657.04 2706.31 20.84 2706.39 1.52 4345.19 73.59 2.62 2683.94 2797.70 24.51 2797.81 0.65 4441.13 73.72 2.24 2710.94 2889.68 28.42 2889.82 0.40 4537.14 73.50 2.17 2738.04 2981.72 31.96 2981.88 0.24 4631.36 73.64 2.22 2764.69 3072.03 35.42 3072.22 0.16 4726.76 73.53 3.42 2791.65 3163.43 39.92 3163.65 1.21 4821.71 73.78 4.72 2818.37 3254.31 46.39 3254.58 1.34 4917.79 73.96 5.39 2845.06 3346.25 54.52 3346.58 0.70 5014.22 73.83 4.90 2871.81 3438.52 62.83 3438.91 0.51 5110.69 74.15 3.88 2898.42 3530.97 69.93 3531.42 1.07 • 5205.71 73.90 3.54 2924.57 3622.13 75.84 3622.63 0.43 5301.83 73.79 2.83 2951.31 3714.31 80.97 3714.84 0.72 5397.94 73.27 2.64 2978.56 3806.38 85.37 3806.94 0.57 5493.28 73.26 2.63 3006.01 3897.58 89.56 3898.17 0.01 5591.21 73.62 2.61 3033.93 3991.35 93.86 3991.98 0.37 5686.63 73.15 2.69 3061.21 4082.69 98.08 4083.34 0.50 5782.60 73.55 3.05 3088.71 4174.52 102.69 4175.21 0.55 5878.19 73.42 3.34 3115.88 4266.02 107.79 4266.75 0.32 5973.03 73.48 3.33 3142.90 4356.78 113.08 4357.55 0.06 6069.78 73.46 3.31 3170.42 4449.38 118.45 4450.18 0.03 6165.67 73.21 3.85 3197.92 4541.06 124.19 4541.91 0.60 6260.09 73.36 3.99 3225.08 4631.28 130.37 4632.17 0.21 6356.37 73.70 3.27 3252.38 4723.42 136.22 4724.36 0.80 6452.07 71.49 5.89 3281.01 4814.43 143.50 4815.43 3.49 6547.50 69.35 6.96 3312.98 4903.77 153.55 4904.85 2.48 Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth ( °) ( °) Vertical (ft) (ft) Section Rate 411 38 CANRIG OA Nikaitchuq OPO4 -07 ens • (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) 0100ft) 6645.59 72.45 5.90 3345.08 4995.87 163.92 4997.02 3.32 6740.71 74.52 6.18 3372.12 5086.55 173.52 5087.78 2.19 6835.97 74.27 5.88 3397.74 5177.79 183.16 5179.10 0.40 6931.70 73.46 4.42 3424.35 5269.38 191.41 5270.75 1.69 7024.91 73.55 3.69 3450.81 5358.53 197.73 5359.94 0.76 7121.31 73.61 1.78 3478.06 5450.89 202.14 5452.33 1.90 7218.28 73.18 2.75 3505.78 5543.74 205.82 5545.21 1.06 7313.21 74.19 3.18 3532.44 5634.72 210.53 5636.23 1.15 7408.43 74.31 0.86 3558.29 5726.30 213.76 5727.83 2.35 7504.59 74.32 359.22 3584.29 5818.88 213.82 5820.41 1.64 7600.69 74.42 358.34 3610.18 5911.40 211.85 5912.91 0.89 7695.92 74.49 356.71 3635.71 6003.06 207.89 6004.54 1.65 7792.22 74.81 356.04 3661.20 6095.74 202.02 6097.16 0.75 7888.48 75.49 356.15 3685.87 6188.57 195.68 6189.94 0.72 7981.95 74.31 356.57 3710.22 6278.63 189.95 6279.95 1.33 8079.31 76.86 355.74 3734.45 6372.70 183.63 6373.97 2.75 • 8175.30 78.60 356.83 3754.85 6466.29 177.55 6467.51 2.13 8270.62 81.30 358.44 3771.49 6560.06 173.69 6561.24 3.28 8366.69 82.53 357.83 3785.00 6655.12 170.59 6656.28 1.43 8462.44 82.01 358.04 3797.88 6749.94 167.17 6751.06 0.58 8558.12 81.43 357.96 3811.66 6844.56 163.87 6845.66 0.61 8654.72 81.68 357.57 3825.84 6940.04 160.14 6941.11 0.48 8686.40 82.88 358.11 3830.10 6971.41 158.96 6972.47 4.15 8736.74 83.36 359.18 3836.13 7021.38 157.77 7022.42 2.32 8828.76 83.65 359.19 3846.54 7112.80 156.47 7113.83 0.32 8923.62 84.45 0.01 3856.37 7207.15 155.82 7208.17 1.20 9019.29 88.12 359.44 3862.57 7302.60 155.36 7303.61 3.88 9112.76 90.38 359.28 3863.79 7396.05 154.31 7397.05 2.42 9210.88 89.52 357.35 3863.88 7494.12 151.43 7495.10 2.15 9306.82 89.24 357.95 3864.92 7589.98 147.49 7590.92 0.69 - Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth ( °) ( °) Vertical (ft) (ft) Section Rate • CANRIG 39 Nikaitchuq OPO4 -07 eni • (ft) Depth (ft) N( +), S( E( +), W( -) (ft) ( ° /100ft) 9402.49 89.90 358.48 3865.63 7685.60 144.51 7686.51 0.88 9498.41 90.10 357.79 3865.63 7781.46 141.39 7782.35 0.75 9594.44 89.47 357.34 3865.99 7877.41 137.31 7878.26 0.81 9689.09 88.89 357.90 3867.35 7971.96 133.38 7972.78 0.85 9785.47 88.43 356.69 3869.60 8068.21 128.84 8068.98 1.34 9880.19 88.34 355.13 3872.27 8162.65 122.08 8163.36 1.65 9976.98 88.51 354.68 3874.93 8259.02 113.49 8259.66 0.50 10072.57 87.22 353.54 3878.49 8354.03 103.69 8354.60 1.80 10167.62 87.02 353.68 3883.27 8448.37 93.12 8448.85 0.26 10259.96 87.19 355.46 3887.93 8540.18 84.40 8540.58 1.93 10359.04 87.62 355.83 3892.42 8638.87 76.88 8639.21 0.57 10454.32 87.74 355.71 3896.28 8733.81 69.86 8734.09 0.18 10550.49 88.51 354.67 3899.42 8829.59 61.80 8829.80 1.35 10645.92 90.07 355.62 3900.61 8924.67 53.72 8924.81 1.91 10742.59 87.85 357.21 3902.36 9021.12 47.68 9021.22 2.82 10838.23 87.11 357.19 3906.57 9116.56 43.01 9116.61 0.77 10934.21 86.59 358.96 3911.84 9212.33 39.79 9212.36 1.92 11029.84 86.13 0.98 3917.91 9307.76 39.74 9307.78 2.16 11125.25 87.48 3.83 3923.23 9402.93 43.74 9402.98 3.30 11220.91 87.91 5.58 3927.08 9498.19 51.58 9498.29 1.88 11316.27 87.16 6.36 3931.18 9592.94 61.49 9593.12 1.13 11411.51 84.59 4.45 3938.03 9687.50 70.44 9687.75 3.36 11506.14 84.56 2.85 3946.98 9781.51 76.44 9781.81 1.68 11603.03 87.79 3.73 3953.44 9878.01 81.98 9878.35 3.45 11698.05 91.50 5.04 3954.03 9972.73 89.25 9973.13 4.14 11792.93 92.34 3.33 3950.85 10067.30 96.17 10067.75 2.01 11887.18 92.05 0.89 3947.24 10161.41 99.64 10161.88 2.61 11986.89 92.65 0.10 3943.15 10261.03 100.50 10261.51 0.99 12081.01 92.85 359.62 3839.64 10355.04 100.27 10355.52 0.55 12144.00 92.85 359.62 3935.50 10417.96 99.85 10418.42 _ 0.00 410 CANRIG 40 • • S iikk Nikaitchuq OPO4 -07 em 5.2 Bit Record Avg. Jets / Depth In Total Ft Bit WOB RPM PP Bit Size Make Type / S# ROP Wear BHA TFA MD / Drilled Hrs (Klbs) (avg) (psi) (ft/hr) 3x20, 1 16 Smith XR+ PP2373 120 446 3.25 149.5 9.6 12.2 599.3 1- 1- WT- A- E -I -NO -BHA 2 1x16 3x20, 2 16 Hughes MX -1; 6074139 566 1889 21.0 172.5 21.9 7.2 933.4 1- 1- WT- A- E- I -NO -TD 2 1x16 3 12% Hycalog MSX619; 220297 6x16 2455 6295 83.3 140.1 9.3 129.2 1947.7 2- 6- WT- A- E- I -NO -TD 3 RSX616M; 3x12, 4 8.5 Hycalog 8750 3990 54.6 222.4 0- 1- CT- S- X- I -NO -TD 4 123905 6x11 41 CANRIG 0 0 S Nikaitchuq OPO4 -07 eni 5.3 Mud Record Contractor: MI SWACO Mud Type: SPUD MUD 160' TO 2245', LSND 4625' TO 8750'. OBM Versa Clean 8750' TO 12144' Depth MW VIS FL Sols O/W Sd CI Ca Date PV YP Gels FC MBT pH MD/TVD (ppg) (s /qt) (cc) ( %) Ratio ( %) (m1/1) (m1/1) 5/18/2010 312/312 8.8 75 21 23 12/13/- 4 0.25/95.75 tr 26 9.3 5/19/2010 541/541 8.9 78 22 22 12/14/- 5 -/95 29 9.2 5/20/2010 881/875 8.9 100 7 31 17/21/- 10 -/90 20 8.3 2600 120 5/21/2010 2130/1915 9.3 91 7 22 17/21/- 12 3/- 6 -/94 tr 23 8.2 2300 120 5/22/2010 2245/2098 9.5 94 14 26 12/31/- 8 3/- 7 -/93 0.3 22 8.0 2200 120 5/23/2010 2245/2098 9.4 15 5 1/2/- 6 -/94 14 7.5 100 60 5/24/2010 2245/2098 9.4 15 5 1/2/- 6 -/94 14 7.5 100 60 5/25/2010 2245/2098 9.4 15 5 1/2/- 6 -/94 14 7.5 100 60 5/26/2010 4050/2504 9.0 48 11 17 7/10/10 7 2/- 4 1/96 0.2 3 9.8 650 200 5/27/2010 5550/3020 9.1 53 14 24 11/20/- 6 2/- 5 2/93 0.3 4 9.5 600 160 5/28/2010 6463/3286 9.0 48 11 15 7/15/18 7 1/- 5 2/93 0.2 9 8.9 800 120 5/29/2010 7380/3551 9.2 13 21 8/20/21 6 1/- 5 2/93 0.1 12 9.3 800 120 5/30/2010 8430/3811 9.3 54 15 23 7/22/28 6 1/- 7 3/91 0.05 17 10.0 1100 40 5/31/2010 8750/3838 9.3 55 16 21 10/24/31 6 1/- 7 4/90 0.05 17 9.8 850 40 6/01/2010 8750/3838 9.2 14 20 8/17/21 5.5 1/- 6.5 4/90 0.05 17 9.0 900 20 6/02/2010 8750/3838 9.4 61 16 22 8/18/22 5 1/- 7 4/90 0.05 16.5 8.9 900 40 42 CANRIG • • S Nikaitchuq OPO4 -07 eni MW VIS FL Sols O/W Sd CI Ca Date Depth PV YP Gels FC MBT pH (ppg) (s /qt) (cc) ( %) Ratio ( %) (m1/1) (m1/1) 6/03/2010 8730 9.3 47 12 15 6/ -/- 6/04/2010 8750 9.1 62 17 9 6/10/13 6/05/2010 8750 8.8 - 15 8 5/10/- 8.69 79/21 40500 6/06/2010 8750 8.8 - 17 11 11/14/- - -/- 8.57 78/22 44000 6/07/2010 9525 8.9 19 19 14 16/19/21 - -/- 10.31 79/21 37000 6/08/2010 10075 8.9 - 18 14 15/19/20 - -/- 10.37 79/21 - 30000 6/09/2010 11350 8.9 66 19 13 16/21/23 - -/- 9.9 80/20 40000 6/10/2010 12144 9.0 68 19 16 16/22/25 - -/- 10.41 80/20 40000 6/11/2010 12144 9.0 69 19 16 16/24/28 - -/- 10.41 80/20 40000 6/12/2010 6/13/2010 6/14/2010 6/15/2010 _ 6/16/2010 6/17/2010 6/18/2010 6/19/2010 6/20/2010 6/21/2010 6/22/2010 6/23/2010 43 CANRIG • S • Nikaitchuq OPO4 -07 eni Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point 44 CANRIG Daily Report Page 1 of 1 ENI Petroleum • DAILY WELLSITE REPORT EPOCH 0PO4 -07 REPORT FOR Beauchamp/Smith/Buchanan DATE May 18, 2010 DEPTH 120.00000 PRESENT OPERATION Rig up Canrig TIME 24:00 YESTERDAY 120.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV VP FL Gels CL- FC SOL SD OIL MBL pH Ca* CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG • PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Rig Up Canrig; Pre -spud prep on rig EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $5295; RW $2650 REPORT BY E. Opitz S file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/19/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Ill DAILY WELLSITE REPORT HI OPO4 -07 REPORT FOR Scott Beauchamp /David Smith /Andrew Buchanan DATE May 19,2010 DEPTH 563.00000 PRESENT OPERATION Drill ahead TIME 24:00 YESTERDAY 120.00000 24 HOUR FOOTAGE 443 CASING INFORMATION 20" @ 120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 16" Smith XR+ Mill Tooth PP2373 3x20, 1016 120 566 446 3.25 1- 1- WT- A- E -I -NO BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 488.3 @ 223 00000 15.4 @ 470.00000 149.8 152.74950 FT /HR SURFACE TORQUE 4373 @ 174.00000 665 0 303 00000 754.7 0.00000 AMPS WEIGHT ON BIT 25 @ 541 00000 0 @ 304.00000 9.6 23 48816 KLBS ROTARY RPM 36 0 300.00000 26 0 169.00000 12 2 0.00000 RPM PUMP PRESSURE 866 0 222.00000 395 0 248.00000 5593 694.39490 PSI DRILLING MUD REPORT DEPTH MW 8.9 VIS 78 PV 22 YP 22 FL - Gels 12/14/- CL- - FC - SOL 5 SD - OIL - MBL 29 pH 9.2 Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 479.00000 0 @ 560 00000 0.0 TRIP GAS - CUTTING GAS 0 @ 563.00000 0 @ 563 00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 9 @ 484.00000 9 @ 563.00000 1.9 CONNECTION GAS HIGH - ETHANE (C-2) 0 @ 563 00000 0 @ 563.00000 0.0 AVG - • PROPANE (C -3) 0 @ 563 00000 0 @ 563.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 563.00000 0 @ 563.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 563.00000 0 @ 563.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Pickup BHA #1. Performed shallow gas evacuation doll. Pre -spud meeting held after dolI. Wash down /clean out conductor to 110', and drill to 175'. TOH and rack back 2 stds. PJSM for SUMMARY continuing to P/U BHA #1 R/U Gyro survey. Doll to 227', then circulate to clean clay out of flow line. Drill from 227' to 566'. POOH and LID bit Could not build angle, dialing up mud motor EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $5295; Rigwatch $2650 REPORT BY E. Opitz S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/20/2010 Daily Report Page 1 of 1 ENI Petroleum • EPOCH H DAILY WELLSITE REPORT 0PO4 -07 REPORT FOR Scott Beauchamp /David Smith /Andrew Buchanan • DATE May 20, 2010 DEPTH 881 00000 PRESENT OPERATION Drilling ahead • TIME 24'00 YESTERDAY 564.00000 • 24 HOUR FOOTAGE 317 CASING INFORMATION 20 "@ 120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 837 14.31 4.66 833.00 802 13 12 6.32 798.99 SURVEY DATA 774 11 91 11.81 771.66 740 10.52 12.76 738.31 708 9 13 12 28 706.78 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 16" Hughes MX1 6074139 3x20, 1016 566 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 359.9 @ 564.00000 8.3 @ 687 00000 168.0 141.62100 FT /HR SURFACE TORQUE 3484 @ 755.00000 0 @ 826 00000 248.0 000000 AMPS WEIGHT ON BIT 41 @ 601.00000 0 @ 564.00000 25.5 17.27700 KLBS ROTARY RPM 32 @ 692.00000 0 @ 829.00000 3.0 0 00000 RPM PUMP PRESSURE 1054 @ 826.00000 392 @ 564 00000 753.3 705.85700 PSI DRILLING MUD REPORT DEPTH MW 8.9 VIS 100 PV 7 YP 31 FL - Gels 17/21/- CL- 2600 FC - SOL 10 SD - OIL -/90 MBL 20 pH 83 Ca, 120 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 881.00000 0 @ 881.00000 0.0 TRIP GAS - • CUTTING GAS 0 @ 881.00000 0 @ 881 00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 0 @ 881.00000 0 @ 881 00000 0.0 CONNECTION GAS HIGH - ETHANE (C -2) 0 @ 881.00000 0 @ 881 00000 0.0 AVG - PROPANE (C-3) 0 @ 881.00000 0 @ 881.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 881.00000 0 @ 881.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 881.00000 0 @ 881.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY Drilling/Sliding from 566' Ream and wash 8 degree dogleg from 626' to 645'. Continue drtlhng /sliding to 849', taking gyro surveys every 30'. Slide from 849' to 881'. Circulate and condition, pump ACTIVITY sweep and follow with 2.5 bosoms up. POOH, rack back drill string and check bit gauge and grade. R/D Eline, gyro data. P/U smart tools Service top drive, C/O gear oil in top drive. RIH to 575'. SUMMARY Shim from top drive guide pads dropped approx 20' to rig floor (shim 2 "x5 "x1/8 ", WT= Boz.). Clear rig floor and assess situation Plan for replacement of shim. Check torque on all bolts and install keeper wires. Inspect the rest of top drive rail from floor to crown. Resume RIH from 575' to 854 EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $5295; Rigwatch $2650 REPORT BY E. Opitz • file: / /CADOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/21/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH DAILY WELLSITE REPORT El OPO4 -07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 21, 2010 DEPTH 2194.00000 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 882.00000 24 HOUR FOOTAGE 1312 CASING INFORMATION 20 "@ 120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2120 47.41 0.11 1898.95 2022 44.1 357.92 1830 63 SURVEY DATA 1927 38 41 357.21 1758 76 1833 38.91 358.48 1685.73 1736 35.38 359.68 1608 24 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 16" Hughes MX1 6074139 3x20, 1a16 566 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 10502 @ 1322.00000 132 @ 1812.00000 166.6 172 00200 FT /HR SURFACE TORQUE 16797 @ 1247.00000 0 @ 1023.00000 1034.4 7.48846 AMPS WEIGHT ON BIT 48 @ 1484.00000 0 @ 920 00000 22.2 8.20815 KLBS ROTARY RPM 40 @ 1653.00000 0 @ 2165.00000 6.6 0.00000 RPM PUMP PRESSURE 1270 @ 1212.00000 578 @ 1409.00000 890.1 876.45990 PSI DRILLING MUD REPORT DEPTH MW 9.3 VIS 91 PV 7 YP 22 FL 12 Gels 17/21/- CL- 2300 FC 3/- SOL 6 SD Tr OIL -/94 MBL 23 pH 8.2 Ca+ 120 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 252 @ 1887 00000 0 @ 1461.00000 38.5 TRIP GAS - III CUTTING GAS 0 @ 2194.00000 0 @ 2194.00000 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY - METHANE (C -1) 50399 @ 1887.00000 46 @ 1306.00000 7951.0 CONNECTION GAS HIGH - ETHANE (C-2) 0 @ 2194.00000 0 @ 2194.00000 00 AVG - PROPANE (C -3) 0 @ 2194.00000 0 @ 2194.00000 0.0 CURRENT - BUTANE (C-4) 0 @ 2194.00000 0 @ 2194 00000 00 CURRENT BACKGROUND /AVG 21 PENTANE (C -5) 0 @ 2194.00000 0 @ 2194 00000 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY Sandstone, Sand, Clayslone, Conglomeratic Sand, Conglomerate PRESENT LITHOLOGY 50% Sand, 40% Clayslone; 10% Conglomeratic Sand ' DAILY ACTIVITY SUMMARY Slide ahead from 881', reaming 6+ degree doglegs. Wart on weather 1030hrs, potential ice buildups falling on rig floor. Continue drilling ahead @ 1200hrs from 1452' to 2193'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $5295; Rigwatch $2650 REPORT BY E. Opitz S file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/22/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH H Nikait DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 22, 2010 DEPTH 2455 00000 PRESENT OPERATION Laying down BHA TIME 24:00'00 YESTERDAY 2194.00000 24 HOUR FOOTAGE 261 CASING INFORMATION 20 "@ 120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2382.52 57 83 357.72 2060.0 SURVEY DATA 2308.38 54.27 357 84 2018.6 2216.7 50.3 359 96 1962 52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 16" Hughes MX1 6074139 3x20, 1016 566 2455 1889 21.1 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 872 9 @ 2243 00000 27.0 @ 2322 00000 202.9 41.56852 FT /HR SURFACE TORQUE 11635 @ 2392.00000 0 @ 2414.00000 18980 4160.91553 AMPS WEIGHT ON BIT 43 @ 2268.00000 0 @ 2375.00000 20.1 11 79295 KLBS ROTARY RPM 34 @ 2381 00000 0 @ 2421.00000 10.5 32 25487 RPM PUMP PRESSURE 1338 @ 2439.00000 876 @ 2194.00000 11551 1130.51392 PSI DRILLING MUD REPORT DEPTH 2455 MW 9.5 VIS 94 PV 14 VP 26 FL 8 Gels 12/31/- CL- 2200 FC 3/- SOL 7 SD 0.3 OIL -/93 MBL 22 pH 8.0 Ca+ 120 CCI n.r. MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 204 @ 2261.00000 13 @ 2320.00000 60.5 TRIP GAS 111 CUTTING GAS 0 @ 2455.00000 0 @ 2455.00000 0.0 WIPER GAS 284 • CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 41557 @ 2260.00000 2920 @ 2320.00000 12746.6 CONNECTION GAS HIGH 12 ETHANE (C -2) 0 @ 2455.00000 0 @ 2455.00000 0.0 AVG 8 PROPANE (C -3) 0 @ 2455.00000 0 @ 2455.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2455.00000 0 @ 2455.00000 0.0 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 0 @ 2455.00000 0 @ 2455.00000 0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 50% claystone, 30% sand, 10% coal, 10% carbonaceous shale PRESENT LITHOLOGY 80% clayslone, 20% sand DAILY ACTIVITY Drill ahead from 2193 ft to 2455 ft; circulate bottoms -up x4, back ream hole from 2455 ft to 1525 ft; trip in hole to 2000 ft, back ream hole from 2000 ft to 481 ft - heavy returns, trip in hole SUMMARY from 481 ft to 2385 ft, pump high viscosity sweep and circulate bottoms -up x3.5; trip out of hole to BHA - no tight spots; lay down BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3670; RigWatch - $1150 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN \MY DOCUMENTS\MY WEL... 5/23/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH • Nikaitchuq DAILY WELLSITE REPORT 01'04-07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 23, 2010 DEPTH 2455.00000 PRESENT OPERATION Nipple down diverter TIME 24.00:00 YESTERDAY 2455 00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @120' 133/8" @2420' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH I SURVEY DATA 2382.52 57 83 357 72 2060.0 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 2455 MW 9.4 VIS n.r. PV 15 YP 5 FL n.r. Gels 1/2/- CL- 100 FC -/- SOL 6 SD n.r. OIL 0/94 MBL 14 pH 7.5 Ca+ 60 CCI - MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 37 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Resume laying down BHA; pick up and rig up casing tools, runt 33/8" casing to 2379 ft, filling while running in and topping off every 10 joints; circulate bottoms up; rig up cement lines and SUMMARY equipment, circulate and condition mud; pressure test cement lines, displace cement, bump plug, and land casing @ 2420 ft; blow down cement lines nod rig down cementing equipment, flush BOP stack and nipple down deserter in preparation for BOP testing. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3045; Rig Watch - $1450 REPORT BY D. Grunwald 0 file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/24/2010 Daily Report Page 1 of 1 trole • ENI Petroleum EPOCH Nik DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 24,2010 DEPTH 2455.00000 PRESENT OPERATION Testing BOP's TIME 241)0.00 YESTERDAY 2455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 120' 133/8" @ 2420' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2382 52 57 83 357.72 2060 0 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 2455 MW 9.4 VIS n.r. PV 15 YP 5 FL n r. Gels 1/2/- CL- 100 FC -/- SOL 6 SD - OIL -/94 MBL 14 pH 7.5 Ca-, 60 CCI n r MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA ID ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Finish n pping down drverter; install and pressure test well head; install annular valve and rser; remove diverter line and nipple up BOP stack; install choke, kill line, bell nipple, and flow line; SUMMARY slip and cut drilling line; pick up test Joint, set test plug, and test BOP's; miscellaneous mudlogging activity - recalibrate gas detection equipment and service gas trap EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3045; Rig Watch - $1450 REPORT BY D. Grunwald O file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/25/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH • Nikaitchuq DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 25, 2010 DEPTH 2455 00000 PRESENT OPERATION Drilling out cement TIME 24:00'00 YESTERDAY 2455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2382.52 57.83 357.72 2060.0 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619 220297 6x16 2455 NA 0 0 NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 2455 MW n.r. VIS n.r. PV n r YP n r. FL n.r. Gels n r CL- n.r. FC n.r. SOL n.r SD n r. OIL n.r. MBL n r. pH n.r. Ca+ n.r. CCI - MWD SUMMARY INTERVAL 2455 TO 2455 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Test BOP'S - upper IBOP failed; replace upper IBOP valve in top dove; re -test upper 100P successfully; rig down test equipment, install wear bushing, and lay down test joint; clear ice from SUMMARY derrick, pick up BHA, load nuclear source; pick up 12 joints drill pipe; circulate mud and shallow lest MWD loolstnng; trip in hole and tag cement at 2326', circulate bottoms -up, pressure test casing; drill out cement to 2455'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3045; Rig Watch - $1450 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/26/2010 Daily Report Page 1 of 1 ENO Petroleum EPOCH • Nikaitchuq DAILY WELLSITE REPORT 0PO4 -07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 26, 2010 DEPTH 4220.00000 PRESENT OPERATION Drilling ahead TIME 24:00 00 YESTERDAY 2455.00000 24 HOUR FOOTAGE 1765 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3483 26 74.2 1 17 2442.99 SURVEY DATA 3386.26 73.81 1.27 2416.28 3290.73 73.94 2.16 2389.75 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619 220297 6x16 2455 NA 1765 13.0 NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 956.4 @ 2811.00000 7 4 @ 3359.00000 205.5 213 82751 FT /HR SURFACE TORQUE 17958 @ 3560.00000 2950 @ 3488.00000 8303 6 1056925293 AMPS WEIGHT ON BIT 28 @ 3769.00000 0 @ 2538.00000 6.5 6.85065 KLBS ROTARY RPM 142 @ 3170.00000 32 @ 2455.00000 118.9 102.34602 RPM PUMP PRESSURE 1682 @ 4166.00000 640 @ 2544.00000 1241 2 1643.57556 PSI DRILLING MUD REPORT DEPTH 4050 MW 90 VIS 48 PV 11 YP 17 FL 7 Gels 7/10/10 CL- 650 FC 2/- SOL 4 SD 0.2 OIL 1/96 MBL 3 pH 9.8 Ca, 200 CCI - MWD SUMMARY INTERVAL 2455 TO 4220 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoeletnc GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 66 @ 2995.00000 0 @ 2865.00000 23.5 TRIP GAS NA CUTTING GAS 0 @ 4220.00000 0 @ 4220 00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 • METHANE (C -1) ETHANE (C -2) 14766 @ 2995 00000 49 @ 2865 00000 4961.9 CONNECTION GAS HIGH 0 10 @ 3747 00000 0 @ 3871.00000 1.1 AVG 0 PROPANE (C -3) 4 @ 4167 00000 0 @ 4129.00000 0.2 CURRENT 0 BUTANE (C-4) 0 @ 4220 00000 0 @ 4220 00000 0.0 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 0 @ 4220.00000 0 @ 4220.00000 0 0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 50% sand, 20% siltstone, 15% conglomeratic sand, 10% carbonaceous shale /coal, 5% claystone PRESENT LITHOLOGY 60% sand, 30% siltstone, 10% conglomeratic sand DAILY ACTIVITY Drill ahead from 2455 ft to 2475 ft; circulate bottoms -up to swap out spud mud with LSND mud, perform leak -off test to 12.4 ppg eq. mud weight; circulate and condition mud; doll ahead SUMMARY from 2475 ft to 3645 ft; circulate bottoms -up; drill ahead from 3645 ft to 4220 ft, pumping sweep at 3741 ft. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3045 ; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/27/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH • Nikaitchuq DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Scott Beauchamp /Gary Goerlich /Andrew Buchanan DATE May 27, 2010 DEPTH 5605.00000 PRESENT OPERATION Drilling ahead TIME 24.00:00 YESTERDAY 4220.00000 24 HOUR FOOTAGE 1385 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5591 21 73.35 2 52 3034.70 SURVEY DATA 5493.28 73 24 2.65 3006.70 5397 94 73 25 2 98 2979.07 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12 25 Hycalog MSX619 220297 6x16 2455 NA 3150 30 8 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 3986 @ 5369.00000 2.1 @ 4615.00000 1405 80.89888 FT /HR SURFACE TORQUE 19896 @ 4610 00000 4373 12/ 4872.00000 9041.0 11427 78027 AMPS WEIGHT ON BIT 20 @ 4682.00000 0 @ 5034 00000 10.2 18.44499 KLBS ROTARY RPM 148 @ 5587.00000 57 @ 4612.00000 136.0 140 83273 RPM PUMP PRESSURE 2170 @ 5560.00000 1199 @ 4332.00000 18300 2107.73633 PSI DRILLING MUD REPORT DEPTH 5550 MW 9.1 VIS 53 PV 14 YP 24 FL 6 Gels 11/20/- CL- 600 FC 2/- SOL 5 SD 0.3 OIL 2/93 MBL 4 pH 9.5 Can 160 CCI - MWD SUMMARY INTERVAL 4220 TO 5605 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 4276.00000 0 @ 5052 00000 12.2 TRIP GAS NA CUTTING GAS 0 @ 5605 00000 0 @ 5605.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 • METHANE (G -1) 12988 @ 4276 00000 44 @ 5052.00000 2741.8 CONNECTION GAS HIGH 0 ETHANE (C -2) 11 @ 4246.00000 -1 @ 4792.00000 23 AVG 0 PROPANE (C -3) 2 @ 5122 00000 -1 @ 4792.00000 0.2 CURRENT 0 BUTANE (C-4) 0 @ 5605.00000 -2 @ 4792.00000 -0 0 CURRENT BACKGROUND /AVG 1 PENTANE (C -5) 0 @ 5605 00000 -2 @ 4792.00000 -0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 60% sand/sandstone, 15% siltstone, 10% claystone, 10% conglomeratic sand /conglomerate, 5% carbonaceous shale and coat PRESENT LITHOLOGY 60% claystone, 20% siltstone, 20% sand DAILY ACTIVITY Drill ahead from 4220 ft to 56055: miscellaneous mudlogging activity - primary gas trap fails at approximately 04:00, switch to secondary gas trap, replace motor in primary gas trap and SUMMARY reinstall same, service and test gas trap repeatedly as gas levels are extremely low, hoist replacement hydrogen cylinder to top of rig and swap out empty hydrogen cylinders. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3135; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/28/2010 Daily Report Page 1 of 1 ENS Petroleum EPOCH VH al NikaRChuq DAILY WELLSITE REPORT OPO4 -07 REPORT FOR Jack Keener /Gary Goerlich/Andrew Buchanan DATE May 28, 2010 DEPTH 6655.00000 PRESENT OPERATION Drilling ahead TIME 2400:00 YESTERDAY 5605.00000 24 HOUR FOOTAGE 1050 CASING INFORMATION 20 "@ 160' 133/8" @2420.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6645.59 72.41 6.98 3345.23 SURVEY DATA 6547.50 69.32 7.82 3313 08 6452.07 71 45 5.85 3284 17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619 220297 6x16 2455 NA 4200 45.7 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 269.1 @ 5849.00000 2 5 @ 6553 00000 118.9 84.99386 FT /HR SURFACE TORQUE 15885 @ 6000.00000 8154 @ 6558.00000 118468 13153.81641 AMPS WEIGHT ON BIT 25 @ 6318.00000 0 @ 5855.00000 7.5 1034987 KLBS ROTARY RPM 145 @ 6085.00000 81 @ 6132.00000 138.3 139.05028 RPM PUMP PRESSURE 2723 @ 6499.00000 1767 @ 6332.00000 22304 2436.34277 PSI DRILLING MUD REPORT DEPTH 6463 MW 9.0 VIS 48 PV 11 YP 15 FL 7 Gels 7/15/18 CL- 800 FC 1/- SOL 5 SD 02 OIL 2/93 MBL 9 pH 8.9 Cat- 120 CCI - MWD SUMMARY INTERVAL 2455 TO 6655 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 6653.00000 0 @ 5888.00000 2.2 TRIP GAS 0 CUTTING GAS 0 @ 6655.00000 0 @ 6655 00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 110 METHANE (C -1) 1048 @ 5723 00000 39 @ 6550 00000 462 3 CONNECTION GAS HIGH 0 ETHANE (C -2) 50 @ 5653.00000 0 @ 5750.00000 2.3 AVG 0 PROPANE (C -3) 5 @ 6488.00000 0 @ 6610.00000 0.2 CURRENT 0 BUTANE (C -4) 8 @ 6654.00000 0 @ 6610 00000 0.1 CURRENT BACKGROUND /AVG 4 PENTANE (C -5) 0 @ 6655 00000 0 @ 6655.00000 0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 55% sand /sandstone, 20% conglomeratic sand, 20% siltstone, 5% claystone, trace carbonaceous shale and coal PRESENT LITHOLOGY 60% sand, 40% conglomeratic sand DAILY ACTIVITY Drill ahead from 5605 ft to 6441 ft - losing 20 -40 bbl/hr at 6441 ft; pull back 1 stand, circulate bottoms -up 2x, reducing ECD to 9.69 ppg with estimated losses of 20 -25 bbl/hr; drill ahead from SUMMARY 6441 ft to 6486 ft - losing 75 bbl/hr at 6486 ft; pump 35 bbl LCM pill; POOH to 6124 ft, circulate and condition mud for 1 hr, run in hole to 6420 ft, wash down to 6486 ft; drill ahead from 6486 ft to 6655 ft. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3185; RigWatch - $1450 REPORT BY D. Grunwald 0 file: / /CADOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/29/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH 411, Nikattchuq DAILY WELLSITE REPORT OPO4 -07 HI REPORT FOR Jack Keener /Gary Goerlich/Andrew Buchanan DATE May 29, 2010 DEPTH 7734.00000 PRESENT OPERATION Drilling ahead TIME 2400'00 YESTERDAY 6655 00000 24 HOUR FOOTAGE 1079 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420 9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7600 69 74 18 358.33 3610.57 SURVEY DATA 7504.59 74.29 359.39 3584.46 7408.43 74.29 0.78 3558.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619 220297 6016 2455 NA 5279 62 6 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 713 2 @ 7093.00000 0.8 @ 7734.00000 110.7 0.81764 FT /HR SURFACE TORQUE 19722 @ 7733.00000 9607 @ 7606.00000 13665.6 13204.64258 AMPS WEIGHT ON BIT 20 @ 7525.00000 0 @ 6951 00000 10.8 18.15027 KLBS ROTARY RPM 149 @ 6997.00000 75 @ 7732.00000 132.3 85.61938 RPM PUMP PRESSURE 2607 @ 7192 00000 1924 @ 6815.00000 2469.8 2501 39990 PSI DRILLING MUD REPORT DEPTH 7380 MW 9.2 VIS n r. PV 13 YP 21 FL 6 Gels 8/20/21 CL- 800 FC 1/- SOL 5 SD 0.1 OIL 2/93 MBL 12 pH 9.3 Ca+ 120 CCI n.r. MWD SUMMARY INTERVAL 2455 TO 7734 TOOLS Gamma, Resistivity, Neutron Density and Porosity, Photoelectric GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 113 @ 6981.00000 0 @ 7159 00000 12.8 TRIP GAS NA CUTTING GAS 0 @ 7734.00000 0 @ 7734 00000 0 0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 1110 METHANE (C -1) 28659 @ 6952.00000 111 @ 7159.00000 2809.8 CONNECTION GAS HIGH 0 ETHANE (C -2) 105 @ 7676 00000 0 @ 7004.00000 8.8 AVG 0 PROPANE (C -3) 22 @ 7676.00000 0 @ 7465.00000 1.6 CURRENT 0 BUTANE (C -4) 30 @ 7676.00000 0 @ 7598 00000 2.1 CURRENT BACKGROUND /AVG 10 PENTANE (C -5) 30 @ 7676 00000 0 @ 7634.00000 1.1 HYDROCARBON SHOWS 1) 6970' -7433' trace; 2) 7483' - 7516' poor; 3) 7535-7599' fair, 4) 7647-7724' fair INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 6970 -7433; 7483 -7516; 7535 -7599; (all shows) 1)2u -3u avg 2) 25u max 3) 41u (all shows) trace medium brown stain, 10% scattered yellow fluorescence, clear to straw cut, white to yellow cut 7647 -7724 sand/sandstone max 4) 83u max fluorescence, light residue with white to yellow fluorescence LITHOLOGY 60% sand /sandstone, 40% conglomeratic sand, trace carbonaceous shale PRESENT LITHOLOGY 80% sand, 20% conglomeratic sand DAILY ACTIVITY Drill ahead from 6655 ft to 7149 ft, pump LCM pill and circulate bottoms -up twice due to losses of 25 bbl/hr, drill ahead from 7149 ft to 7284 ft; service top drive; drill ahead from 7284 ft to SUMMARY 7734 ft; miscellaneous mudlogging activity - calibrate gas detection equipment EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3230; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/30/2010 Daily Report Page 1 of 1 . ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Jack Keener /Gary GoerItch/Andrew Buchanan DATE May 30, 2010 DEPTH 8510.00000 PRESENT OPERATION Drilling ahead TIME 2400:00 YESTERDAY 7734 00000 24 HOUR FOOTAGE 776 CASING INFORMATION 20" @ 160' 13 3/8" @ 240.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8366.69 82.44 358.95 3785 95 SURVEY DATA 8270.62 81.23 358.04 3772.31 8175.30 7859 356.81 3755.61 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619 220297 6x16 2455 NA 6055 80.0 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 260.6 @ 7994.00000 0.8 @ 7734.00000 78.2 85.43763 FT /HR SURFACE TORQUE 19251 @ 7848 00000 9507 @ 8310.00000 13505.9 11862 35156 AMPS WEIGHT ON BIT 28 @ 8335 00000 0 @ 7856 00000 12.7 17.07658 KLBS ROTARY RPM 147 @ 8035 00000 75 @ 7849.00000 120.9 87 81669 RPM PUMP PRESSURE 2734 @ 8378.00000 1762 @ 8148.00000 2470 6 2650.14307 PSI DRILLING MUD REPORT DEPTH 8430 MW 9.3 VIS 54 PV 15 YP 23 FL 6 Gels 7/22/28 CL- 1100 FC 1/- SOL 7 SD 005 OIL 3/91 MBL 17 pH 100 Ca+ 40 CCI n.r. MWD SUMMARY INTERVAL 2455 TO 8510 TOOLS Gamma, Resistivity, Neutron Density and Porosity, Photoelectric GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 267 @ 8006.00000 1 @ 7734.00000 43.3 TRIP GAS NA CUTTING GAS 0 @ 8510.00000 0 @ 8510.00000 0 0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 • METHANE (C -1) 54989 @ 8006.50000 227 @ 7734.00000 9035.8 CONNECTION GAS HIGH 34 ETHANE (C -2) 607 @ 8006.00000 1 @ 7735.00000 86.3 AVG 4 PROPANE (0 -3) 253 @ 8167.00000 0 @ 8392.00000 371 CURRENT 0 BUTANE(C-4) 449 @ 7847.00000 0 @ 8124.00000 806 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 351 @ 7970.00000 0 @ 7747.00000 65.7 HYDROCARBON SHOWS 4) 7795- 7900', 5) 7940'- 8010'; 6) 8150' -8210' INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 7795- 7900; 7940 -8010; (all shows) 5) 216 max 6) 267 (all shows) trace to abundant brown stain, faint to moderate odor, 40% - 90% dull to medium golden yellow fluorescence, clear to 8150 -8210 sand/sandstone max 7) 223 max straw cut, streaming yellow -white cut fluorescence, light residue fluoresces medium yellow LITHOLOGY 80% sand/sandstone, 15% conglomeratic sand, 10% siltstone, trace marl and shell material PRESENT LITHOLOGY 90% sand /sandstone, 10% conglomeratic sand DAILY ACTIVITY Pump 10.5 ppg sweep with hole lubricant (vegetable shortening/lard), drill ahead from 7734 ft to 8510 ft, losses of 137 bbls on day tour and 122 bbls on night tour ( -11 bbl/hr SUMMARY average). EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $4375; RigWatch - $1150 REPORT BY D. Grunwald • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\EN1\Daily Report... 6/1/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikait DAILY WELLSITE REPORT OPO4 -07 REPORT FOR Jack Keener /Gary Goerlich /Andrwe Buchanan DATE May 31, 2010 DEPTH 8750 00000 PRESENT OPERATION Tnpping in hole TIME 24:00'00 YESTERDAY 8510.00000 24 HOUR FOOTAGE 240 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8366.69 82.44 358.95 3785.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 1225 MSX619 220297 6x16 2455 8750 6295 83.3 NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1315 @ 8643.00000 192 @ 8720.00000 848 75.82100 FT /HR SURFACE TORQUE 17352 0 8731 00000 11310 0 8636 00000 14280.8 13836.80100 AMPS WEIGHT ON BIT 29 @ 8621.00000 4 @ 8720.00000 15.8 814500 KLBS ROTARY RPM 147 @ 8570 00000 87 0 8515 00000 140.0 140.34300 RPM PUMP PRESSURE 2726 0 8749.00000 1945 0 8640.00000 2595.0 2726.49000 PSI DRILLING MUD REPORT DEPTH 8750 MW 93 VIS 55 PV 16 YP 21 FL 6 Gels 10/24/31 CL- 850 FC 1/- SOL 7 SD 0.05 OIL 4/90 MBL 17 pH 9.8 Ca. 40 CCI n.r. MWD SUMMARY INTERVAL 2455 TO 8750 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 135 @ 8748 00000 0 @ 8576 00000 25.6 TRIP GAS 0 CUTTING GAS 0 @ 8750.00000 0 @ 8750.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 280223 @ 8750 00000 153 @ 8576 00000 7594.8 CONNECTION GAS HIGH 0 • ETHANE (C -2) 259 @ 8744.00000 0 @ 8576 00000 36 6 AVG 0 PROPANE (C -3) 78 @ 8744.00000 0 @ 8576.00000 11 9 CURRENT 0 BUTANE (C-4) 209 @ 8744.00000 1 @ 8733.00000 40.8 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 171 @ 8750.00000 0 @ 8733 00000 36.8 HYDROCARBON 8) B045ft to TD (to be continued) SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 8045 -8050 sand/sandstone 8) 134 light brown stain on 40% of grains, slight odor, 90% dull gold fluorescence, streaming yellow -white cut fluorescence, slight brown residue max fluoresces yellow -white LITHOLOGY 70% sand/sandstone, 15% conglomeratic sand, 10% siltstone, trace carbonaceous shale, coal, and conglomerate PRESENT LITHOLOGY 100% sand /sandstone DAILY ACTIVITY Dr ae fro 85 ft o t 8750 ft; begate high vic, poutag tialled reme ping e mell los, trip of h ill ole h fro m 875 0 fI to 10 7500 ft; back ream in tof from circul 7500 ft i to sursface osity casing sweep shoe wer at 24 ge fl - on 6 bb loss - opera arculate ons st bottom s up 1.5 at hours; shoe; se pum top drove swe an d crown ; hip onitor in ho from - no 2420 ses ft to 4507 out SUMMARY ft, and fill pipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $4425; RigWatch - $1150 REPORT BY D. Grunwald • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Daily Report... 6/2/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH • Nikaitchuq DAILY WELLSITE REPORT till OPO4 -07 REPORT FOR Jack Keener /Gary Goerlich/Andrew Buchanan DATE Jun 01, 2010 DEPTH 8750 00000 PRESENT OPERATION Testing BOP's TIME 24.0050 YESTERDAY 8750.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 133/8 "@ 2420.9 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8686.40 82.88 358.11 383010 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 1225 MSX619 220297 6x16 2455 8750 6295 83.3 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8750 MW 9.2 VIS n.r. PV 14 YP 20 FL 55 Gels 8/17/20 CL- 900 FC 1/- SOL 65 SD 0.05 OIL 4/90 MBL 17 pH 90 Ca+ 20 CCI n.r. MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 8 CUTTING GAS NA @ NA @ NA WIPER GAS 8 CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA ID ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY Continue topping in hole from 4507 fl to 8750 ft following wiper trip, filling drill pipe every 15 stands - 8 units wiper /trip gas (possibly low - service gas trap); circulate bottoms -up and monitor well ACTIVITY for 10 minutes - no losses; trip out of hole from 8750 ft to 488 ft, pumping dry lob at 7762 ft; stand back heavyweight drill pipe, lay down remainder of BHA, unload nuclear source; clear and clean SUMMARY rig floor; remove wear bushing; pick up landing joint for casing, make dummy run, and lay down landing joint; change out BOP rams to 9 5/8" rams, run in hole with test plug and test joint, and test rams; drain stack and lest BOP's; miscellaneous mud logging actvily - replace agitator blades in gas trap and calibrate gas detection equipment. EPOCH PERSONNEL ON BOARD 3 DAILY COST DML - $3555; Rig Watch - $1450 REPORT BY D. Grunwald ID file: //C *DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/2/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT HI OPO4 -07 REPORT FOR Jack Keener /Gary Goencch/Andrew Buchanan DATE Jun 02, 2010 DEPTH 8750.00000 PRESENT OPERATION Circulate and condition mud for cement job TIME 24.00:00 YESTERDAY 8750.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1 SURVEY DATA 8686.40 82 88 358.11 3830.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8750 MW 9.4 VIS 61 PV 16 YP 22 FL 5 Gels 8/18/22 CL- 900 FC 1/- SOL 7 SD 0.05 OIL 4/90 MBL 16.5 pH 8.9 Ca+ 40 CCI n.r. MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 23 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG 7 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Rig down BOP testing equipment and lay down test joint; ng up to run 9 5/8" casmg, run m hole with 9 5/8" casing to 8750 ft, circulating bottoms -up at 2405 ft, 4400 ft, 6460 ft, 8000 ft, SUMMARY and 8750 ft; pick up landing lent EPOCH PERSONNEL ON BOARD 3 DAILY COST DML - $3645; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/3/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Jack Keener /Gary Goerlich /Andrew Buchanan DATE Jun 03, 2010 DEPTH 8750.00000 PRESENT OPERATION Topping in hole TIME 24.00:00 YESTERDAY 8750.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420 9' 9.6" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8686.40 82.88 358.11 383010 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8750 MW 9.3 VIS 47 PV 12 YP 15 FL n r Gels 6 / -/- CL- n.r. FC n.r. SOL n.r. SD n.r. OIL nr. MBL n.r pH n r Ca-) n.r. CCI n MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 32 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Circulate bottoms up folbwing casing run - 32u trip gas; rig down Frank's casing tool; rig up cement lines and cement head, circulate bottoms -up to condition mud for cement lob, pressure test SUMMARY cement lines; pump cement lob and bump plug, rig down cement head and flush BOP stack, lay down landing joint and casing elevators; install and pressure test wellhead; change out upper rams, test BOP's; pull test plug, set wear ring, lay down test joint, blow down lines, trip in hole in preparation for laying down worn drill pipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3370; RigWatch - $1450 REPORT BY D. Grunwald , 0 file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\EN1\20100604.htm 6/4/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nit DAILY WELLSITE REPORT El OPO4 -07 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Jun 04, 2010 DEPTH 8750.00000 PRESENT OPERATION Laying down drill pipe TIME 24:00'00 YESTERDAY 8750.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' 9 5/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8686.40 82.88 358.11 3830.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8750 MW 91 VIS 62 PV 17 VP 9 FL Gels 6/10/13 CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA i 'i HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Continue to trip in hole with drill pipe to 3814 ft in order to lay down worn joints; clean out mud pits and take on oil -based mud; sip and cut drilling line; service drawworks and crown; lay down SUMMARY worn drill pipe, vacuuming oil -based mud out of each, clear ice from derrick, trip in hole with drill pipe to 4950 ft in order to lay down worn joints; lay down drill pipe, vacuuming oil -based mud out of each. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3345; Rig Watch - $1450 REPORT BY D. Grunwald • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENFDaily Report... 6/8/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH IP Nikaitchuq DAILY WELLSITE REPORT HI OPO4 -07 REPORT FOR Jack Keener /Dave Morns /Andrew Buchanan DATE Jun 05, 2010 DEPTH 8750.00000 PRESENT OPERATION POOH /stand back drill pipe TIME 24:00:00 YESTERDAY 8750.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420 9' 9 5/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8686.40 8288 358.11 3830.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8750 MW 8.8 VIS n.r. PV 15 YP 8 FL n.r Gels 5/10/- CL- 40500 FC n.r. SOL 869 SD n.r. OIL 79/21 MBL n.r. pH n.r. Ca+ 1.56 (Ib/bbl lime) CCI n.r MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA III ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Pickup new drill pipe and run in hole to 3250 ft; circulate and condition mud, clean drill pipe; trip out of hole, rack back 34 stands; service iron roughneck and drawworks, clean drill floor, and SUMMARY strap new dnll pipe m pipe shed; pick up new drill pipe and run in hole to 8200 ft; cuculate and condition mud, clean drill pipe; miscellaneous mudlogging activity - calibrate gas detection equipment EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3125; RigWatch - $1450 REPORT BY D. Grunwald S file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Daily Report... 6/8/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Jun 06, 2010 DEPTH 8758.00000 PRESENT OPERATION Circulating and conditioning mud TIME 24'0000 YESTERDAY 8750.00000 24 HOUR FOOTAGE 8 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' 9 5/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8686 40 82 88 358.11 3830.10 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8.5" Hycalog 123905 3x12, 6x11 8750 NA 8 0.1 NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1401 @ 8756 00000 65 5 @ 8751.00000 99.4 80 86980 FT /HR SURFACE TORQUE 13836 @ 8750.00000 6120 @ 8752.00000 8059.5 6239.26221 AMPS WEIGHT ON BIT 8 @ 8750.00000 6 @ 8752.00000 8 4 7.16698 KLBS ROTARY RPM 140 @ 8750 00000 54 @ 8751.00000 72.1 54 54874 RPM PUMP PRESSURE 2726 @ 8750 00000 1589 @ 8751.00000 1932.8 1590.94043 PSI DRILLING MUD REPORT DEPTH 8750 MW 8.8 VIS n.r. PV 17 VP 11 FL - Gels 11/14/- CL- 44000 FC -/- SOL 8.57 SD n.r. OIL 78/22 MBL n.r pH n r Ca+ 0.72 (Ib/bbl lime) CCI n r MWD SUMMARY INTERVAL 8750 TO 8758 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric factor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 133 @ 8750.00000 5 @ 8755.00000 24 9 TRIP GAS 0 CUTTING GAS 0 @ 8758.00000 0 @ 8758.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) 280223 @ 8750 00000 4868 @ 8758.00000 35636.5 CONNECTION GAS HIGH NA • ETHANE (C-2) 213 @ 8750 00000 9 @ 8758.00000 27 9 AVG NA PROPANE )C -3) 72 @ 8750.00000 4 @ 8758.00000 9.7 CURRENT NA BUTANE (C-4) 191 @ 8750 00005 191 @ 8750.00000 23 9 CURRENT BACKGROUND /AVG 20 PENTANE(C -5) 171 @ 8750.00000 171 @ 6750.00000 21.4 HYDROCARBON SHOWS (to be determined) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 100% sand /sandstone PRESENT LITHOLOGY 100% sand /sandstone DAILY ACTIVITY Trip new drill pipe out of hole and rack back; pick up 8 joints heavyweight drill pipe and Jars and run in hole with same, trip heavyweight drill pipe out of hole and rack back, pick up BHA and trip in SUMMARY hole to 1000 f1; circulate and condition mud, and shallow test MWD tools; trip in hole to 8500 ft, filling pipe every 20 stands; circulate bottoms -up 2x to clean hole; pressure test casing/shoe to 3000 psi, wash down to float tag at 8644 ft; drill out float and cement, tag shoe a18728 ft; drill ahead to 8758 ft; circulate and condition mud while attempting to downlink to rotary steerable tools EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3125; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Daily Report... 6/8/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OPO4 -07 1 REPORT FOR Jack Keener/Dave Morris /Andrew Buchanan DATE Jun 07, 2010 DEPTH 9670.00000 PRESENT OPERATION Drilling ahead TIME 24:00'00 YESTERDAY 8758.00000 HOUR FOOTAGE 912 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' 95/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH I SURVEY DATA 9880.19 8834 354.36 3872.59 9785 47 88 43 356 67 3869.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED 4 8.5" Hycalog RSX616M 123905 3x12, 6x11 8750 NA 912 15 5 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 817.4 @ 8797 00000 1.1 @ 8969.00000 142.7 145.91440 FT /HR SURFACE TORQUE 11665 @ 8996.00000 6168 @ 8798 00000 7661.7 7966.52295 AMPS WEIGHT ON BIT 25 @ 9028.00000 0 @ 9368.00000 5.0 2.36627 KLBS ROTARY RPM 126 0 9186.00000 54 0 8758.00000 94.5 100.18189 RPM PUMP PRESSURE 2958 0 9252.00000 1590 @ 8758 00000 2688.9 2803.48633 PSI DRILLING MUD REPORT DEPTH 9750 MW 8.9 VIS n.r. PV 19 YP 14 FL - Gels 16/19/21 CL- 37000 FC -/- SOL 10.31 SD n r OIL 69.5 MBL n r pH n.r Ca+ 1 24 (Ib/bbl lime) CCI n.r. MWD SUMMARY INTERVAL 8750 TO 9670 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric Factor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 123 @ 8795.00000 0 @ 9456.00000 35.5 TRIP GAS NA CUTTING GAS 0 @ 9670.00000 0 @ 9670 00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 III METHANE (C -1) 147766 @ 9194.00000 25 @ 9265.00000 24407.6 CONNECTION GAS HIGH 0 ETHANE (C -2) 583 @ 9194.00000 0 @ 9276 00000 92.4 AVG 0 PROPANE (C -3) 121 @ 9194.00000 0 @ 9447.00000 17.3 CURRENT 0 BUTANE (C -4) 181 @ 9194.00000 0 @ 9447.00000 30.3 CURRENT BACKGROUND /AVG 50 PENTANE (C -5) 256 0 9381.00000 0 0 9276.00000 14.2 HYDROCARBON SHOWS (production lateral, to be continued) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 8730 - TD sand /sandstone 10u to 200 +u trace stain, even, dull while fluorescence, amber to pale straw cut, dull white cut fluorescence LITHOLOGY 80% sand /sandstone, 20% siltstone PRESENT LITHOLOGY 100% sand /sandstone DAILY ACTIVITY Drill ahead from 8758 ft to 8797 ft, circulate bottoms -up; perform formation integrity test to 1032 psi /14 ppg equivalent mud weight, blow down kill line and rig down testing SUMMARY equipment,drill ahead from 8797 ft to 9670 ft. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3125; Rig Watch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/8/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH • Nikaitchuq DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Jack Keener /Dave Morns /Andrew Buchanan DATE Jun 08, 2010 DEPTH 10190.00000 PRESENT OPERATION Drilling ahead TIME 24:0090 YESTERDAY 9670.00000 24 HOUR FOOTAGE 1116 (includes footage prior to sidetrack) CASING INFORMATION 20" @ 160' 13 3/8" @ 2420 9' 9 5/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10072 57 87.23 352.97 3878.48 10167.62 87.03 354 31 3883.24 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED 4 8.5" Hycalog RSX616M 123905 3x12, 6x11 87570 NA 2036 25.6 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 800.7 @ 9983.00000 3.0 @ 10168.00000 165 0 211.71489 FT /HR SURFACE TORQUE 11210 @ 10051 00000 7287 @ 9751.00000 8762.3 9232.67773 AMPS WEIGHT ON BIT 14 @ 9999 00000 0 @ 10139 00000 3.9 2.13144 KLBS ROTARY RPM 124 @ 9848 00000 99 @ 10041.00000 118.0 119 14869 RPM PUMP PRESSURE 2864 @ 9940.00000 1932 @ 10141.00000 2729 9 2789.75366 PSI DRILLING MUD REPORT DEPTH MW 89 VIS n r. PV 18 YP 14 FL n.r Gels 15/19/20 CL- 30000 FC n.r SOL 10 37 SD n r. OIL 70 MBL n.r. pH n.r. Ca-- 0.72 (lb/bbl lime) CCI n.r. MWD SUMMARY INTERVAL 9670 TO 10190 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric Factor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 415 @ 10156.00000 0 @ 10006.00000 106.9 TRIP GAS NA CUTTING GAS 0 @ 10190.00000 0 @ 10190.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 III METHANE (C -1) 137302 @ 9870.00000 55 @ 10006.00000 40405.7 CONNECTION GAS HIGH 0 ETHANE (0-2) 550 @ 9870.00000 0 @ 10006.00000 173.5 AVG 0 PROPANE (C -3) 186 @ 1001600000 0 @ 10006.00000 371 CURRENT 0 BUTANE (C-4) 371 @ 10016 00000 0 @ 10006.00000 69.8 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 439 @ 10016.00000 0 @ 10006.00000 45 8 HYDROCARBON SHOWS (production interval, in progress) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 85% sand /sandstone, 15% siltstone PRESENT LITHOLOGY 100% sand /sandstone DAILY ACTIVITY Drill ahead from 9670 ft to 10,540 ft, reaming each stand; circulate bottoms -up, and continue to circulate until hole is clean, trip out of hole from 10,540 ft to 9944 ft, stand back 6 stands of drill SUMMARY pipe, and prepare directional drilling and rig monitoring systems for sidetrack; kick off open hole sidetrack from 9544 ft; drill ahead to 10190 ft, miscellaneous mudbgging activity - recalibrate gas detection equipment EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3125; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/9/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OPO4- 07 -ST1 REPORT FOR Jack Keener /Dave Morns /Andrew Buchanan DATE Jun 09, 2010 DEPTH 11378 00000 PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 10190.00000 24 HOUR FOOTAGE 1188 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420 9' 95/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11220.25 87 49 4 19 3923 59 11316.27 87 17 7.14 3931.51 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED 4 8.5 Hycalog RSX616M 123905 3x12, 6x11 8750 NA 3224 24 4 NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 475.9 @ 10231 00000 3.8 @ 11283.00000 1367 748783 FT /HR SURFACE TORQUE 13057 @ 10797.00000 8291 @ 11283 00000 9686.9 10132 43750 AMPS WEIGHT ON BIT 21 @ 11293.00000 0 @ 10576 00000 32 1225106 KLBS ROTARY RPM 127 @ 10346 00000 80 @ 11287.00000 123.3 94.99631 RPM PUMP PRESSURE 3048 @ 11107.00000 1944 00 1033000000 2796.1 2898.94995 PSI DRILLING MUD REPORT DEPTH 11350 MW 8.9 VIS 66 PV 19 YP 13 FL n r. Gels 16/21/23 CL- 40000 FC n.r. SOL 9.9 SD n.r. OIL 17.5 MBL n.r. pH n r Ca+ 1 3 (15/551 lime) CCI n.r. MWD SUMMARY INTERVAL 8750 TO 11378 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric Factor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 449 @ 10251.00000 0 @ 11375.00000 112.4 TRIP GAS NA CUTTING GAS 0 @ 11378 00000 0 @ 11378 00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 • METHANE (C -1) 100142 @ 10448.00000 148 @ 10372.00000 31354.5 CONNECTION GAS HIGH 0 ETHANE (C -2) 483 @ 10545.00000 1 @ 11375.00000 148.8 AVG 0 PROPANE (C -3) 255 @ 10335.00000 0 @ 11375.00000 45.9 CURRENT 0 BUTANE (C -4) 617 @ 10545.00000 1 @ 11375 00000 108.6 CURRENT BACKGROUND /AVG 1 PENTANE (C -5) 390 @ 10335.00000 0 @ 10365.00000 71.0 HYDROCARBON SHOWS (production lateral, in progress) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION sand/sandstone LITHOLOGY 100% sand /sandstone, trace siltstone PRESENT LITHOLOGY 100% sand /sandstone DAILY ACTIVITY SUMMARY Drill ahead from 10,190 0 to 11378 ft, reaming each stand. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3780; RigWatch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/10/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OPO4- 07 -ST1 REPORT FOR Jack Keener /Dave Moms DATE Jun 10, 2010 DEPTH 12144.00000 PRESENT OPERATION Pulling out of hole TIME 24.00:00 YESTERDAY 11378.00000 24 HOUR FOOTAGE 766 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' 95/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081.01 92 85 359.62 3938 64 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8.5" Hycalog RSX616M 123905 3016, 6x1 8750 12144 3990 55.5 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 461 5 @ 11761.00000 4.5 @ 11837.00000 137.9 59.07450 FT /HR SURFACE TORQUE 13055 @ 11734.00000 8598 0 11665.00000 105326 11075.46973 AMPS WEIGHT ON BIT 25 @ 11951.00000 0 @ 11972.00000 4.8 3.07120 KLBS ROTARY RPM 124 @ 12008.00000 94 0 11378.00000 122.8 123.29716 RPM PUMP PRESSURE 3492 @ 1149500000 2350 @ 11380.00000 30581 3111.24976 PSI DRILLING MUD REPORT DEPTH 12144 MW 9.0 VIS 68 PV 19 YP 16 FL n r. Gels 16/22/25 CL- 40000 FC n r. SOL 10.41 SD n.r OIL 70 MBL n r pH n.r. Ca+ 1.04 (Ibacbl lime) CCI n.r. MWD SUMMARY INTERVAL 8750 TO 12144 TOOLS Gamma, Resistivity, Neutron Density & Porosity, Photoelectric Factor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 @ 11700.00000 0 @ 11444.00000 13 2 TRIP GAS NA CUTTING GAS 0 @ 12143.00000 0 @ 12143.00000 00 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 83705 @ 11798.00000 90 @ 11444.00000 257290 CONNECTION GAS HIGH 0 • ETHANE (C -2) 423 @ 11798.00000 0 0 11444.00000 122.7 AVG 0 PROPANE (C -3) 109 @ 11798.00000 0 @ 11444.00000 382 CURRENT 0 BUTANE (C-4) 264 @ 11835.00000 0 @ 11444.00000 88 1 CURRENT BACKGROUND /AVG 25 PENTANE (C -5) 196 @ 11835.00000 0 0 11444.00000 54 9 HYDROCARBON 8730 ft to 12144 ft, fair to good show (production lateral) SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8730-12144 sand /sandstone Ou to Rare stain, even, dull while fluorescence over entire sample, amber cut, immediate dull white cut fluorescence, light brown cut fluoresces faint 449u white LITHOLOGY 75% sand /sandstone, 25% siltstone PRESENT LITHOLOGY 80% sand /sandstone, 20% siltstone DAILY ACTIVITY Drill ahead from 11378 ft to 12144 ft, reaming each stand; circulate bottoms -up; pump high viscosity sweep until cuttings are clean (7800 strokes); pump weighted sweep until cuttings are SUMMARY clean (7800 strokes); pull out of hole from 12144 ft to 8700 ft; circulate bottoms -up at shoe, miscellaneous mudlogging activity - calibrate gas detection equipment. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3360; Rig Watch - $1450 REPORT BY D. Grunwald S file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Daily Repor... 6/11/2010 Daily Report Page 1 of 1 II ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH 0PO4- 07 -ST1 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Jun 11, 2010 DEPTH 12144.00000 PRESENT OPERATION Tripping in hole TIME 2400:00 YESTERDAY 12144.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2420.9' 95/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081 01 92.85 359 62 3938.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12144 MW 9.0 VIS 69 PV 19 YP 16 FL n r. Gels 16/24/28 CL- 40000 FC n.r. SOL 10.41 SD n.r. OIL 70 MBL n.r. pH n r Ca+ 1 17 (Ib. bl lime) CCI n.r. MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Continue to circulate at the intermediate casing shoe, pump dry lob; blow down top drive; monitor hole for 10 minutes - hole static; pull out of hole from 8700 ft to 625 fl; lay down BHA; clear and SUMMARY clean drill floor; rig up BOP testing equipment, remove wear bushing and install lest plug; test BOP's; lay down test tool, pull test plug, and install wear ring; lay down lest Joint, blow down choke manifold; slip and cut drilling line; service top drive and blocks; pick up BHA; trip in hole with hole opener BHA to 6074 ft, change out swivel packing. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3315; Rig Watch - $1450 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/12/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH 0 Nikaitchuq DAILY WELLSITE REPORT OPO4- 07 -ST1 El REPORT FOR Joe Longo /Scott Beauchamp /Andrew Buchanan DATE Jun 12,2010 DEPTH 12144 PRESENT OPERATION POOH TIME 24:0000 YESTERDAY 12144 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2520.9' 9 5/8" @ 8727.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081 01 92.85 359.62 3938.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12144 MW 9.9 VIS 23 PV nr VP nr FL nr Gels nr CL- nr FC nr SOL nr SD nr OIL nr MBL nr pH nr Ca+ nr CCI nr MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA NA @ NA NA TRIP GAS 90 CUTTING GAS NA @ NA NA @ NA NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA NA @ NA NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA NA @ NA NA AVG NA PROPANE (C -3) NA @ NA NA @ NA NA CURRENT NA BUTANE (C-4) NA @ NA NA @ NA NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA NA @ NA NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA Service the top drive with grease then test. Trip in the hole. From 6050', fill every 20 joints to proper displacement down to 8840'. Ream and wash the hole. Run in hole with no pumps and no DAILY ACTIVITY SUMMARY rotation from 9424' 10 10240'. Reaming and washing through several tight spots from 10240' to 12144. Circulate and condition the hole. Circulate 2 bottoms up. Trip out of hole then flow check the well at 11530. Run in hole to bottom and circulate and conditwn 1 bottoms up Displace to completion fluid (Brine). Trip out of hole and flow check. No flow. Pull out of hole EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3125; RigWatch - $1450 REPORT BY Z. Beekman • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Daily Repor... 6/13/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchug DAILY WELLSITE REPORT lug OPO4- 07 -ST1 REPORT FOR Jack Keener /Dave Morns /Andrew Buchanan DATE Jun 13, 2010 DEPTH 12144 PRESENT OPERATION RIH w /completion finer TIME 24:00•00 YESTERDAY 12144 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2520.9' 9 5/8" @ 8728.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081.01 92 85 359.62 3938.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12144 MW 9.9 VIS 23 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA NA @ NA NA TRIP GAS 0 CUTTING GAS NA @ NA NA @ NA NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA NA @ NA NA CONNECTION GAS HIGH NA III ETHANE (C -2) NA @ NA NA @ NA NA AVG NA PROPANE (C -3) NA @ NA NA @ NA NA CURRENT NA BUTANE (C -4) NA @ NA NA @ NA NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA NA @ NA NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Pull out of hole. Lay down BHA. Service ng. Run or hole with completion liner. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3125; RigWatch - $1450 REPORT BY Z. Beekman S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/14/2010 Daily Report Page 1 of 1 ENI Petroleum • EPOCH Nikaitchuq DAILY WELLSITE REPORT 0PO4- 07 -ST1 Ell REPORT FOR Scott Beauchamp /Dave Moms /Andrew Buchanan DATE Jun 14, 2010 DEPTH 12144 PRESENT OPERATION Tripping TIME 2400:00 YESTERDAY 12144 24 HOUR FOOTAGE 0 CASING INFORMATION 5.5 liner@ 12144 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081.01 92.85 359 62 3938.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TB /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH MW 9.9 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 4 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Run in hole with 5.5" slotted liner. Set packer and pull out of hole and lay down drill pipe EPOCH PERSONNEL ON BOARD 2 DAILY COST DML - $2845; Rig Watch - $1450 REPORT BY Z. Beekman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 6/15/2010 Daily Report Page 1 of 1 ENI Petroleum • PI EPOCH Nikaachuq DAILY WELLSITE REPORT OPO4- 07 -ST1 REPORT FOR Scott Beauchamp /Dave Morris /Andrew Buchanan DATE Jun 15, 2010 DEPTH 12144 PRESENT OPERATION RIH W/ 5 1/2" TUBING TIME 24.00:00 YESTERDAY 12144 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 2520.9' 9 5/8" @ 8728.9' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081 01 92.85 359 62 3938.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12144 MW 9.9 VIS 24 PV VP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Continueing to ng up wirehne equipment and floor to wn in hole with 5 1/2" tubing. As of midnight, run in hole with 1500' of tubing 1450 DAILY COST DML - 2895; Ri Watch - EPOCH PERSONNEL ON BOARD 2 $ $ . Rig Watch BY Z. Beekman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 6/16/2010 Daily Report Page 1 of 1 ENI Petroleum • EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OPO4 -07 REPORT FOR Scott Beauchamp /Dave Morris /Andrew Buchanan DATE Jun 16, 2010 DEPTH 12144.00000 PRESENT OPERATION Nipple Down BOP TIME 24,00'00 YESTERDAY 12144.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8" @ 2420.9' 9 5/8" @ 8728.9' 5.5" L @ 12144' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12081.01 92 85 359.62 3938 64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TB /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12144 MW 9.9 VIS 24 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE )C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE(C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Continue running in hole with 4 1/2" tubing. Run and land tubing at 7866'. Nipple down BOP. Nipple down tree and dress the well head. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML - $2845; RigWatch - $1450 REPORT BY Z. Beekman a S file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 6/17/2010 • CANRIG SHOW REPORT NO. 1 1)RILLI]G TE:CH.VOLOf LTn ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 6970 TO 7433 (MD) TOTAL FTG 463 3436 TO 3565 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 50 -56 AVERAGES: BEFORE I DURING I I AFTER I Average Maximum ROP (fph) 165 127 713 57 WOB 7.9 6.5 18.8 17.8 RPM 143 137 150 129 MUD WT 9 9.0 -9.1 9.1 9.1 CHLORIDE 800 800 800 800 TOTAL GAS 60 9 113 6 • C1 (ppm) 15576 1969 27464 1217 C2 (ppm) 7 1 16 1 C3 (ppm) 2 0 7 0 C4 (ppm) 0 0 1 0 C5 (ppm) 0 0 1 0 RATIO ROP INCREASE TO GAS INCREASE: (- 38/ -51) SAMPLE CUTTINGS FLUORESENCE%: 10% - 40% COLOR YELLOW INTENSITY: MEDIUM CUT: CLEAR TO YELLOW MUD FLUORESCENCE (none) FORMATION DESCRIPTION: SAND /CONGLOMERATIC SAND - medium light gray with a slight brownish secondary hue; fine upper to coarse lower grain dis- aggregated sand; trace very coarse pebbles and pebble fragments; variable proportions of clear to translucent white quartz and dark to light gray lithic grains from roughly even amounts of each to quartz -rich (60 % -70 %) sand; trace brown, orange, and blue -gray grains; trace glauconite; scattered pyrite and coal fines; subangular to angular throughout; slightly calcareous. SHOW RATING: (T,P,F,G) TRACE 0 LOGGING GEOLOGIST(S): John Lundy • CANRIG SHOW REPORT NO. 2 Dn,LLI\(; TECHV((LO(A LID ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 7483 TO 7516 (MD) TOTAL FTG 33 3579 TO 3588 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 58 AVERAGES: I BEFORE I I DURING I I AFTER I Average Maximum ROP (fph) 129 73 108 72 WOB 17.8 18.1 20.6 19.8 RPM 57 130 133 131 MUD WT 9.1 9.1 9.1 9.1 CHLORIDE 800 800 800 800 TOTAL GAS 6 17 34 20 0 C1 (ppm) 1197 3456 6355 4059 C2 (ppm) 17 35 25 C3 (ppm) 0 2 4 5 C4 (ppm) 0 1 3 7 C5 (ppm) 0 1 2 5 RATIO ROP INCREASE TO GAS INCREASE: (- 56/11) SAMPLE CUTTINGS FLUORESENCE%: 10% COLOR YELLOW INTENSITY: MEDIUM CUT: FAST YELLOW -WHITE MUD FLUORESCENCE FORMATION DESCRIPTION: SAND /CONGLOMERATIC SAND - dark brownish gray, well sorted sand; medium- to fine - grained quartz sand with subordinate lithics; very light gray, translucent quartz with variable amounts of yellow and light brown grains; dark gray to black, hard, siliceous cryptocrystalline lithics with minor amounts of blue green glauconitic lithics; quartz grains are subangular with moderate sphericity on average; lithics are subrounded to rounded with moderate sphericity; all grains display evidence of impact abrasions, and quartz grain surfaces are etched; rare intact cuttings of sandstone are bound by calcite cement. SHOW RATING: (T,P,F,G) POOR 40 LOGGING GEOLOGIST(S): Dan Grunwald • CANRIG SHOW REPORT NO. 3 DRILLnr, Tt( H \ In 0(1 LTD. ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 7535 TO 7599 (MD) TOTAL FTG 64 3593 TO 3608 (TVD) BIT INFORMATION: BIT Hycalog MSX619 PDC bit BIT HOURS- 59 AVERAGES: BEFORE I DURING ( I AFTER Average Maximum ROP (fph) 69 73 106 62 WOB 19 17 20.6 17.9 RPM 130 120 138 103 MUD WT 9.1 9.1 9.1 9.1 CHLORIDE 800 800 800 800 TOTAL GAS 14 24 41 8 0 C1 (ppm) 2816 4997 8702 1524 C2 (ppm) 14 30 55 8 C3 (ppm) 2 5 11 2 C4 (ppm) 1 9 22 2 C5 (ppm) 1 6 13 1 RATIO ROP INCREASE TO GAS INCREASE: 4/10 SAMPLE CUTTINGS FLUORESENCE%: 10% COLOR YELLOW INTENSITY: MEDIUM CUT: FAST YELLOW -WHITE MUD FLUORESCENCE FORMATION DESCRIPTION: SAND /CONGLOMERATIC SAND - dark brownish gray, well sorted sand; medium- to fine - grained quartz sand with subordinate lithics; very light gray, translucent quartz with variable amounts of yellow and light brown grains; dark gray to black, hard, siliceous cryptocrystalline lithics with minor amounts of blue green glauconitic lithics; quartz grains are subangular with moderate sphericity on average; lithics are subrounded to rounded with moderate sphericity; all grains display evidence of impact abrasions, and quartz grain surfaces are etched; rare intact cuttings of sandstone are bound by calcite cement. SHOW RATING: (T,P,F,G) FAIR 4 , LOGGING GEOLOGIST(S): Dan Grunwald • RIG SHOW REPORT NO. 4 DRILL LIV . TLCHVOLU{D LTD. ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 7647 TO 7724 (MD) TOTAL FTG: 77 3623 TO 3644 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 61 AVERAGES: BEFORE I DURING I I AFTER I Average Maximum ROP (fph) 60 74 119 61 WOB 17.8 15.4 18.5 15.4 RPM 103 101 109 115 MUD WT 9.1 9.1 9.1 9.1 CHLORIDE 800 800 800 800 TOTAL GAS 8 28 83 11 • C1 (ppm) 1507 5638 16388 2470 C2 (ppm) 7 37 105 12 C3 (ppm) 2 8 22 4 C4 (ppm) 2 12 31 2 C5 (ppm) 1 10 31 1 RATIO ROP INCREASE TO GAS INCREASE: 14/20 SAMPLE CUTTINGS FLUORESENCE%: 10% COLOR YELLOW INTENSITY: MEDIUM CUT: FAST YELLOW -WHITE MUD FLUORESCENCE FORMATION DESCRIPTION: SAND /CONGLOMERATIC SAND - dark brownish gray, well sorted sand; medium- to fine - grained quartz sand with subordinate lithics; very light gray, translucent quartz with variable amounts of yellow and light brown grains; dark gray to black, hard, siliceous cryptocrystalline lithics with minor amounts of blue green glauconitic lithics; quartz grains are subangular with moderate sphericity on average; lithics are subrounded to rounded with moderate sphericity; all grains display evidence of impact abrasions, and quartz grain surfaces are etched; rare intact cuttings of sandstone are bound by calcite cement. SHOW RATING: (T,P,F,G) FAIR 0 LOGGING GEOLOGIST(S): Dan Grunwald • CANRIG SHOW REPORT NO. 5 ()MILLI \G TLtH\(lLO D L,TD. ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 7795 TO 7900 (MD) TOTAL FTG; 105 3662 TO 3689 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 68.58 AVERAGES: BEFORE I DURING I I AFTER I Average Maximum ROP (fph) 86 39 199 96 WOB 9.5 11 20 12 RPM 140 143 146 151 MUD WT 9.15 9.15 9.15 9.15 CHLORIDE 1100 1100 1100 1100 TOTAL GAS 23 56 216 26 C1 (ppm) 4809 11473 46954 5159 C2 (ppm) 22 105 481 47 C3 (ppm) 12 40 168 21 C4 (ppm) 7 91 449 53 C5 (ppm) 3 64 283 41 RATIO ROP INCREASE TO GAS INCREASE: 76/263 SAMPLE CUTTINGS FLUORESENCE%: 40% to100% COLOR YELLOW INTENSITY: MEDIUM CUT: FAST STRMING MUD FLUORESCENCE: FORMATION DESCRIPTION: Sand /sandstone = medium gray with a slight brownish secondary hue; recovered as loose sand with moderate to scattered thin flaky hard fine grain sandstone; friable in part moderately to locally well sorted; medium lower to fine upper, medium upper and very fine grain; trace coarse and very coarse; scatered 3mm pebble /pebble fragments; vertically sorted in moderate beds; aout evenly divided between translucent white to clear and slightly smokey quartz and medium to light gray lithic /mineral grains; trace to common light gray to black mafic mineral /lithics; trace coal fines; trace orange jasper; no clay matrix noted; partially silica cemented; slightly to very slightly calcareous; 40 to 100% medium yellow fluorescence; fast streaming cut to yellow - white; moderate brown residue with muddy yellow fluorescence; slight oil odor; trace to common free oil in samples; slight to moderate oil stain. SHOW RATING: (T,P,F,G) fair to good 10 LOGGING GEOLOGIST(S): John Lundy • CANRIG SHOW REPORT NO. 6 DRIL.I \G TB H\01 0(,) Lrn. ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 7940 TO 8010 (MD) TOTAL FTG 70 3700 TO 3718 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 70.92 AVERAGES: BEFORE DURING I AFTER I Average Maximum ROP (fph) 83 93 261 91 WOB 13 7 14 11 RPM 141 141 144 150 MUD WT 9.15 9.2 9.2 9.2 CHLORIDE 1100 1100 1100 1100 TOTAL GAS 24 100 267 52 C1 (ppm) 4925 20631 54989 10723 C2 (ppm) 41 211 607 111 C3 (ppm) 21 59 164 30 C4 (ppm) 47 101 265 35 C5 (ppm) 11 118 351 39 RATIO ROP INCREASE TO GAS INCREASE: 76/263 SAMPLE CUTTINGS FLUORESENCE%: 80 -100 COLOR YELLOW INTENSITY: MEDIUM CUT: FAST STRMING MUD FLUORESCENCE: FORMATION DESCRIPTION: Sand /sandstone = medium gray with a slight to moderate brownish secondary hue; samples collected as loose sand with scattered hard well indurated fine to very fine grain sandstone; friable in part; medium upper to medium lower; fine upper, coarse lowerand very fine grain; moderate beds; vertically sorted; angular to sub - angular to sub - spheroidal and slightly rounded; translucent white to slightly smokey and clear quartz predominate; 20 to 30% light to medium gray lithic /mineral grains; trace to common dark mafic mineral /lithics; trace orange jasper; trace brown mineral /lithics; locally common pyrite nodules; trace to common off white shell fragments; 60 to 90% dull golden yellow fluorescence; fast streaming cut to yellow - white; slight brownish residue fluoresces medium yellow; slight to locally moderate oil odor; trace to very abundant brown oil stain; free oil on shaker at 8005'; very slightly to slightly calcareous. SHOW RATING: (T,P,F,G) Fair to Good LOGGING GEOLOGIST(S): John Lundy • CANRIG SHOW REPORT NO. 7 DRILLI'I6 TLCHNULOGY LTD. ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 8150 TO 8210 (MD) TOTAL FTG: 60 3750 TO 3771 (TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 73.04 AVERAGES: BEFORE 1 DURING I I AFTER Average Maximum ROP (fph) 83 40 132 37 WOB 15 9 15 19 RPM 108 80 138 80 MUD WT 9.15 9.15 9.15 9.1 CHLORIDE 1100 1100 1100 1100 TOTAL GAS 18 127 223 51 0 C1 (ppm) 3555 26720 50320 10806 C2 (ppm) 54 276 537 106 C3 (ppm) 22 139 253 69 C4 (ppm) 10 223 371 195 C5 (ppm) 26 155 329 106 RATIO ROP INCREASE TO GAS INCREASE: 76/263 SAMPLE CUTTINGS FLUORESENCE%: 50% - 90% COLOR YELLOW -GOLD INTENSITY: MEDIUM CUT: FAST STRMING MUD FLUORESCENCE: FORMATION DESCRIPTION: SAND /SANDTONE - medium gray with a slight brownish secondary hue; dis- aggregated sand with trace fragments of fine to very fine sandstone; friable in part; translucent white to clear quartz predominates; angular to subangular; 20% to 40% light to medium gray Iithics; trace dark mafic minerals/lithics; trace pyrite; trace biotite mica; common tan to off -white shell fragments; partially matrix supported; grades to and interbedded with similar sandy siltstone. SHOW RATING: (T,P,F,G) Fair to Good illo LOGGING GEOLOGIST(S): John Lundy 1 . CANRIG SHOW REPORT NO. 8 DRILI.IV. TLCHNULUGY L.TD. ENI Petroleum OPO4 -07 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 8730 TO 8750 (MD) TOTAL FTG 20 3837 TO 3840 {TVD) BIT INFORMATION: BIT TYPE- Hycalog MSX619 PDC bit BIT HOURS- 83 AVERAGES: BEFORE I DURING I ( AFTER I Average Maximum ROP (fph) 92 90.5 106 N/A; TD WOB 121 14 16 RPM 149 150 147 MUD WT 9.35 9.3 9.3 CHLORIDE TOTAL GAS 49 64 135 0 C1 (ppm) 9464 35865 280223 C2 (ppm) 57 108 259 C3 (ppm) 17 33 78 C4 (ppm) 50 39 209 C5 (ppm) 26 49 171 RATIO ROP INCREASE TO GAS INCREASE: 8/86 = .093 SAMPLE CUTTINGS FLUORESENCE%: 90% COLOR Golden Yellow INTENSITY: Dull CUT: Mod fst streaming MUD FLUORESCENCE dull greenish yellow FORMATION DESCRIPTION: Sand = Medium gray with a slight brownish secondary hue; samples collected as dis- aggregated loose sand and scattered very fine grain sandstone and occasional medium grain pyrite cemented sandstone fragments; friable in part; medium lower to fine upper and medium upper grain; trace coarse and 3 to 4 mm pebble /fragments; sub - angular to angular and sub - spheroidal some coarser fragments slightly to moderately rounded; evenly divided overall between quartz and lithics; show zone more predominantly translucent white to clear quartz; 30 to 40% medium to ddark gray and gray -brown lithics /chert; trace dark gray to black mafic mineral /lithics; trace coal fines; common to abundant pyrite nodules; 90% dull golden yellow fluoresceence; moderate fast streaming cut to yellow - white; slight brownish residue ring cuts readily to yellow - white; slight oil odor; slight oil stain on 40% of sand grains; trace thin oil on partings in associated siltstone; very slightly calcareous. SHOW RATING: (T,P,F,G) fair 40 LOGGING GEOLOGIST(S): John Lundy I 0 CANRIG SHOW REPORT NO 9 DRILLIV, TECHNOLOGY LT D. ENI Petroleum OPO4- 07 -ST1 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 8750 TO 12144 (MD) TOTAL FTG: 3394 3837 TO 3935 (TVD) BIT INFORMATION: BIT TYPE- Hycalog RSX616M PDC bit BIT HOURS- 33.3 AVERAGES: BEFORE I DURING I I AFTER Average Maximum ROP (fph) N/A 142 817 N/A WOB (csg shoe) 4.2 25 (total depth) RPM 150 147 MUD WT 8.9 9 CHLORIDE 35000 40000 TOTAL GAS 68 449 . C1 (ppm) 29475 147766 C2 (ppm) 131 583 C3 (ppm) 35 255 C4 (ppm) 77 617 C5 (ppm) 48 439 RATIO ROP INCREASE TO GAS INCREASE: N/A SAMPLE CUTTINGS FLUORESENCE%: 100% COLOR: white INTENSITY: dull CUT: immediate dull white MUD FLUORESCENCE dull to bright white FORMATION DESCRIPTION: sand /sandstone (production lateral) = samples consist of an olive brown slurry of well sorted, very fine - grained loose sand; the sand is primarily composed of translucent very light gray to pale yellow quartz; minor very dark brown to black lithics and trace blue green glauconite make up the rest of the sand; grains are mostly subangular, though glauconite tends to be subrounded; grain sphericity is moderate on average; samples are very calcareous, and very rare, tiny, intact but poorly indurated sandstone cuttings are cemented by calcite. SHOW RATING: (T,P,F,G) fair to good 0 LOGGING GEOLOGIST(S): Daniel Grunwald, Emil Opitz, Zack Beekman F� 0PO4-07 AND �� Egli Petroleum OPO4-07 P61 Sot 0PO4-07 AND eni Enf Petroleum CqNRIP 0 PO4-07 PB1 e Enl Petroleum OPO4 -07 AND BRIG OPO4-07 PB1 I9d LO-frOdO wnepp -. gi3 pia a Nt/ LO 6 wnaiogadN3 a NV LOi'Od 0 49d LOi'OdO wneicaired aNy LOi'OdO '� • Formation Logs • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
